San Diego Gas & Electric 10-K 26 Feb 16 2015 FY Annual report Financial data

DOCUMENT AND ENTITY INFORMATION

DOCUMENT AND ENTITY INFORMATION - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Feb. 19, 2016	Jun. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	Sempra Energy
Entity Central Index Key	1,032,208
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Well Known Seasoned Issuer	Yes
Entity Filer Category	Large Accelerated Filer
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Common Shares Outstanding		249,215,763
Entity Public Float			$ 24,500
Trading symbol	SRE

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($)		Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents		$ 403,000,000	$ 570,000,000	[1]
Restricted cash		27,000,000	11,000,000	[1]
Trade accounts receivable		1,283,000,000	1,242,000,000	[1]
Other accounts and notes receivable, net		190,000,000	152,000,000	[1]
Due from affiliates, current		6,000,000	38,000,000	[1]
Income taxes receivable		30,000,000	45,000,000	[1]
Deferred income taxes, net current assets		0	305,000,000	[1]
Inventories		298,000,000	396,000,000	[1]
Regulatory balancing accounts - undercollected		307,000,000	746,000,000	[1]
Fixed-price contracts and other derivatives, current assets		80,000,000	93,000,000	[1]
Asset held for sale, power plant		0	293,000,000	[1]
Other current assets		267,000,000	293,000,000	[1]
Total current assets		2,891,000,000	4,184,000,000	[1]
Investments And Other Assets [Abstract]
Restricted cash, noncurrent		20,000,000	29,000,000	[1]
Due from affiliaties, noncurrent		186,000,000	188,000,000	[1]
Regulatory Assets, Noncurrent		3,273,000,000	3,031,000,000	[1]
Nuclear decommissioning trusts		1,063,000,000	1,131,000,000	[1]
Other investments		2,905,000,000	2,848,000,000	[1]
Goodwill		819,000,000	931,000,000	[1]
Other intangible assets		404,000,000	415,000,000	[1]
Assets held in trust		464,000,000	512,000,000	[1]
Insurance receivable for Aliso Canyon costs		325,000,000	0	[1]
Sundry		761,000,000	480,000,000	[1]
Total investments and other assets		10,220,000,000	9,565,000,000	[1]
Property, plant and equipment:
Property, Plant and Equipment, Gross		38,200,000,000	35,407,000,000	[1]
Less accumulated depreciation and amortization		(10,161,000,000)	(9,505,000,000)	[1]
Property, plant and equipment, net		28,039,000,000	25,902,000,000	[1]
Total assets	[2]	41,150,000,000	39,651,000,000	[1]
Current liabilities:
Short-term debt		622,000,000	1,733,000,000	[3]
Accounts payable - trade		1,133,000,000	1,198,000,000	[3]
Accounts payable - other		142,000,000	155,000,000	[3]
Due to affiliaties, current		14,000,000	2,000,000	[3]
Dividends and interest payable		303,000,000	282,000,000	[3]
Accrued compensation and benefits		423,000,000	373,000,000	[3]
Regulatory balancing accounts - overcollected		34,000,000	0	[3]
Current portion of long-term debt		907,000,000	469,000,000	[3]
Fixed-price contracts and other derivatives, current liabilities		56,000,000	55,000,000	[3]
Customer deposits		153,000,000	153,000,000	[3]
Reserve for Aliso Canyon costs		274,000,000	0	[3]
Other current liabilities		551,000,000	649,000,000	[3]
Total current liabilities		4,612,000,000	5,069,000,000	[3]
Long-term debt		13,134,000,000	12,086,000,000	[3]
Deferred Credits and Other Liabilities [Abstract]
Customer advances for construction		149,000,000	144,000,000	[3]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent		1,152,000,000	1,064,000,000	[3]
Deferred income taxes, net noncurrent liabilities		3,157,000,000	3,003,000,000	[3]
Deferred investment tax credits		32,000,000	37,000,000	[3]
Regulatory liabilities arising from removal obligations		2,793,000,000	2,741,000,000	[3]
Asset retirement obligations		2,126,000,000	2,048,000,000	[3]
Fixed-price contracts and other derivatives, noncurrent liabilities		240,000,000	255,000,000	[3]
Deferred credits and other		1,176,000,000	1,104,000,000	[3]
Total deferred credits and other liabilities		10,825,000,000	10,396,000,000	[3]
Equity:
Common stock		2,621,000,000	2,484,000,000	[3]
Retained earnings		9,994,000,000	9,339,000,000	[3]
Accumulated other comprehensive income (loss)	[4]	(806,000,000)	(497,000,000)	[3]
Total shareholders' equity		11,809,000,000	11,326,000,000	[3]
Preferred stock of subsidiaries		20,000,000	20,000,000	[3]
Other noncontrolling interests		750,000,000	754,000,000	[3]
Total equity		12,579,000,000	12,100,000,000	[3]
Total liabilities and equity		41,150,000,000	39,651,000,000	[3]
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents		20,000,000	8,000,000	[5]
Restricted cash		23,000,000	8,000,000
Trade accounts receivable		331,000,000	285,000,000	[5]
Other accounts and notes receivable, net		17,000,000	35,000,000	[5]
Due from affiliates, current		1,000,000	1,000,000	[5]
Inventories		75,000,000	73,000,000	[5]
Regulatory balancing accounts - undercollected		307,000,000	711,000,000	[5]
Regulatory Assets, Current		107,000,000	54,000,000	[5]
Fixed-price contracts and other derivatives, current assets		53,000,000	44,000,000	[5]
Other current assets		70,000,000	125,000,000	[5]
Total current assets		1,004,000,000	1,344,000,000	[5]
Investments And Other Assets [Abstract]
Restricted cash, noncurrent		0	11,000,000
Deferred taxes recoverable in rates		914,000,000	824,000,000	[5]
Regulatory Assets, Noncurrent		977,000,000	1,086,000,000	[5]
Nuclear decommissioning trusts		1,063,000,000	1,131,000,000	[5]
Sundry		301,000,000	246,000,000	[5]
Total investments and other assets		3,255,000,000	3,298,000,000	[5]
Property, plant and equipment:
Property, Plant and Equipment, Gross		16,458,000,000	15,478,000,000	[5]
Less accumulated depreciation and amortization		(4,202,000,000)	(3,860,000,000)	[5]
Property, plant and equipment, net		12,256,000,000	11,618,000,000	[5]
Total assets		16,515,000,000	16,260,000,000	[5]
Current liabilities:
Short-term debt		168,000,000	246,000,000	[5]
Accounts payable - trade		377,000,000	441,000,000	[5]
Due to affiliaties, current		55,000,000	21,000,000	[5]
Income taxes payable		0	30,000,000	[5]
Deferred income taxes, net current liabilities		0	53,000,000	[5]
Dividends and interest payable		39,000,000	40,000,000	[5]
Accrued compensation and benefits		129,000,000	124,000,000	[5]
Accrued franchise fees		66,000,000	71,000,000	[6]
Current portion of long-term debt		50,000,000	365,000,000	[5]
Fixed-price contracts and other derivatives, current liabilities		51,000,000	40,000,000	[5]
Asset Retirement Obligation		99,000,000	120,000,000	[5]
Customer deposits		72,000,000	71,000,000	[5]
Other current liabilities		101,000,000	166,000,000	[5]
Total current liabilities		1,207,000,000	1,788,000,000	[5]
Long-term debt		4,455,000,000	4,283,000,000	[5]
Deferred Credits and Other Liabilities [Abstract]
Customer advances for construction		46,000,000	41,000,000	[5]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent		212,000,000	216,000,000	[5]
Deferred income taxes, net noncurrent liabilities		2,472,000,000	2,121,000,000	[5]
Deferred investment tax credits		19,000,000	22,000,000	[5]
Regulatory liabilities arising from removal obligations		1,629,000,000	1,557,000,000	[5]
Asset retirement obligations		729,000,000	754,000,000	[5]
Fixed-price contracts and other derivatives, noncurrent liabilities		106,000,000	153,000,000	[5]
Deferred credits and other		364,000,000	333,000,000	[5]
Total deferred credits and other liabilities		5,577,000,000	5,197,000,000	[5]
Equity:
Common stock		1,338,000,000	1,338,000,000	[5]
Retained earnings		3,893,000,000	3,606,000,000	[5]
Accumulated other comprehensive income (loss)	[4]	(8,000,000)	(12,000,000)	[5]
Total shareholders' equity		5,223,000,000	4,932,000,000	[5]
Other noncontrolling interests		53,000,000	60,000,000	[5]
Total equity		5,276,000,000	4,992,000,000	[5]
Total liabilities and equity		16,515,000,000	16,260,000,000	[5]
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents		58,000,000	85,000,000	[1]
Trade accounts receivable		635,000,000	586,000,000	[1]
Other accounts and notes receivable, net		99,000,000	51,000,000	[1]
Due from affiliates, current		48,000,000	4,000,000	[1]
Income taxes receivable		0	5,000,000	[1]
Inventories		79,000,000	181,000,000	[1]
Regulatory balancing accounts - undercollected		0	35,000,000	[1]
Regulatory Assets, Current		7,000,000	5,000,000	[1]
Other current assets		40,000,000	36,000,000	[1]
Total current assets		966,000,000	988,000,000	[1]
Investments And Other Assets [Abstract]
Regulatory assets arising from pension obligations		699,000,000	617,000,000	[1]
Regulatory Assets, Noncurrent		636,000,000	472,000,000	[1]
Insurance receivable for Aliso Canyon costs		325,000,000	0	[1]
Sundry		207,000,000	125,000,000	[1]
Total investments and other assets		1,867,000,000	1,214,000,000	[1]
Property, plant and equipment:
Property, Plant and Equipment, Gross		14,171,000,000	12,886,000,000	[1]
Less accumulated depreciation and amortization		(4,900,000,000)	(4,642,000,000)	[1]
Property, plant and equipment, net		9,271,000,000	8,244,000,000	[1]
Total assets		12,104,000,000	10,446,000,000	[1]
Current liabilities:
Short-term debt		0	50,000,000	[1]
Accounts payable - trade		422,000,000	532,000,000	[1]
Accounts payable - other		76,000,000	88,000,000	[1]
Due to affiliaties, current		0	13,000,000	[1]
Income taxes payable		3,000,000	0	[1]
Deferred income taxes, net current liabilities		0	53,000,000	[1]
Accrued compensation and benefits		160,000,000	129,000,000	[1]
Regulatory balancing accounts - overcollected		34,000,000	0	[1]
Current portion of long-term debt		9,000,000	0	[1]
Customer deposits		76,000,000	75,000,000	[1]
Reserve for Aliso Canyon costs		274,000,000	0	[1]
Other current liabilities		184,000,000	149,000,000	[1]
Total current liabilities		1,238,000,000	1,089,000,000	[1]
Long-term debt		2,481,000,000	1,891,000,000	[1]
Deferred Credits and Other Liabilities [Abstract]
Customer advances for construction		103,000,000	102,000,000	[1]
Pension obligation, net of plan assets		716,000,000	633,000,000	[1]
Deferred income taxes, net noncurrent liabilities		1,532,000,000	1,212,000,000	[1]
Deferred investment tax credits		14,000,000	16,000,000	[1]
Regulatory liabilities arising from removal obligations		1,145,000,000	1,167,000,000	[1]
Asset retirement obligations		1,354,000,000	1,255,000,000	[1]
Deferred credits and other		372,000,000	300,000,000	[1]
Total deferred credits and other liabilities		5,236,000,000	4,685,000,000	[1]
Equity:
Preferred stock		22,000,000	22,000,000	[1]
Common stock		866,000,000	866,000,000	[1]
Retained earnings		2,280,000,000	1,911,000,000	[1]
Accumulated other comprehensive income (loss)	[4]	(19,000,000)	(18,000,000)	[1]
Total shareholders' equity		3,149,000,000	2,781,000,000	[1]
Total equity		3,149,000,000	2,781,000,000	[1]
Total liabilities and equity		$ 12,104,000,000	$ 10,446,000,000	[1]
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	December 31, 2014 and 2013 have been adjusted for the retrospective adoption of ASU 2015-03.
[3]	As adjusted for the retrospective adoption of ASU 2015-03.
[4]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
[5]	As adjusted for the retrospective adoption of ASU 2015-03.
[6]	As adjusted for the retrospective adoption of ASU 2015-03.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Property, plant and equipment related to VIE	$ 383	$ 410	[1]
Long-term debt related to VIE	$ 303	$ 312	[1]
Shareholders' equity:
Preferred stock, shares authorized	50,000,000	50,000,000
Preferred stock, shares issued	0	0
Common stock, shares authorized	750,000,000	750,000,000
Common stock, shares outstanding	248,298,080	246,330,884
San Diego Gas and Electric Company [Member]
Property, plant and equipment related to VIE	$ 383	$ 410	[2]
Long-term debt related to VIE	$ 303	$ 312	[2]
Shareholders' equity:
Preferred stock, shares authorized	45,000,000
Common stock, shares authorized	255,000,000	255,000,000
Common stock, shares outstanding	117,000,000	117,000,000
Southern California Gas Company [Member]
Shareholders' equity:
Preferred stock, shares authorized	1,000,000
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares outstanding	91,000,000	91,000,000
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03, as we discuss in Note 2.

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
REVENUES
Utilities		$ 9,254	$ 9,758	$ 9,309
Energy-related businesses		977	1,277	1,248
Total revenues		10,231	11,035	10,557
Utilities [Abstract]
Cost of natural gas		(1,134)	(1,758)	(1,646)
Cost of electric fuel and purchased power		(2,136)	(2,281)	(1,932)
Energy-related businesses [Abstract]
Cost of natural gas, electric fuel and purchased power		(335)	(552)	(435)
Other cost of sales		(148)	(163)	(178)
Sempra Global And Parent [Abstract]
Operation and maintenance		2,895	2,935	2,995
Depreciation and amortization		(1,250)	(1,156)	(1,113)
Plant closure adjustment (loss)		26	(6)	(200)
Franchise fees and other taxes		(423)	(408)	(374)
Gains on sale of equity interests and assets		70	62	114
Equity earnings (losses) before income tax [Abstract]
Equity earnings, before income tax		104	81	31
Other income (expense), net		126	137	140
Interest income		29	22	20
Interest expense		(561)	(554)	(559)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries		1,704	1,524	1,430
Income tax (expense) benefit		(341)	(300)	(366)
Equity earnings, net of income tax		85	38	24
Net income		1,448	1,262	1,088
Earnings attributable to noncontrolling interest		(98)	(100)	(79)
Call premium on preferred stock of subsidiary		0	0	(3)
Preferred dividends of subsidiaries		(1)	(1)	(5)
Earnings		$ 1,349	$ 1,161	$ 1,001
Basic earnings per common share:
Basic earnings per common share		$ 5.43	$ 4.72	$ 4.1
Basic earnings per common share, weighted-average number of shares outstanding (thousands)	[1]	248,249	245,891	243,863
Diluted earnings per common share:
Diluted earnings per common share		$ 5.37	$ 4.63	$ 4.01
Diluted earnings per common share, weighted-average number of shares outstanding (thousands)		250,923	250,655	249,332
San Diego Gas and Electric Company [Member]
Utility operating revenues
Electric		$ 3,719	$ 3,785	$ 3,537
Natural gas		500	544	529
Total utility operating revenues		4,219	4,329	4,066
Utility operating expenses
Utility cost of natural gas		153	208	204
Utility cost of electric fuel and purchased power		1,151	1,309	1,019
Utility operation and maintenance		1,017	1,076	1,157
Utility depreciation and amortization		604	530	494
Utility franchise fees and other taxes		262	241	210
Utility plant closure (adjustment) loss		(26)	6	200
Total utility operating expenses		3,161	3,370	3,284
Utility operating income		1,058	959	782
Equity earnings (losses) before income tax [Abstract]
Other income (expense), net		36	40	40
Interest income		0	0	1
Interest expense		(204)	(202)	(197)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries		890	797	626
Income tax (expense) benefit		(284)	(270)	(191)
Net income		606	527	435
Earnings attributable to noncontrolling interest		(19)	(20)	(24)
Earnings		587	507	411
Call premium on preferred stock		0	0	(3)
Preferred dividend requirements		0	0	(4)
Earnings attributable to common shares		587	507	404
Southern California Gas Company [Member]
Utility operating revenues
Total utility operating revenues		3,489	3,855	3,736
Utility operating expenses
Utility cost of natural gas		921	1,449	1,362
Utility operation and maintenance		1,370	1,321	1,324
Utility depreciation and amortization		461	431	383
Utility franchise fees and other taxes		129	133	128
Total utility operating expenses		2,881	3,334	3,197
Utility operating income		608	521	539
Equity earnings (losses) before income tax [Abstract]
Other income (expense), net		30	20	11
Interest income		4	0	0
Interest expense		(84)	(69)	(69)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries		558	472	481
Income tax (expense) benefit		(138)	(139)	(116)
Net income		420	333	365
Earnings		420	333	365
Preferred dividend requirements		(1)	(1)	(1)
Earnings attributable to common shares		$ 419	$ 332	$ 364
[1]	Includes fully vested restricted stock units held in our Deferred Compensation Plan of 491 in 2015, 212 in 2014 and none in 2013. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net income	$ 1,448	$ 1,262	$ 1,088
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Net of Tax, Total	(334)	(290)	140
Preferred dividends of subsidiaries	(1)	(1)	(5)
San Diego Gas and Electric Company [Member]
Net income	606	527	435
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Net of Tax, Total	10	(1)	19
Southern California Gas Company [Member]
Net income	420	333	365
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Net of Tax, Total	(1)
Before-Tax Amount [Member]
Net income	1,691	1,462	1,375
Comprehensive income, net of income tax
Foreign currency translation adjustments	(260)	(193)	111
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	(80)	(106)	13
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(3)	(20)	47
Other Comprehensive Income (Loss), Net of Tax, Total	(343)	(319)	171
Total comprehensive income	1,348	1,143	1,546
Preferred dividends of subsidiaries	(1)	(1)	(5)
Total comprehensive income, after preferred dividends of subsidiaries	1,347	1,142	1,541
Before-Tax Amount [Member] | San Diego Gas and Electric Company [Member]
Net income	871	777	602
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	7	(5)	3
Other Comprehensive Income (Loss), Net of Tax, Total	7	(5)	3
Total comprehensive income	878	772	605
Before-Tax Amount [Member] | Southern California Gas Company [Member]
Net income	558	472	481
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	1		1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(2)		(2)
Other Comprehensive Income (Loss), Net of Tax, Total	(1)		(1)
Total comprehensive income	557	472	480
Income Tax (Expense) Benefit [Member]
Net income	(341)	(300)	(366)
Comprehensive income, net of income tax
Foreign currency translation adjustments	0	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	33	42	(4)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1	8	(19)
Other Comprehensive Income (Loss), Net of Tax, Total	34	50	(23)
Total comprehensive income	(307)	(250)	(389)
Preferred dividends of subsidiaries	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	(307)	(250)	(389)
Income Tax (Expense) Benefit [Member] | San Diego Gas and Electric Company [Member]
Net income	(284)	(270)	(191)
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(3)	2	(1)
Other Comprehensive Income (Loss), Net of Tax, Total	(3)	2	(1)
Total comprehensive income	(287)	(268)	(192)
Income Tax (Expense) Benefit [Member] | Southern California Gas Company [Member]
Net income	(138)	(139)	(116)
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	(1)		0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1		1
Other Comprehensive Income (Loss), Net of Tax, Total	0		1
Total comprehensive income	(138)	(139)	(115)
Net-Of-Tax Amount [Member]
Net income	1,350	1,162	1,009
Comprehensive income, net of income tax
Foreign currency translation adjustments	(260)	(193)	111
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	(47)	(64)	9
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(2)	(12)	28
Other Comprehensive Income (Loss), Net of Tax, Total	(309)	(269)	148
Total comprehensive income	1,041	893	1,157
Preferred dividends of subsidiaries	(1)	(1)	(5)
Total comprehensive income, after preferred dividends of subsidiaries	1,040	892	1,152
Net-Of-Tax Amount [Member] | San Diego Gas and Electric Company [Member]
Net income	587	507	411
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	4	(3)	2
Other Comprehensive Income (Loss), Net of Tax, Total	4	(3)	2
Total comprehensive income	591	504	413
Net-Of-Tax Amount [Member] | Southern California Gas Company [Member]
Net income	420	333	365
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0		1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(1)		(1)
Other Comprehensive Income (Loss), Net of Tax, Total	(1)		0
Total comprehensive income	419	333	365
Noncontrolling Interests [Domain]
Net income	98	100	79
Comprehensive income, net of income tax
Foreign currency translation adjustments	(30)	(20)	(27)
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	5	(1)	19
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	(25)	(21)	(8)
Total comprehensive income	73	79	71
Preferred dividends of subsidiaries	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	73	79	71
Noncontrolling Interests [Domain] | San Diego Gas and Electric Company [Member]
Net income	19	20	24
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	6	2	17
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	6	2	17
Total comprehensive income	25	22	41
Total Equity [Member]
Net income	1,448	1,262	1,088
Comprehensive income, net of income tax
Foreign currency translation adjustments	(290)	(213)	84
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	(42)	(65)	28
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(2)	(12)	28
Other Comprehensive Income (Loss), Net of Tax, Total	(334)	(290)	140
Total comprehensive income	1,114	972	1,228
Preferred dividends of subsidiaries	(1)	(1)	(5)
Total comprehensive income, after preferred dividends of subsidiaries	1,113	971	1,223
Total Equity [Member] | San Diego Gas and Electric Company [Member]
Net income	606	527	435
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	6	2	17
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	4	(3)	2
Other Comprehensive Income (Loss), Net of Tax, Total	10	(1)	19
Total comprehensive income	$ 616	$ 526	$ 454

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,448		$ 1,262		$ 1,088
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,250		1,156		1,113
Deferred income taxes and investment tax credits	239		146		334
Gains on sale of assets	(70)		(62)		(114)
Loss from plant closure	(26)		6		200
Equity earnings	(189)		(119)		(55)
Fixed-price contracts and other derivatives	(10)		(25)		(21)
Other adjustments to reconcile net income to net cash provided by operating activities	75		108		13
Net change in other working capital components [Abstract]
Net change in accounts and notes receivable	(99)		44		(273)
Net change in income taxes, net	39		62		(38)
Net change in inventories	65		(133)		116
Net change in regulatory balancing accounts	586		(317)		(198)
Net change in regulatory assets and liabilities	(4)		8		1
Net change in other current assets	(18)		(10)		15
Net change in accounts payable	(157)		109		(28)
Net change in reserve for Aliso Canyon costs	274		0		0
Net change in other current liabilities	13		(138)		(215)
Net change in other working capital components	699		(375)		(620)
Insurance receivable for Aliso Canyon costs	(325)		0		0
Changes in other assets	(162)		19		(171)
Changes in other liabilities	(24)		45		17
Net cash provided by (used in) operating activities	2,905		2,161		1,784
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,156)		(3,123)		(2,572)
Expeditures for investments and acquisition of businesses, net of cash acquired	(200)		(240)		(22)
Proceeds from sale of assets	373		149		570
Proceeds from U.S. Treasury grants	0		0		238
Distributions from investments	15		13		152
Proceeds from sales by nuclear decommissioning and other trusts	577		601		695
Purchases of nuclear decommissioning and other trust assets	(531)		(613)		(697)
Increase in restricted cash	(100)		(152)		(356)
Decrease in restricted cash	93		155		329
Advances to unconsolidated affiliates	(31)		(185)		(14)
Decrease (increase) in notes receivable to unconsolidated affiliates, net	74		18		0
Other cash flows from investing activities	1		35		(12)
Net cash provided by (used in) investing activities	(2,885)		(3,342)		(1,689)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(628)		(598)		(606)
Redemptions of preferred stock of subsidiary	0		0		(82)
Preferred dividends paid by subsidiaries	(1)		(1)		(5)
Issuances of common stock	52		56		62
Repurchases of common stock	(74)		(38)		(45)
Issuances of debt (maturities greater than 90 days)	2,992		3,272		2,081
Payments on long-term debt	(1,854)		(2,034)		(1,788)
Proceeds from sale of noncontrolling interest, net of offering costs.	0		0		574
Increase (decrease) in short-term debt, net	(622)		412		256
Purchase of noncontrolling interests	0		(74)		0
Distributions to noncontrolling interests	(73)		(104)		(69)
Excess Tax Benefit From Share Based Compensation Financing Activities	52		0		0
Other cash flows from financing activities	(17)		(37)		(40)
Net cash provided by (used in) financing activities	(173)		854		338
Effect of exchange rate changes on cash and cash equivalents	(14)		(7)		(4)
Increase (decrease) in cash and cash equivalents	(167)		(334)		429
Cash and cash equivalents, beginning of period	570	[1]	904		475
Cash and cash equivalents, end of period	403		570	[1]	904
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	537		536		544
Income tax payments, net of refunds	67		102		120
Acquisition Of Business [Abstract]
Assets acquired	10		0		13
Accrued purchase price	(5)		0		0
Liabilities assumed	(2)		0		(2)
Cash paid	3		0		11
Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization	0		0		512
Accrued capital expenditures	566		433		437
Increase in capital lease obligations for investment in property, plant and equipment	24		60		0
Financing of build-to-suit property	61		61		14
Capital expenditures recoverable by U. S. Treasury grants receivable	0		0		3
Sequestration of U.S. Treasury grants receivable	0		0		(23)
Redemption of industrial development bonds	79		0		0
Common Stock Issued Employee Stock Trust	55		42		0
Dividends declared but not paid	180		166		157
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	606		527		435
Adjustments to reconcile net income to net cash provided by operating activities:
Utility depreciation and amortization	604		530		494
Deferred income taxes and investment tax credits	195		223		171
Adjustment To Utility Loss From Plant Closure	(26)		6		200
Fixed-price contracts and other derivatives	(4)		(6)		(8)
Other adjustments to reconcile net income to net cash provided by operating activities	(16)		(23)		(37)
Net change in other working capital components [Abstract]
Net change in accounts and notes receivable	(10)		(47)		(40)
Net change in due to/from affiliates, net	21		(10)		38
Net change in income taxes, net	0		35		(50)
Net change in inventories	(2)		4		(14)
Net change in regulatory balancing accounts	474		(208)		(140)
Net change in other current assets	(24)		(16)		7
Net change in accounts payable	(28)		(23)		50
Net change in interest payable	(1)		0		4
Net change in other current liabilities	(16)		(104)		(260)
Net change in other working capital components	414		(369)		(405)
Changes in other assets	(122)		191		(150)
Changes in other liabilities	13		18		19
Net cash provided by (used in) operating activities	1,664		1,097		719
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,133)		(1,100)		(978)
Proceeds from sale of assets	0		0		11
Proceeds from sales by nuclear decommissioning trusts	577		601		685
Purchases of nuclear decommissioning trust assets	(526)		(609)		(692)
Increase in restricted cash	(39)		(84)		(81)
Decrease in restricted cash	35		96		82
Other cash flows from investing activities	0		(30)		0
Net cash provided by (used in) investing activities	(1,086)		(1,126)		(973)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(300)		(200)		0
Preferred dividends paid	0		0		(5)
Redemptions of preferred stock of subsidiary	0		0		(82)
Issuances of long-term debt	444		100		450
Payments on long-term debt	(547)		(24)		(199)
Increase (decrease) in short-term debt, net	(131)		187		59
Distributions to noncontrolling interests	(30)		(53)		(26)
Other cash flows from financing activities	(2)		0		(3)
Net cash provided by (used in) financing activities	(566)		10		194
Increase (decrease) in cash and cash equivalents	12		(19)		(60)
Cash and cash equivalents, beginning of period	8	[2]	27		87
Cash and cash equivalents, end of period	20		8	[2]	27
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	199		196		187
Income tax payments, net of refunds	88		(4)		84
Acquisition Of Business [Abstract]
Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization	0		0		512
Accrued capital expenditures	191		217		182
Increase in capital lease obligations for investment in property, plant and equipment	15		60		0
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	420		333		365
Adjustments to reconcile net income to net cash provided by operating activities:
Utility depreciation and amortization	461		431		383
Deferred income taxes and investment tax credits	127		130		117
Other adjustments to reconcile net income to net cash provided by operating activities	(11)		(7)		(5)
Net change in other working capital components [Abstract]
Net change in accounts and notes receivable	(90)		30		(113)
Net change in due to/from affiliates, net	(11)		(1)		(57)
Net change in income taxes, net	8		17		51
Net change in inventories	102		(113)		82
Net change in regulatory balancing accounts	112		(109)		(58)
Net change in other current assets	8		(3)		3
Net change in accounts payable	(143)		156		(54)
Net change in customer deposits	1		0		(1)
Net change in reserve for Aliso Canyon costs	274		0		0
Net change in other current liabilities	45		3		24
Net change in other working capital components	306		(20)		(123)
Insurance receivable for Aliso Canyon costs	(325)		0		0
Changes in other assets	(91)		(131)		(52)
Changes in other liabilities	(7)		29		(4)
Net cash provided by (used in) operating activities	880		765		681
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,352)		(1,104)		(762)
Decrease (increase) in notes receivable to unconsolidated affiliates, net	(50)		0		34
Net cash provided by (used in) investing activities	(1,402)		(1,104)		(728)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(50)		(100)		(50)
Preferred dividends paid	(1)		(1)		(1)
Issuances of long-term debt	599		747		0
Payments on long-term debt	0		(250)		0
Increase (decrease) in short-term debt, net	(50)		8		42
Debt issuance costs	(3)		(7)		0
Net cash provided by (used in) financing activities	495		397		(9)
Increase (decrease) in cash and cash equivalents	(27)		58		(56)
Cash and cash equivalents, beginning of period	85	[1]	27		83
Cash and cash equivalents, end of period	58		85	[1]	27
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	79		62		65
Income tax payments, net of refunds	1		(10)		(52)
Acquisition Of Business [Abstract]
Accrued capital expenditures	$ 189		$ 168		$ 130
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		San Diego Gas and Electric Company [Member]		Southern California Gas Company [Member]		Preferred StockSouthern California Gas Company [Member]	Common Stock	Common StockSan Diego Gas and Electric Company [Member]	Common StockSouthern California Gas Company [Member]	Retained Earnings	Retained EarningsSan Diego Gas and Electric Company [Member]	Retained EarningsSouthern California Gas Company [Member]	Accumulated Other Comprehensive Income (Loss)	Accumulated Other Comprehensive Income (Loss)San Diego Gas and Electric Company [Member]	Accumulated Other Comprehensive Income (Loss)Southern California Gas Company [Member]	Total Shareholders' Equity	Total Shareholders' EquitySan Diego Gas and Electric Company [Member]	Noncontrolling Interests [Domain]	Noncontrolling Interests [Domain]San Diego Gas and Electric Company [Member]
Equity, beginning of period at Dec. 31, 2012	$ 10,683		$ 4,298		$ 2,235		$ 22	$ 2,217	$ 1,338	$ 866	$ 8,441	$ 2,895	$ 1,365	$ (376)	$ (11)	$ (18)	$ 10,282	$ 4,222	$ 401	$ 76
Net income	1,088		435		365						1,009	411	365				1,009	411	79	24
Comprehensive income	140		19											148	2		148	2	(8)	17
Share-based compensation expense	40							40									40
Common stock dividends declared	(615)				(50)						(615)		(50)				(615)
Preferred stock dividends declared			(4)		(1)							(4)	(1)					(4)
Preferred dividends of subsidiaries	(5)										(5)						(5)
Issuance of common stock	62							62									62
Repurchases of common stock	(45)							(45)									(45)
Sale of noncontrolling interests, net of offering costs	574							135									135		439
Distributions to noncontrolling interests	(69)		(26)																(69)	(26)
Call premium on preferred stock of subsidiary	(3)										(3)						(3)
Call premium on preferred stock			(3)									(3)						(3)
Equity, end of period at Dec. 31, 2013	11,850		4,719		2,549		22	2,409	1,338	866	8,827	3,299	1,679	(228)	(9)	(18)	11,008	4,628	842	91
Net income	1,262		527		333						1,162	507	333				1,162	507	100	20
Comprehensive income	(290)		(1)											(269)	(3)		(269)	(3)	(21)	2
Share-based compensation expense	48							48									48
Common stock dividends declared	(649)		(200)		(100)						(649)	(200)	(100)				(649)	(200)
Preferred stock dividends declared					(1)								(1)
Preferred dividends of subsidiaries	(1)										(1)						(1)
Issuance of common stock	97							97									97
Repurchases of common stock	(38)							(38)									(38)
Distributions to noncontrolling interests	(107)		(53)																(107)	(53)
Equity contributed by noncontrolling interests	1																		1
Purchase of noncontrolling interest in subsidiary	(73)							(32)									(32)		(41)
Call premium on preferred stock of subsidiary	0
Call premium on preferred stock			0
Equity, end of period at Dec. 31, 2014	12,100	[1]	4,992	[2]	2,781	[3]	22	2,484	1,338	866	9,339	3,606	1,911	(497)	(12)	(18)	11,326	4,932	774	60
Net income	1,448		606		420						1,350	587	420				1,350	587	98	19
Comprehensive income	(334)		10		(1)									(309)	4	(1)	(309)	4	(25)	6
Share-based compensation expense	52							52									52
Common stock dividends declared	(694)		(300)		(50)						(694)	(300)	(50)				(694)	(300)
Preferred stock dividends declared					(1)								(1)
Preferred dividends of subsidiaries	(1)										(1)						(1)
Issuance of common stock	107							107									107
Repurchases of common stock	(74)							(74)									(74)
Tax benefit related to share-based compensation	52							52									52
Distributions to noncontrolling interests	(80)		(32)																(80)	(32)
Equity contributed by noncontrolling interests	3																		3
Call premium on preferred stock of subsidiary	0
Call premium on preferred stock			0
Equity, end of period at Dec. 31, 2015	$ 12,579		$ 5,276		$ 3,149		$ 22	$ 2,621	$ 1,338	$ 866	$ 9,994	$ 3,893	$ 2,280	$ (806)	$ (8)	$ (19)	$ 11,809	$ 5,223	$ 770	$ 53
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	As adjusted for the retrospective adoption of ASU 2015-03.

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Significant Accounting Policies And Other Financial Data	SEMPRA ENERGY AND SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS NOTE 1. SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Energy Sempra Energy’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based Fortune 500 energy-services holding company, and its consolidated subsidiaries and variable interest entities (VIEs). Sempra Energy’s principal operating units are San Diego Gas & Electric Company (SDG & E) and Southern C alifornia Gas Company ( SoCalGas ), which are separate, reportable segments; Sempra International, which includes our Sempra South American Utilities and Sempra Mexico reportable segments; and Sempra U.S. Gas & Power, which includes our Sempra Renewables and Sempra Natural Gas reportable segments. We provide descriptions of each of our segments in Note 16. We refer to SDG & E and SoCalGas collectively as the California Util ities, which do not include the utilities in our Sempra International and Sempra U.S. Gas & Power operating unit s . Sempra Global is the holding company for most of our subsidiaries that are not subject to California utility regulation. All references in the s e Notes to “ Sempra International,” “ Sempra U.S. Gas & Power” and the ir respective repor table segments are not intend ed to refer to any legal entity with the same or similar name. Our Sempra Mexico segment includes the operating companies of our subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. ( IEnova ), as well as certain holding c ompanies and risk management activity. We discuss IEnova below under “ Noncontrolling Interests – Sale of Noncontrolling Interests.” Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to ex ercise significant influence, but not control. We discuss our investments in unconsolidated entities in Notes 3, 4 and 10. SDG & E SDG&E’s Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary benefici ary, as we discuss below under “Variable Interest Entities . ” SDG & E ’ s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy. SoCalGas SoCalGas ’ Consolidated Financial Statements include its accounts and the de minimis accounts of inactive subsidiaries. SoCalGas ’ common stock is w holly owned by Pacific Enterprises (PE) , which is a wholly owned subsidiary of Sempra Energy. BASIS OF PRESENTATION Th is is a combined report of Sempra Energy, SDG & E and SoCalGas . We provide separate information for SDG & E and SoCalGas as required. References in this report to “ we, ” “ our ” and “ Sempra Energy Consolidated ” are to Sempra Energy and its consolidated entities, unless otherwise indicated by the context. We have eliminated intercompany accounts and transactions within the consolidated financial statements of each reporting entity. Regulated Operations Sempra South American Utilities has controlling interests in tw o electric distribution utilities in South America, Chilquinta Energía S.A. ( Chilquinta Energía ) in Chile and Luz del Sur S.A.A. (Luz del Sur) in Peru and their subsidiaries. Sempra Natural Gas owns Mobile Gas Service Corporation (Mobile Gas) in southwest Alabama and Willmut Gas Company ( Willmut Gas) in Mississippi, and Sempra Mexico owns Ecogas México, S. de R.L. de C.V. ( Ecogas ) in northern Mexico, all natural gas distribution utilities. The California Utilities, Mobile Gas, Willmut Gas, and Ecogas prepar e their financial statements in accordance with the provisions of accounting principles generally accepted in the United States of America (U.S. GAAP) governing rate-regulated operations, as we discuss below under “Regulatory Matters.” We discuss revenue r ecognition at our utilities in “Revenues – Utilities” below. Pipeline projects currently under construction by IEnova that are both regulated by the Comisión Reguladora de Energía (or CRE, the Energy Regulatory Commission) and meet the regulatory accounting requirements of U.S. GAAP record the impact of allowance for funds used during construction (AFUDC) related to equity. We discuss AFUDC below. Use of Estimates in the Preparation of the Financial Statements We have prepare d our Consolidated F inancial S tatem ents in conformity with U.S. GAAP. T his requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are re asonable, actual amounts ultimately may differ significantly from those estimates. Subsequent Events We evaluated events and transactions that occurred after December 31, 2015 through the date the financial statements were issued, and in the opinion of man agement, the accompanying statements reflect all adjustments and disclosures necessary for a fair presentation. REGULATORY MATTERS Effects of Regulation The accounting policies of the California Utilities conform with U.S. GAAP for rate- regulated enterprises and reflect the policies of the California Public Utilities Commission (CPUC) and the Federal Energy Regulatory Commission (FERC). The California Utilities prepare their financial statements in accordance with U.S. GAAP provisions governing rate- regulated operations. Under these provisions, a regulated utility records regulatory asset s, which are generally costs th at would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover th ose asset s from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regula tory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, gen erally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future ra tes. In addition, the California Utilities record regulatory liabilities when the CPUC or the FERC requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery requires significant judgment by management and may include, but is not limited to, consideration of: the nature of the event giving rise to the assessment; existing statutes and regulatory code; legal precedents ; regula tory principles and analogous regulatory actions; testimony presented in regulatory hearings; proposed regulatory decisions; final regulatory orders; a commission-authorized mechanism established for the accumulation of costs; status of applications for re hearings or state court appeals; specific approval from a commission; and historical experience. Mobile Gas , Willmut Gas and Ecogas also apply U.S. GAAP for rate- regulated utilities to their operations , including the same evaluation of probability of recov ery of regulatory assets described above . We provide information concerning regulatory assets and liabilities below in “ Regulatory Balancing Accounts ” and “ Regulatory Asset s and Liabilities” and in Notes 13 and 14. Regulatory Balancing Accounts The following table summarizes our regulatory balancing accounts at December 31. SUMMARY OF REGULATORY BALANCING ACCOUNTS AT DECEMBER 31 (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2015 2014 2015 2014 2015 2014 Current: Overcollected $ (1,200) $ (1,730) $ (756) $ (1,195) $ (444) $ (535) Undercollected 1,473 2,476 1,063 1,906 410 570 Net current receivable (payable)(1) 273 746 307 711 (34) 35 Noncurrent: Undercollected(2) 215 173 ― ― 215 173 Total net receivable $ 488 $ 919 $ 307 $ 711 $ 181 $ 208 (1) At December 31, 2015, the net receivable at SDG&E and the net payable at SoCalGas are shown separately on Sempra Energy's Consolidated Balance Sheet. (2) Long-term undercollected balance is included in Regulatory Assets (long-term) on Sempra Energy's Consolidated Balance Sheets and Other Regulatory Assets (long-term) on SoCalGas' Consolidated Balance Sheets. Over- and under collected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, primarily commodity costs. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. Balancing account treatment eliminates the impact on earnings from variances in the covered costs from authorized amounts. Absent balancing account treatment, variations in the cost of fuel supply and c ertain operating and maintenance costs from amounts approved by the CPUC would increase volatility in utility earnings. We provide additional information about regulatory matters in Notes 13, 14 and 15 . Regulatory Assets and Liabilities We show the detail s of regulatory assets and liabilities in the following table, and discuss each of them separately below. REGULATORY ASSETS (LIABILITIES) AT DECEMBER 31 (Dollars in millions) 2015 2014 SDG&E: Fixed-price contracts and other derivatives $ 99 $ 76 Costs related to SONGS plant closure(1) 257 308 Costs related to wildfire litigation 362 373 Deferred taxes recoverable in rates 914 824 Pension and other postretirement benefit plan obligations 180 171 Removal obligations(2) (1,629) (1,557) Unamortized loss on reacquired debt 12 12 Environmental costs 16 27 Legacy meters(1) 32 47 Sunrise Powerlink fire mitigation 117 116 Other 9 10 Total SDG&E 369 407 SoCalGas: Pension and other postretirement benefit plan obligations 629 613 Employee benefit costs 51 52 Removal obligations(2) (1,145) (1,167) Deferred taxes recoverable in rates 330 195 Unamortized loss on reacquired debt 11 12 Environmental costs 22 22 Workers’ compensation 13 23 Total SoCalGas (89) (250) Other Sempra Energy: Sempra Natural Gas (7) (17) Sempra Mexico 33 23 Total Other Sempra Energy 26 6 Total Sempra Energy Consolidated $ 306 $ 163 (1) Regulatory assets earning a rate of return. (2) Represents cumulative amounts collected in rates for future nonlegal asset removal costs. NET REGULATORY ASSETS (LIABILITIES) AS PRESENTED ON THE CONSOLIDATED BALANCE SHEETS AT DECEMBER 31 (Dollars in millions) 2015 2014 Sempra Sempra Energy Energy Consolidated SDG&E SoCalGas Consolidated SDG&E SoCalGas Current regulatory assets(1) $ 115 $ 107 $ 7 $ 59 $ 54 $ 5 Noncurrent regulatory assets(2) 3,058 1,891 1,120 2,858 1,910 916 Current regulatory liabilities(3) (2) ― ― (7) ― ― Noncurrent regulatory liabilities(4) (2,865) (1,629) (1,216) (2,747) (1,557) (1,171) Total $ 306 $ 369 $ (89) $ 163 $ 407 $ (250) (1) At Sempra Energy Consolidated, included in Other Current Assets. (2) Excludes long-term undercollected balancing accounts at December 31, 2015 and 2014 of $215 million and $173 million, respectively, recorded at Sempra Energy Consolidated as Regulatory Assets (long-term) and at SoCalGas as Other Regulatory Assets (long-term). (3) Included in Other Current Liabilities. (4) At December 31, 2015 and 2014, $72 million and $6 million, respectively, at Sempra Energy Consolidated and $71 million and $4 million, respectively, at SoCalGas are included in Deferred Credits and Other. In the tables above: Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. Regulatory assets arising from the San Onofre Nuclear Generating Station (SONGS) pla nt closure are associated with SDG&E’s investment in SONGS as of the plant closure date and the cost of operations since Units 2 and 3 were taken offline, as we discuss further in Note 13. Regulatory assets arising from costs related to wildfire litigation are costs in excess of liability insurance coverage and amounts recovered from third parties, as we discuss in Note 14 under “SDG&E Matters – Wildfire Claims Cost Recovery ” and Note 15 under “ S DG&E – 2007 Wildfire Litigation.” Defer red taxes recoverable in rates are base d on current regulatory ratemaking and income tax laws. SDG & E , S oCalGas and Sempra Mexico expect to recover n et regulatory assets related to deferred income taxes over the lives of the assets that give rise to the accumulated deferred income tax liabilitie s . Regulatory assets include certain income tax benefits associated with flow-through repair allowance deductions, which we discuss further in “Joint Matters – CPUC General Rate Case (GRC) – 2016 General Rate Case (2016 GRC)” in Note 14. Regulatory assets /liabilities related to pension and other postre tirement benefit obligations are offset by corresponding liabilities /assets and are being recovered in rates as the plans are funded. Regulatory assets related to unamortized losses on reacquired debt are recovered over the remaining amortization periods o f the losses on reacquired d ebt. These periods range from 2 years to 12 years for SDG & E and from 6 years to 10 years for SoCalGas . Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end o f the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. The regulatory asset related to the legacy meters removed from service and rep laced under the Smart Meter Program is their undepreciated value. SDG & E is recovering this asset over a remaining 2-year period in rate base . T he regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 54-year period. We discuss the trust further in Note 15. The regulatory asset related to workers’ compensation represents accrued costs for future claims that will be recovered from customers in future rates as expenditures are made . Amortization expense on regulatory assets for the years ended December 31, 2015, 2014 and 2013 was $62 million, $20 million and $28 million, respectively, at Sempra Energy Consolidated, $60 million, $18 million and $26 million, respectively, at SDG&E, and $2 million in each y ear at SoCalGas . FAIR VALUE MEASUREMENTS We apply recurring fair value measurements to certain assets and liabilities, primarily nuclear decommissioning and benefit plan trust assets and derivatives. “F air 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 (exit price). A fair value measurement reflect s the assumptions market participants would us e in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an is suer ’ s credit standing when measuring its liabilities at fair value. We establish a f air value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for iden tical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Quoted prices are available in active markets for identical asset s or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily co nsist of listed e quities, U.S. government treasury securities and exchange-traded derivatives . Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporti ng date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: quoted forward prices for commodities tim e value current market and contractual prices for the underlying instruments volatility factors other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be de rived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the N uclear Decommissioning Trusts and in our pension and postretirement benefit plans, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter (OTC) forwards and options. Level 3 – Pricing inputs include significant inputs th at are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management ’ s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instrument s relate to congestion revenue rights (CRRs) and fixed-price electricity positions at SDG&E. CASH AND CASH EQUIVALENTS Cash equivalents are highly liquid investments with maturities of three months or less at the date of purchase. RESTRICTED CASH Restricted cash at Sempra Energy, including amounts at SDG&E discussed below, was $ 47 million and $40 million at December 31, 2015 and 2014, respectively. Of this, $27 million and $11 million was classified as current and $20 million and $29 million was classified as noncurrent at December 31, 2015 and 2014, respectively. SDG&E had $ 23 million and $19 million of restricted cash at December 31, 2015 and 2014, respectively, which represents funds held by a trustee for Otay Mesa VIE (see “Variable Interest Entities – SDG&E – Otay Mesa VIE” below) to pay certain operating costs. In 2015, all restricted cash was classified as current. In 2014, $8 million of restricted cash was classified as current and $11 million as noncurrent. Sempr a Mexico had restricted cash of $20 million and $18 million classified as noncurrent at December 31, 2015 and 2014, respectively, representing funds to pay for rights of way, license fees, permits, topographic surveys and other costs pursuant to trust agre ements related to a pipeline project. Sempra Renewables had restricted cash of $4 million and $3 million classified as current at December 31, 2015 and 2014, respectively, primarily representing funds held in accordance with debt agreements at Copper Mount ain Solar 1. COLLECTION ALLOWANCES We record allowances for the collection of trade and other accounts and notes receivable, which include allowances for doubtful customer accounts and for other receivables. We show t he changes in these allowances in the table below: COLLECTION ALLOWANCES (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Allowances for collection of receivables at January 1 $ 34 $ 29 $ 31 Provisions for uncollectible accounts 20 25 16 Write-offs of uncollectible accounts (22) (20) (18) Allowances for collection of receivables at December 31 $ 32 $ 34 $ 29 SDG&E: Allowances for collection of receivables at January 1 $ 7 $ 5 $ 6 Provisions for uncollectible accounts 7 7 4 Write-offs of uncollectible accounts (5) (5) (5) Allowances for collection of receivables at December 31 $ 9 $ 7 $ 5 SoCalGas: Allowances for collection of receivables at January 1 $ 17 $ 12 $ 14 Provisions for uncollectible accounts 11 15 7 Write-offs of uncollectible accounts (11) (10) (9) Allowances for collection of receivables at December 31 $ 17 $ 17 $ 12 We evalu ate accounts receivable collecta bility using a combination of factors, including past due status based on contractual terms, trends in write-offs, the age of the receivable, counterparty creditworthiness , economic conditions and specific events, such as bankruptcies. Adjustments to the allowance for doubtful accounts are made when necessary based on the results of analysis, the aging of receivables, and histo rical and industry trends. We write off accounts receivable in the period in which we deem the r eceivable to be uncollectible. We record recoveries of accounts receivable previously written off when it is known that they will be received. INVENTORIES The California Utilities value natural gas inventory by the last-in first-out (LIFO) method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. Materials and supplies at the California Utilities are generally valued at the lower of average cost or net realizable value . Sempra South American Utilities, Sempra Mexico and Sempra Natural Gas value natural gas inventory and materials and supplies at the lower of average cost or net realizable value . Sempra Mexico and Sempra Natural Gas value liquefied natural gas (LNG) inventory by the first-in first-out method. The components of inventories by segment are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Natural gas LNG Materials and supplies Total 2015 2014 2015 2014 2015 2014 2015 2014 SDG&E $ 6 $ 8 $ ― $ ― $ 69 $ 65 $ 75 $ 73 SoCalGas 49 (1) 155 ― ― 30 26 79 (1) 181 Sempra South American Utilities ― ― ― ― 30 33 30 33 Sempra Mexico ― ― 3 9 10 9 13 18 Sempra Renewables ― ― ― ― 3 2 3 2 Sempra Natural Gas 94 83 3 5 1 1 98 89 Sempra Energy Consolidated $ 149 $ 246 $ 6 $ 14 $ 143 $ 136 $ 298 $ 396 (1) As of December 31, 2015, SoCalGas recorded an estimated inventory loss related to the Aliso Canyon natural gas leak of $11 million, included in Insurance Receivable for Aliso Canyon Costs on Sempra Energy's and SoCalGas' Consolidated Balance Sheets. See additional discussion about the Aliso Canyon natural gas storage facility leak in Note 15. U.S. TREASURY GRANTS At December 31, 2012, we had receivables for U.S. Treasury grants based on eligible costs at certain of our renewable generating facilities. During the first quarter of 2013, the federal government imposed automatic federal budget cuts, known as “sequestration,” as required by The Budget Control Act of 2011. As a result, we recorded a reduction to our grants receivable of $23 million and a reve rsal of income tax benefit of $5 million during the first quarter of 2013. Later in 2013, we received $238 mi llion in cash for the remaining grant s receivable . INCOME TAXES Income tax expense includes current and deferred income taxes from operations during the year. W e record deferred income taxes for temporary differences between the book and the tax ba sis of assets and liabilities. Investment tax credits from prior years are amortized to income by the California Utilities over the estimated service lives of the properties as required by the CPUC. At our other businesses, we reduce the book basis of the related asset by the amount of investment tax credit earned. At Sempra Renewables, production tax credits are recognized in income tax expense as earned. The California Utilities and Sempra Mexico r ecognize regulatory assets to offset deferred tax liabilities if it is probabl e that the amounts will be recovered from customers; and regulatory liabilities to offset deferred tax assets if it is probable that the amount s will be returned to customers. Except for the current year Peruvian earnings for which we have accrued U.S. in come tax, w e currently do not record deferred income taxes for basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries and non-U.S. joint ventures because the related cumulative undistributed earnings are in definitely reinvested . When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a “more likely than not” chance of being sustained (based on the position’s technic al merits) upon challenge by the respective authorities. The term “more likely than not” means a likelihood of more than 50 percent. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the “more likely than not” criterion at the largest amount of tax benefit that is greater than 50 percent likely of being realized upon its effective resolution. Unrecognized tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our effective tax rate . We provide additional informat ion about income taxes in Note 6 . GREENHOUSE GAS (GHG) ALLOWANCES The California Utilities, Sempra Mexico and Sempra Natural Gas are required by California Assembly Bill 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas transportation . We record GHG allowances at the lower of weighted average cost or market, and include them in Other Current Assets and Sundry on the Consolidated Balance Sheets based on the dates that they are required to be surrendered. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. We include the obligation in Other Cu rrent Liabilities and Deferred Credits and Other on the Consolidated Balance Sheets based on the dates that the allowances will be surrendered. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. The California U tilities balance costs and revenues associated with the GHG program through Regulatory Balancing Accounts on the Consolidated Balance Sheets. RENEWABLE ENERGY CERTIFICATES Renewable e nergy certificates (RECs ) represent property rights established by governmental agencies for the environmental, social, and other nonpower qualities of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable power purchase agreements, internal generation or separate purchases in the market to comply with renewable portfolio standards established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with renewa ble portfolio standards . The cost of RECs at SDG&E is recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Consolidated Statements of Operation s . PROPERTY , PLANT AND EQUIPMENT Property, plant and equipment primarily represents the buildings, equipment and oth er facilities used by the California Utilities to provide natural gas and electric utility se rvices, and by Sempra International and Sempra U.S. Gas & Power in their operations, including construction work in progress at these operating units. Property, plant and equipment also includes lease improvements and other equipment at Parent and Other, as well as property acquired under a build-to-su it lease, which we discuss further in Note 15. Our plant costs include labor materials and contract services expenditures for replacement parts incurred during a major maintenance outage of a generating plant In addition, the cost of utility plant at our r ate-regulated businesses and non-utility regulated projects that meet the regulatory accounting requirements of U.S. GAAP at Sempra Mexico and Sempra Natural Gas includes AFUDC. We discuss AFUDC below. The cost of non-utility plant includes capitalized int erest. Maintenance c osts are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation. We discuss assets pledged as security for loans in Note 5. PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) Property, plant Depreciation rates for and equipment at years ended December 31, December 31, 2015 2014 2015 2014 2013 SDG&E: Natural gas operations $ 1,642 $ 1,535 2.52 % 2.72 % 2.35 % Electric distribution 6,151 5,795 3.79 3.79 3.36 Electric transmission(1) 4,870 4,525 2.62 2.59 2.58 Electric generation(2) 1,891 1,862 3.89 3.86 3.76 Other electric(3) 981 851 5.73 7.09 7.58 Construction work in progress(1) 923 910 NA NA NA Total SDG&E 16,458 15,478 SoCalGas: Natural gas operations(4) 13,241 12,098 3.83 3.89 3.70 Other non-utility 110 120 3.95 2.88 1.56 Construction work in progress 820 668 NA NA NA Total SoCalGas 14,171 12,886 Estimated Weighted average Other operating units and parent (5) : useful lives useful life Land and land rights 289 290 26 to 55 years(6) 40 Machinery and equipment: Utility electric distribution operations 1,362 1,434 12 to 46 years 43 Generating plants 782 596 5 to 80 years 39 LNG terminals 1,124 1,122 5 to 43 years 43 Pipelines and storage 2,311 2,003 3 to 55 years 45 Other 233 213 1 to 50 years 15 Construction work in progress 1,022 1,053 NA NA Other 448 332 2 to 80 years 35 7,571 7,043 Total Sempra Energy Consolidated $ 38,200 $ 35,407 (1) At December 31, 2015, includes $374 million in electric transmission assets and $25 million in construction work in progress related to SDG&E's 91-percent interest in the Southwest Powerlink (SWPL) transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures. (2) Includes capital lease assets of $258 million and $243 million at December 31, 2015 and 2014, respectively, primarily related to variable interest entities of which SDG&E is not the primary beneficiary. (3) Includes capital lease assets of $20 million and $19 million at December 31, 2015 and 2014, respectively. (4) Includes capital lease assets of $30 million and $27 million at December 31, 2015 and 2014, respectively. (5) The December 31, 2015 balances include $142 million, $204 million and $28 million and the December 31, 2014 balances include $150 million, $191 million and $24 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively. (6) Estimated useful lives are for land rights. Depreciation expense is based on the straight-line method over the useful lives of the assets or, for the California Utilities, a shorter period prescribed by the CPUC. Depreciation expense is computed using the stra ight-line method over the asset’ s estimated original composite useful life , the CPUC-prescribed period or the remaining term of the s ite leases, whichever is shortest . Depreciation expense on property, plant and equipment for Sempra Energy for the years ended December 31, 2015, 2014 and 2013 was $1,178 million, $1,126 mil lion and $1,075 million, respectively . Depreciation expense on property, plant and equipment for SDG&E for the years ended December 31, 201 5 , 201 4 and 201 3 was $ 544 million, $ 512 million and $ 468 million, respectively. Depreciation expense on property, plant and equipment for SoCalGas for the years ended December 31, 201 5, 2014 and 2013 was $459 million, $429 million and $381 million, respectively . A ccumulated depreciation on our Consolidated Balance Sheets is as follows: ACCUMULATED DEPRECIATION (Dollars in millions) December 31, 2015 2014 SDG&E: Accumulated depreciation: Electric(1) $ 3,512 $ 3,192 Natural gas 690 668 Total SDG&E 4,202 3,860 SoCalGas: Accumulated depreciation of natural gas uti

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
New Accounting Standards	NOTE 2. NEW ACCOUNTING STANDARDS We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures. SEMPRA ENERGY, SDG&E AND SOCALGAS Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers” (ASU 2014-09) and ASU 2015-14, “Revenue from Contracts with Customers: Deferral of the Effective Date” (ASU 2015-14): ASU 2014-09 provides accounti ng guidance for revenue from contracts with customers and affects all entities that enter into contracts to provide goods or services to the ir customers. The guidance also provides a model for the measurement and recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full re trospective approach for all periods presented in the period of adoption or a modified retrospe ctive approach. ASU 2015-14 defers the effective date of ASU 2014-09 by one year for all entities and permits early adoption on a limited basis. For public enti ties, ASU 2014-09 is effective for fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We are currently evaluating t he effect of the standard on our ongoing financial reporting and have not yet selected the year in which we will adopt the sta ndard or our transition method. ASU 2015-03, “Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Co sts” (ASU 2015-03) and ASU 2015-15, “Interest – Imputation of Interest: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements” (ASU 2015-15) : ASU 2015-03 provides guidance on the financial statement pres entation of debt issuance costs and requires an entity to present debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related long-term debt liability. This guidance must be applied using a full retrospective appr oach for all periods presented in the period of adoption. We retrospectively adopted ASU 2015-03 during ou r annual reporting period ended December 31, 2015, and the adoption did not affect our results of operations or cash flows. The Sempra Energy, SDG&E and SoCalGas Consolidated Balance Sheets at December 31, 2014 reflect the reclassification of $81 million, $36 million, and $15 million, respectively, from Sundry to Long-Term Debt. We provide information about our long-term debt and related debt issuance costs in Note 5 . ASU 2015-15 clarifies ASU 2015-03 to provide additional guidance related to line-of-credit arrangements and states that the Securities and Exchange Commission staff would not object to an entity continuing to defer and present costs relate d to line-of-credit arrangements as an asset and subsequently amortizing the deferred costs ratably over the term of the line-of-credit arrangements, regardless of whether there are any outstanding borrowings on the line-of-credit arrangements. We adopted ASU 2015-15 for our annual reporting peri od ended December 31, 2015 and continue to include deferred costs related to our line-of-credit arrangements that are the subject of ASU 2015-15 in Sundry on the Sempra Energy, SDG&E and SoCalGas Consolidated Balanc e Sheets . ASU 2015-17, “Income Taxes – Balance Sheet Classification of Deferred Taxes” (ASU 2015-17): ASU 2015-17 simplifies the financial statement presentation of deferred tax assets and liabilities and requires an entity to present deferred tax asse ts and liabilities as noncurrent on the balance sheet. This guidance may be applied prospectively or retrospectively. We adopted ASU 2015-17 on a prospective basis for ou r annual reporting period ended December 31, 2015, and the adoption did not affect ou r result s of operations or cash flows. Prior Consolidated Balance Sheets of Sempra Energy, SDG&E and SoCalGas wer e not retrospectively adjusted. We discuss deferred tax assets and liabilities in Note 6. ASU 2016-01, “Recognition and Measurement of Financia l Assets and Financial Liabilities” (ASU 2016-01): ASU 2016-01 primarily affects the a ccounting for equity investments (except those accounted for under the equity method of accounting) , financial liabilities under the fair value option, and the presentati on and disclosure requirements for financial instruments. In addition, it clarifie s guidance related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. Upon ado ption, entities must record a cumulative-effect adjustment to the balance sheet as of the beginning of the first reporting period in which the standard is adopted. The guidance on equity securities without readily determinable fair value will be applied pr ospectively to all equity investments that exist as of the date of adoption of the standard. For public entities, ASU 2016-01 is effective for fiscal years beg inning after December 15, 2017. We will adopt ASU 2016-01 on January 1, 2018 as required and do not expect it to materially affect our financial condition, resul ts of operations or cash flows. We will make the required changes to our disclosures upon adoption. ASU 2016-02, “Leases” (ASU 2016-02): ASU 2016-02 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to not recognize leases with a maximum possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP, other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures f or both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and le ssors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes optional practical expedients that may be elected, which would allow entities to c ontinue to account for leases that commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operat ing leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting.

ACQUISTION AND DIVESTITURE ACTI

ACQUISTION AND DIVESTITURE ACTIVITY	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Acquistion and divestiture activity	NOTE 3. ACQUISITION AND DIVESTITURE ACTIVITY We consolidate assets and liabilities acquired as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date. POTENTIAL ACQUISITION Sempra Mexico IEnova and Petróleos Mexicanos (or PEMEX, the Mexican state-owned oil company) are 50-50 partners in the joint venture Gasoductos de Chihuahua ( GdC ). GdC develops and operates energy infrastructure in Mexico. On July 31, 2015, IEnova entered into an agreement to purc hase PEMEX’s 50-percent interest for $1.325 billion (excluding the assumption of approximately $170 million of net debt), which upon closing would increase its interest from 50 percent to 100 percent. The assets involved in the acquisition included three n atural gas pipelines, an ethane pipeline, and a liquid petroleum gas pipeline and associated storage terminal. The transaction excluded the Los Ramones Norte pipeline that is being developed under a separate joint venture with GdC , PEMEX, BlackRock and Fir st Reserve, keeping IEnova’s interest in the project at the current 25 percent. In December 2015, Mexico’s Comisión Federal de Competencia Económica (COFECE or Mexican Competition Commission) objected to the transaction as proposed and specified that, bas ed upon previous antitrust rulings on PEMEX’s indirect ownership of the TDF S. de R.L. de C.V. liquid petroleum gas pipeline and the San Fernando natural gas pipeline, these assets must be offered by PEMEX in a competitive bidding process as a prerequisite for approval of any transaction involving these two assets. COFECE’s decision did not object to IEnova’s acquisition of the assets on a market concentration basis. The parties are in the process of restructuring the transaction so that PEMEX can proceed w ith a bidding process on these two assets in accordance with the COFECE ruling. IEnova will have the right to approve the winning bidder as a new partner. Any restructured transaction will require negotiation of satisfactory terms for the revised transacti on, and will also be subject to IEnova and PEMEX board approvals and satisfactory completion of the Mexican antitrust review, and may require further approvals from Mexican authorities. Acquisitions Sempra Renewables In March 2015, Sempra Renewables inves ted $8 million to acquire a 100-percent interest in the Black Oak Getty Wind project, a 78-MW wind farm under development in Stearns County, Minnesota. The wind farm has a 20-year power purchase agreement with Minnesota Municipal Power Agency that will com mence upon commercial operation in late 2016. In May 2014, Sempra Renewables invested $121 million (as adjusted for financial position at closing) to become a 50-percent partner with Consolidated Edison Development (Con Edison Development) in four fully o perating solar facilities in California. The joint venture includes Con Edison Development’s CED California Holdings, LLC portfolio, which consists of the 50-MW Alpaugh 50, the 20-MW Alpaugh North and the 20-MW White River 1 facilities in Tulare County, an d the 20-MW Corcoran 1 facility in Kings County (collectively, the California solar partnership). The renewable power from all of the projects has been sold under long-term contracts. We account for our investment in the California solar partnership under the equity method. DIVESTITURES Sempra South American Utilities In June 2013, Sempra South American Utilities completed the sale of its 43-percent interest in two Argentine natural gas utility holding companies, Sodigas Pampeana and Sodigas Sur, which we discuss in Note 4. Sempra Renewables In December 2015, Sempra Renewables sold its 100-percent interest in Rosamond Solar, a development project located in Antelope Valley, California for $26 million in cash. Upon completion of the sale that was comprised o f $18 million of net property, plant and equipment, Sempra Renewables recognized a pretax gain of $8 million ($5 million after-tax), which is included in Gain on Sale of Equity Interests and Assets on our Consolidated Statement of Operations. Sempra Natural Gas In February 2013, Sempra Natural Gas sold one 625-MW block of its 1,250-MW Mesquite Power natural gas-fired power plant in Arizona, including a portion related to common plant, for approximately $371 million in cash. The asset was classified as held for sale at December 31, 2012. We recognized a pretax gain on the sale of $74 million ($44 million after-tax), included in Gain on Sale of Equity Interests and Assets on our Consolidated Statement of Operations in 2013. In April 2015, Sempra Natural Gas sold the remaining 625-MW block of the Mesquite Power plant that was classified as held for sale at December 31, 2014, together with a related power sales contract, for net cash proceeds of $347 million. We recognized a pretax gain on the sale of $61 m illion ($36 million after-tax), included in Gain on Sale of Equity Interests and Assets on our Consolidated Statement of Operations in 2015. SALE OF EQUITY INTERESTS AND JOINT VENTURE INVESTMENT In 2014 and 2013, Sempra Energy completed the sale of equity interests in various subsidiaries that were previously wholly owned, as well as the contribution of Cameron LNG, LLC to a joint venture in exchange for an equity interest in the joint venture. The following table summarizes the deconsolidation of those subs idiaries, and we discuss each transaction below. DECONSOLIDATION OF SUBSIDIARIES (Dollars in millions) Years ended December 31, 2014 2013 Proceeds, net of transaction costs(1) $ 152 $ 169 Cash (10) ― Restricted cash (5) ― Other current assets (23) ― Property, plant and equipment, net (1,557) (727) Other assets (65) (102) Accounts payable and accrued expenses 188 ― Due to affiliate 39 ― Long-term debt, including current portion 251 443 Other liabilities 12 50 Accumulated other comprehensive income (7) ― Gain on sale of equity interests(2) (60) (40) (Increase) in equity method investments upon deconsolidation $ (1,085) $ (207) (1) Transaction costs were negligible in 2014 and $6 million in 2013. (2) Included in Gain on Sale of Equity Interests and Assets on our Consolidated Statements of Operations. Sempra Mexico In July 2014, Sempra Mexico completed the sale of a 50-percent interest in the 155-MW first phase of its Energía Sierra Juárez wind project to a wholly owned subsidiary of InterGen N.V. for cash proceeds of $24 million, net of $2 million cash sold. Sempra Mexico recognized a pretax gain on the sale of $19 million ($14 million after-tax). Included in the deconsolidation were net property, plant and equipment of $137 million and long- term debt, including current portion , of $82 million. The gain on sale included a $7 million after-tax gain attributable to the remeasurement of the retained investment to fair value. Our remaining 50-percent interest in Energía Sierra Juárez is accounted f or under the equity method. Sempra Renewables In November 2014, Sempra Renewables formed a joint venture with Con Edison Development, by selling a 50-percent interest in the 75-MW Broken Bow 2 Wind project for $58 million in cash. Included in the deconsolidation were net property, plant and equipment of $151 million and long-term debt, including current portion, of $72 million. Sempra Renewables recognized a pretax gain on the sale of $14 million ($8 million after-tax). In March 2014, Sempra Renewables formed a joint venture with Co n Edison Development, by selling a 50-percent interest in its 250-MW Copper Mountain Solar 3 solar power facility for $66 million in cash, net of $2 million cash sold. Included in the deconsolidation were net property, plant and equipment of $247 million a nd long-term debt, including current portion, of $97 million. Sempra Renewables recognized a pretax gain on the sale of $27 million ($16 million after-tax). In September 2013, Sempra Renewables formed a joint venture with Con Edison Development, by selling a 50-percent interest in its 150-MW Mesquite Solar 1 solar power facility for $103 million in cash. Included in the deconsolidation were net property, plant and equipment of $461 million and long-term debt, including current portion, of $297 million. Sempr a Renewables recognized a pretax gain on the sale of $36 million ($22 million after-tax). In July 2013, Sempra Renewables formed a joint venture with Con Edison Development, by selling a 50-percent interest in its 150-MW Copper Mountain Solar 2 solar powe r facility for $72 million in cash. Included in the deconsolidation were net property, plant and equipment of $266 million and long-term debt, including current portion, of $146 million. Sempra Renewables recognized a pretax gain on the sale of $4 million ( $2 million after-tax). Our remaining 50-percent interests in these investments are accounted for under the equity method. Based on the nature of the underlying assets, these investments are considered in-substance real estate. Therefore, in accordance wit h applicable U.S. GAAP, for each of these investment transactions, the equity method investments were measured at their historical cost and no portion of the gains was attributable to a remeasurement of the retained investments to fair value. Pretax gains from the sale of our interests in these investments are included in Gain on Sale of Equity Interests and Assets on our Consolidated Statements of Operations. Sempra Natural Gas On August 6, 2014, Sempra Natural Gas and its project partners, comprised of affiliates of ENGIE S.A. (formerly GDF SUEZ S.A.), Mitsui & Co., Ltd., and Mitsubishi Corp oration (through a related company jointly established with Nippon Yusen Kabushiki Kaisha), provided their respective final investment decision with regard to the investment in the development, construction and operation of the natural gas liquefaction exp ort facility at the terminal in Hackberry, Louis iana, owned by Cameron LNG, LLC. The Cameron LNG liquefaction project utilizes Cameron LNG , LLC ’s existing facilities, including two marine berths, three LNG storage tanks, and vaporization capability of 1.5 billion cubic feet ( Bcf ) per day. The current liquefaction project is comprised of three liquefaction trains and is being designed to a nameplate capacity of 13. 9 million tonnes per annum ( Mtpa ) of LNG, with an expected export capability of 12 Mtpa of LNG, or approximately 1.7 Bcf per day. Commercial operation of all three trains is expected to commence in 2018, with the first year of full operations in 2019. The effective date of Cameron LNG JV among Sempra Energy and its project partners occurred on Octob er 1, 2014 after satisfaction of various conditions, including receipt of final regulatory approval and satisfaction of conditions precedent to the first disbursement of the project financing. Our equity in Cameron LNG JV was derived from our contribution of Cameron LNG , LLC to the joint venture at its historical carrying value. Included in the deconsolidation was net pr operty, plant and equipment of approximately $ 1.0 billion . The other partners were issued equity interests in Cameron LNG JV in an aggregat e of 49.8 percent. Cameron LNG, LLC thereby ceased to be wholly owned by Sempra Natural Gas, which retained a 50.2 percent interest in Cameron LNG JV. As of the October 1, 2014 effective date, Sempra Natural Gas began to account for its investment in Camer on LNG JV under the equity method. Sempra Energy did not recognize a gain or loss related to the contribution of Cameron LNG , LLC.

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Investments in Unconsolidated Entities	NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. In these cases, our pro rata shares of the entities’ net assets are included in Investments on the Co nsolidated Balance Sheets. We adjust each investment for our share of each investee’s earnings or losses, dividends, and other comprehensive income or loss. We evaluate the carrying value of unconsolidated entities for impairment under the U.S. GAAP provisions for equity method investments . We provide the carrying value of our investments and earnings (losses) on these investments below: EQUITY METHOD AND OTHER INVESTMENT BALANCES (Dollars in millions) December 31, 2015 2014 Sempra South American Utilities: Eletrans(1) $ (12) $ (8) Sempra Mexico: Energía Sierra Juárez(2) 30 25 Gasoductos de Chihuahua(3) 489 409 Sempra Renewables: Wind: Auwahi Wind 44 45 Broken Bow 2 Wind 41 44 Cedar Creek 2 Wind 75 82 Flat Ridge 2 Wind 275 284 Fowler Ridge 2 Wind 46 46 Mehoopany Wind 92 82 Solar: California solar partnership 120 125 Copper Mountain Solar 2 32 61 Copper Mountain Solar 3 44 56 Mesquite Solar 1 86 86 Sempra Natural Gas: Cameron LNG JV(4) 983 1,007 Rockies Express Pipeline LLC(5) 477 340 Parent and other: RBS Sempra Commodities LLP 67 71 Total equity method investments 2,889 2,755 Other(6) 16 93 Total $ 2,905 $ 2,848 (1) Includes losses on forward exchange contracts, which we discuss below. (2) The carrying value of our equity method investment is $12 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014 due to the remeasurement of our retained investment to fair value. (3) The carrying value of our equity method investment is $65 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014 due to equity method goodwill. (4) The carrying value of our equity method investment is $143 million and $94 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, primarily due to guarantees, which we discuss below, and interest capitalized on the investment, as the joint venture has not commenced its planned principal operations. (5) The carrying value of our equity method investment is $357 million and $369 million lower than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, due to an impairment charge recorded in 2012. (6) Other includes Sempra Natural Gas ’ $77 million investment in industrial development bonds at Mississippi Hub at December 31, 2014, which increased by $2 million and was fully redeemed in June 2015. EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2015 2014 2013 Earnings (losses) recorded before income tax: Sempra Renewables: Wind: Auwahi Wind $ 4 $ 4 $ 4 Broken Bow 2 Wind (2) ― ― Cedar Creek 2 Wind (6) (3) (4) Flat Ridge 2 Wind (12) (7) (8) Fowler Ridge 2 Wind 4 2 (3) Mehoopany Wind (1) (1) (2) Solar: California solar partnership 6 6 ― Copper Mountain Solar 2 7 3 ― Copper Mountain Solar 3 8 2 ― Mesquite Solar 1 16 14 1 Sempra Natural Gas: Cameron LNG JV 5 2 ― Rockies Express Pipeline LLC 79 60 47 Parent and other: RBS Sempra Commodities LLP (4) (2) (3) Other ― 1 (1) $ 104 $ 81 $ 31 Earnings (losses) recorded net of income tax(1): Sempra South American Utilities: Sodigas Pampeana and Sodigas Sur $ ― $ ― $ (11) Eletrans (4) (4) (4) Sempra Mexico: Energía Sierra Juárez 6 3 ― Gasoductos de Chihuahua 83 39 39 $ 85 $ 38 $ 24 (1) As the earnings (losses) from these investments are recorded net of income tax, they are presented below the income tax expense line, so as not to impact our effective income tax rate. Our share of the undistributed earnings of equity method investments was $299 million and $187 million at December 31, 2015 and 2014, respectively. The December 31, 2015 and 2014 balances do not include remaining distributions of $67 million and $71 million, respectively, associated with our investment in RBS Sempra Commodities LLP (RBS Sempra Commodities) and expected to be received from the partnership as it is dissolved, as we discuss below. SEMPRA SOUTH AMERICAN UTILITIES Sempra South American Utilities previously owned 43 percent of two Argentine natural gas utility holding companies, Sodigas Pampeana and Sodigas Sur. In December 2006, we decided to sell these investments and actively pursued their sale since that time. In the first quarter of 2013, we recorded a noncash impairment charge of $10 million ($7 million after-tax) to reduce the carrying value of our in vestments to estimated fair value at that time. The net charge is reported in Equity Earnings, Net of Income Tax, on the Consolidated Statement of Operations for the year ended December 31, 2013. In June 2013, we completed the sale of our Argentine investm ents for $13 million in cash and recorded an additional $7 million loss ($4 million after-tax) on the sale, which is also included in Equity Earnings, Net of Income Tax. As a result of the devaluation of the Argentine peso at the end of 2001 and subsequent changes in the value of the peso, Sempra South American Utilities had reduced the carrying value of its investments by a cumulative total of $270 million prior to the sale. These noncash adjustments, based on fluctuations in the value of the Argentine pes o, did not affect earnings, but were recorded in Comprehensive Income and Accumulated Other Comprehensive Income (Loss). As a result of the sale of our investments, this cumulative foreign currency translation adjustment was reclassified to Equity Earnings , Net of Income Tax, where it was substantially offset by the elimination of a $250 million accrued liability established in 2006. In 2013, Chilquinta Energía entered into two 50-percent owned joint ventures, Eletrans S.A. and Eletrans II S.A. (collectivel y, Eletrans ), with Sociedad Austral de Electricidad Sociedad Anónima (SAESA) to construct four transmission lines in Chile. In 2013, Eletrans entered into forward exchange contracts to manage the foreign currency exchange rate risk of the Chilean Unidad de Fomento (CLF) relative to the U.S. dollar, related to certain construction commitments that are denominated in CLF. The forward exchange contracts settle based on anticipated payments to vendors, generally monthly, ending in July 2018. During each of the years ended December 31, 2015, 2014 and 2013, we recorded $4 million of equity losses related to these forward contracts in Equity Earnings, Net of Income Tax, on the Consolidated Statements of Operations. SEMPRA MEXICO Sempra Mexico owns a 50-percent int erest in GdC , a joint venture with PEMEX . The joint venture operates several natural gas pipelines and propane and ethane systems in Mexico and is developing natural gas pipe lines and other energy infrastructure. See Note 3 for discussion regarding Sempra Mexico’s potential acquisition of the remaining 50-percent interest in GdC . In July 2014, Sempra Mexico completed the sale of a 50-percent interest in the 155-MW first phase of its Energía Sierra Juárez wind project to a wholly owned subsidiary of InterGen N.V., which we discuss further in Note 3. SEMPRA RENEWABLES Sempra Renewables has 50-percent interests in wind and solar energy generation facilities in operation or under construction in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Nebraska, Nevada, and Pennsylvania. The generating capacities of the facilities in operation or under construction are contracted under long-term power purchase agreements. These facilities are accounted for under the equity method. SEMPRA NATURAL GAS Rockies Express Sempra Natural Gas owns a 25-percent in terest in Rockies Express, a partnership that operates a natural gas pipeline, REX, that links the Rocky Mountain region to the upper Midwest and the eastern United States. Tallgrass Energy Partners, L.P. (Tallgrass) owns a 50-percent interest and Phillips 66 owns the remaining 25-percent interest. Our investment in Rockies Express is accounted for as an equity method investment. In April 2015, Sempra Natural Gas invested $113 million of cash in Rockies Express to repay project debt that matured in early 20 15. Cameron LNG JV October 1, 2014 was the effective date of the formation of a joint venture partnership among Sempra Energy and three project partners involving Sempra Natural Gas ’ Cameron LNG facility in Louisiana, as we discuss in Note 3. As of October 1, 2014, Sempra Natural Gas began accounting for its investment in Cameron LNG JV under the equity method. During the year ended December 31, 2015, Sempra Natural Gas invested $10 million of cash in Cameron LNG JV and capitalized $49 million of interest r elated to this equity method investment that has not commenced planned principal operations. Cameron LNG JV Financing General. On August 6, 2014, Cameron LNG JV entered into finance documents (collectively, Loan Facility Agreements) for senior secured financing in an initial aggregate principal amount of up to $7.4 billion under three debt facilities provided by the Japan Bank for International Cooperation (JBIC) and 29 international commercial banks, some of which will benefit from insurance coverage provided by Nippon Export and Investment Insurance (NEXI). The Cameron LNG JV Loan Facility Agreements and related finance documents provide senior secured term loa ns with a maturity date of July 15, 2030. The proceeds of the loans will be used for financing the cost of development and construction of the three-train Cameron LNG project. The Loan Facility Agreements and related finance documents contain customary rep resentations and affirmative and negative covenants for project finance facilities of this kind with the lenders of the type participating in the Cameron LNG JV financing. On August 6, 2014, Sempra Energy entered into a completion agreement in favor of HS BC Bank USA, National Association, as security trustee for the benefit of all of Cameron LNG JV ’ s creditors under the Loan Facility Agreements . Pursuant to this completion agreement, Sempra Energy has severally guaranteed 50.2 percent of Cameron LNG JV ’ s s enior debt obligations under the Loan Facility Agreements, or a maximum principal amount of $3.7 billion. Completion guarantees for the remaining 49.8 percent of Cameron LNG JV ’ s senior secured financing have been provided by the other project partners. Th e occurr ence of the effectiveness of the Cameron LNG Holdings joint venture on October 1, 2014, as fu rther described in Note 3 , was a condition precedent to first disbursement of funds under the Loan Facility Agreements. The Sempra Energy completion g uaran tee of 50.2 percent of Cameron LNG JV financing also became effe ctive upon effectiveness of the Ca meron LNG Holdings joint venture . Sempra Energy’s completion agreement and guarantee will terminate upon financial completion of the three-train Cameron LNG p roject, which is subject to satisfaction of certain conditions, including all three trains achieving commercial operations and meeting certain operational performance tests. Financial completion is scheduled for the second half of 2019. Sempra Energy recor ded a liability of $82 million on October 1, 2014 for the fair value of its obligations associated with the Loan Facility Agreements , which constitute guarantees. This liability is being reduced on a straight-line basis over the duration of the guarantees by recognizing equity earnings from Cameron LNG JV, included in Equity Earnings, Before Income Tax. On August 6, 2014, Sempra Energy and the other project partners entered into a transfer restrictions agreement with Soci é t é G é n é ral e , as intercreditor agent for the lenders under the Loan Facility Agreements. Pursuant to the transfer restriction agreement, Sempra Energy agreed to certain restrictions on its ability to dispose of Sempra Energy’s indirect fully diluted economic and beneficial ownership in terests in Cameron LNG JV. These restrictions vary over time. Prior to financial completion of the three-train Cameron LNG project, Sempra Energy must retain 37.65 percent of such interest in Cameron LNG JV. Starting six months after financial completion o f the three-train Cameron LNG project, Sempra Energy must retain at least 10 percent of the indirect fully diluted economic and beneficial ownership interest in Cameron LNG JV. In addition, at all times, a Sempra Energy controlled (but not necessarily wholly owned) subsidiary must directly own 50.2 percent of the membership interests o f the Cameron LNG JV. Interest. The weighted average all-in cost of the loans outstanding under all the Loan Facility Agreements (and based on certain assumptions as to timing of drawdown) is 1.59 percent per annum over LIBOR prior to financial completion of the project and 1.78 percent per annum over LIBOR following financial completion of the project. The Loan Facility Agreements require Cameron LNG JV to hedge 50 perc ent of outstanding borrowings to fix the interest rate, beginning in 2016. The hedges are to remain in place until the debt principal has been amortized by 50 percent. In November 2014, Cameron LNG JV entered into floating-to-fixed interest rate swa ps for approximately $3.7 billion notional amount, resulting in a n effective fixed rate of 3.19 percent . In June 2015, Cameron LNG JV entered into additional floating-to-fixed interest rate swaps for approximately $1.5 billion notional amount, resulting in an eff ective fixed rate of 3.32 percent. Mandatory Prepayments. Cameron LNG JV must make mandatory prepayments of all loans made under the Loan Facility Agreements under certain circumstances, including: upon receipt of certain insurance proceeds and expropria tion compensation; upon receipt of certain performance liquidated damages under Cameron LNG JV’s engineering, procurement and construction contract for the liquefaction terminal; in connection with the loss of its tolling agreements or export permits that result in a reduction of Cameron LNG JV ’s debt service coverage ratios below a specified thresho ld; if it becomes unlawful in any applicable jurisdiction for a lender to fund or maintain its loans; or in connection with any mandatory prepayment of senior notes outstanding (if any). The loans under the NEXI Covered Loan Facility Agreement and the loan s held by JBIC under the JBIC Loan Facility Agreement are subject to certain additional mandatory prepayments that would be triggered if the Japanese sponsors fail to maintain certain ownership interests in Cameron LNG JV , if Cameron LNG JV ’s Japanese toll ing customers do not hold commitments for a certain quantum of nameplate capacity at the liquefaction terminal or if the aggregate annual contracted LNG commitments by Cameron LNG JV ’s tolling customers to Japanese LNG buyers fall below a certain minimum t hreshold under certain circumstances. Events of Default. Cameron LNG JV ’s Loan Facility Agreements and related finance documents also contain events of default customary for such financings, including events of default for: failure to pay principal and int erest on the due date; insolvency of Cameron LNG JV ; abandonment of the project; expropriation; unenforceability or termination of the finance documents; and a failure to achieve financial completion of the project by a financial completion deadline date o f September 30, 2021 (with up to additional 365 days extension beyond such date permitted in cases of force majeure). A delay in construction that results in a failure to achieve financial completion of the project by this financial completion deadline dat e would therefore result in an event of default under Cameron LNG JV ’s financing and a potential demand on Sempra Energy’s guarantee s . Security. To support Cameron LNG JV ’s obligations under the Loan Facility Agreements and related finance documents, Camer on LNG JV has granted security over all of its assets, subject to customary exceptions, and all equity interests in Cameron LNG JV have been pledged to HSBC Bank USA, National Association, as security trustee for the benefit of all Cameron LNG JV ’s credito rs. As a result, an enforcement action by the lenders taken in accordance with the finance documents could result in the exercise of such security interests by the lenders and the loss of ow nership interests in Cameron LNG JV by Sempra Energy and the other project partners. The security trustee under Cameron LNG JV ’s financing can demand that a payment be made by Sempra Energy under its guarantee s of Sempra Energy’s 50.2 percent share of senior debt obligations due and payable either on the date such amounts were due from Cameron LNG JV (taking into account cure periods) in the event of a failure by Cameron LNG JV to pay such senior debt obligation s when they become due or within 10 business days in the event of an acceleration of senior debt obligations under the terms of the finance documents. If an event of default occurs under the Sempra Energy completion agreement, the security trustee can dema nd that Sempra Energy purchase its 50.2 percent share of all then outstanding senior debt obligations within five business days (other than in the case of a bankruptcy default, which is automatic). RBS SEMPRA COMMODITIES RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra Energy and The Royal Bank of Scotland plc (RBS) in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra Energy. We and RBS sold substantially all of the partnership’s businesses and assets in four separate transactions completed in 2010 and 2011. We account for our investment in RBS Sempra Commodities under the equity method, and report miscellaneous costs since the sale of the business in Parent and Other. We recorded $4 million, $2 million and $3 million in pretax equity losses fo r the years ended December 31, 2015, 2014 and 2013, respectively. In April 2011, we and RBS entered into a letter agreement (Letter Agreement) which amended certain provisions of the agreements that formed RBS Sempra Commodities. The Letter Agreement addre sses the wind-down of the partnership and the distribution of the partnership’s remaining assets. In accordance with the Letter Agreement, we received distributions of $50 million in 2013. The investment balance of $67 million at December 31, 2015 reflects remaining distributions expected to be received from the partnership in accordance with the Letter Agreement. The timing and amount of distributions, if any, may be impacted by the matters we discuss related to RBS Sempra Commodities in Note 15 under “Legal Proceedings – Oth er Litigation.” In addition, amounts may be retained by the partnership for an extended period of time to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership. In connection with the Let ter Agreement described above, we also released RBS from its indemnification obligations with respect to items for which J.P. Morgan Chase & Co. (JP Morgan), one of the buyers of the partnership’s businesses, has agreed to indemnify us. SUMMARIZED FINANCIAL INFORMATION We present summarized financial information below, aggregated for all of our equity method investments for the periods in which we were invested in the entity. The amount s below represent the aggregate financial position and results of operations of 100 percent of each of Sempra Energy’s equity method inve stments. SUMMARIZED FINANCIAL INFORMATION (Dollars in millions) Years ended December 31, 2015 2014 2013 Gross revenues $ 1,533 $ 1,296 $ 1,734 Operating expense (845) (749) (1,287) Income from operations 688 547 447 Interest expense (312) (298) (251) Net income/Earnings(1) 440 291 222 At December 31, 2015 2014 Current assets $ 750 $ 865 Noncurrent assets 15,112 13,161 Current liabilities 859 1,131 Noncurrent liabilities 7,862 6,228 (1) Except for Gasoductos de Chihuahua, Energía Sierra Juárez, Eletrans and the Argentine investments, there was no income tax recorded by the entities, as they are primarily domestic partnerships. GUARANTEES Project financing at our solar and wind joint ventures , except Auwahi Wind, requires the jo int venture partners, for each partner’s interest, to return cash to the projects in the event that the projects do not meet certain cash flow criteria or in the event that the projects’ debt service, operation and maintenance, and firm transmission and production tax credits reserve accounts are not maintained at specific thresholds. In some cases, the joint venture partners have provided guarantees to t he lenders in lieu of the projects funding the reserve account requirements. We recorded liabilities for the fair value of certain of our obligations associated with these guarantees and the liabilities are being amortized over their expected lives. The ou tstanding loans at our solar and wind joint ventures are not guaranteed by the partners, but are secured by project assets. At December 31, 2015, we provided guarantees aggregating a maximum of $ 332 million with an associated aggregated carrying value of $ 10 million for guarantees related to project financing. In addition, at December 31, 2015, we provided guarantees to solar and wind farm joint ventures aggregating a maximum of $ 170 million with an associated aggregated carrying value of $ 2 million, prima rily related to purchased-power agreements and engineering, procurement and construction contracts.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Debt and Credit Facilities	NOTE 5 . DEBT AND CREDIT FACILITIES LINES OF CREDIT At December 31, 2015, Sempra Energy Consolidated had an aggregate of $4.2 billion in three primary committed lines of credit for Sempra Energy, Sempra Global and the California Utilities to provide liquidity and to support commercial paper, the major components of which we detail below. Available unused credit on these lines at December 31, 2015 was $3.7 billion. Our foreign operations have additional general purpose credit facilities, aggregating $1 .1 billion at December 31, 2015. Available unused credit on these lines totaled $889 million at December 31, 2015. Sempra Energy Sempra Energy has a $1 billion, five-year syndicate d revolving credit agreement, as amended and restated in October 2015, expiring in October 2020. Citibank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. The amended credit faci lity restates and supersedes Sempra Energy’s $1.067 billion credit agreement that was to expire in 2017. Borrowings bear interest at benchmark rates plus a margin that varies with Sempra Energy’s credit ratings. The facility requires Sempra Energy to maint ain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At December 31, 2015, Sempra Energy was in compliance with this and all other financial covenants under the credi t facility. The facility also provides for issuance of up to $400 million of letters of credit on behalf of Sempra Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. At Decemb er 31, 2015, Sempra Energy had no outstanding borrowings or letters of credit supported by the facility. Sempra Global Sempra Global has a $2.21 billion, five-year syndicated revolving credit agreement, as amended and restated in October 2015, expiring in October 2020. Citibank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. The amended credit facility restates and supersedes Sempra Global’s $2.189 billion credit agreement that w as to expire in 2017. Sempra Energy guarantees Sempra Global’s obligations under the credit facility. Borrowings bear interest at benchmark rates plus a margin that varies with Sempra Energy’s credit ratings. The facility requires Sempra Energy to maintai n a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At December 31, 2015, Sempra Energy was in compliance with this and all other financial covenants under the credit facility. At December 31, 2015, Sempra Global had $335 million of commercial paper outstanding sup ported by the facility and $1.87 billion of available unused credit on the line. California Utilities SDG&E and SoCalGas have a combined $1 billion, five-year syndicated revolving credit agreement, as amended and restated in October 2015, expiring in October 2020. JPMorgan Chase Bank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. Th e agreement permits each utility to individually borrow up to $750 million, subject to a combined limit of $1 billion for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credi t commitment of $250 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. The amended credit facility restates and supersedes the California Utilities’ $877 m illion credit agreement that was to expire in 2017. Borrowings bear interest at benchmark rates plus a margin that varies with the borrowing utility’s credit rating. The agreement requires each utility to maintain a ratio of total indebtedness to total cap italization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At December 31, 2015, the California Utilities were in compliance with this and all other financial covenants under the credit facility. Each utility’s obligations under the agreement are individual obligations, and a default by one utility would not constitute a default by the other utility or preclude borrowings by, or the issuance of letters of credit on behalf of, the other utility. At December 31, 20 15, SDG&E had $168 million of commercial paper outstanding, supported by the facility. SoCalGas had no outstanding borrowings supported by the facility . Available unused credit on the line at December 31, 2015 was $582 million and $750 million at SDG&E and SoCalGas , respectively, subject to the $1 billion maximum combined credit limit. Sempra South American Utilities Sempra South American Utilities has Peruvian Nuevo Sol and Chilean Peso-denominated credit facilities aggregating $544 million U.S. dollar equivalent , expiring b etween 2016 and 2018 . The credit facilities were entered into to finance working capital and for general corporate purposes. The Peruvian facilities require a debt to equity ratio of no more than 170 percent. At December 31, 2015, Peru was in compliance wi th this financial covenant under the credit facilities. At December 31, 2015, Sempra South American Utilities had outstanding borrowings of $154 million and bank guarantees of $10 million against the Peruvian facilities, and $270 million of available unused credit. There were no outstanding borrowings at December 31, 2015 under the $110 million Chilean facility . Sempra Mexico In 2014, IEnova entered into an agreement for a $200 million, U.S. dollar-denominated, three-year corporate revolving credi t facility with Banco Santander, (México), S.A., Institución de Banca Múltiple , Grupo Financiero Santander Mexico. Also in 2014, IEnova entered into an agreement for a $100 million, U.S. dollar-denominated, three-year corporate revolving credit facility wi th Sumitomo Mitsui Banking Corporation. Both revolving credit facilities were entered into to finance working capital and for general corporate purposes. In August 2015, IEnova entered into a $400 million, five-year revolving credit agreement to replace, and repay the $210 million in outstanding borrowings under, the two revolving credit facilities described above. The lenders are Banco Santander (México), S.A., Institución de Banca Múltiple , Grupo Financiero Santander México, The Bank of Tokyo - Mitsubish i UFJ, LTD., The Bank of Nova Scotia and Sumitomo Mitsui Banking Corporation. In December 2015, an amendment to the agreement increased the amount of credit on the line from $400 million to $600 million. At December 31, 2015, IEnova had $91 million of outs tanding borrowings supported by the facility, and available unused credit on the line was $509 million. WEIGHTED AVERAGE INTEREST RATES The weighted average interest rates on the total short-term debt outstanding at Sempra Energy Consolidated were 1.09 percent and 0.70 percent at December 31, 2015 and 2014, respectively. The weighted average interest rate on the total short-term debt at SDG&E was 1.01 percent at December 31, 2015. At December 31, 2014, the weighted average interest rates on total short-term debt at SDG&E and SoCalGas were 0.27 percent and 0.25 percent, respectively. LONG-TERM DEBT The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2015 2014(1) SDG&E First mortgage bonds (secured by plant assets): 5.3% November 15, 2015 $ ― $ 250 Bonds at variable rates (0.68% at December 31, 2015) March 9, 2017 140 ― 1.65% July 1, 2018(2) 161 161 3% August 15, 2021 350 350 1.914% payable 2015 through February 2022 232 ― 3.6% September 1, 2023 450 450 6% June 1, 2026 250 250 5% to 5.25% payable 2015 through December 2027(2) 105 150 5.875% January and February 2034(2) 176 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039(2) 75 75 6% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.5% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.3% April 1, 2042 250 250 3,989 3,912 Other long-term debt (unsecured unless otherwise noted): 5.3% Notes July 1, 2021(2)(3) ― 39 5.5% Notes December 1, 2021(2)(3) ― 60 4.9% Notes March 1, 2023(2)(3) ― 25 5.2925% OMEC LLC loan payable 2013 through April 2019 (secured by OMEC plant assets) 315 325 366-day commercial paper borrowings May 2015, classified as long-term debt (0.40% weighted average at December 31, 2014) ― 100 Capital lease obligations: Purchased-power agreements 243 233 Other 1 1 559 783 4,548 4,695 Current portion of long-term debt (50) (365) Unamortized discount on long-term debt (10) (11) Unamortized long-term debt issuance costs (33) (36) Total SDG&E 4,455 4,283 SoCalGas First mortgage bonds (secured by plant assets): 5.45% April 15, 2018 250 250 1.55% June 15, 2018 250 ― 3.15% September 15, 2024 500 500 3.2% June 15, 2025 350 ― 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 2,500 1,900 Other long-term debt (unsecured): 4.75% Notes May 14, 2016(2) 8 8 5.67% Notes January 18, 2028 5 5 Capital lease obligations 1 1 14 14 2,514 1,914 Current portion of long-term debt (9) ― Unamortized discount on long-term debt (7) (8) Unamortized long-term debt issuance costs (17) (15) Total SoCalGas 2,481 1,891 LONG-TERM DEBT (CONTINUED) (Dollars in millions) December 31, 2015 2014(1) Sempra Energy Other long-term debt (unsecured): 6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating rate swaps effective January 2011 (4.77% at December 31, 2015) $ 750 $ 750 2.3% Notes April 1, 2017 600 600 6.15% Notes June 15, 2018 500 500 9.8% Notes February 15, 2019 500 500 2.4% Notes March 15, 2020 500 ― 2.85% Notes November 15, 2020 400 ― 2.875% Notes October 1, 2022 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 ― 6% Notes October 15, 2039 750 750 Market value adjustments for interest rate swaps, net (2) ― Build-to-suit lease(4) 136 75 Sempra South American Utilities Other long-term debt (unsecured): Chilquinta Energía 4.25% Series B Bonds payable 2014 through October 30, 2030(2) 170 192 Luz del Sur Bank loans 5.05% to 6.7% payable 2016 through December 2018 136 91 Notes at 4.75% to 8.75% payable 2014 through September 2029 292 345 Other bonds at 3.77% to 4.61% payable 2020 through May 2022 8 10 Capital lease 6 ― Sempra Mexico Other long-term debt (unsecured): Notes February 8, 2018 at variable rates (2.66% after floating-to-fixed rate cross-currency swaps effective February 2013) 75 88 6.3% Notes February 2, 2023 (4.12% after cross-currency swap) 227 265 Notes at variable rates (1.28% at December 31, 2014) August 25, 2017(2)(3) ― 51 Sempra Renewables Other long-term debt (secured by project assets): Loan at variable rates (2.24% at December 31, 2015) payable 2012 through December 2028, except for $69 at 4.54% after floating-to-fixed rate swaps effective June 2012(2) 91 97 Sempra Natural Gas First mortgage bonds (Mobile Gas, secured by plant assets): 4.14% September 30, 2021 20 20 5% September 30, 2031 42 42 Other long-term debt (unsecured unless otherwise noted): Notes at 2.87% to 3.51% October 1, 2016(2) 19 19 8.45% Notes payable 2012 through December 2017, secured by parent guarantee 11 16 3.1% Notes December 30, 2018, secured by plant assets(2) 5 5 4.5% Industrial development bonds July 1, 2024, secured by a promissory note(2)(3) ― 77 Industrial development bonds at variable rates (0.05% at December 31, 2014) August 1, 2037, secured by letter of credit(2)(3) ― 55 7,086 6,048 Current portion of long-term debt (848) (104) Unamortized discount on long-term debt (10) (9) Unamortized premium on long-term debt 5 7 Unamortized debt issuance costs (35) (30) Total other Sempra Energy 6,198 5,912 Total Sempra Energy Consolidated $ 13,134 $ 12,086 (1) As adjusted for the retrospective adoption of ASU 2015-03. (2) Callable long-term debt not subject to make-whole provisions. (3) Early redemption in 2015. (4) We discuss this lease in Note 15. MATURITIES OF LONG-TERM DEBT(1) (Dollars in millions) Total Other Sempra Sempra Energy SDG&E SoCalGas Energy Consolidated 2016 $ 46 $ 8 $ 843 $ 897 2017 186 ― 668 854 2018 207 500 662 1,369 2019 320 ― 534 854 2020 36 ― 932 968 Thereafter 3,509 2,005 3,307 8,821 Total $ 4,304 $ 2,513 $ 6,946 $ 13,763 (1) Excludes capital lease obligations, build-to-suit lease and market value adjustments for interest rate swaps. Various long-term obligations totaling $6.8 billion at Sempra Energy at December 31, 2015 are unsecured. This includes unsecured long-term obligations totaling $13 million at SoCalGas . There were no unsecured long-term obligations at SDG&E. CALLABLE LONG-TERM DEBT At the option of Sempra Energy, SDG&E and SoCalGas , certain debt at December 31, 2015 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) Total Other Sempra Sempra Energy SDG&E SoCalGas Energy Consolidated Not subject to make-whole provisions $ 517 $ 8 $ 285 $ 810 Subject to make-whole provisions 3,472 2,505 6,661 12,638 In addition, the OMEC LLC project financing loan discussed in Note 1, with $315 million of outstanding borrowings at December 31, 2015, may be prepaid at the borrowers’ option. FIRST MORTGAGE BONDS The California Utilities issue first mortgage bonds secured by a lien on utility plant. The California Utilities may issue additional first mortgage bonds if in compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma e arnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permi t the issuance, subject to CPUC authorization, of an additional $4.1 billion of first mortgage bonds at SDG&E and $0.8 billion at SoCalGas at December 31, 2015. In March 2015, SDG&E publicly offered and sold $140 million of first mortgage bonds maturing i n 2017 at a variable rate of three-month LIBOR plus 0.20 percent (0.68 percent at December 31, 2015) and $250 million of 1.914-percent amortizing first mortgage bonds maturing in 2022. SDG&E used the proceeds from the offering to repay outstanding commerc ial paper and for other general corporate purposes. In June 2015, SoCalGas publicly offered and sold $250 million of 1.55-percent and $350 million of 3.20-percent first mortgage bonds maturing in 2018 and 2025, respectively. SoCalGas used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. INDUSTRIAL DEVELOPMENT BONDS Sempra Natural Gas To secure an approved exemption from sales and use tax, Sempra Natural Gas had incurred $259 million, out of a ma ximum available $265 million, between the years of 2009 through 2015, of long-term debt related to the construction and equipping of its Mississippi Hub natural gas storage facility. The debt was payable to the Mississippi Business Finance Corporation (MBF C), and we recorded bonds receivable from the MBFC for the same amount. Both the financing obligation and the bonds receivable had interest rates of 4.5 percent and were due on July 1, 2024. Sempra Natural Gas redeemed $180 million in December 2011 and the remaining $79 million in June 2015. In December 2015, Sempra Natural Gas redeemed, prior to their August 2037 maturity, $55 million of industrial development bonds payable at variable rates at Bay Gas Storage Company, Ltd. OTHER LONG-TERM DEBT Sempra Ene rgy In March 2015, Sempra Energy publicly offered and sold $500 million of 2.40-percent, fixed-rate notes maturing in 2020. In November 2015, Sempra Energy publicly offered and sold $400 million of 2.85-percent fixed-rate notes maturing in 2020 and $350 mi llion of 3.75-percent fixed-rate notes maturing in 2025. Sempra Energy used the proceeds from these offerings to repay outstanding commercial paper and for general corporate purposes. SDG&E In August 2015, SDG&E redeemed, prior to maturity, certain outsta nding long-term debt instruments with a total principal amount of $169 million. The coupon rates of these instruments ranged from 4.9 percent to 5.5 percent, with maturities ranging from 2021 to 2027. Sempra South American Utilities Luz del Sur has outsta nding corporate bonds and bank loans which are denominated in the local currency. During 201 5 , Luz del Sur publicly offered and sold $25 million of corporate bonds at 8.75 percent maturing in 2026. Additionally, Luz del Sur drew bank loans in 2015 as follo ws: 2015 BANK LOAN DRAWS – LUZ DEL SUR (Dollars in millions) Amount at Month issued issuance Interest rate Maturity date May $ 13 5.18% May 2018 June 22 5.18% June 2018 August 9 6.70% February 2018 November 15 6.55% November 2017 INTEREST RATE SWAPS We discuss our fair value and cash flow hedging i nterest rate swaps in Note 9 .

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Income Taxes	NOTE 6 . INCOME TAXES Reconciliation of net U.S. statutory federal income tax rate s to the effective income tax rate s is as follows: RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: U.S. federal statutory income tax rate 35 % 35 % 35 % Utility depreciation 5 5 4 U.S. tax on repatriation of foreign earnings 1 2 ― Income tax restructuring related to IEnova stock offerings ― ― 4 State income taxes, net of federal income tax benefit 1 ― 1 Utility repairs expenditures (5) (5) (5) Tax credits (4) (4) (3) Self-developed software expenditures (3) (3) (3) Resolution of prior years’ income tax items (3) (1) (3) Non-U.S. earnings taxed at lower statutory income tax rates (2) (2) (3) Allowance for equity funds used during construction (2) (2) (1) Foreign exchange and inflation effects (2) (2) ― International tax reform ― (1) 1 Other, net (1) (2) (1) Effective income tax rate 20 % 20 % 26 % SDG&E: U.S. federal statutory income tax rate 35 % 35 % 35 % State income taxes, net of federal income tax benefit 5 5 3 Depreciation 4 4 5 SONGS tax regulatory asset write-off ― 2 ― Repairs expenditures (4) (4) (4) Self-developed software expenditures (3) (3) (3) Allowance for equity funds used during construction (2) (2) (2) Resolution of prior years’ income tax items (2) (2) (1) Variable interest entity (1) (1) (1) Other, net ― ― (1) Effective income tax rate 32 % 34 % 31 % SoCalGas: U.S. federal statutory income tax rate 35 % 35 % 35 % Depreciation 8 8 6 State income taxes, net of federal income tax benefit 4 4 4 Repairs expenditures (10) (9) (9) Self-developed software expenditures (6) (5) (6) Resolution of prior years’ income tax items (3) (2) (5) Allowance for equity funds used during construction (2) (2) (1) Other, net (1) ― ― Effective income tax rate 25 % 29 % 24 % In 2015, 2014 and 2013, non-U.S. earnings taxed at lower statutory income tax rates than the U.S. are primarily related to operations in Mexico, Chile and Peru. Foreign exchange and inflation effects for Sempra Energy Consolidated in 2015 and 2014 are primarily due to significant devaluation of the Mexican peso against the U.S. dollar. In 2014, our effective income tax rate was affected by a $25 million state tax benefit due to the release of Louisiana state valuation allowance against a deferred tax as set associated with Cameron LNG developments. This benefit is included in “State Income Taxes, Net of Federal Income Tax Benefit” in the Sempra Energy Consolidated table above. In addition, the effective income tax rates for Sempra Energy Consolidated and SDG&E were impacted in 2014 by a $17 million charge to reduce certain tax regulatory assets attributed to SDG&E’s investment in SONGS that we discuss in Note 13. This charge is included in “Resolution of Prior Years’ Income Tax Items” in the Sempra Energy Consolidated table above. Furthermore, our effective income tax rate was affected by international tax reform in both Peru and Chile in 2014 and in Mexico in 2013. In 2013, our effective income tax rate was affected by $63 million of income tax expense rec orded in the first quarter of 2013 resulting from a corporate reorganization in connection with the IEnova stock offerings. Consolidated results for Sempra Energy Consolidated and SDG&E include Otay Mesa VIE’s pretax earnings, which impacts Sempra Energy C onsolidated’s and SDG&E’s effective income tax rates. For 2015, 2014 and 2013, the impacts on Sempra Energy Consolidated’s and SDG&E’s effective income tax rates were not material. We discuss Otay Mesa VIE further in Note 1 . Utility repairs expenditures significantly affecting the effective income tax rates for Sempra Energy Consolidated, SDG&E and SoCalGas in 2015, 2014 and 2013 are due to a change in 2012 in the income tax treatment of certain repairs that are capitalized for financial statement purposes. The change in income tax treatment of certain repairs for electric transmission and distribution assets, which applied to SDG&E, was made pursuant to an Internal Revenue Service (IRS) Revenue Procedure pro viding a safe harbor for deducting certain repairs expenditures from taxable income when incurred for tax years beginni ng on or after January 1, 2011. The change in income tax treatment of certain repairs expenditures for gas plant assets, which applied to SoCalGas , was made pursuant to an IRS Revenue Procedure, which allows, under an Internal Revenue Code section, such expenditures to be deducted from taxable income when incurred. For SDG&E and SoCalGas , t he CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the re gulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the current effect ive income tax rate. As a result , changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the effective income tax rate. The foll owing items are subject to flow- through treatment: repairs expend itures related to a certain portion of utility plant fixed assets the equity portion of AFUDC a portion of the cost of removal of utility plant assets utility self-developed software expenditures depreciation on a certain portion of utility plant assets st ate income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico has similar flow- through treatment. We use the deferral method for investment tax credits (ITC). For certain solar and wind generating assets placed into service during 2012, we elected to seek cash grants rather than ITC for which the projects also qualify. Accordingly, cash grant accounting was applied. Grant accounting for cash grants is very similar to the deferral method of accounting for ITC, the primary difference being the recording of a cash grant receivable instead of an income tax receivable. Under the deferral method of accounting for ITC and under grant accounting for cash grants, we record a deferred income tax benefit on day one, which is reflected in income tax expense , by recording a deferred income tax asset during the year the renewable energy assets are placed in service. This deferred income tax asset results from the day-one difference in the income tax basis and financial statement basis of the renewable ene rgy assets, referred to as the day - one basis difference. The financial statement ba sis of the assets is reduced by 100 percent of the ITC or grant expected; U.S. federal income tax basis is reduced by only 50 percent for both ITC and grants; and state income tax basis is reduced by 5 0 percent for grants and not at all for ITC. Conversion of ITC to cash is generally dependent on reducing income tax payments and thus the existence of a U.S. federal net operating loss (NOL) carryforw ard can result in delaying this conversion. The geographic components of Income Before Income Taxes and Equity Earnings of Certain Unconsolidated Subsidiaries at Sempra Energy Consolidated are as follows: GEOGRAPHIC COMPONENTS (Dollars in millions) Years ended December 31, 2015 2014 2013 U.S. $ 1,189 $ 1,014 $ 941 Non-U.S. 515 510 489 Total $ 1,704 $ 1,524 $ 1,430 The components of income tax expense are as follows: INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Current: U.S. federal $ 3 $ (10) $ (70) U.S. state (24) (7) (5) Non-U.S. 123 171 107 Total 102 154 32 Deferred: U.S. federal 242 237 275 U.S. state 34 4 15 Non-U.S. (32) (91) 48 Total 244 150 338 Deferred investment tax credits (5) (4) (4) Total income tax expense $ 341 $ 300 $ 366 SDG&E: Current: U.S. federal $ 12 $ (5) $ 9 U.S. state 77 52 11 Total 89 47 20 Deferred: U.S. federal 233 220 149 U.S. state (35) 5 24 Total 198 225 173 Deferred investment tax credits (3) (2) (2) Total income tax expense $ 284 $ 270 $ 191 SoCalGas: Current: U.S. federal $ (1) $ 2 $ 4 U.S. state 12 7 (5) Total 11 9 (1) Deferred: U.S. federal 122 117 103 U.S. state 7 15 16 Total 129 132 119 Deferred investment tax credits (2) (2) (2) Total income tax expense $ 138 $ 139 $ 116 We show the components of deferred income taxes at December 31 for Sempra Energy Consolidated , SDG&E and SoCalGas in the tables below: DEFERRED INCOME TAXES FOR SEMPRA ENERGY CONSOLIDATED (Dollars in millions) December 31, 2015 2014 Deferred income tax liabilities: Differences in financial and tax bases of depreciable and amortizable assets $ 4,487 $ 4,074 Regulatory balancing accounts 745 915 Property taxes 61 57 Differences in financial and tax bases of partnership interests(1) 796 650 Other deferred income tax liabilities 100 53 Total deferred income tax liabilities 6,189 5,749 Deferred income tax assets: Tax credits 381 276 Net operating losses 1,856 1,908 Compensation-related items 252 244 Postretirement benefits 446 433 Other deferred income tax assets 179 156 Litigation and other accruals not yet deductible 72 73 Deferred income tax assets before valuation allowances 3,186 3,090 Less: valuation allowances 34 39 Total deferred income tax assets 3,152 3,051 Net deferred income tax liability(2) $ 3,037 $ 2,698 (1) Amounts primarily represent differences in financial and tax bases of depreciable and amortizable assets within our partnerships. (2) At December 31, 2015, the net deferred income tax liability includes $120 million recorded as a noncurrent asset in Sundry on the Consolidated Balance Sheet. DEFERRED INCOME TAXES FOR SDG&E AND SOCALGAS (Dollars in millions) SDG&E SoCalGas December 31, December 31, 2015 2014 2015 2014 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 2,392 $ 2,181 $ 1,473 $ 1,194 Regulatory balancing accounts 234 441 515 481 Property taxes 42 39 20 18 Other 5 5 5 10 Total deferred income tax liabilities 2,673 2,666 2,013 1,703 Deferred income tax assets: Net operating losses ― 297 110 64 Postretirement benefits 90 85 268 261 Compensation-related items 11 8 42 40 State income taxes 46 27 13 11 Litigation and other accruals not yet deductible 36 39 20 23 Other 18 36 28 39 Total deferred income tax assets 201 492 481 438 Net deferred income tax liability $ 2,472 $ 2,174 $ 1,532 $ 1,265 At December 31, 20 15, Sempra Energy’s U.S. subsidiaries had $4.9 billion of unused U.S. federal consolidated NOLs that will begin to expire in 2031, $279 million of unused U.S. federal consolidated general business tax credits that will begin to expire in 2032 and $58 million of unused foreign tax credits that will begin to expire in 2024. Included in the NOL amount is $265 million of excess tax deductions related to employee stock expense for which a benefit will be recorded to additional paid in capital when realized. When assessing whether a tax benefit relating to employee stock expense has been realized, we follow the tax law ordering method, under which current year share-based compensation deductions are assumed to be utilized before net operating lo ss carryforwards and other tax attributes. We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not basis. At December 31, 2015, SoCalGas had $363 m illion of unused U.S. federal NOLs which begin to expire in 2032 and $7 million of unused U.S. federal general business tax credits which begin to expire in 2031. We have recorded deferred income tax benefits on these NOLs and tax credits, in total, becaus e we currently believe they will be realized on a more-likely-than-not basis. At December 31, 20 15, Sempra Energy ’ s U.S. subsidiaries ha d $ 2.8 b illion of unused U.S. state NOLs, primarily in Alabama, California and Louisiana. These U.S. state NOLs expire b etween 2016 and 2035 . Included in the NOL amount is $222 million of excess tax deductions related to employee stock expense for which a benefit will be recorded to additional paid in capital when realized. Sempra Energy’s U.S. subsidiaries also had $44 mil lion of unused U.S. state general business tax credits that begin to expire in 2016. We have not recorded deferred income tax benefits on a portion of Sempra Energy’s total U.S. state NOLs and tax credits because we currently believe they will not be reali zed on a more-likely-than-not basis, as discussed below. At December 31, 2015 , Sempra Energy ’ s non-U.S. subsidiaries had $468 million of unused NOLs available to utilize in the future to reduce Sempra Energy’s future non-U.S. income tax expense related to our companies in Mexico and the Netherlands. The carryforward periods for our non-U.S. unused NOLs expire between 2016 and 2025. We have not recorded deferred income tax benefits on a portion of Sempra Energy’s total non-U.S. NOLs because we currently beli eve they will not be realized on a more-likely-t han-not basis, as discussed below . At December 31, 20 15, Sempra Energy recorded a valuation allowance against a portion of its total deferred income tax assets, as shown above in the “ Deferred Income Taxes fo r Sempra Energy Consolidated ” table. A valuation allowance is recorded when, based on more-likely-than-not criteria, negative evidence outweighs positive evidence with regard to our ability to realize a deferred income tax asset in the future. Of the valua tion allowances recorded to date, the negative evidence outweighs the positive evidence primarily due to cumulative pretax losses in various U.S. state and non-U.S. jurisdictions resulting in a deferred income tax asset related to NOLs, as discussed above, that we currently do not believe will be realized on a more-likely-than-not basis. O f Sempra Energy ’ s total valuation allowance of $34 million at December 31, 2015, $6 million is related to non-U.S. NOLs and $28 million to U.S. state NOLs and tax credits. Of Sempra Energy’s total valuation allowance of $ 39 million at December 31, 2014 , $ 8 million is related to non U.S. NOLs and $31 million to U.S. state NOLs. The total va luation allowance decreased in 2015 prima rily due to release of a valuation allowance against a state capital loss deferred tax asset. Sempra Natural Gas and its project partners are currently developing a natural gas liquefaction export facility at the Cameron LNG terminal in Louisiana. In 2014, we released $25 million of Louisiana state v aluation allowance against a deferred tax asset associated with Cameron LNG developments. At December 31, 2015 , Sempra Energy had not recognized a U.S. deferred income tax liability related to a $3.9 billion basis difference between its financial statement and income tax investment amount in its non-U.S. subsidiaries and non-U.S. corporate joint ventures . This b asis difference consists of cumulative undistributed earnings that we expect to reinvest i n definitely outside of the U.S. These cumulative undistributed earnings have previously been reinvested or will be reinvested in active non-U.S. operations, thus we do not intend to use these earnings as a source of funding for U.S. operations. It is not pr actical to determine the hypothetical unrecognized amount of U.S. deferred income taxes that might be payable if the cumulative undistributed earnings were eventually distribute d or the investments were sold. Following is a summary of unrecognized income t ax benefits: SUMMARY OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Total $ 87 $ 117 $ 90 Of the total, amounts related to tax positions that, if recognized in future years, would decrease the effective tax rate(1) $ (83) $ (114) $ (86) increase the effective tax rate(1) 32 21 19 SDG&E: Total $ 20 $ 14 $ 17 Of the total, amounts related to tax positions that, if recognized in future years, would decrease the effective tax rate(1) $ (16) $ (11) $ (14) increase the effective tax rate(1) 11 6 11 SoCalGas: Total $ 27 $ 19 $ 13 Of the total, amounts related to tax positions that, if recognized in future years, would decrease the effective tax rate(1) $ (27) $ (19) $ (13) increase the effective tax rate(1) 21 15 8 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above. F ollowing is a reconciliation of the changes in unrecognized income t ax benefits for the years ended December 31 : RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2015 2014 2013 Sempra Energy Consolidated: Balance as of January 1 $ 117 $ 90 $ 82 Increase in prior period tax positions 10 37 26 Decrease in prior period tax positions ― ― (24) Increase in current period tax positions 8 5 7 Settlements with taxing authorities (48) (15) (1) Balance as of December 31 $ 87 $ 117 $ 90 SDG&E: Balance as of January 1 $ 14 $ 17 $ 12 Increase in prior period tax positions 5 2 7 Decrease in prior period tax positions ― ― (4) Increase in current period tax positions 2 ― 2 Settlements with taxing authorities (1) (5) ― Balance as of December 31 $ 20 $ 14 $ 17 SoCalGas: Balance as of January 1 $ 19 $ 13 $ 5 Increase in prior period tax positions 2 2 4 Increase in current period tax positions 6 4 5 Settlements with taxing authorities ― ― (1) Balance as of December 31 $ 27 $ 19 $ 13 It is reasonably possible that within the next 12 months , unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) At December 31, 2015 2014 2013 Sempra Energy Consolidated: Expiration of statutes of limitations on tax assessments $ (2) $ ― $ (7) Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities (32) (61) (63) $ (34) $ (61) $ (70) SDG&E: Expiration of statutes of limitations on tax assessments $ (1) $ ― $ ― Potential resolution of audit issues with various U.S. federal, state and local taxing authorities (8) (9) (14) $ (9) $ (9) $ (14) SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ (22) $ (15) $ (11) Amoun ts accrued for interest and penalties associated with unrecognized income tax benefits are included in income tax expense on the Consolidated Statements of Operations. We summarize the amounts accrued at December 31 on the Consolidated Balance Sheets for interest and penalties associated with unrecognized income tax benefits and the related expense in the table below. INTEREST AND PENALTIES ASSOCIATED WITH UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) Interest and penalties Accrued interest and penalties Years ended December 31, December 31, 2015 2014 2013 2015 2014 Sempra Energy Consolidated: Interest (income) expense $ (2) $ (4) $ 1 $ 1 $ ― Penalties ― (3) ― ― ― SDG&E: Interest income $ ― $ (1) $ ― $ ― $ ― SoCalGas: Interest income $ ― $ ― $ (1) $ ― $ ― Penalties accrued and expensed at SDG&E and SoCalGas in all periods presented were zero or negligible. INCOME TAX AUDITS Sempra Energy is subject to U.S. federal income tax as well as income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 20 10 . We are subject to examination by major state tax jurisdictions for tax years after 20 08 . Certain major non-U.S. income tax returns for tax years 2008 through the present are open to examination . In addition, we filed federal refund claims for the 2009 and 2010 tax years during 2015; however, no additional tax may be assessed by the IRS for pre-2011 tax years. W e have also filed state refund claims for tax years back to 2006 . The pre-2009 tax years for our major state tax jurisdictions are closed to new issues, therefore, no additional tax may be assessed by the taxing authorities for these tax years. SDG&E and SoCalGas are subject to U.S. federal income tax as well as income tax of state jurisdictions. They remain subject to examination for U.S. federal tax years after 2010 and by state tax jurisdictions for tax years after 20 08.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Employee Benefit Plans	NOTE 7 . EMPLOYEE BENEFIT PLANS We are required by applicable U.S. GAAP to: recognize an asset for a plan ’ s overfunded status or a liability for a plan ’ s underfunded status in the statement of financial position; measure a plan ’ s assets and its obligations that determine its funded status as of the end of the fiscal year (with limited exceptions); and recognize ch anges in the funded status of pension and other postretirement benefit plan s in the year in which the changes occur. Generally, those c hanges are reported in other comprehensive income and as a separate component of shareholders ’ equity. The detailed information presented below covers the employee benefit plans of Sempra Energy and its principal subsidiaries . Sempra Energy has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E and SoCalGas , which collectively cover all eligible employees, including members of the Sempra Energy board of directors who were participants i n a predecessor plan on or before June 1, 1998. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology . IEnova has an unfunded noncontributory defined benefit plan covering all employees. Chilquinta Energía has an unfunded non contributory de fined benefit plan covering all employ ees hired before October 1, 1981. In addition, IEnova and Chilquinta Energía have an unf unded noncontributory terminat ion indemnity obligation covering all employees. The plans generally provide defined benefits to retirees based on date of hire, years of service and final average earnings . Sempra Energy also has other postretirement benefit plans (PBOP) , including separate plans for SD G&E and SoCalGas , which collectively cover all domestic (except Willmut Gas) and certain foreign employees. The life insurance plans are both contributory and noncontributory , and the health care plans are contr ibutory. Participants ’ contributions are adjusted annually. Other postretirement benefits include medical benefits for retirees ’ spouses. Chilquinta Energía also has two noncontributory postretirement benefit plans which cover substantially all employees – a heal th care plan and an energy subsidy plan that provides for reduced energy rates . The health care plan includes benefits f or retirees’ spouses and depende nts . Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amo unts. These assumptions include discount rates expected return on plan assets health care cost trend rates mortality rates rate of com pensation increases termination and retirement rates utilization of postretirement welfare benefits payout elections (lump sum or annuity) lump sum interest rates We review these assumptions on an annual basis and update them as appropriate. We consider c urrent market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans. Rabbi Trust In support of its Supplemental Executive Retirement , Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, whi ch totaled $464 million and $512 million at December 31, 2015 and 20 14 , respectively. Pension and Other Post retirement Benefit Plans Benefit Plan Amendments Affecting 2015 During 2015, executive participants in a company nonqualified pension plan became eligible in this same plan for Supplemental Executive Retirement Plan benefits. Consistent with past practice, this was treated as a plan amendment and increased the recorded pension liability by $5 million at Sempra Energy Consolidated and $3 million at SoCalGas . Effective January 1, 2016, the point of service medical benefit provided to retirees under the age of 65 at our domestic companies, except the represented retirees at SDG&E and retirees enrolled in one of the high deductible medical plans at SoCalGas , is no longer provided by the PBOP plans of the respective companies. This change resulted in a decrease in other postretirement benefit obligations of $9 million at each of Sempra Energy Consolidated and SoCalGas , and by a negligible amount at SDG&E. Benefit Plan Amendments Affecting 2014 During 2014, executive participants in a company nonqualified pension plan became eligible in this same plan for Supplemental Executive Retirement Plan benefits. Consistent with past practice, this was treated as a plan amendment and increased the recorded pension liability by $4 million at Sempra Energy Consolidated. Effect ive January 1, 2014, a new high deductible medical benefit was provided to all SDG&E and SoCalGas retirees under the age of 65, except the represented retirees at SoCalGas , participating in the companies’ PBOP plans. This benefit replaced a previous benefi t provided by the SDG&E plans and was an added benefit in the SoCalGas plan. These changes resulted in an increase in other postretirement benefit obligations by a negligible amount at SDG&E and by $1 million at each of Sempra Energy Consolidated and SoCal Gas . Special Termination Benefits Affecting 2014 At SDG&E in 2014, all nonrepresented employees age 62 with 5 years of service and all other nonrepresented employees age 55 with 10 years of service that retired under the Voluntary Retirement Enhancement Pr ogram offered in that year received an additional postretirement health benefit in the form of a $50,000 Health Reimbursement Account (HRA). In accordance with U.S. GAAP, we elected to treat the benefit obligation attributable to the HRA as special termina tion benefits. This resulted in increases to the recorded liability for other postretirement benefits of approximately $5 million for each of Sempra Energy Consolidated and SDG&E in 2014. Benefit Obligations and Assets The following three tables provide a reconciliation of the changes in the plans ’ projected benefit obligations and the fair value of assets during 20 15 and 20 14 , and a statement of the funded status at December 31, 20 15 and 20 14 : PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 3,839 $ 3,459 $ 1,115 $ 973 Service cost 114 101 26 24 Interest cost 154 161 44 49 Contributions from plan participants ― ― 19 17 Actuarial (gain) loss (180) 441 (172) 105 Benefit payments (273) (217) (60) (58) Plan amendments 5 4 (9) 1 Special termination benefits ― ― ― 5 Settlements and curtailments (10) (110) ― (1) Net obligation at December 31 3,649 3,839 963 1,115 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,807 2,789 1,054 1,012 Actual return on plan assets (73) 217 (21) 67 Employer contributions 33 128 11 16 Contributions from plan participants ― ― 19 17 Benefit payments (273) (217) (60) (58) Settlements (10) (110) ― ― Fair value of plan assets at December 31 2,484 2,807 1,003 1,054 Funded status at December 31 $ (1,165) $ (1,032) $ 40 $ (61) Net recorded (liability) asset at December 31 $ (1,165) $ (1,032) $ 40 $ (61) PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 1,011 $ 939 $ 200 $ 171 Service cost 29 30 7 7 Interest cost 39 43 8 9 Contributions from plan participants ― ― 7 6 Actuarial (gain) loss (52) 101 (43) 15 Benefit payments (56) (25) (14) (13) Special termination benefits ― ― ― 5 Settlements ― (87) ― ― Transfer of liability (to) from other plans (6) 10 ― ― Net obligation at December 31 965 1,011 165 200 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 828 819 164 146 Actual return on plan assets (24) 63 (3) 11 Employer contributions 2 56 7 14 Contributions from plan participants ― ― 7 6 Benefit payments (56) (25) (14) (13) Settlements ― (87) ― ― Transfer of assets from other plans 2 2 ― ― Fair value of plan assets at December 31 752 828 161 164 Funded status at December 31 $ (213) $ (183) $ (4) $ (36) Net recorded liability at December 31 $ (213) $ (183) $ (4) $ (36) PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,398 $ 2,110 $ 866 $ 753 Service cost 74 60 17 16 Interest cost 98 100 34 38 Contributions from plan participants ― ― 12 11 Actuarial (gain) loss (131) 300 (125) 90 Benefit payments (187) (163) (43) (43) Plan amendments 3 ― (9) 1 Settlements ― (10) ― ― Transfer of liability from other plans ― 1 ― ― Net obligation at December 31 2,255 2,398 752 866 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,763 1,758 870 848 Actual return on plan assets (45) 138 (18) 54 Employer contributions 6 39 1 ― Contributions from plan participants ― ― 12 11 Benefit payments (187) (163) (43) (43) Settlements ― (10) ― ― Transfer of assets from other plans ― 1 ― ― Fair value of plan assets at December 31 1,537 1,763 822 870 Funded status at December 31 $ (718) $ (635) $ 70 $ 4 Net recorded (liability) asset at December 31 $ (718) $ (635) $ 70 $ 4 New mortality table studies were released by the Society of Actuaries during 2014 that significantly increased life expectancy assumptions, and during 2015 that consisted of a new mortality improvement projection scale. We have incorporated these assumptions, adjusted for the Sempra Energy companies’ actual mortality experience, in our calculations for each of those years. In 2015, the actuarial gains for pension plans were primarily due to: an increase in weighted-average discount rates; changes in salary scale at SoCalGas ; updated mortality rates; a change in the rate used to convert annuity benefits to lump sums; and the impact of updated census data at SDG&E; offset by the impact of updated census data at Sempra Energy Con solidated and SoCalGas ; and changes in anticipated retirement rates. In 2015, the actuarial gains for other postretirement benefit plans were primarily due to: the impact of updated census data; changes in termination and retirement rates; an increase in weighted-average discount rates; a decrease in the actual versus expected 2016 claims costs; and updated mortality rates; offset by changes in health care cost trend rates; and changes in salary scale at SoCalGas . In 2014, the actua rial losses for pension plans were primarily due to: a decrease in weighted-average discount rates; updated mortality rates; and a change in the rate used to convert annuity benefits to lump sums at SoCalGas ; offset by the impact of updated census data at SoCalGas ; and a decrease in the cash balance interest crediting rate. In 2014, the actuarial losses for other postretirement benefit plans were primarily due to: a decrease in weighted-average discount rates; updated mortality rates; and the impact of up dated census data at SDG&E and SoCalGas ; offset by a decrease in anticipated retiree and spousal participation rates. Net Assets and Liabilities The assets and liabilities of the pension and other postretirement benefit plans are affected by changing marke t conditions as well as when actual plan experience is different than assumed. S uch eve nts result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Our funded pension and other postretirement benefit plans use the asset smoothing method , except for those at SDG&E and the other postretirement benefit plan at Mobile Gas . This method develops an asset value that recognizes realized and unrealized investment gains and losses ov er a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic cost. SDG&E does not use t he asset smoothing method, but rather recognizes realized and unrealized investment gains and losses during the current year. The 10-percent corridor accounting method is used at Sempra Energy Consolidated , SDG&E a nd SoCalGas . Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10 percent of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of a ctive participants. The asset smoothing and 10-percent corridor accounting methods help mitigate volatility of net periodic costs from year to year. We recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets or liabilities, respectively; unrecognized changes in these assets and/or liabilities are normally recorded in Accumulated Other Comprehensive Income (Loss) on the balance sheet. The California Utilities and Mobile Gas record regulatory assets a nd liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on agreements with regulatory agencies. At Willmut Gas, pension contributions are recovered in rates on a prospective basis, but are not recorded as a regulatory asset pending recovery. The California Utilities record annual pension and other postretirement net periodic benefit costs equal to the contributions to their plans as authori zed by the CPUC. The annual contributions to the pension plans are limited to a minimum required funding amount as determined by the IRS. The annual contributions to the other postretirement plans are equal to the lesser of the maximum tax deductible amoun t or the net periodic cost calculated in accordance with U.S. GAAP for pension and other postretirement benefit plans. Mobile Gas records annual pension and other postretirement net periodic benefit costs based on an estimate of the net periodic cost at th e beginning of the year calculated in accordance with U.S. GAAP for pension and other postretirement benefit plans, as authorized by the Alabama Public Service Commission. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for the California Utilities are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. The net ( liability ) asset is included in the following categories on the Consolidated Balance Sheets at December 31: PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS AT DECEMBER 31 (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 Sempra Energy Consolidated: Noncurrent assets $ ― $ ― $ 70 $ 4 Current liabilities (43) (33) ― ― Noncurrent liabilities (1,122) (999) (30) (65) Net recorded (liability) asset $ (1,165) $ (1,032) $ 40 $ (61) SDG&E: Current liabilities $ (5) $ (3) $ ― $ ― Noncurrent liabilities (208) (180) (4) (36) Net recorded liability $ (213) $ (183) $ (4) $ (36) SoCalGas: Noncurrent assets $ ― $ ― $ 70 $ 4 Current liabilities (2) (2) ― ― Noncurrent liabilities (716) (633) ― ― Net recorded (liability) asset $ (718) $ (635) $ 70 $ 4 Amounts recorded in a ccumulated o ther c omprehensive i ncome (l oss) at December 31, 20 15 and 20 14 , net of income tax effects and amounts recorded as regulatory assets, are as follows: AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 Sempra Energy Consolidated: Net actuarial (loss) gain $ (84) $ (82) $ 2 $ (1) Prior service cost (5) (2) ― ― Total $ (89) $ (84) $ 2 $ (1) SDG&E: Net actuarial loss $ (8) $ (13) Prior service credit ― 1 Total $ (8) $ (12) SoCalGas: Net actuarial loss $ (4) $ (5) Prior service (cost) credit (1) 1 Total $ (5) $ (4) The accumulated benefit obligation for defined benefit pension plans at December 31, 20 15 and 20 14 was as follows: ACCUMULATED BENEFIT OBLIGATION (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2015 2014 2015 2014 2015 2014 Accumulated benefit obligation $ 3,397 $ 3,555 $ 939 $ 978 $ 2,056 $ 2,182 Sempra Energy , SDG&E , SoCalGas and Mobile Gas each have a funded pension plan. We also have unfunded pension plans at Sempra Energy , SDG&E , SoCalGas , IEnova and Chilquinta Energía . The following table shows the obligations of funded pension plans with benefit obligation s in excess of plan assets at December 31: OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) 2015 2014 Sempra Energy Consolidated: Projected benefit obligation $ 3,410 $ 3,592 Accumulated benefit obligation 3,183 3,343 Fair value of plan assets 2,484 2,807 SDG&E: Projected benefit obligation $ 927 $ 964 Accumulated benefit obligation 906 937 Fair value of plan assets 752 828 SoCalGas: Projected benefit obligation $ 2,236 $ 2,379 Accumulated benefit obligation 2,039 2,166 Fair value of plan assets 1,537 1,763 Net Periodic Benefit Cost The following three tables provide the components of net periodic benefit cost and pre tax amounts recognized in other comprehensive income (loss) for the years ended December 31: NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 NET PERIODIC BENEFIT COST Service cost $ 114 $ 101 $ 109 $ 26 $ 24 $ 28 Interest cost 154 161 148 44 49 44 Expected return on assets (173) (171) (162) (68) (63) (58) Amortization of: Prior service cost (credit) 11 11 4 (4) (5) (4) Actuarial loss 38 18 54 ― ― 7 Settlement and curtailment charges 4 31 2 ― (1) ― Special termination benefits ― ― ― ― 5 5 Regulatory adjustment (110) (31) (20) 12 6 6 Total net periodic benefit cost 38 120 135 10 15 28 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) Net loss (gain) 17 38 (30) (4) 1 (8) Prior service cost 4 4 1 ― ― ― Amortization of actuarial loss (14) (23) (9) ― ― (1) Total recognized in other comprehensive income (loss) 7 19 (38) (4) 1 (9) Total recognized in net periodic benefit cost and other comprehensive income (loss) $ 45 $ 139 $ 97 $ 6 $ 16 $ 19 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 NET PERIODIC BENEFIT COST Service cost $ 29 $ 30 $ 32 $ 7 $ 7 $ 8 Interest cost 39 43 41 8 9 8 Expected return on assets (54) (55) (52) (11) (10) (8) Amortization of: Prior service cost 8 2 2 3 2 4 Actuarial loss 2 4 14 ― ― ― Settlement charge ― 19 1 ― ― ― Special termination benefits ― ― ― ― 5 2 Regulatory adjustment (20) 12 14 ― 1 ― Total net periodic benefit cost 4 55 52 7 14 14 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) Net (gain) loss (6) 8 (2) ― ― ― Amortization of actuarial loss (1) (3) (1) ― ― ― Total recognized in other comprehensive (loss) income (7) 5 (3) ― ― ― Total recognized in net periodic benefit cost and other comprehensive (loss) income $ (3) $ 60 $ 49 $ 7 $ 14 $ 14 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 NET PERIODIC BENEFIT COST Service cost $ 74 $ 60 $ 67 $ 17 $ 16 $ 17 Interest cost 98 100 90 34 38 34 Expected return on assets (106) (104) (98) (56) (51) (48) Amortization of: Prior service cost (credit) 9 9 2 (7) (8) (8) Actuarial loss 21 6 31 ― ― 6 Settlement charge ― 4 ― ― ― ― Special termination benefits ― ― ― ― ― 2 Regulatory adjustment (90) (43) (34) 12 5 6 Total net periodic benefit cost 6 32 58 ― ― 9 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) Net loss ― 5 3 ― ― ― Prior service cost 2 ― ― ― ― ― Amortization of actuarial loss ― (5) (1) ― ― ― Total recognized in other comprehensive income 2 ― 2 ― ― ― Total recognized in net periodic benefit cost and other comprehensive income $ 8 $ 32 $ 60 $ ― $ ― $ 9 The estimated net loss for the pension and other postretirement benefit plans that will be amortized from accumulated other comprehensive income (loss) into net periodic benefit cost in 2016 is $ 8 million for S empra Energy Consolidated, $1 million for SDG&E and a negligible amount for SoCalGas . The estimated prior ser vice cost that will be similarly amortized in 2016 is $1 million for Sempra Energy Consolidated and negligible amounts for SDG&E and SoCalGas . Assumptions for Pension and Other Postretirement Benefit Plans Benefit Obligation and Net Periodic Benefit Cost Except for the IEnova and Chilquinta Energía plans, we develop the discount rate assumptions based on the results of a third party modeling tool that develops the discount rate by matching each plan’ s e xpected cash flows to interest rates and expected maturity values of individually selected bonds in a hypothetical portfolio . The model controls the level of accumulated surplus that may result from the selection of bonds based solely on their premium yields by limiting the number of years to look back for selection to 3 years for pre-30-year and 6 years for post-30-year benefit payments. Additionally, the model ensures that an adequate number of bonds are selected in the portfolio by limiting the amount of the plan’s benefit payments that can be met by a single bond to 7.5 percent. We selected individual bonds from a universe of Bloomberg AA-rated bonds which: have an outstanding issue of at lea st $50 million; are non-callable (or callable with make-whole provisions); exclude collateralized bonds; and exclude the top and bottom 10 percent of yields to avoid relying on bonds which might be mispriced or misgraded . This selection methodology al so mitigates the impact of market volatility on the portfolio by excluding bonds with the following characteristics: The issuer is on review for downgrade by a major rating agency if the downgrade would eliminate the issuer from the portfolio. Recent event s have caused significant price volatility to which rating agencies have not reacted. Lack of liquidity is causing price quotes to vary significantly from broker to broker. We believe that this bond selection approach provides the best estimate of discount rates to estimate settlement values for our plans’ benefit obligations as required by applicable U.S. GAAP. We develop the discount rate assumptions for the plans at IEnova by constructing a synthetic government zero coupon bond yield curve from the avai lable market data, based on duration matching, and we add a risk spread to allow for the yields of high-quality corporate bonds. We develop the discount rate assumptions for the plans at Chilquinta Energía based on 10-year Chilean government bond yields an d the expected local long- term rate of inflation. The s e method s for developing the discount rate are required when there is no deep market for high quality corporate bonds. Long-term return on assets is based on the weighted-average of the plans’ investment allocation as of the measurement date and the expected returns for those asset types. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under GAAP. The significant assumptions affecting benefit obligation and net periodic benefit cost are as follo ws: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31 Pension benefits Other postretirement benefits 2015 2014 2015 2014 Sempra Energy Consolidated: Discount rate 4.46 % 4.09 % 4.49 % 4.15 % Rate of compensation increase 2.00-10.00 3.50-10.00 2.00-10.00 3.50-10.00 SDG&E: Discount rate 4.35 % 4.00 % 4.50 % 4.15 % Rate of compensation increase 2.00-10.00 3.50-10.00 2.00-10.00 3.50-10.00 SoCalGas: Discount rate 4.50 % 4.15 % 4.50 % 4.15 % Rate of compensation increase 2.00-10.00 3.50-10.00 2.00-10.00 3.50-10.00 WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST FOR YEARS ENDED DECEMBER 31 Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 Sempra Energy Consolidated: Discount rate 4.09 % 4.85 % 4.04 % 4.15 % 4.95 % 4.09 % Expected return on plan assets 7.00 7.00 7.00 6.98 6.97 6.96 Rate of compensation increase 2.00-10.00 3.50-10.00 3.50-9.50 2.00-10.00 3.50-10.00 3.50-9.50 SDG&E: Discount rate 4.00 % 4.69 % 3.94 % 4.15 % 5.00 % 4.10 % Expected return on plan assets 7.00 7.00 7.00 6.91 6.88 6.81 Rate of compensation increase 2.00-10.00 3.50-10.00 3.50-9.50 2.00-10.00 3.50-10.00 N/A SoCalGas: Discount rate 4.15 % 4.94 % 4.10 % 4.15 % 4.95 % 4.10 % Expected return on plan assets 7.00 7.00 7.00 7.00 7.00 7.00 Rate of compensation increase 2.00-10.00 3.50-10.00 3.50-9.50 2.00-10.00 3.50-10.00 3.50-9.50 Health Care Cost Trend Rates Assumed health care cost trend rates have a significant effect on the amount s that we report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans(1) Pre-65 retirees Retirees aged 65 years and older 2015 2014 2013 2015 2014 2013 Health care cost trend rate assumed for next year 8.10 % 7.75 % 8.25 % 5.50 % 5.25 % 5.50 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 5.00 % 5.00 % 5.00 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2022 2020 2020 2022 2020 2020 (1) Excludes Mobile Gas Plan. For Mobile Gas, the health care cost trend rate assumed for next year for all retirees was 8.10 percent, 7.75 percent and 7.50 percent in 2015, 2014 and 2013, respectively; the ultimate trend was 5.00 percent in 2015, 2014 and 2013; and the year the rate reaches the ultimate trend was 2022, 2020 and 2019 in 2015, 2014 and 2013, respectively. For Chilquinta Energía, the health care cost trend rate assumed for next year and all subsequent years was 3.00 percent in each of 2015, 2014 and 2013. A one-p ercent change in assumed health care cost trend rates would have had the following effects in 2015 : EFFECT OF ONE-PERCENT CHANGE IN ASSUMED HEALTH CARE COST TREND RATES (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 1% 1% 1% 1% 1% 1% increase decrease increase decrease increase decrease Effect on total of service and interest cost components of net periodic postretirement health care benefit cost $ 7 $ (5) $ 1 $ (1) $ 5 $ (4) Effect on the health care component of the accumulated other postretirement benefit obligations 74 (62) 5 (4) 67 (55) Plan Assets Investment Allocation Strategy for Sempra Energy’s Pension Master Trust Sempra Energy’s pension master trust holds the investments for the pension and other postretirement benefit plans. We maintain additional trusts as we discuss below for certain of the California Utilities’ other postretirement benefit plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra Energy. The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks. Currently, the pension plans’ target asset allocations a re 38 percent domestic equity 26 percent international equity 18 percent long credit 5 percent global high yield credit 5 percent real assets 4 percent STRIPS 4 percent long government The asset allocation of the plans is reviewed by our Plan Funding Commi ttee and our Pension and Benefits Investment Committee (the Committees) on a regular basis. When evaluating strategic asset allocations, the Committees consider many variables, including: long-term cost variability and level of contributions funded status a range of expected outcomes over varying confidence levels We maintain allocations at strategic levels with reasonable bands of variance. In accordance with the Sempra Energy pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitiz e cash, hedge certain exposures, and as substitutes for certain types of fixed income securities . Rate of Return Assumption The expected return on assets in our p ension and other postretirement benefit plans is based on the weighted-average of the plans’ investment allocations to specific asset classes as of the measurement date. We arrive at a 7 percent expected return on assets by considering both the historical and forecasted long-term rates of return on those asset classes. We expect a return of between 7 percent and 9 percent on return-seeking assets and between 3 percent and 5 percent for ri sk-mitigating assets. Certain trusts that hold assets for the SDG&E and Mobile Gas other postretirement benefit plans are subject to taxation, which impacts the expected after-tax return on assets in these plans. Concentration of Risk Plan assets are full y diversified across global equity and bond markets, and other than what is indicated by the target asset allocations, contain no concentration of risk in any one economic, industry, maturity or geographic sector. Investment Strategy for SDG&E’s and SoCalGas ’ Other Postretirement Benefit Plans SDG&E’s and SoCalGas ’ other postretirement benefit plans are funded by cash contributions from SDG&E and SoCalGas and their current retirees. The assets of these plans are placed into the pension master trust a nd other Voluntary Employee Beneficiary Association (VEBA) trusts. The assets in the VEBA trusts are invested at an allocation similar to the pension master trust, with 70 percent invested in return-seeking and 30 percent invested in risk- mitigating assets . This allocation is periodically reviewed to ensure that plan assets are best positioned to meet plan obligations. Fair Value of Pension and Other Postretirement Benefit Plan Assets We classify the investments in Sempra Energy’s pension master trust and t he trusts for the California Utilities’ other postretirement benefit plans into: Level 1, for securities valued using quoted prices from active markets for identical assets; Level 2, for securities not traded on an active market but for which observable m arket inputs are readily available; and Level 3, for securities and investments valued based on significant unobservable inputs. Investments are classified in their entirety based on the lowest level of input that is significant to the fair value measureme nt. The following are descriptions of the valuation methods and assumptions we use to estimate the fair values of investments held by pension and other postretirement benefit plan trusts. Equity Securities – Equity securities are valued using quoted prices listed on nationally recognized securities exchanges. Fixed Income Securities – Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based o n yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flows approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Certain high yield fixed-income securities are valued by applying a price adjustment to the bi d side to calculate a mean and ask value. Adjustments can vary based on maturity, credit standing, and reported trade frequencies. The bid to ask spread is determined by the investment manager based on the review of the available market information. Regist ered Investment Companies – Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices for equity and certain

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Share-based Compensation	NOTE 8 . SHARE-BASED COMPENSATION SEMPRA ENERGY EQUITY COMPENSATION PLANS Sempra Energy has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra Energy. The plans permit a wide variety of share-based awards, including: non-qualified stock options incenti ve stock options restricted stock restricted stock units stock appreciation rights performance awards stock payments dividend equivalents Eligible employees, including those from the California Utilities , particip ate in Sempra Energy’ s share-based compens ation plans as a component of their compensation package. In May 2013, shareholders approved the Sempra Energy 2013 Long-Term Incentive Plan. Upon approval, the remaining authorized shares from the Sempra Energy 2008 Long Term Incentive Plan and the 2008 L ong Term Incentive Plan for EnergySouth , Inc. Employees and Other Eligible Individuals were applied to the number of shares authorized in the 2013 Plan. At December 31, 20 15 , Sempra Energy had the following types of equity awards outstanding: Non-Qualified Stock Options: Options have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a four-year period, and expire 10 years from the date of grant. Vesting and/or the ability to exer cise may be accelerated upon a change in control, in accordance with severance pay agreements , in accordance with the terms of the grant, or upon eligibility for retirement . Options are subject to forfeiture or earlier expiration when an employee terminate s employment. Performance-Based Restricted Stock Units: These restricted stock unit awards generally vest in Sempra Energy common stock at the end of three-year (for awards granted in 2015) or four-year performance periods based on Sempra Energy’s total r eturn to shareholders relative to that of specified market indices or based on the compound annual growth rate of Sempra Energy’s earnings per common share (EPS) . For awards granted in 2013 or earlier, i f Sempra Energy’s total return to shareholders exceeds target levels , up to an additional 50 percent of the number of granted restricted stock units may be issued. For awards granted during or after 2014, up to an additional 100 percent of the granted restricted stock units may be issued if total retur n to shareholders or EPS growth exceeds target levels. If Sempra Energy’s total return to shareholders or EPS growth is below the target levels but above threshold performance levels, shares are subject to part ial vesting on a pro rata basis . For awards gr anted in 2015 that vest based on Sempra Energy’s total return to shareholders, a modifier adds 20 percent to the award’s payout (as initially calculated based on total return to shareholders relative to that of specified market indices) for total sharehold er return performance in the top quartile relative to historical benchmark data for Sempra Energy and reduces the award’s payout by 20 percent for performance in the bottom quartile. However, in no event will more than an additional 100 percent of the gran ted restricted stock units be issued. If performance falls within the second or third quartiles, the modifier is not triggered, and the payout is based solely on total return to shareholders relative to that of specified market indices. Also, v esting may b e subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control under the applicable long-term incentive plan, or in accordance with severance pay agreements. Dividend equivalents on shares subject to restric ted stock units are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate. Other Performance-Based Restricted Stock Units: Restricted stock units were granted in 2014 and 2015 in connection with the creation of Cameron LNG JV. The 2014 awards vest to the extent that the Compensation Committee of Sempra Energy’s Board of Directors determines that the objectives of the joint venture are continuing to be achieved. These awards vest on the anniversary of the grant date over a period of either two or three years. The 2015 awards vest to the extent that the Compensation Committee of Sempra Energy’s Board of Directors determines that Sempra Energy has achieved positive cumulative net income for fiscal years 2015 through 2017 and Cameron LNG JV has commenced commercial operations of the first train. Vesting may be subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control under the applicable long-term incentive plan, or in accordance with severance pay agreements. Dividend equivalents on shares subject to restricted stock units are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate . Service-Based Restricted Stock Units : Restricted stock units may also be service- based; these generally vest at the end of three-year (for awards granted in 2015) or four-year service periods. Vesting may be subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control under the applicabl e long-term incentive plan, in accordance with severance pay agreements, or at the discretion of the Compensation Committee of Sempra Energy’s Board of Directors. Dividend equivalents on shares subject to restricted stock units are reinvested to purchase a dditional shares that become subject to the same vesting conditions as the restricted stock units to which the dividends relate. Restricted Stock: R estricted stock awards are solely service-based and are generally exercisable at the end of four years of service. Vesting is subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control under the applicable long-term incentive plan, in accordance with severance pay agreements or upon eligibility for retirement . Holders of restricted stock have full voting rights. They also have full dividend rights; however, dividends paid on restricted s tock held by officers are reinvested to purchase additional shares that become subject to the same vesting conditions as the restricted stock to which the dividends relate. In April 2013, the IEnova board of directors approved the IEnova 2013 Long-Term In centive Plan. The purpose of this plan is to align the interests of employees and directors of IEnova with its shareholders. All awards issued from this plan and any related dividend equivalents will settle in cash at vesting based on the price of IEnova c ommon stock. In 2015, 2014 and 2013, IEnova issued 278,538; 468,339 and 1,014,899 restricted stock units from this plan, respectively, 570,218 of which remain outstanding at December 31, 2015. During 2015 and 2014, IEnova paid cash of $4 million and $3 mil lion, respectively, to settle vested awards. No awards vested in 2013. SHARE - BASED AWARDS AND COMPENSATION EXPENSE W e measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant . We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for non-qualified stock options and restricted stock and stock units on a straight-line b asis over the requisite service period of the award, which is generally three or four years. However, in the year that an employee becomes eligible for retirement, the remaining expense related to the employee’ s awards is recognized immediately. Substantia lly all awards outstanding are classified as equity instruments; therefore, we recognize additional paid in capital as we recognize the compensation expense associated with the awards. At December 31, 20 15 , 6,148,009 shares were authorized and available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. Total share-based compensation expense for all of Sempra Energy’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE – SEMPRA ENERGY CONSOLIDATED (Dollars in millions, except per share amounts) Years ended December 31, 2015 2014 2013 Share-based compensation expense, before income taxes $ 48 $ 46 $ 38 Income tax benefit (19) (18) (15) Share-based compensation expense, net of income taxes $ 29 $ 28 $ 23 Net share-based compensation expense, per common share Basic $ 0.12 $ 0.11 $ 0.09 Diluted $ 0.12 $ 0.11 $ 0.09 Sempra Energy Consolidated’s capitalized share-based compensation cost was $6 million in 2015, $5 million in 2014 and $4 million in 2013 . We classify t he tax benefits resulting from tax deductions in excess of tax benefit s related to the co mpensation cost recognized for stock option exercises and the vesting of restricted stock and related dividend equivalents as financing cash flows. There was $52 million in realized tax benefits for share-based payment award deductions in 2015 over and above the $19 million income tax benefit shown above. Sempra Energy subsidiaries record an expense for the plans to the extent that subsidiary employees participate in the plans and/or the subsidiaries are allocated a portion of the Sempra Energy plans’ corporat e staff costs. Expenses and capitalized compensation cost s recorded by SDG&E and SoCalGas were as follows: SHARE-BASED COMPENSATION EXPENSE – SDG&E AND SOCALGAS (Dollars in millions) Years ended December 31, 2015 2014 2013 SDG&E: Compensation expense $ 8 $ 8 $ 8 Capitalized compensation cost 4 3 3 SoCalGas: Compensation expense $ 10 $ 8 $ 8 Capitalized compensation cost 2 2 1 SEMPRA ENERGY NON - QUALIFIED STOCK OPTIONS We use a Black-Scholes option-pricing model (Black-Scholes model) to estimate the fair value of each non-qualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on the historical volatility of Sempra Energy’s stock price . We base the average expected life for options on the contractual term of the option and expected employee exercise and post-terminat ion behavior. The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected life assumed at the date of the grant. No new options were granted in 2015, 2014 or 2013. The following table shows a summary of n on-qualified stock options at December 31, 20 15 and activity for the year then ended: NON-QUALIFIED STOCK OPTIONS Weighted- Weighted- average Shares average remaining Aggregate under exercise contractual term intrinsic value option price (in years) (in millions) Outstanding at January 1, 2015 757,412 $ 53.84 Exercised (227,815) $ 54.48 Forfeited/canceled (1,600) $ 36.30 Outstanding at December 31, 2015 527,997 $ 53.62 2.6 $ 21 Vested at December 31, 2015 527,997 $ 53.62 2.6 $ 21 Exercisable at December 31, 2015 527,997 $ 53.62 2.6 $ 21 The aggregate intrinsic value at December 31, 20 15 is the total of the difference between Sempra Energy’s closing stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for non-qualified stock options exercised in the last three years was $12 million in 2015 $33 million in 2014 $4 1 million in 2013 All outstanding stock options were fully vested at December 31, 2014. The total fair value of shares vested i n 2014 and 2013 was $1 million and $2 million, respectively. We received cash of $12 million from option exercises during 20 15 . SEMPRA ENERGY RESTRICTED STOCK AWARDS AND UNITS We use a Monte-Carlo simulation model to estimate the fair value of the restricted stock awards and units. Our determination of fair value is affected by the historical volatility of the stock price and the dividend yields for Sempra Energy and its peer group companies. The valuation also is affected by the risk-free rates of return, and a number of other variables. Below are key assumptions for awards granted in 2015, 2014 and 2013 for Sempra Energy: 2015 2014 2013 Risk-free rate of return 1.1 % 1.2 % 0.6 % Annual dividend yield(1) N/A N/A 3.3 Stock price volatility 14 16 19 (1) Annual dividend yield was not used in valuations performed in 2015 or 2014. Restricted Stock Awards We provide below a summary of Sempra Energy ’s restricted stock awards at December 31, 20 15 and the activity during the year. RESTRICTED STOCK AWARDS Weighted- average grant-date Shares fair value Nonvested at January 1, 2015 9,238 $ 63.81 Vested (7,701) $ 61.41 Nonvested at December 31, 2015 1,537 $ 75.87 Expected to vest at December 31, 2015 1,537 $ 75.87 T otal compensation cost related to nonvested restricted stock awards not yet recognized as of December 31, 20 1 5 is negligible . No restricted stock awards were granted in 2015 or 2014. The weighted-average per-share fair value for restricted stock awards grant ed in 2013 was $75.82 . The total fair value of shares vested in the last three years was $1 million in each of 2015 , 2014 and 2013 . Restricted Stock Units We provide below a summary of Sempra Energy’s restricted stock units as of December 31, 20 15 and the activity during the year. RESTRICTED STOCK UNITS Performance-based Service-based restricted stock units(1) restricted stock units Weighted- Weighted- average average grant-date grant-date Units fair value Units fair value Nonvested at January 1, 2015 2,874,942 $ 54.55 303,237 $ 73.41 Granted 438,318 $ 123.30 72,835 $ 111.43 Vested (1,036,645) $ 42.34 (25,000) $ 88.71 Forfeited (4,940) $ 103.58 (2,266) $ 90.48 Nonvested at December 31, 2015(2) 2,271,675 $ 73.28 348,806 $ 80.14 Expected to vest at December 31, 2015 2,220,408 $ 72.89 338,086 $ 79.81 (1) Includes restricted stock units issued in 2015 in connection with the creation of Cameron LNG JV. (2) Each unit represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based restricted stock units, except for those issued in connection with the creation of Cameron LNG JV, up to an additional 50 percent (100 percent for awards granted during or after 2014) of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions. The total fair value of shares vested was $46 million in 2015 and $33 million in each of 2014 and 2013. The $ 39 million of total compensation cost related to nonvested restricted stock units not yet recognized as of December 31, 20 15 is expected to be recognized over a weighted-average period of 1.9 years. The weighted-average per-share fair values for performance-based restricted stock units granted were $88.01 and $57.55 in 2014 and 2013, respectively. The weighted-average per-share fair values for service-based restricted stock units granted were $91.54 and $72.71 in 2014 and 2013, respectively.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Derivative Financial Instruments	NOTE 9. DERIVATIVE FINANCIAL INSTRUMENTS We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines i n anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated reven ues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignate d. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (loss) (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Consolidated St atements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accou nting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetti ng the risk that the future cash flows of a given revenue or expense item may vary, and other criteria. We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest r ate to a variable rate. The combination of the derivative and debt instrument results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical loca tions where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed pri ce natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting acti vity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Co nsolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. SDG&E is allocated and may purchase congestion revenue rights (CRRs), which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are r ecorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations . Sempra Mexico and Sempra Natural Gas may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: LNG, natural gas transportation, power generation, and Sempra Natural Gas’ storage. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico also uses natural gas energy derivatives with the objective of managing price risk and lowering n atural gas prices at its Mexican distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Consolidated Statements o f Operations. From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel . We summarize net energy derivative volumes at December 31, 2015 and 2014 as follows : NET ENERGY DERIVATIVE VOLUMES December 31, Segment and Commodity 2015 2014 California Utilities: SDG&E: Natural gas 70 million MMBtu (1) 55 million MMBtu Electricity 1 million MWh (2) ― Congestion revenue rights 36 million MWh 27 million MWh SoCalGas – natural gas 1 million MMBtu 1 million MMBtu Energy-Related Businesses: Sempra Natural Gas – natural gas 43 million MMBtu 29 million MMBtu (1) Million British thermal units (2) Megawatt hours In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the phys ical locations of contractual obligations and assets, such as natural gas purchases and sales . INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We utiliz e interest rate swaps typically designated as fair value hedges, as a means to achieve our targeted level of variable rate debt as a percent of total debt. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock i n interest rates on outstanding debt or in anticipation of future financings. Interest rate derivatives are utilized by the California Utilities as well as by other Sempra Energy subsidiaries. Interest rate derivatives are generally accounted for as hedges , and although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes. At December 31, 2015 and 2014, the net notional amounts of our interest rate derivatives, excluding the cross-currency swaps discussed below, were: INTEREST RATE DERIVATIVES (Dollars in millions) December 31, 2015 December 31, 2014 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges(1) $ 384 2016-2028 $ 399 2015-2028 Fair value hedges 300 2016 300 2016 SDG&E: Cash flow hedge(1) 315 2016-2019 325 2015-2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. FOREIGN CURRENCY DERIVATIVES We are exposed to exchange rate movements at our Mexican subsidiaries, which have U.S. dollar denominated cash balances, receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. These subsidiaries also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated into U.S. dollars for financial reporting purposes. We utilize fo reign currency derivatives at our subsidiaries and at the consolidated level as a means to manage the risk of exposure to significant fluctuations in our income tax expense from these impacts. We also utilize cross-currency swaps to hedge exposure rela ted to Mexican peso-denominated debt at our Mexican subsidiaries and joint ventures. In addition, Sempra South American Utilities uses foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. W e discuss such swaps at Chilquinta Energía’s Eletrans joint venture investment in Note 4. FINANCIAL STATEMENT PRESENTATION Each Consolidated Balance Sheet reflects the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Consolidated Balance Sheets at December 31, 2015 and 2014, including the amount of cash collateral receivables that were not offset, as the cash collateral is in excess of liability positions DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2015 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Investments Fixed-price Fixed-price contracts and other contracts contracts and other assets: and other and other derivatives(1) Sundry derivatives(2) derivatives Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 4 $ 1 $ (15) $ (156) Commodity contracts not subject to rate recovery 13 ― ― ― Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 245 32 (239) (21) Associated offsetting commodity contracts (232) (20) 232 20 Associated offsetting cash collateral (6) ― 4 ― Commodity contracts subject to rate recovery 28 49 (61) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 50 60 (49) (193) Additional cash collateral for commodity contracts not subject to rate recovery 2 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 28 ― ― ― Total(4) $ 80 $ 60 $ (49) $ (193) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (14) $ (23) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery ― ― (1) ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 27 49 (60) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 25 47 (44) (59) Additional cash collateral for commodity contracts not subject to rate recovery 1 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 27 ― ― ― Total(4) $ 53 $ 47 $ (44) $ (59) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery $ ― $ ― $ (1) $ ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 1 ― (1) ― Net amounts presented on the balance sheet 1 ― (1) ― Additional cash collateral for commodity contracts subject to rate recovery 1 ― ― ― Total $ 2 $ ― $ (1) $ ― (1) Included in Current Assets: Other for SoCalGas. (2) Included in Current Liabilities: Other for SoCalGas. (3) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (4) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2014 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Investments Fixed-price Fixed-price contracts and other contracts contracts and other assets: and other and other derivatives(1) Sundry derivatives(2) derivatives Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 10 $ 3 $ (17) $ (109) Commodity contracts not subject to rate recovery 25 ― ― ― Derivatives not designated as hedging instruments: Interest rate instruments 8 27 (7) (22) Commodity contracts not subject to rate recovery 143 32 (135) (29) Associated offsetting commodity contracts (129) (27) 129 27 Associated offsetting cash collateral (11) ― ― ― Commodity contracts subject to rate recovery 36 76 (36) (20) Associated offsetting commodity contracts (3) (1) 3 1 Associated offsetting cash collateral ― ― 23 13 Net amounts presented on the balance sheet 79 110 (40) (139) Additional cash collateral for commodity contracts subject to rate recovery 14 ― ― ― Total(4) $ 93 $ 110 $ (40) $ (139) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (16) $ (31) Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery 32 76 (32) (20) Associated offsetting commodity contracts ― (1) ― 1 Associated offsetting cash collateral ― ― 23 13 Net amounts presented on the balance sheet 32 75 (25) (37) Additional cash collateral for commodity contracts subject to rate recovery 12 ― ― ― Total(4) $ 44 $ 75 $ (25) $ (37) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ ― $ (4) $ ― Associated offsetting commodity contracts (3) ― 3 ― Net amounts presented on the balance sheet 1 ― (1) ― Additional cash collateral for commodity contracts subject to rate recovery 2 ― ― ― Total $ 3 $ ― $ (1) $ ― (1) Included in Current Assets: Other for SoCalGas. (2) Included in Current Liabilities: Other for SoCalGas. (3) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (4) Normal purchase contracts previously measured at fair value are excluded. The effects of derivative instruments designated as hedges on the Consolidated Statement s of Operations and in Other Comprehensive Income (Loss) (OCI) and Accumulated Other Comprehensive Income (Loss) (AOCI) for the years ended December 31 were : FAIR VALUE HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Years ended December 31, Location 2015 2014 2013 Sempra Energy Consolidated: Interest rate instruments Interest Expense $ 6 $ 8 $ 8 Interest rate instruments Other Income, Net (5) (3) (7) Total (1) $ 1 $ 5 $ 1 (1) There was no hedge ineffectiveness in 2015 or 2013. There were gains of $9 million from hedge ineffectiveness in 2014. All other changes in the fair value of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt and recorded in Other Income, Net. CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax (loss) gain Pretax (loss) gain reclassified recognized in OCI from AOCI into earnings (effective portion) (effective portion) Years ended December 31, Years ended December 31, 2015 2014 2013 Location 2015 2014 2013 Sempra Energy Consolidated: Interest rate and foreign exchange instruments(1) $ (18) $ (24) $ 1 Interest Expense $ (18) $ (21) $ (11) Gain on Sale of Equity Interest rate instruments ― 3 ― Interests and Assets ― 3 ― Equity Earnings, Interest rate instruments (80) (127) 15 Before Income Tax (12) (10) (10) Equity Earnings, Interest rate instruments (20) ― ― Net of Income Tax (13) ― ― Commodity contracts not Revenues: Energy-Related subject to rate recovery 12 19 (4) Businesses 14 8 1 Total(2) $ (106) $ (129) $ 12 $ (29) $ (20) $ (20) SDG&E: Interest rate instruments(1)(3) $ (6) $ (9) $ 8 Interest Expense $ (12) $ (11) $ (9) SoCalGas: Interest rate instrument(3) $ ― $ ― $ ― Interest Expense $ (1) $ (1) $ (1) (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. (2) There was $2 million, $1 million and $1 million of losses from ineffectiveness related to these cash flow hedges in 2015, 2014 and 2013, respectively. (3) There was negligible hedge ineffectiveness related to these cash flow hedges at SDG&E and SoCalGas in 2015, 2014 and 2013. For Sempra Energy Consolidated, we expect that losses of $16 million, which are net of income tax benefit, that are currently recorded in AOCI (including $12 million in noncontrolling interests, substantially all of which is related to Otay Mesa VIE at SDG&E) related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivativ e contracts that are currently outstanding mature. SoCalGas expects that negligible losses, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve month s as the hedged items affect earnings. For all forecasted transactions, the maximum term over which we are hedging exposure to the variability of cash flows at December 31, 2015 is approximately 13 years and 3 years for Sempra Energy Consolidated and SDG&E , respectively. The maximum remaining term of hedged interest rate variability related to debt at equity method investees is 20 years. The effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations for the year s ended December 31 were: UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Years ended December 31, Location 2015 2014 2013 Sempra Energy Consolidated: Interest rate and foreign exchange instruments Other Income, Net $ (4) $ (24) $ 17 Foreign exchange instruments Equity Earnings, Net of Income Tax (4) (5) (4) Commodity contracts not subject Revenues: Energy-Related to rate recovery Businesses 42 17 (1) Commodity contracts not subject Cost of Natural Gas, Electric to rate recovery Fuel and Purchased Power ― 3 ― Commodity contracts not subject to rate recovery Operation and Maintenance (1) (4) 1 Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power (126) (10) 53 Commodity contracts subject to rate recovery Cost of Natural Gas 1 ― ― Total $ (92) $ (23) $ 66 SDG&E: Commodity contracts not subject to rate recovery Operation and Maintenance $ ― $ (1) $ ― Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power (126) (10) 53 Total $ (126) $ (11) $ 53 SoCalGas: Commodity contracts not subject to rate recovery Operation and Maintenance $ (1) $ (2) $ 1 Commodity contracts subject to rate recovery Cost of Natural Gas 1 ― ― Total $ ― $ (2) $ 1 CONTINGENT FEATURES For Sempra Energy Consolidated and SDG&E, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these der ivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. For Sempra Energy Consolidated, the total fair value of this group of derivative instruments in a net liability position at December 31, 2015 and 2014 is $ 6 million and $9 million, respectively. At December 31, 2015, if the credit ratings of Sempra Energy were reduced below investment grade, $6 million of additional assets could be required to be posted as collateral for these derivative co ntracts. For SDG&E, the total fair value of this group of derivative instruments in a net liability position at December 31, 2015 and 2014 is $ 5 million and $2 million, respectively. At December 31, 2015, if the credit ratings of SDG&E were reduced below i nvestment grade, $6 million of additional assets could be required to be posted as collateral for these derivative contracts. For Sempra Energy Consolidated, SDG&E and SoCalGas , some of our derivative contracts contain a provision that would permit the cou nterparty, in ce rtain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above .

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Fair Value Measurements	NOTE 1 0 . F AIR VALUE MEASUREMENTS Recurring Fair Value Measures The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2015 and 2014. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valu ation of fair value assets and liabilities, and their placement within the fair value hierarchy levels. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 9 under “Finan cial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash d eposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2015 and 2014 in the tables below include the following: Nuclear decommissioning trusts re flect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances. A third party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other i ndependent data sources. Equity and certain debt securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Ot her debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corro borated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard m odels that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long -term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.” Rabbi Trust i nvestments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identica l security is traded (Level 1). Investments in marketable securities at December 31, 2015 and 2014 were negligible. There were no transfers into or out of Level 1, Level 2 or Level 3 for Sempra Energy Consolidated , SDG&E or SoCalGas during the periods pre sented , nor any changes in valuation techniques used in recurring fair value measurements. RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Interest rate and foreign exchange instruments ― 5 ― ― 5 Commodity contracts not subject to rate recovery 22 16 ― (4) 34 Commodity contracts subject to rate recovery ― 1 72 28 101 Total $ 688 $ 404 $ 72 $ 24 $ 1,188 Liabilities: Interest rate and foreign exchange instruments $ ― $ 171 $ ― $ ― $ 171 Commodity contracts not subject to rate recovery 5 3 ― (4) 4 Commodity contracts subject to rate recovery ― 68 53 (54) 67 Total $ 5 $ 242 $ 53 $ (58) $ 242 Fair value at December 31, 2014 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 655 $ ― $ ― $ ― $ 655 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 47 ― ― 109 Municipal bonds ― 129 ― ― 129 Other securities ― 207 ― ― 207 Total debt securities 62 383 ― ― 445 Total nuclear decommissioning trusts(2) 717 383 ― ― 1,100 Interest rate and foreign exchange instruments ― 48 ― ― 48 Commodity contracts not subject to rate recovery 28 16 ― (11) 33 Commodity contracts subject to rate recovery ― 1 107 14 122 Total $ 745 $ 448 $ 107 $ 3 $ 1,303 Liabilities: Interest rate and foreign exchange instruments $ ― $ 155 $ ― $ ― $ 155 Commodity contracts not subject to rate recovery 3 9 ― (4) 8 Commodity contracts subject to rate recovery ― 52 ― (36) 16 Total $ 3 $ 216 $ ― $ (40) $ 179 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. (2) Excludes cash balances and cash equivalents. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Commodity contracts not subject to rate recovery ― ― ― 1 1 Commodity contracts subject to rate recovery ― ― 72 27 99 Total $ 666 $ 382 $ 72 $ 28 $ 1,148 Liabilities: Interest rate instruments $ ― $ 37 $ ― $ ― $ 37 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 67 53 (54) 66 Total $ 1 $ 104 $ 53 $ (55) $ 103 Fair value at December 31, 2014 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 655 $ ― $ ― $ ― $ 655 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 47 ― ― 109 Municipal bonds ― 129 ― ― 129 Other securities ― 207 ― ― 207 Total debt securities 62 383 ― ― 445 Total nuclear decommissioning trusts(2) 717 383 ― ― 1,100 Commodity contracts subject to rate recovery ― ― 107 12 119 Total $ 717 $ 383 $ 107 $ 12 $ 1,219 Liabilities: Interest rate instruments $ ― $ 47 $ ― $ ― $ 47 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 51 ― (36) 15 Total $ 1 $ 98 $ ― $ (37) $ 62 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. (2) Excludes cash balances and cash equivalents. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Commodity contracts subject to rate recovery $ ― $ 1 $ ― $ 1 $ 2 Total $ ― $ 1 $ ― $ 1 $ 2 Liabilities: Commodity contracts not subject to rate recovery $ 1 $ ― $ ― $ (1) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 1 $ 1 $ ― $ (1) $ 1 Fair value at December 31, 2014 Level 1 Level 2 Level 3 Netting(1) Total Assets: Commodity contracts subject to rate recovery $ ― $ 1 $ ― $ 2 $ 3 Total $ ― $ 1 $ ― $ 2 $ 3 Liabilities: Commodity contracts not subject to rate recovery $ 2 $ ― $ ― $ (2) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 2 $ 1 $ ― $ (2) $ 1 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. Level 3 Information The following table sets forth reconciliations of changes in the fair value of congestion revenue r ights (CRRs) and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E: LEVEL 3 RECONCILIATIONS (Dollars in millions) Years ended December 31, 2015 2014 2013 Balance at January 1 $ 107 $ 99 $ 61 Realized and unrealized (losses) gains (134) 15 11 Allocated transmission instruments 12 19 51 Settlements 34 (26) (24) Balance at December 31 $ 19 $ 107 $ 99 Change in unrealized (losses) gains relating to instruments still held at December 31 $ (27) $ 8 $ 11 SDG&E’s Energy and Fuel Procurement department , in conjunction with SDG&E’s finance group, is responsible for determining the appropriate fair value methodolo gies used to value and classify CRRs and long-term, fixed-price electricity positions on an ongoing basis . Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness . SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction pric es published by the California ISO , an objective sou rce. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instrume nts are classified as Level 3 . T he fair value of these instruments is derived from auction price differences between two locations . From Januar y 1, 2015 to December 31, 2015, the auction prices ranged from $(16) per MWh to $8 per MWh at a given location, a nd from January 1, 2014 to December 31, 2014, the auction prices ranged from $(6) per MWh to $12 per MWh at a given location . Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between tw o locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement . We summarize CRR volumes in Note 9. Long-term , fixed-price electricity positions that are valued using significant unobservable data are classified as Lev el 3 because the contract terms relate to a delivery location or tenor for which observable market r ate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs . At December 31, 2015, these inputs range from $21.45 per MWh to $60.05 per MWh. A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. Realized gains and losses associated with CRRs and long-term electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. Derivative Positions Net of Cash Collateral Each Consolidated Balance Sheet reflects the offsetting of net derivative positions with fair value amounts for cash collateral with the same counterparty when a legal right of offset exists. The following table provides the amount of fair value of cash collateral receivables that were not offset in the Consolidated Balance Sheets a t December 31, 2015 and 2014 : December 31, (Dollars in millions) 2015 2014 Sempra Energy Consolidated $ 30 $ 14 SDG&E 28 12 SoCalGas 1 2 Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, current amounts due to/from unconsolidated affiliates, dividends and accounts pa yable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance R estoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The follow ing table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Consolidated Balance Sheets at December 31: FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) December 31, 2015 Carrying Fair Value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 175 $ ― $ 97 $ 69 $ 166 Total long-term debt (2)(3) 13,761 ― 13,985 648 14,633 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,304 $ ― $ 4,355 $ 315 $ 4,670 SoCalGas: Total long-term debt (5) $ 2,513 $ ― $ 2,621 $ ― $ 2,621 Preferred stock 22 ― 25 ― 25 December 31, 2014 Carrying Fair Value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 184 $ ― $ 132 $ 38 $ 170 Total long-term debt (2)(3) 12,347 ― 12,782 917 13,699 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,461 $ ― $ 4,563 $ 425 $ 4,988 SoCalGas: Total long-term debt (5) $ 1,913 $ ― $ 2,124 $ ― $ 2,124 Preferred stock 22 ― 25 ― 25 (1) Excluding accumulated interest outstanding of $11 million and $4 million at December 31, 2015 and 2014, respectively. (2) Before reductions for unamortized discount (net of premium) and debt issuance costs of $107 million and $102 million at December 31, 2015 and 2014, respectively, and excluding build-to-suit and capital leases of $387 million and $310 million at December 31, 2015 and 2014, respectively. We discuss our long-term debt in Note 5. (3) Level 3 instruments include $315 million and $325 million at December 31, 2015 and 2014, respectively, related to Otay Mesa VIE. (4) Before reductions for unamortized discount and debt issuance costs of $43 million and $47 million at December 31, 2015 and 2014, respectively, and excluding capital leases of $244 million and $234 million at December 31, 2015 and 2014, respectively. (5) Before reductions for unamortized discount and debt issuance costs of $24 million and $23 million at December 31, 2015 and 2014, respectively, and excluding capital leases of $1 million at both December 31, 2015 and 2014. We base the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other noncurrent amounts due from unconsolidated affiliates of our South American Utilities using a perpetuity approach based on the obligation’s fixed interest rate, the absence of a stated maturity date and a discount rate reflecting local borrowing cost s (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3). We provide the fair values for the securities held in the nuclear decommissioning trust funds related to SONGS in Note 13 below. Non-Recurring Fair Value Measures – Sempra Energy Consolidated Energía Sierra Juárez In July 2014, Sempra Mexico completed the sale of a 50-percent interest in the 155-MW first phase of its Energía Sierra Juárez wind project to a wholly owned subsidiary of InterGen N.V. for cash proceeds of $24 million, net of $2 million cash sold, as discussed in Note 3. Sempra Mexico recognized a pretax gain on the sale of $19 million ($ 14 million after-tax). Upon deconsolidati on, our equity method investment in Energía Sierra Juárez was measured at fair value, which resulted in a $7 million after-tax gain attributable to a remeasurement of the retained investment to fair value. The fair value measurement was based on the cash s ales price of $26 million paid by InterGen N.V., a nonrelated party and market participant. Use of this market participant input as the indicator of fair value is a Level 2 measurement in the fair value hierarchy . The following table summarizes significa nt inputs impacting non-recurring fair value measures related to our investment in Energía Sierra Juárez : NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Estimated Fair % of Inputs used to fair value Fair value develop Range of value Valuation technique hierarchy measurement measurement inputs Investment in Energía Sierra Juárez $ 26 (1) Market approach Level 2 100% Equity sale offer price 100% (1) At measurement date of July 16, 2014. At December 31, 2015, our investment in Energía Sierra Juárez had a carrying value of $30 million, reflecting subsequent equity method activity to record distributions and earnings.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Preferred Stock	NOTE 11 . PREFERRED STOCK The table below shows the details of p referred stock for SoCalGas . All series of SDG&E preferred stock were redeemed during 2013 as we discuss below. PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2015 2014 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 SoCalGas - Total preferred stock 22 22 Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises (2) (2) Sempra Energy - Total preferred stock of subsidiary $ 20 $ 20 F ollowing are the attributes of each company’s preferred stock. No shares currently outstanding are subject to mandatory redemption. SOCALGAS None of SoCalGas’ outstandi ng preferred stock is callable. All outstanding series have one vote pe r share, cumulative preferences as to dividends and liquidation preferences of $25 per s hare plus any unpaid dividends. SoCalGas currently is also authorized to issue 5 million shares of series preferred stock and 5 million shares of preference stock, both without par value and with cumulative prefe rences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock. Other rights and privileges of any new series of such s tock would be established by the board of directors at the time of issuance. SDG&E In October 2013, SDG&E redeemed all six series of its outstanding shares of contingently redeemable preferred stock for $82 million, including a $3 million early call premium. Each series was redeemed for cash at redemption prices ranging from $20.25 to $26 per share plus accrued dividends up to the redemption date of $1 million. The early call premium is presented as Call Premium on Preferred Stock of Subsidiary on Sempra Energy’s and Call Premium on Preferred Stock on SDG&E’s Consolidated Statements of Operations. The shares are no longer outstanding. SDG&E is currently authorized to issue up to 45 million shares of preferred stock. The rights, preferences, privileges and restrictions for any new series of pref erred stock would be established by the board of directors at the time of issuance.

SHAREHOLDERS' EQUITY AND EARNIN

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Shareholders' Equity And Earnings Per Share	NOTE 12 . SEMPRA ENERGY – SHAREHOLDERS ’ EQUITY AND EARNINGS PER SHARE The following table provides the per share computations for our earnings for years ended December 31 , 2015 , 2014 and 2013 . Basic EPS is calculated by dividing earnings attributable to common stock by the weighted-average number of common shares outstanding for the year. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock. EARNINGS PER SHARE COMPUTATIONS AND DIVIDENDS DECLARED (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2015 2014 2013 Numerator: Earnings/Income attributable to common shares $ 1,349 $ 1,161 $ 1,001 Denominator: Weighted-average common shares outstanding for basic EPS(1) 248,249 245,891 243,863 Dilutive effect of stock options, restricted stock awards and restricted stock units 2,674 4,764 5,469 Weighted-average common shares outstanding for diluted EPS 250,923 250,655 249,332 Earnings per share: Basic $ 5.43 $ 4.72 $ 4.10 Diluted $ 5.37 $ 4.63 $ 4.01 Dividends declared per share of common stock $ 2.80 $ 2.64 $ 2.52 (1) Includes fully vested restricted stock units held in our Deferred Compensation Plan of 491 in 2015, 212 in 2014 and none in 2013. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued. The dilution from common stock options is based on the treasury stock method. Under this method, proceeds based on the exercise price plus unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits are tax deductions we would receive upon the assumed exercise of stock options in excess of the deferred income taxes we recorded related to the c ompensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation of dilutive common stock equivalents excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). During 2015, 2014 and 2013, we had no such antidilutive stock options outstanding and no stock options outstanding that were antidilutive because of the unearned compen sation and windfall tax benefits included in the assumed proceeds under the treasury stock method. The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Proceeds equal to the unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, related to the awards and units are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefi ts or tax shortfalls recognized are the difference between tax deductions we would receive upon the assumed vesting of RSAs or RSUs and the deferred income taxes we recorded related to the compensation expense on such awards and units. There were no antidi lutive RSAs from the application of unearned compensation in the treasury stock method during 2015, 2014 or 2013. There were 722; 4, 087 and no such antidilutive RSUs during 2015, 2014 and 2013, respectively. Our performance-based RSUs include awards that vest at the end of three-year (for awards granted in 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. We primarily use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies to develop our EPS RSU targets. TSR RSUs represent the right to receive from zero to 1.5 shares (2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate. Our RSAs, which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above. We include RSAs and these RSUs in potential dilutive shares at 100 percent, subject to the application of the treasury stock method. We includ e our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of bo th Sempra Energy stock and the comparative indices, dilutive TSR RSU shares may vary widely from period-to-period. If it were assumed that performance goals for all performance-based RSUs were met at maximum levels and if the treasury stock method were not applied to any of our RSAs or RSUs, the incremental potential dilutive shares would be 1,968,062; 949,351 and 641,751 for the years ended December 31, 2015, 2014 and 2013, respectively. We are authorized to issue 750,000,000 shares of no-par value common stock. In addition, we are authorized to issue 50,000,000 shares of preferred stock having rights, preferences and privileges that would be established by the Sempra Energy board of directors at the time of issuance. C ommon stock activity consisted of the following: COMMON STOCK ACTIVITY Years ended December 31, 2015 2014 2013 Common shares outstanding, January 1 246,330,884 244,461,327 242,368,836 Restricted stock units vesting(1) 1,499,062 989,027 1,491,170 Stock options exercised 227,815 699,783 1,237,348 Savings plan issuance 652,631 398,042 ― Common stock investment plan(2) 249,665 205,203 ― Restricted stock issuances ― ― 21,121 Shares repurchased(3) (661,977) (422,498) (657,148) Common shares outstanding, December 31 248,298,080 246,330,884 244,461,327 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) From time to time, we purchase shares of our common stock from long-term incentive plan participants who elect to sell to us a sufficient number of vested restricted shares or units to meet minimum statutory tax withholding requirements. Our board of directors has the discretion to determine the payment and amount of future dividends.

NUCLEAR PLANT

NUCLEAR PLANT	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Nuclear Plant	NOTE 13. SAN ONOFRE NUCLEAR GENERATING STATION (SONGS) SDG&E has a 20-percent ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which ceased operations in June 2013. On June 6, 2013, Southern California Edison Company (Edison), the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the Nuclear Regulatory Commission (NRC) to start the decommissioning activities for the entire faci lity. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of expenses and capital expendit ures. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. SONGS Steam Generator Replacement Project As part of the Steam Generator Replacement Project (SGRP), the steam generators were repl aced in SONGS Units 2 and 3, and the Units returned to service in 2010 and 2011, respectively. Both Units were shut down in early 2012 after a water leak occurred in the Unit 3 steam generator. Edison concluded that the leak was due to unexpected wear from tube-to-tube contact. At the time the leak was identified, Edison also inspected and tested Unit 2 and subsequently found unexpected tube wear in Unit 2’s steam generator. These issues with the steam generators ultimately resulted in Ed i son’s decision to permanently retire SONGS . The replacement steam generators were designed and provided by Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). In July 2013, SDG&E filed a lawsuit against MHI seeking to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators. In October 2013, Edison instituted arbitration proceedings against MHI seeking damages as well. SDG&E is participatin g in the arbitration as a claimant and respondent. We discuss these proceedings in Note 15. Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII) SONGS OII In November 2012, in response to the ou tage, the CPUC issued the SONGS OII, pursuant to California Public Utilities’ Code Section 455.5, which applies to cost recovery issues resulting from long-term outages of operating assets. The SONGS OII consolidated most SONGS outage-related issues into a single proceeding. The SONGS OII, among other things, designated all revenues associated with the investment in, and operation of, SONGS since January 1, 2012 as subject to refund to customers, pending the outcome of all phases of the proceeding. The SONG S OII proceeding was intended to determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outage, including purchased replacement power costs, which are typically recovered through the Energy Resource Recovery Account (ERRA). Entry Into Settlement Agreement Pursuant to CPUC rules concerning settlements, SDG&E, Edison, The Utility Reform Network (TURN), and the CPUC Office of Ratepayer Advocates (ORA) held a settlement conference in March 2014 to discu ss the terms to resolve the SONGS OII, and in April 2014, SDG&E, along with Edison, TURN, the ORA and two other intervenors who joined the Settlement Agreement to the SONGS OII proceeding (collectively, the Settling Parties), filed a Settlement Agreement w ith the CPUC. On September 5, 2014, the CPUC issued a ruling proposing specific changes that included, as they relate to SDG&E, greater ratepayer benefit from third party cost recoveries and funding of a research program to reduce greenhouse gas emissions at a shareholder cost of $1 million per year for 5 years. On September 23, 2014, the Settling Parties executed an Amended and Restated Settlement Agreement (Amended Settlement Agreement), which amended the Settlement Agreement to adopt all of the modifica tions and clarifications requested in the CPUC ruling. On October 9, 2014, the CPUC issued a proposed decision approving the Amended Settlement Agreement, which was adopted by the CPUC as a final decision on November 20, 2014. As approved by the CPUC, the Amended Settlement Agreement constitutes a complete and final resolution of the SONGS OII and related CPUC proceedings regarding the SGRP at SONGS and the related outage and subsequent shutdown of SONGS. This resolution also required the compliance filing referenced below under “Accounting and Financial Impacts.” The Amended Settlement Agreement does not affect on-going or future proceedings before the NRC, or litigation or arbitration related to potential future recoveries from third parties (except for th e allocation to ratepayers of any recoveries as described below) or proceedings addressing decommissioning activities and costs. In November 2014, in accordance with the Amended Settlement Agreement, SDG&E filed an advice letter seeking authority from the CPUC, among other things, to implement the terms and establish the revenue requirement in accordance with the Amended Settlement Agreement in rates starting January 1, 2015. In December 2014, the CPUC approved the advice letter and authorized SDG&E to upda te rates accordingly , subject to revision pending the results of a CPUC review of the changes to the revenue requirement proposed by SDG&E for consistency with the terms of the approved settlement decision. In March 2015, SDG&E received a final disposition letter from the CPUC confirming that SDG&E’s proposed rate changes were in compliance with t he approved settlement decision. The following is a summary of the Amended Settlement Agreement as it relates to SDG&E. Disallowances, Refunds and Rate Recoveries The final decision provided that SDG&E: remove from rate base, as of February 1, 2012, its investment in the SGRP and refund to its customers the amount collected for its investment in and any return on its investment in the SGRP since such date. As of Feb ruary 1, 2012, SDG&E’s net book value in the SGRP was approximately $160 million; be authorized to recover in rates its remaining investment in SONGS, including base plant and construction work in progress, generally over a ten-year period commencing Febr uary 1, 2012, together with a return on investment at a reduced rate equal to: SDG&E’s weighted average return on debt, plus 50 percent of SDG& E’s weighted average return on preferred stock, as authorized in the CPUC’s Cost of Capital proceeding then in effect (collectively, SONGS rate of return or SONGS ROR). This has result ed in a SONGS ROR of 2.35 percent for the period from January 1, 2013 t hrough December 31, 201 5 . The SONGS ROR for future periods will fluctuate based on SDG&E’s authorized weighted average returns on debt and preferred stock in effect for those future periods . The 2.35 percent SONGS ROR will remain in effect through 2017 ; be authorized to recover in rates its recorded 2012 and 2013 operations and maintenance expenses; in addition, SDG&E was authorized to recover in rates the recorded costs for the 2012 refueling outage of Unit 2, subject to customary prudency review; be authorized to recover in rates, subject to a reasonableness review, its 2014 recorded operation and maintenance expenses and non-operating operations and maintenance expenses ; be authorized to recover in rat es its remaining investment in materials and supplies over a ten-year period commencing February 1, 2012, together with a return on investment at the SONGS ROR; be authorized to recover in rates its remaining investment in nuclear fuel inventory and any c osts incurred, or to be incurred, associated with nuclear fuel supply contracts over a ten-year period, together with a return equal to SDG&E’s commercial paper borrowing rate; be authorized to recover in rates through its fuel and purchased power balanci ng account (ERRA), subject to the normal CPUC compliance reviews, all costs incurred to purchase power in the market to replace the power that would have been generated at SONGS if not for the outage and shutdown of SONGS, and to recover by December 31, 20 15 any SONGS-related ERRA undercollections , which amounts have been collected . SDG&E’s replacement power purchase costs through June 6, 2013 (the date of SONGS’ retirement) were approximately $165 million, using the methodology followed in the SONGS OII; a nd have a five-year funding commitment of $1 million per year to the University of California Energy Institute (or other existing University of California entity engaged in energy technology development) to create a Research Development and Demonstration p rogram, whose goal would be to deploy new technologies, methodologies, and /or design modifications to reduce GHG emissions, particularly at current and future generating plants in California. This term was a modification requested by the CPUC. In April 2 015, a petition for modification (PFM) was filed with the CPUC by Alliance for Nuclear Responsibility (A4NR), an intervenor in the SONGS OII proceeding, asking the CPUC to set aside its decision approving the Amended Settlement Agreement and reopen the SON GS OII proceeding. In June 2015, TURN, a party to the Amended Settlement Agreement, filed a response supporting the A4NR petition. TURN does not question the merits of the Amended Settlement Agreement, but is concerned that certain allegations regarding Ed ison raised by A4NR have undermined the public’s confidence in the regulatory process. SDG&E has responded that TURN’s concerns regarding public perception do not impact the reasonableness of the Amended Settlement Agreement and are insufficient to overtur n it. SDG&E is unable to determine what actions the CPUC will take, if any, in response to the A4NR PFM. In August 2015, ORA, also a party to the Amended Settlement Agreement, filed a PFM with the CPUC, withdrawing its support for the Amended Settlement A greement and asking the CPUC to reopen the SONGS OII proceeding. The ORA does not question the merits of the Amended Settlement Agreement, but is concerned with the CPUC’s approach toward recent disclosures concerning Edison ex parte communications with th e CPUC. SDG&E responded that the ORA’s PFM is insufficient to overturn the Amended Settlement Agreement, because the ORA fails to make a case that the Amended Settlement Agreement is no longer in the public interest. SDG&E is unable to determine what actio ns the CPUC will take, if any, in response to the ORA PFM . Accounting and Financial Impacts Through Decem ber 3 1 , 2015, the cumulative after-tax loss from plant closure recorded by Sempra Energy and SDG&E is $12 5 million, including a reduction in the after -tax loss of $13 million recorded in the first quarter of 2015 based on the CPUC’s approval in March 2015 of SDG&E’s compliance filing and establishment of the SONGS settlement revenue requirement , and a reduction in the after-tax loss of $2 million based on a settlement with Nuclear Electric Insurance Limited in the fourth quarter of 2015 , as we discuss below . In the second quarter of 2013, based on an initial assessment of the financial impact of the outcome of the SONGS OII proceeding, SDG&E reported an after-tax loss from plant closure of $119 million. In the first quarter of 2014, after entering into the Settlement Agreement, SDG&E recorded a $9 million increase in the after-tax loss. In the fourth quarter of 2014, based on the compliance filing regardi ng SDG&E’s annual revenue requirement and the timing of refunds to ratepayers, SDG&E recorded a $12 million increase to the after-tax loss. The regulatory asset for the expected recovery of SONGS costs, consistent with the Amended Settlement Agreement, is $2 57 million ($42 million current and $2 15 million long-term) at Dec ember 3 1 , 2015 and is recorded on the Consolidated Balance Sheets in Other Current Assets and Regulatory Assets Noncurrent, respectively, at Sempra Energy, and in Regulatory Assets Curren t and Other Regulatory Assets Noncurrent, respectively, at SDG&E . The amortization period prescribed for the regulatory asset is 10 years, which began on February 1, 2012. However, since the CPUC’s final decision approving the Amended Settlement Agreement was not issued until November 2014, amortization did not commence until January 2015. Settlement with Nuclear Electric Insurance Limited (NEIL) As we discuss in Note 1 5 , NEIL insures domestic and international nuclear utilities for the costs associated wit h interruptions, damages, decontaminations and related nuclear risks. In October 2015, the SONGS co-owners (Edison, SDG&E and the City of Riverside) reached an agreement with NEIL to resolve all of SONGS’ insurance claims arising out of the failures of the replacement steam generators for a total payment by NEIL of $400 million, SDG&E’s share of which is $80 million. Pursuant to the terms of the SONGS OII Amended Settlement Agreement, after reimbursement of legal fees and a 5-percent allocation to sharehold ers, the net proceeds of $75 million were allocated to ratepayers through ERRA. NRC Proceedings In December 2013, Edison received a final NRC Inspection Report that identified a violation for the failure to verify the adequacy of the thermal-hydraulic and flow-induced vibration design of the Unit 3 replacement steam generator. In January 2014, Edison provided a response to the NRC Inspection Report stating that MHI, as contracted by Edison to prepare the SONGS replacement steam generator design, was the par ty responsible for validating the design of the steam generators. In addition, the NRC issued an Inspection Report to MHI containing a Notice of Nonconformance for its flawed computer modeling in the design of the replacement steam generators. Because SONGS has ceased operation, NRC inspection oversight of SONGS will now be continued through the NRC’s Decommissioning Power Reactor Inspection Program to verify that decommissioning activities are being conducted safely, that spent fuel is safely stored on site or transferred to another licensed location, and that the site operations and licensee termination activities conform to applicable regulatory requirements, licensee commitments and management controls. Nuclear Decommissioning and Funding As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison has begun the decommissioning phase of the plant. The process of decommissioning a nuclear power plant is governed by the regulations of various governmental and other agencies, includi ng but not limited to, those of the NRC, the U.S. Department of the Navy (the land owner) and the CPUC. The NRC regulations generally categorize the decommissioning activities into three phases: initial activities, major decommissioning and storage activit ies, and license termination. Initial activities include providing notice of permanent cessation of operations (provided by Edison to the NRC on June 12, 2013) and notice of permanent removal of fuel from the reactor vessels (provided by Edison on June 28 and July 22, 2013 for Units 3 and 2, respectively). Within two years after the cessation of operations, the licensee (Edison) must submit a post-shutdown decommissioning activities report (PSDAR), an irradiated fuel management plan (IFMP) and a site-specif ic decommissioning cost estimate (DCE). Edison submitted each of the PSDAR, the IFMP and the DCE to the NRC in September 2014. In accordance with state and federal requirements and regulations, SDG&E has assets held in trusts, referred to as the Nuclear Decommissioning Trusts (NDT), to fund decommissioning costs for SONGS Units 1, 2 and 3. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work will be done when Units 2 and 3 are decommissioned. At December 31, 201 5, the fair value of SDG&E’s NDT assets was $1.1 billion. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning cos ts for Units 2 and 3. In February 2014, SDG&E filed a request with the CPUC for such authorization for costs incurred in 2013. In April 2015, SDG&E withdrew its pending request and filed a new request based on updated decommissioning cost information, seek ing authorization to access trust funds for up to $55 million in decommissioning costs incurred in 2013. The CPUC authorized the request in July 2015. In August 2015, SDG&E withdrew $37 million of the authorized amount, $34 million of which will be funded to customers through the ERRA balancing account. Another $3 million of the amount withdrawn was used to refund regulatory assets and certain costs pursuant to the SONGS OII Settlement Agreement. The remaining $18 million of the CPUC authorization is expect ed to be withdrawn pending satisfactory clarification by the Internal Revenue Service (IRS) that certain spent fuel costs and other costs are eligible decommissioning costs, payable from qualified nuclear decommissioning trusts. We are uncertain as to when such clarification will be provided. In October 2015, SDG&E filed a request with the CPUC seeking authorization to access trust funds for $36 million for SONGS Units 2 and 3 decommissioning costs incurred in 2014. The CPUC approved the request in Novembe r 2015. In December 2015, SDG&E withdrew $ 23 million of the authorized amount, $19 million of which will be funded to customers through the ERRA balancing account . Another $4 million of the amount withdrawn was used to refund regulatory assets and certain costs pursuant to the SONGS OII Settlement Agreement. The remaining $13 million will be withdrawn pending satisfactory clarification by the IRS, as discussed above. SDG&E will continue to use working capital to pay for any SONGS Units 2 and 3 decommission ing costs incurred, and file periodic requests with the CPUC seeking authorization to access funds for reimbursement from the NDT for incurred decommissioning costs . Nuclear Decommissioning Trusts The amounts collected in rates for SONGS’ decommissioning are invested in externally managed trust funds. Amounts held by the trusts are invested in accordance with CPUC regulations. These trusts are shown on the Sempra Energy and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in Regulatory Liabilities Arising from Removal Obligations. The following table shows the fair values and gross unrealized gains and losses for the securities h eld in the NDT . We provide additional fair value disclosures for the NDT in Note 1 0 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Gross Gross Estimated unrealized unrealized fair Cost gains losses value At December 31, 2015: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 89 $ 2 $ ― $ 91 Municipal bonds (2) 148 8 ― 156 Other securities (2) 194 1 (13) 182 Total debt securities 431 11 (13) 429 Equity securities 214 412 (7) 619 Cash and cash equivalents 15 ― ― 15 Total $ 660 $ 423 $ (20) $ 1,063 At December 31, 2014: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 103 $ 6 $ ― $ 109 Municipal bonds 121 8 ― 129 Other securities 206 7 (6) 207 Total debt securities 430 21 (6) 445 Equity securities 215 444 (4) 655 Cash and cash equivalents 30 1 ― 31 Total $ 675 $ 466 $ (10) $ 1,131 (1) Maturity dates are 2016-2065. (2) Maturity dates are 2016-2115. The following table shows the proceeds f rom sales of securities in the NDT and gross realized gains and losses on those sales. SALES OF SECURITIES (Dollars in millions) Years ended December 31, 2015 2014 2013 Proceeds from sales(1) $ 577 $ 601 $ 685 Gross realized gains 29 11 26 Gross realized losses (15) (11) (18) (1) Excludes securities that are held to maturity. Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification. Ratepayer contribution amounts are determined by the CPUC using estimates of after-tax investment returns, decommissioning costs, and decommissioning cost escalation rates. Changes in investment returns and decommissioning costs may result in a change in fu ture ratepayer contributions. Asset Retirement Obligation and Spent Nuclear Fuel SDG&E ’ s asset retirement obligation related to decommissioning costs for the SONGS units was $ 667 million at December 31, 20 15 . That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complet e the decommissioning of Unit 1, which is substantially complete. The asset retirement obligation at December 31, 2015 is based on an updated cost study prepared in 2014 that reflects the acceleration of the start of decommissionin g Units 2 and 3 as a result of the early closure of the plant. SDG&E’s share of decommissioning costs in 2014 dollars is approximately $937 million, or escalated to 2015 dollars, is $956 million. Unit 1 was permanently shut down in 1992, and physical decom missioning began in January 2000. Most structures, foundations and large components have been dismantled, removed and disposed of. Spent nuclear fuel has been removed from the Unit 1 Spent Fuel Pool and stored on-site in an Independent Spent Fuel Storage I nstallation (ISFSI) licensed by the NRC. The decommissioning of Unit 1 remaining structures (subsurface and intake/di scharge) will take place as Units 2 and 3 are decommissioned. The ISFSI will be decommissioned after a spent fuel storage facili ty becomes available and the U.S. Department of Energy (DOE) removes the spent fuel from the site. The Unit 1 reactor vessel is expected to remain on site until Units 2 and 3 are fully decommissioned. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS un til the DOE accepts it for final disposal. Spent nuclear fu el for Units 2 and 3 has been stored in the SONGS spent fuel pools for each reactor and in the ISFSI . W e provide additional information about SONGS in Note 15.

CALIFORNIA UTILITIES' REGULATOR

CALIFORNIA UTILITIES' REGULATORY MATTERS	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Sempra Utilities' Regulatory Matters	NOTE 14. CALIFORNIA UTILITIES’ REGULATORY MATTERS JOINT MATTERS CPUC General Rate Case (GRC) The CPUC uses a general rate case proceeding to set sufficient rates to allow the California Utilities to recover their reasonable cost of operations and maintenance and to provide the opportunity to realize their authorized rates of return on their investment. 2016 General Rate Case (2016 GRC) The California Utilities filed their 2016 General Rate Case (2016 GRC) applications in November 2014. These filings requested revenue requirement increases of $133 mi llion and $256 million for SDG&E and SoCalGas , respectively, over their 2015 revenue requirements. In September 2015, the California Utilities filed settlement agreements with the CPUC that resolve all material matters related to the proceeding, except fo r the revenue requirement implications of certain income tax benefits associated with flow-through repair allowance tax deductions, discussed below. The settlement agreements are with eight of eleven intervening parties. For SoCalGas , the settlement propos es a total revenue requirement in 2016 of $2.219 billion, which is $133 million less than its original request. The proposed settlement represents an increase of $122 million or 6 percent over the 2015 total revenue requirement , excluding the impact of the 2015 revenue requirement increase discussed below under “ SoCalGas Matters – Increase to CPUC-Authorized Annual Revenue Requirement.” For SDG&E, the settlement proposes a total revenue requirement in 2016 of $1.811 billion, which is $100 million less than its original request (as revised). The proposed settlement represents an increase of $17 million, or one percent over the 2015 total revenue requirement . This increase reflects a $16 million adjustment to the 2015 estimated revenue requirement since the No vember 2014 filings. The filed settlement agreements also call for attrition adjustments of 3.5 percent for both 2017 and 2018. The California Utilities also filed a separate agreement, reached with ORA, proposing that a fourth year (2019) be added to the GRC period, with a revenue requirement increase of 4.3 percent over 2018. Because the 2016 settlement has not been finalized, the California Utilities will collect rates identical to 2015 authorized amounts until a 2016 decision is approved. The settlemen t agreements described above exclude a proposal, for both SDG&E and SoCalGas , regarding certain intra-rate case income tax benefits. The proposal recommends that the CPUC adjust SoCalGas ’ rate base by $92 million and SDG&E’s rate base by $93 million, and a dditionally reduce both utilities’ revenue requirements by amounts currently being tracked in tax memorandum accounts for the year 2015. At December 31, 2015, the pretax balances tracked in these memorandum accounts total $74 million for SoCalGas and $39 m illion for SDG&E. We believe the proposed treatment would violate and contradict long standing rate making and income tax policy, and would represent a material departure from historical practice. If this proposal is adopted, the outcome would reduce the r evenue requirement amounts agreed to in the respective settlement agreements described above. SDG&E and SoCalGas do not expect that the prospective reduction to rate base described above would result in an immediate earnings impact if this proposal is adop ted. However, if this proposal is adopted, the amounts currently being tracked in the tax memorandum accounts for 2015 could result in a material charge against earnings when the draft decision is received . We anticipate all matters to be resolved in the C PUC’s final decision on the 2016 GRC proceeding. We expect the CPUC to issue a final decision in the proceeding in the second quarter of 2016. 2012 General Rate Case (Final 2012 GRC Decision) In May 2013, the CPUC approved a final decision in the Californ ia Utilities’ 2012 GRC. The Final 2012 GRC Decision was effective retroactive to January 1, 2012, and SDG&E and SoCalGas recorded the cumulative earnings effect of the retroactive application of the Final 2012 GRC Decision of $69 million and $37 million, r espectively, in the second quarter of 2013. For SDG&E and SoCalGas , respectively, these amounts included an incremental earnings impact of $52 million and $25 million related to 2012 and $17 million and $12 million related to the first quarter of 2013. Th e amount of revenue associated with the retroactive period was recovered in SDG&E’s rates over a 28-month period beginning in September 2013, and in SoCalGas ’ rates over a 31-month period beginning in June 2013. At December 31, 2014, SDG&E reported on its Consolidated Balance Sheet $162 million as a regulatory asset, all classified as current, representing the retroactive revenue from the Final 2012 GRC Decision recovered by SDG&E in rates in 2015. At December 31, 2014, SoCalGas reported on its Consolidated Balance Sheet a regulatory asset of $52 million, all classified as current, representing the retroactive revenue from the Final 2012 GRC Decision recovered in rates in 2015. CPUC Cost of Capital A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized rate of return on rate base (ROR), which is a weighted average of the authorized returns on debt, preferred stock, and common equity (return on equity or ROE), weighted on a basis consistent with the authorized capital structure. The authorized ROR is the rate that the California Utilities are authorized to use in establishing rates to recover the cost of debt and equity used to finance their investment in CPUC-regulated electric distribution and generation as well as natural gas distribution, transmission and storage assets. In addition, a cost of capital proceeding also addresses the automatic cost of capital adjustment mechanism (CCM ) which applies market-based benchmarks to determine whether an adjustment to the authorized ROR is required during the interim years between cost of capital proceedings. The market-based benchmark for SDG&E’s and SoCalGas ’ CCM is the 12-month average mont hly A-rated utility bond index , as published by Moody’s for the 12-month period of October 1st through September 30th (CCM Period) of each calculation year. In the last cost of capital proceeding, SDG&E’s and SoCalGas ’ CCM benchmark rate was set at 4.24 pe rcent. If at the end of the CCM Period the monthly average benchmark rate falls outside of the established range of 3.24 percent to 5.24 percent, SDG&E’s and SoCalGas ’ authorized ROE would be adjusted, upward or downward, by one-half of the difference betw een the 12-month average and the benchmark rate. In addition, the authorized recovery rate for SDG&E’s and SoCalGas ’ cost of debt and preferred stock would be adjusted to their respective actual weighted average costs, with no change to the authorized capi tal structure. All three adjustments with the new rate would become effective on January 1st of the following year in which the benchmark range was exceeded. For the twelve-month period ended September 30, 201 5 , the 12-month average of monthly Moody’s A-ra ted utility bond index was 4 . 04 percent , which is within the established range of 3.24 percent and 5.24 percent . The CCM only applies during the intervening years between scheduled cost of capital proceedings. In the year the cost of capital proceeding is scheduled, the cost of capital proceeding takes precedence over CCM and will set new rates for the following year. In December 2014, the CPUC granted both SDG&E and SoCalGas an extension of their filing deadlines for their next cost of capital applications by one year, from April 2015 to April 2016. The CPUC also extended the current CCM until the April 2016 filing date. The one year extension was made in response to a joint request by SDG&E, SoCalGas , Pacific Gas and Electric Company (PG&E) and Edison with the CPUC in November 2014. In November 2015, the CPUC granted both SDG&E and SoCalGas an extension of their filing deadlines for one more year to April 2017 . Th is additional extension was made in response to a joint request with the CPUC by SDG&E, SoCalG as , PG&E and Edison. The CPUC also extended the current CCM until the April 201 7 filing date. However, in the event the adjustment mechanism is triggered, the utilities agree that no changes to the current cost of c apital w ill be made under the mechanism. In February 2016 , the CPUC approved a joint PFM filed by the California Utilities, the ORA and TURN to effectuate the agreement among the parties. SDG&E’s current CPUC-authorized ROR is 7.79 percent and SoCalGas ’ current CPUC-authorized ROR is 8.02 percent based on their authorized capital structures as follows: COST OF CAPITAL AND AUTHORIZED RATE STRUCTURE SDG&E SoCalGas Authorized weighting Authorized rate of recovery Weighted authorized ROR Authorized weighting Authorized rate of recovery Weighted authorized ROR 45.25% 5.00% 2.26% Long-Term Debt 45.60% 5.77% 2.63% 2.75% 6.22% 0.17% Preferred Stock 2.40% 6.00% 0.14% 52.00% 10.30% 5.36% Common Equity 52.00% 10.10% 5.25% 100.00% 7.79% 100.00% 8.02% SDG&E files separately with the FERC for authorized ROE on FERC-regulated electric transmission operations and assets as described below in “Federal Energy Regulatory Commission (FERC) Formulaic Rate Matters”. Natural Gas Pipeline Operations Safety Assessments Various regulatory agencies, including the CPUC, are evaluating natural gas pipeline safety regulations, practices and procedures. In February 2011, the CPUC opened a forward-looking rulemaking proceeding to examine what changes should be made to existing pipeline safety regulations for California natural gas pipelines. The California Utilities are parties to this proceeding. In June 2011, the CPUC directed SoCalGas , SDG&E, PG&E and Southwest Gas to file comprehensive implementation plans to test or replace natural gas transmission pipelines located in populated areas that have not been pressure tested. The California Utilities filed their Pipeline Safety Enhancement Plan (PSEP) with the CPUC in A ugust 2011. The California Utilities’ total estimated cost for Phase 1 of the two-phase plan is $2.1 billion ($1.6 billion for SoCalGas and $500 million for SDG&E) over the 10-year period of 2012 to 2022. We anticipate that these costs may be updated to re flect the development of more detailed estimates, actual costs experienced as portions of the work are completed and changes in scope. The California Utilities requested that the incremental capital investment required as a result of any approved plan be i ncluded in rate base and that cost recovery be allowed for any other incremental cost not eligible for rate-base recovery . The costs that are the subject of these plans were outside the scope of the 2012 GR C proceedings concluded in 2013. Similarly, these costs are not included in the California U tilities’ 2016 GRC filings . In April 2012, the CPUC transferred the PSEP to the Triennial Cost Allocation Proceeding (TCAP) and authorized SDG&E and SoCalGas to establish regulatory accounts to record the increment al costs of initiating the PSEP prior to a final decision on the PSEP. Also in April 2012, the CPUC issued a decision expanding the scope of the rulemaking proceeding to incorporate the provisions of California Senate Bill (SB) 705, which requires gas uti lities to develop and implement a plan for the safe and reliable operation of their gas pipeline facilities. SDG&E and SoCalGas submitted their pipeline safety plans in June 2012. The CPUC decision also orders the utilities to undergo independent managemen t and financial audits to assure that the utilities are fully meeting their safety responsibilities. The CPUC’s Safety and Enforcement Division will select the independent auditors and will oversee the audits. A schedule for the audits has not been establi shed. In December 2012, the CPUC issued a final decision accepting the utilities’ pipeline safety plans filed pursuant to SB 705. In June 2014, the CPUC issued a final decision in the TCAP proceeding addressing SDG&E’s and SoCalGas ’ PSEP. Specifically, th e decision determined the follo wing for Phase 1 of the program: approved the utilities’ model for implementing PSEP; approved a process, including a reasonableness review, to determine the amount that the utilities will be authorized to recover from ratepa yers for the interim costs incurred through the date of the final decision to implement PSEP, which is recorded in the regulatory accounts authorized by the CPUC as noted above; approved balancing account treatment, subject to a reasonableness review, for incremental costs yet to be incurred to implement PSEP; and established the criteria to determine the amounts that would not be eligible for cost recovery, including: certain costs incurred or to be incurred searching for pipeline test records, the cost of pressure testing pipelines installed after July 1, 1961 for which the company has not found sufficient records of testing, and any undepreciated balances for pipelines installed after 1961 that were replaced due to insufficient documentation of pressur e testing. As a result of this decision, SoCalGas recorded an after-tax earnings charge of $5 million in 2014 for costs incurred in prior periods that were no longer subject to recovery. After taking the amounts disallowed for recovery into consideration, as of December 31 , 2015, SDG&E and SoCalGas have recorded PSEP costs of $ 10 million and $ 162 million, respectively, in the CPUC-authorized regulatory account. In regard to requesting recovery from customers for PSEP costs inc urred and recorded in accordance with the TCAP decision, SDG&E and SoCalGas are authorized to file an application with the CPUC for recovery of such costs up to the date of the TCAP decision and then annually for costs incurred through the end of each cale ndar yea r beginning with the period ended December 31, 2015. SoCalGas and SDG&E currently expect to file such applications no later than the second quarter of the year following and would expect a decision from the CPUC approximately 12 to 18 months follow ing the date of the application (i.e., a decision on the recovery of costs recorded in the PSEP regulatory accounts as of December 31, 2015 would be expected by mid-2017). In October 2014, SDG&E and SoCalGas filed a petition for modification with the CPUC requesting authority to begin to recover PSEP costs from customers in the year in which the costs are incurred, subject to refund pending the results of a reasonableness review by the CPUC, instead of in a subsequent year. This request is pending at the CPUC. In December 2014, SDG&E and SoCalGas filed an application with the CPUC for recovery of $0.1 million and $46 mi llion, respectively, in costs recorded in the regulatory account through June 11, 2014. In June 2015, SDG&E and SoCalGas agreed to remove certain projects from the filing and defer their review to future proceedings and, as a result, are now requesting rec overy of $0.1 million and $26.8 million, respectively. The O RA, TURN, and the Southern California Generation Coalition (SCGC) have recommended disallowances related to completed projects, as well as facilities build-out costs, de-scoped projects, and proje ct management and consulting costs. The ORA’s recommended disallowance would result in an $11.1 million decrease to SoCalGas ’ original recovery application of $26.8 million, to $15.7 million. The disallowance recommended by TURN and SCGC would result in a $2.3 million decrease to SoCalGas ’ original recovery application of $26.8 million, to $24.5 million . We expect a decision on this application in the first half of 2016. In July 2014, the ORA and TURN filed a joint application for rehearing of the CPUC’s J une 2014 final decision. The ORA and TURN alleged that the CPUC made a legal error in directing that ratepayers, not shareholders, be responsible for the costs associated with testing or replacing transmission pipelines that were installed between January 1, 1956 and July 1, 1961 for which the California Utilities do not have a record of a pressure test. In November 2014, the CPUC denied the ORA and TURN request for rehearing of the decision adopting the PSEP. In December 2014, the ORA and TURN sought rehea ring of the CPUC’s decision on rehearing. In late December 2014, SoCalGas and SDG&E filed their opposition to this second application for rehearing, and are continuing to implement PSEP in accordance with the June 2014 CPUC decision. In March 2015, the CPU C issued a decision denying the ORA’s and TURN’s second request for rehearing, but keeping the record in the proceeding open to admit additional evidence on the limited issue of pressure testing of pipelines installed between January 1, 1956 and July 1, 19 61. As part of this review, the CPUC will allow parties to submit additional evidence relevant to this narrow issue to ensure a complete record, with no additional discovery allowed. The ORA and TURN filed their responses on May 1, 2015. In December 2015, the CPUC issued a final decision finding that ratepayers should not bear the costs associated with pressure testing subject pipelines, or, if replaced, ratepayers should bear neither the average cost of pressure testing nor the undepreciated balance of aba ndoned pipeline s . Through Dec ember 3 1 , 2015, the after-tax disallowed costs for SoCalGas and SDG&E are $ 3.2 million and $ 0.5 million, respectively . In January 2016, SoCalGas and SDG&E jointly filed a request with the CPUC seeking rehearing of its December 2015 decision. A CPUC decision on the rehearing request is expected in 2016 . Utility Incentive Mechanisms The CPUC applies performance-based measures and incentive mechanisms to all California investor-owned utilities (IOUs) , under which the California Utilities have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. SDG&E has incentive mechanisms a ssociated with: operational incentives energy efficiency SoCalGas has incentive mechanisms associated with: energy efficiency natural gas procurement unbundled natural gas storage and system operator hub services Incentive awards are included in our ea rnings when we receive any required CPUC approval of the award. We would record penalties for results below the specified benchmarks in earnings when we believe it is probable that the CPUC would assess a penalty. Energy Efficiency The CPUC established incentive mechanisms that are based on the effectiveness of energy efficiency programs . In December 2013, the CPUC awarded $3.1 million to SoCalGas and $3.9 million to SDG& E for their 2011 program year results. In December 2014, the CPUC approved awards to SoCalGas and SDG&E of $5.9 million and $7.5 million, respectively, for program year 2012 and for the first half of program year 2013. In December 2015, the CPUC approved a wards to SoCalGas and SDG&E of $4.2 million and $6.5 million, respectively, for the second half of program year 20 13 and all of program year 2014 . In September 2015, the CPUC issued a decision granting two rehearing requests filed by the ORA and TURN rega rding the utility incentive awards for SDG&E and SoCalGas , as well as Edison and PG & E, for program years 2006 through 2008, which totaled $16.2 million for SDG&E and $17.3 million for SoCalGas . The decision directs that the rehearing ensure that the incent ive awards granted were just and reasonable and based on calculations verified by the CPUC, or otherwise refunded to customers . We expect a CPUC decision in the second half of 2016 . Natural Gas Procurement The California Utilities procure natural gas on behalf of their core natural gas customers. The CPUC has established incentive mechanisms to allow the California Utilities the opportunity to share in the savings and/or costs from buying natural gas for their core customers at prices below or above monthly market-based benchmarks. SoCalGas procures natural gas for SDG&E’s core natural gas customers’ requirements. SoCalGas ’ g as cost incentive mechanism (GCIM) is applied on the combined portfolio basis. In 2015, 2014 and 2013, the CPUC approved GCIM awards for SoCalGas of $13.7 million, $5.8 million and $5.4 million, respectively, for the 12-month periods ending March 31, 2014 , 2013 and 2012, respectively. In December 2015, the CPUC approved a $7.25 million GCIM award for SoCalGas for the 12-month period ended March 31, 2015. Operational Incentives The CPUC may establish operational incentives and associated performance benchmarks as part of a general rate case or cost of service proceeding. In the California Utilities’ Final 2012 GRC Decision, SDG&E was directed to establish a performance measure and incentive for electric reliability. In September 2014, the CPUC approved SDG&E’s proposed mechanism, which was applied to calendar year 2015 and will be considered in the 2016 GRC. The CPUC did not establish any operational incentives for SoCalGas in the Final 2012 GRC Decision. SDG&E MATTERS SONGS We discuss regulatory and other matters related to SONGS in Note 13. Power Procurement and Resource Planning We discuss SDG&E’s major projects below in “California Utilities – Major Projects.” Background – Electric Industry Regulation California’s legislative response to the 2000 – 2001 energy crisis resulted in the California Department of Water Resources (DWR) purchasing a substantial portion of power for California’s electricity users. In 2001, the DWR entered into long-term contracts with suppliers, including Sempra Natural Gas, to provide power for the utility pr ocurement customers of each of the California IOUs , including SDG&E. The CPUC allocates the power and its administrative responsibility, including collection of power contract costs from utility customers, among the IOUs. The las t of these power contracts expired in 2013, with one remaining transportation contract allocated to SDG&E that will expire in 2018. Renewable Energy SDG&E is subject to the Renewables Portfolio Standard (RPS) Program administered by both the CPUC and the C alifornia Energy Commission, which requires each California utility to procure 33 percent of its annual electric energy requirements from renewable energy sources by 2020, with an average of 20 percent required from January 1, 2011 to December 31, 2013; 25 percent by December 31, 2016; and 33 percent by December 31, 2020. The CPUC began a rulemaking proceeding in May 2011 to address the implementation of the 33% RPS Program. The 33% RPS Program contains flexible compliance mechanisms that can be used to com ply with or meet the 33% RPS Program mandates in 2011 and beyond. The mechanisms provide for a CPUC waiver under certain conditions, including: 1) a finding of inadequate transmission; 2) delays in the start-up of commercial operations of renewable energy projects due to permitting or interconnection; or 3) unexpected curtailment by an electric system balancing authority, such as the California ISO. SDG&E continues to procure renewable energy supplies to achieve the 33% RPS Program requirements. A substant ial number of these supply contracts, however, are contingent upon many factors, including: access to electric transmission infrastructure; timely regulatory approval of contracted renewable energy projects; the renewable energy project developers’ abil ity to obtain project financing and permitting; and successful development and implementation of the renewable energy technologies. In August 2014, SDG&E made a required filing with the CPUC indicating that its procurement of renewable energy during the period January 1, 2011 through December 31, 2013 exceeded the 20-percent minimum amount required by RPS. SDG&E believes it will be able to comply with the 33% RPS Program requirements based on its contracting activity and, if necessary, application of the flexible compliance mechanisms. SDG&E’s failure to comply with the RPS Program requirements could subject it to CPUC-imposed penalties, which could materially affect its business, cash flows, financial condition, results of operations and/or prospects. The limit on the total amount of penalties for failure to comply with the RPS requirements is $75 million for the first compliance period (2011-2013); $75 million for the second compliance period (2014-2016); $100 million for the third compliance period (2017 -2020); and $25 million for each annual compliance period beginning in 2021 . SB 350, signed into law in October 2015, increased the RPS requirements to 50 percent by 2030, with interim targets of 40 percent by the end of 2024, and 45 percent by the end of 2027. SDG&E expects to be fully compliant with these RPS requirements. We expect the CPUC to begin implementation of SB 350 in 2016 . Sunrise Powerlink Electric Transmission Line In August 2015, SDG&E filed a petition with the CPUC requesting that it revise and confirm the project cost cap for the Sunrise Powerlink, a 500- kilovolt (kV) electric transmission line between the Imperial Valley and the San Diego region that was energized and placed in service in June 2012. While post-energization construction activities for the project were completed in 2013, certain matters relating to outstanding claims were not resolved until the first quarter of 2015. The filing requests CPUC approval of the final expenditure report for the project and the proposed revisions to the total project cost cap. As evidenced in the final report, and summarized in the table below, actual expenditures for the project total ed $1,887.4 million (in 2012 dollars, on a net present value basis), which exceeds the total project cost cap approved by the CPUC in 2008 (CPUC Approval Decision) by $4.4 million. SUNRISE POWERLINK ELECTRIC TRANSMISSION LINE – PROPOSED REVISIONS TO TOTAL PROJECT COST CAP (Dollars in millions) Total Construction costs Undergrounding on Mitigation (2012 dollars, net and AFUDC Alpine Blvd. and monitoring costs present value basis) Final status report $ 1,490.9 $ 11.7 $ 384.8 $ 1,887.4 2008 CPUC approval decision 1,594.2 91.0 197.8 1,883.0 Difference $ (103.3) $ (79.3) $ 187.0 $ 4.4 Subsequent to the required approvals of the U.S. Department of Interior, Bureau of Land Management in January 2009 and the U.S. Forest Service (USFS) in July 2010, which formed the basis of the CPUC Approval Decision summarized above, the CPUC’s Energy Division and the federal agencies published the Sunrise Final Mitigation Monitoring, Compliance, and Reporting Program (MMCRP). The MMCRP increased the amount of required mitigation activities and costs by $187 million. Offsetting this cost, in part, was a reduction in the total mileage of undergrounding on Alpine Boulevard by approximately two miles. The terms of the CPUC Approval Decision contemplate the potential reduction in undergrounding mileage at an estimated $11 million per one quarter mile. The CPUC Approval Decis ion did not anticipate the changes in monitoring and mitigation costs. In its petition, SDG&E proposes that the applicable total cost cap be revised and confi rmed at the amount of $1,887.4 m illion. This amount will be the basis used in SDG&E’s FERC-regulat ed transmission rates. SDG&E expects a CPUC decision on the petition in 2016. Federal Energy Regulatory Commission (FERC) Formulaic Rate Matters In February 2013, SDG&E submitted its Electric Transmission Formula Rate (TO4) filing with the FERC to set the rate making methodology and rate of return for SDG&E’s FERC-regulated electric transmission operations and assets for a multi-year period beginning September 1, 2013. The TO4 filing proposed a FERC ROE of 11.3 percent and requested: 1) rates to be determined by a base period of historical costs and a forecast of capital inve stments and 2) a true-up period similar to balancing account treatment that is designed to provide SDG&E earnings of no more and no less than its actual cost of service including its authorized return on investment. In June and July 2013, the FERC issued o rders accepting the filing, subject to refund, and established settlement and hearing procedures, with rates being effective September 1, 2013. On January 31, 2014, SDG&E filed an uncontested multi-party settlement at the FERC regarding the TO4 filing. The settlement, approved by the FERC in May 2014, will be in effect through December 31, 2018, is subject to a one-time right of termination by any party, and established a 10.05 percent ROE. The settlement also requires SDG&E to make annual information filings o n December 1 of a given year to update rates for the following calendar year. SDG&E also has the right to file for any ROE incentives that might apply under FERC rules. SDG&E’s debt to equity ratio will be set annually based on the actual ratio at the end of each year . Energy Resource Recovery Account (ERRA) The ERRA is the regulatory balancing account that SDG&E uses to recover the electric fuel and purchased power costs it incurs to provide energy to its bundled service customers. SDG&E files an application with the CPUC each year to establish the ERRA revenue requirement needed for the following calendar year. Additionally, to the extent the ERRA balance exceeds a certain tolerance or “ERRA Trigger”, SDG&E must file an application to adjust its rates upward or downwa rd, as applicable, to address the under- or overcollected ERRA balance, respectively. In 2014, the CPUC authorized SDG&E to collect $221 million of revenue requirement as a result of an ERRA Trigger. SDG&E collected the revenue requirement over the period April 2014 through December 31, 2015. In December 2015, the CPUC approved SDG&E’s 2016 ERRA revenue requirement of $1.3 billion, an increase of $43 million from its 2015 revenue requirement . SDG&E implemented the increased revenue requirement, to be collected in 2016, beginning January 1 . Wildfire Claims Cost Recovery In August 2009, SDG&E and SoCalGas filed an application, along with other related filings, with the CPUC proposing a new framework and mechanism for the future recovery of all wildfire-related expenses for claims, litigation expenses and insurance premiums that are in excess of amounts aut horized by the CPUC for recovery in distribution rates. In December 2012, the CPUC issued a final decision that ultimately did not approve the proposed framework for the utilities but allowed SDG&E to maintain its authorized memorandum account so that SDG& E may file applications with the CPUC requesting recovery of amounts properly recorded in the memorandum account at a later time, subject to reasonableness review. In February 2014, the Presiding Judge assigned by the FERC to SDG&E’s annual Electric Transm ission Formula Rate filing (TO3 Formula Cycle 6) issued an Initial Decision and an Order on Summary Judgment which authorizes SDG&E to recover all of the costs incurred and allocated to SDG&E’s FERC-regulated operations for the 12-month period ended March 31, 2012, resulting from settlement activities for 2007 wildfire claims. In connection with this proceeding, the CPUC filed an appeal in the Ninth Circuit Court of Appeal of an earlier decision by the FERC denying the CPUC’s request to postpone the FERC pr oceeding pending CPUC action on cost recovery of the excess wildfire costs. The FERC sought dismissal of the CPUC’s appeal on procedural grounds, and in December 2015, the Court of Appeal dismissed the appeal. In September 2015, SDG&E filed an applicatio n with the CPUC requesting rate recovery of an estimated $379 million in costs related to the October 2007 wildfires that have been recorded to the Wildfire Expense Memorandum Account (WEMA). These costs represent a portion of the estimated total of $2.4 b illion in costs and legal fees that SDG&E has incurred to resolve third-party damage claims arising from the October 2007 wildfires. The requested amount of $379 million is the net estimated cost incurred by SDG&E after deductions for insurance reimburseme nt ($1.1 billion), third party settlement recoveries ($824 million) and allocations to FERC-jurisdictional rates ($80 million), and reflects a voluntary 10 percent shareholder contribution applied to the net WEMA balance ($42 million). SDG&E requested a CP UC decision by the end of 2016 and is proposing to recover the costs in rates over a six- to ten-year period . Intervening parties have recommended a phased approach, with Phase 1 addressing t

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Commitments and Contingencies	NOTE 15 . COMMITMENTS AND CONTINGENCIES LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could material ly adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued. At December 31, 2015, Sempra Energy’s accrued liabilities for legal proceedings, including associated legal fees and costs of litigation, on a consolidated basis, were $49 million. At December 31, 2015, accrued liabilities for legal proceedings for SDG&E and SoCalGas were $26 million and $21 million, respectively. See discussion below for matters related to the Aliso Canyon n atural g as l eak SDG&E 2007 Wildfire Litigation In October 2007, San Diego County experienced several catastrophic wildfires. Reports issued by the California Department of Forestry and Fire Protection (Cal Fire) concluded that two of these fires (the Witch and Rice fires) were SDG&E “power line caused” and that a third fire (the Guejito fire) occurred when a wire securing a Cox Communications’ (Cox) fiber optic cable came into contact with an SDG&E power line “causing an arc and starting the fire.” A September 2008 staff report issued by the CPUC’s Consumer Protection and Safety Division, now known as the Safety and Enforcement Division, reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice fire s and the lashing wire involved in the Guejito fire were not properly designed, constructed and maintained. Numerous parties sued SDG&E and Sempra Energy in San Diego County Superior Court seeking recovery of unspecified amounts of damages, including punit ive damages, from the three fires. They asserted various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without reg ard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines. SDG&E has resolved almost all of these lawsuits. One case remains subject to a damages-only trial, where the value of any compensatory damages resul ting from the fires will be determined. Two appeals are pending after judgment in the trial court. SDG&E does not expect additional plaintiffs to file lawsuits given the applicable statutes of limitation, but could receive additional settlement demands a nd damage estimates from the remaining plaintiff until the case is resolved. SDG&E establishes reserves for the wildfire litigation as information becomes available and amounts are estimable. SDG&E has concluded that it is probable that it will be permitte d to recover in rates a substantial portion of the costs incurred to resolve wildfire claims in excess of its liability insurance coverage and the amounts recovered from third parties. Accordingly, at December 31, 2015, Sempra Energy and SDG&E have recorde d assets of $362 million in Other Regulatory Assets (long-term) on their Consolidated Balance Sheets, including $359 million related to CPUC-regulated operations, which represents the amount substantially equal to the aggregate amount it has paid and reser ved for payment for the resolution of wildfire claims and related costs in excess of its liability insurance coverage and amounts recovered from third parties. On September 25, 2015, SDG&E filed an application with the CPUC seeking authority to recover the se costs, as we discuss in Note 14. Should SDG&E conclude that recovery in rates is no longer probable, SDG&E will record a charge against earnings at the time such conclusion is reached. If SDG&E had concluded that the recovery of regulatory assets relate d to CPUC-regulated operations was no longer probable or was less than currently estimated at December 31, 2015, the resulting after-tax charge against earnings would have been up to approximately $213 million. A failure to obtain substantial or full recov ery of these costs from customers, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s results of operations and cash flows. We provide additional information about excess wildfire claims cost recovery and related CPUC actions in Note 14 and discuss how we assess the probability of recovery of our re gulatory assets in Note 1. Smart Meters Patent Infringement Lawsuit In October 2011, SDG&E was sued by a Texas design and manufacturing company in Federal District Court, Southern District of California, and later transferred to the Federal District Court, Western District of Oklahoma as part of Multi-District Litigation (MDL) proceedings , alleging that SDG&E’s recently installed smart meters infringed certain patents. The meters were purchased from a third party vendor that has agreed to defend and indemnify SDG&E. The lawsuit seeks injunctive relief and recovery of unspecified amounts of damages . The MDL court has finished ruling on pre-trial matters, and SDG&E expects that it will return the case to the Southern District of California . Lawsuit Against Mitsubishi Heavy Industries, Ltd. On July 18, 2013, SDG&E filed a lawsuit in the Superior Court of California in the County of San Diego against Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). The lawsuit seeks to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators MHI provided to the SONGS nuclear power plant. The lawsuit asserts a number of causes of action, including fraud, based on the repr esentations MHI made about its qualifications and ability to design generators free from defects of the kind that resulted in the permanent shutdown of the plant and further seeks to set aside the contractual limitation of damages that MHI has asserted. On July 24, 2013, MHI removed the lawsuit to the United States District Court for the Southern District of California and on August 8, 2013, MHI moved to stay the proceeding pending resolution of the dispute resolution process involving MHI and Edison arisin g from their contract for the purchase and sale of the steam generators. On October 16, 2013, Edison initiated an arbitration proceeding against MHI seeking damages stemming from the failure of the replacement steam generators. In late December 2013, MHI a nswered and filed a counterclaim against Edison. On March 14, 2014, MHI’s motion to stay the United States District Court proceeding was granted with instructions that require the parties to allow SDG&E to participate in the ongoing Edison/MHI arbitration. As a result, SDG&E is now participating in the arbitration as a claimant and respondent . Arbitration hearings are scheduled to begin in early 2016. We expect a decision by the end of 2016. Investment in Wind Farm In 2011, the CPUC and FERC approved SDG&E’s estimated $285 million tax equity investment in a wind farm project and its purchase of renewable energy credits from that project. SDG&E’s contractual obligations to both invest in the Rim Rock wind farm and to purchase renewable energy credits from the wind farm under the power purchase agreement are subject to the satisfaction of certain conditions which, if not achieved, would allow SDG&E to terminate the power purchase agreement and not make the investment. In December 2013, SDG&E received a closing notice from the project developer indicating that all such conditions had been met. SDG&E responded to the closing notice asserting that the contractual conditions had not been satisfied. On December 19, 2013, SDG&E filed a complaint against the project developer in San Diego Superior Court, asking that the court determine that SDG&E is entitled to terminate both the investment contract and the power purchase agreement due to the project de veloper’s failure to satisfy certain conditions. The project developer filed a separate complaint against SDG&E in Montana state court asking that court to determine that SDG&E breached the investment contract and the power purchase agreement, and asking f or several categories of relief, including requiring SDG&E to invest in the project, requiring SDG&E to continue performing under the power purchase agreement, and payment of damages. On January 27, 2014, the Montana court ordered SDG&E to continue making payments under the power purchase agreement pending a hearing on the project developer’s preliminary injunction motion. On March 14, 2014, SDG&E notified the project developer that the investment agreement expired by its own terms because a closing had no t occurred by that date. The project developer is disputing SDG&E’s position. On March 28, 2014, SDG&E filed an amended complaint against the project developer in San Diego seeking damages and declaratory relief that SDG&E was entitled to terminate the pow er purchase agreement and to permit the investment agreement to expire. On April 25, 2014, the Montana court granted the project developer’s preliminary injunction motion to prevent SDG&E from terminating the power purchase agreement on the grounds that th e project developer would be irreparably harmed if the payments were not made while the parties’ respective rights were being determined in the litigation. The court did not rule on the merits of the parties’ claims. On July 18, 2014, the Montana Supreme C ourt determined that the parties’ contractual agreement to resolve any disputes in San Diego was mandatory, and ordered that the Montana action be dismissed. The San Diego court has scheduled a trial in May 2016. On February 11, 2016, SDG&E, the project de veloper and several of the project developer’s parent and affiliated entities entered into a conditional settlement agreement. Under the conditional settlement agreement, among other things, the parties agreed to terminate the tax equity investment arrange ment, continue the power purchase agreement for the wind farm generation, and release all claims against each other. The conditional settlement agreement is not fully effective until approved by the CPUC. Concluded Matter In February 2011, opponents of the Sunrise Powerlink, a 500-kV electric transmission line between the Imperial Valley and the San Diego region that was energized and placed in service in June 2012, filed a lawsuit in Sacramento County Superior Court against the State Water Resources Control Board and SDG&E alleging that the water quality certification issued by the Board under the Federal Clean Water Act violated the California Environmental Quality Act. The Superior Court denied the plaintiffs’ petition in July 2012, and the plaintiffs appealed. On May 19, 2015 the California Court of Appeals affirmed the lower court’s decision and, on June 16, 2015, denied plaintiffs’ request for rehearing. Plaintiffs did not seek review by the California Supreme Court within the prescribed time, so the Court of Appeals decision is final. SoCalGas Aliso Canyon Natural Gas Storage Facility Gas Leak In October 2015, SoCalGas discovered a leak at one of its injection and withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility, located in the northern part of the San Fernando Valley in Los Angeles County. The Aliso Canyon facility, which has been operated by So CalGas since 1972, is situated in the Santa Susana Mountains. SS25 is more than one mile away from and 1,200 feet above the closest homes. It is one of more than 100 injection and withdrawal wells at the storage facility. Stopping the Leak and Mitigation Efforts . SoCalGas worked cl osely with several of the world ’s leading experts to stop the leak, including planning and obtaining all necessary approvals for drilling relief wells. After discovering the leak, SoCalGas made seven unsuccessful attempts to plug SS25 by pump ing fluids down the well shaft. In early December 2015, SoCalGas began drilling a relief well designed to stop the leak by plugging the well at its base. On February 11 , 2016, SoCalGas began pumping heavy fluids through the relief well into SS 25 near the base of the well, which controlled the flow of natural gas through the well and stopped the leak. In order to permanently seal the well and consistent with directives from the California Department of Conservation’s Division of Oil, Gas, and Ge othermal Resources ( DOGGR ) and CPUC, SoCalGas then injected cement into SS25 at its base, and on February 18, 2016, t he DOGGR confirmed that the well was p ermanently sealed. SoCalGas has been providing temporary relocation support to residents in the nearby community who request it. In addition, SoCalGas has been providing air filtration and purification systems to those residents in the nearby community requesting them. On December 24, 2015, by stipulation and court order, SoCalGas agreed to implement a formal plan for assisting residents in the nearby community to temporarily relocate, as well as to pay for additional overtime and costs associated with extra Los Angeles Police Department security patrols, among other things. Pursuant to the order, SoCalGas also worked with representatives from the Los Angeles City Attorney’s office to establish a mediation process to resolve disputes between individuals requesting temporary relocation or other services under this plan and SoCalGas . As a result of receiving the confirmation from DOGGR that the SS25 well was permanently sealed, SoCalGas started winding down its temporary relocation support. Subject to certain exceptions, the period for temporary relocation support to residents who temporarily relocated to short-term housing, such as hotels, concluded on February 25, 2016. This deadline has been challenged and is subject to a recent court order extending such period for an additional 22 days for certain residents. SoCalGas has appealed this order extending the support period. Additionally, residents who have been placed in rental housing will have through the agreed term of their leases to return home. In addition, SoCalGas also intends to mitigate the GHG emissions from the actual natural gas released. The total costs incurred to remediate and stop the leak and to mitigate environmental and local communit y impacts will be significant, and to the extent not covered by insurance, or if there were to be significant delays in receiving insurance recoveries, such costs could have a material adverse effect on SoCalGas ’ and Sempra Energy’s cash flows, financial c ondition and results of operations. Governmental Investigations and Civil and Criminal Litigation. Various governmental agencies, including the DOGGR, Los Angeles County Department of Public Health (LA County DPH), South Coast Air Quality Management Distri ct ( SCAQMD ) , California Air Resources Board ( CARB ) , CPUC, U.S. Environmental Protection Agency , Los Angeles District Attorney’s Office and California Attorney General’s Office, ar e investigating this incident. On January 25, 2016, the DOGGR and CPUC select ed Blade Energy Partners to conduct an independent analysis under their supervision and to be funded by SoCalGas to investigate the technical root c ause of the Aliso Canyon leak. SoCalGas has been working in close cooperation with these agencies. As of February 24, 2016, 83 lawsuits have been filed (81 in Los Angeles County Superior Court and 2 in San Diego County Superior Court) against SoCalGas , some of which have also named Sempra Energy , and , in derivative claims on behalf of Sempra Energy and SoCa lGas , certain officers and directors of Sempra Energy and SoCalGas . These various lawsuits assert causes of action for negligence, strict liability, property damage, fraud, nuisance, trespass, and breach of fiduciary duties, among other things, and additio nal litigation may be filed against us in the future related to this incident. Many of these complaints seek class action status, compensatory and punitive damages, injunctive relief, and attorneys’ fees. The Los Angeles City Attorney and Los Angeles Count y Counsel have also filed a complaint on behalf of the people of the State of California against SoCalGas for public nuisance and violation of the California Unfair Competition Law. The California Attorney General , acting in her independent capacity and on behalf of the people of the State of California and the CARB, joined this lawsuit. The complaint, as amended to include the California Attorney General, adds allegations of violations of California Health and Safety Code sections 41700, prohibiting discha rge of air contaminants that cause annoyance to the public, and 25510, requiring reporting of the release of hazardous material, as well as California Government Code section 12607 for equitable relief for the protection of natural resources. The complaint seeks an order for injunctive relief, to abate the public nuisance, and to impose civil penalties. The SCAQMD also filed a complaint against SoCalGas seeking civil penalties for alleged violations of several nuisance-related statutory provisions arising f rom the leak and delays in stopping the leak. That suit seeks up to $250,000 in civil penalties for each day the violations occurred. On February 2, 2016, the Los Angeles District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas s eeking penalties for alleged failure to provide timely notice of the leak pursuant to California Health and Safety Code section 25510(a), Los Angeles County Code section 12.56.030, and Title 19 California Code of Regulations section 2703(a), and for violat ing California Health and Safety Code section 41700 prohibiting discharge of air contaminants that cause annoyance to the public. All of these complaints are being reviewed by SoCa lGas and outside legal counsel. The costs of defending against these civil a nd criminal lawsuits and cooperating with these investigations, and any damages and civil and criminal fines and other penalties, if awarded or imposed, could be significant and to the extent not covered by insurance, or if there were to be significant del ays in receiving insurance recoveries, could have a material adverse effect on SoCalGas ’ and Sempra Energy’s cash flows, financial condition and results of operations. Governmental Orders, Additional Regulation and Reliability . On January 6, 2016, the Gove rnor of the State of California issued the Governor’s Order proclaiming a state of emergency to exist in Los Angeles County due to the natural gas leak at the Aliso Canyon facility. The Governor’s Order implements the following orders, among other things: Stopping the Leak: The Governor’s Order directs: subject to reliability restrictions, the CPUC and California Energy Commission to take all actions necessary to ensure that SoCalGas maximizes daily withdrawals of natural gas from the Aliso Canyon storage f acility for use or storage elsewhere; the DOGGR to direct SoCalGas to take any and all viable and safe actions to capture leaking gas and odorants while relief wells are being completed; and the DOGGR to require SoCalGas to identify how it will stop the ga s leak if relief wells fail to seal the leaking well, or if the existing leak worsens. Protecting Public Health and Safety: State agencies will: continue the prohibition against SoCalGas injecting any gas into the Aliso Canyon storage facility until a com prehensive review, utilizing independent experts, of the safety of the storage wells and the air quality of the surrounding community is completed; expand real-time monitoring of emissions in the surrounding community; convene an independent panel of scien tific and medical experts to review public health concerns stemming from the natural gas leak and evaluate whether additional measures are needed to protect public health; and take all actions necessary to ensure the continued reliability of natural gas an d electricity supplies in the coming months during the moratorium on gas injections into the Aliso Canyon storage facility. Ensuring Accountability: The CPUC will ensure that SoCalGas covers costs related to the natural gas leak and its response, while pro tecting ratepayers; and CARB will develop a program to fully mitigate the leak’s emissions of methane by March 31, 2016, with such program to be funded by SoCalGas . Strengthening Oversight: The DOGGR will promulgate emergency regulations for gas storage fa cility operators throughout the state, requiring: at least daily inspection of gas storage well heads using gas leak detection technology such as infrared imaging; ongoing verification of the mechanical integrity of all gas storage wells; ongoing measureme nt of annular gas pressure or annular gas flow within wells; regular testing of all safety valves used in wells; minimum and maximum pressure limits for each gas storage facility in the state; and a comprehensive risk management plan for each facility that evaluates and prepares for risks, including corrosion potential of pipes and equipment. Additionally, the DOGGR, the CPUC, the CARB and the California Energy Commission will submit to the Governor’s Office a report that assesses the long-term viability of natural gas storage facilities in California. As described above, SoCalGas is addressing a number of the actions required by the Governor’s Order, while at the same time continuing to reliably supply natural gas to its customers. In addition, SoCalGas con tinues to work in close cooperation with the Governor’s Office and the state agencies described in the Order. During the month of January 2016, the Hearing Board of the SCAQMD conducted public hearings on a stipulated abatement order regarding the Aliso Ca nyon leak. On January 23, 2016, the Hearing Board ordered SoCalGas to, among other things: stop all injections of natural gas except as directed by the CPUC, withdraw the maximum amount of natural gas feasible in a contained and safe manner, subject to ord ers of the CPUC, and permanently seal the well once the leak has ceased; continuously monitor the well site with infrared cameras until 30 days after the leak has ceased; provide the public with daily air monitoring data collected by SoCalGas ; provide the SCAQMD with certain natural gas injection, withdrawal and emissions data from the Aliso Canyon facility; prepare and submit to the SCAQMD for its approval an enhanced leak detection and reporting well inspection program for the Aliso Canyon facility; provi de the SCAQMD with funding to develop a continuous air monitoring plan for the Aliso Canyon facility and the nearby schools and community; prepare and submit to the SCAQMD for its approval an air quality notification plan to provide notice to SCAQMD, other public agencies and the nearby community in the event of a future reportable release; and provide the SCAQMD with funding to conduct an independent health study on the potential impacts of exposure to the constituents of the natural gas released from the facility as well as any odor suppressants used to mitigate odors from the leaking well. Additional hearings in the state legislature as well as with various other regulatory agencies have been or are expected to be scheduled, additional legislation has bee n proposed in the state legislature, and additional laws, orders, rules and regulations may be adopted. SoCalGas estimates that approximately 57 Bcf of natural gas has been delivered to customers or moved to other gas storage facilities from an initial s tarting point of approximately 77 Bcf of gas in storage on October 23, 2015 at the Aliso Canyon facility. The CPUC has directed SoCalGas to maintain a minimum of 15 Bcf of working natural gas to help ensure reliability of the system through the spring and summer months, and based upon the CARB estimates of lost gas, the facility is approximately at this level. As a result and consistent with the order issued by the Hearing Board of the SCAQMD as described above, SoCalGas is no longer withdrawing gas from th is facility. SoCalGas will conduct a measurement of natural gas lost from the leak and will provide that information to the relevant regulatory bodies. Natural gas withdrawn from storage is important for ensuring service relia bility during peak demand peri ods, including heating needs in the winter, as well as peak electric generation needs in the summer. Aliso Canyon, with a storage capacity of 86 Bcf , is the largest storage facility and an important element of SoCalGas ’ delivery system, serving millions of homes and businesses across Southern California. Aliso Canyon represents 63 percent of SoCalGas ’ owned natural gas storage capacity. SoCalGas has not injected natural gas into Aliso Canyon since October 25, 2015, and in accordance with the Governor’s Ord er and subject to contrary CPUC reliability-based direction, SoCalGas will continue this moratorium on further injections until the completion of a review, utilizing independent experts, of the safety of each of the storage wells and air quality in the sur rounding communities and an evaluation by an independent panel of scientific and medical experts on whether additional measures are needed to protect public health. We are also currently reviewing the recently released DOGGR safety review requirements asso ciated with returning Aliso Canyon to an active injection/withdrawal status. In addition, effective February 5, 2016, the DOGGR amended the California Code of Regulations to require all underground natural gas storage facility operators, including SoCalGas , to take further steps to help ensure the safety of their gas storage operations. If this facility were to be taken out of service for any meaningful period of time, it could result in an impairment of the Aliso Canyon facility and significantly higher than ex pected operating costs and/or additional capital expenditures, and natural gas reliability and electric generation could be jeopardized. At December 31, 2015, the Aliso Canyon facility has a net book value of $243 million, excluding $162 million of constru ction work in progress for the project to construct a new compression station. Any significant impairment of this asset could have a material adverse effect on SoCalGas ’ and Sempra Energy’s results of operations for the period in which it is recorded. High er operating costs and additional capital expenditures incurred by SoCalGas may not be recoverable in customer rates, and SoCalGas ’ and Sempra Energy ’ s results of operations, cash flows and financial condition may be materially adversely affected. Cost Estimates and Accounting Impact. At December 31, 2015, SoCalGas recorded estimated costs of $330 million related to the leak. Of these amounts, approximately 70 percent is for the temporary relocation program and approximately 20 percent is for attempts to control the well, stop the leak, and stop or reduce the emissions. The remaining amount includes estimates for the value of lost gas, costs to mitigate the GHG emissions from the actual natural gas released, and other costs. The $330 million represents management’s best estimate of costs related to the leak. Of these costs, certain amounts have been paid and $274 million is recorded as Reserve for Aliso Canyon Costs at December 31, 2015 on SoCalGas ’ and Sempra Energy’s Consolidated Balance Sheets for amounts expected to be paid in 2016. We will refine this estimate as further information becomes available, primarily from relocation companies who are administering the temporary relocation program. SoCalGas ’ estimate of temporary relocation costs was primarily determined considering the current experience of temporary relocations. The remainder of the reserve was estimated primarily based on the rate of cost accumulation and duration of the leak. Any significant differences in actual costs incurred will impact these estimates. In addition, the period for temporary relocation support to residents who temporarily relocated to short-term housing, such as hotels, concluded on February 25, 2016. This deadline has been challenged and is subject to a recent court order extending such period for an additional 22 days for certain residents. SoCalGas has appealed this order extending the support period. Any increased costs related to such extension are not included in these estimates. At December 31, 2015, we recorded the expected recover y of the costs described in the immediately preceding paragraph related to the leak (less insurance retentions) of $ 325 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas ’ and Sempra Energy’s Consolidated Balance S heet s. If we were to conclude that this receivable or a portion of it was no longer probable of recovery from insurers, some or all of this receivable may be charged against earnings. The above amounts do not include any damage awards, any civil or criminal fi nes and other penalties that may be impos ed, or associated legal costs, as it is not possible to predict the outcome of any criminal or civil proceeding or any administrative action in which such damage awards or civil or criminal fines or other penalties could be imposed, and any such amounts, if awarded or imposed, cannot be estimated at this time. Insurance. We have at least four kinds of insurance policies that provide in excess of $1 billion in insurance coverage. We cannot predict all of the potential categories of costs or the total amount of costs that we may incur as a result of the leak. In reviewing each of our policies, and subject to various policy limits, exclusions and conditions, based upon what we know as of the filing date of this report, we believe that our insurance policies collectively should cover the following categories of costs: the costs incurred for temporary relocation, costs to address the leak and stop or reduce emissions, the value of lost natural gas and estimated costs to mi tigate the GHG emissions from the actual natural gas released, the costs associated with litigation and claims by nearby residents and businesses, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have b een communicating with our insurance carriers and intend to pursue the full extent of our insurance coverage. There can be no assurance that we will be successful in obtaining insurance coverage for these costs under the applicable policies, and to the ext ent we are not successful, it could result in a material charge against earnings. Other SoCalGas , along with Monsanto Co., Solutia, Inc., Pharmacia Corp. and Pfizer, Inc., are defendants in seven Los Angeles County Superior Court lawsuits filed beginning i n April 2011 seeking recovery of unspecified amounts of damages, including punitive damages, as a result of plaintiffs’ exposure to PCBs (polychlorinated biphenyls). The lawsuits allege plaintiffs were exposed to PCBs not only through the food chain and ot her various sources but from PCB-contaminated natural gas pipelines owned and operated by SoCalGas . This contamination allegedly caused plaintiffs to develop cancer and other serious illnesses. Plaintiffs assert various bases for recovery, including neglig ence and products liability. SoCalGas has settled six of the seven lawsuits for an amount that is not significant. Sempra Mexico Permit Challenges and Property Disputes Sempra Mexico has been engaged in a long-running land dispute relating to property adjacent to its Energía Costa Azul LNG terminal near Ensenada, Mexico. Ownership of the adjacent property is not required by any of the environmental or other regulatory permits issued for the operation of the terminal. A claimant to the adjacent property has nonetheless asserte d that his health and safety are endangered by the operation of the facility, and filed an action in the Federal Court challenging the permits. In February 2011, based on a complaint by the claimant, the municipality of Ensenada opened an administrative pr oceeding and sought to temporarily close the terminal based on claims of irregularities in municipal permits issued six years earlier. This attempt was promptly countermanded by Mexican federal and Baja California state authorities. No te

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Segment Information	NOTE 16 . SEGMENT INFORMATION We have six separately managed reportable segments, as follows: SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. Sempra South American Utilities develops, owns and operates, or holds interests in, electric transmission, distribution and gen eration infrastructure in Chile and Peru. Sempra Mexico develops , owns and operates, or holds interests in, natural gas transmission pipelines and propane and ethane systems, a natural gas distribution utility, electric generation facilities (including win d), a terminal for the import of LNG, and marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. Sempra Renewables develops, owns and operates, or holds interests in, wind and solar energy projects in Arizona, Cal ifornia, Colorado, Hawaii, Indiana, Kansas, Minnesota, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States. Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities, natural gas distribution utilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. Sempra Natural Gas also owned and operated the M esquite Power plant, a natural gas-fired electric generati on asset, the remaining 625-MW block of which was sold in April 2015, as we discuss in Note 3. Sempra South American Utilities and Sempra Mexico comprise our Sempra International operating unit. Sempra Renewables and Sempra Natural Gas comprise our Sempra U.S. Gas & Power operating unit. We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC. The California Utilities’ operations are based on rates set by the CPUC and the FERC. We describe the accounting policies of all of our segments in Note 1. Common services shared by the business segments are assigned direct ly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation. The following tables sho w selected information by segment from our Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 4. Amounts labeled as “All other” in the following tables consis t primarily of parent organizations. SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2015 2014 2013 REVENUES SDG&E $ 4,219 41 % $ 4,329 39 % $ 4,066 39 % SoCalGas 3,489 34 3,855 35 3,736 35 Sempra South American Utilities 1,544 15 1,534 14 1,495 14 Sempra Mexico 669 7 818 8 675 6 Sempra Renewables 36 ― 35 ― 82 1 Sempra Natural Gas 653 6 979 9 908 9 Adjustments and eliminations (2) ― (3) ― (2) ― Intersegment revenues(1) (377) (3) (512) (5) (403) (4) Total $ 10,231 100 % $ 11,035 100 % $ 10,557 100 % INTEREST EXPENSE SDG&E $ 204 $ 202 $ 197 SoCalGas 84 69 69 Sempra South American Utilities 32 33 27 Sempra Mexico 23 17 17 Sempra Renewables 3 5 23 Sempra Natural Gas 72 111 116 All other 263 241 241 Intercompany eliminations (120) (124) (131) Total $ 561 $ 554 $ 559 INTEREST INCOME SDG&E $ ― $ ― $ 1 SoCalGas 4 ― ― Sempra South American Utilities 19 14 14 Sempra Mexico 7 4 2 Sempra Renewables 4 1 20 Sempra Natural Gas 75 115 88 All other ― 1 ― Intercompany eliminations (80) (113) (105) Total $ 29 $ 22 $ 20 DEPRECIATION AND AMORTIZATION SDG&E $ 604 48 % $ 530 46 % $ 494 44 % SoCalGas 461 37 431 37 383 35 Sempra South American Utilities 50 4 55 5 59 5 Sempra Mexico 70 6 64 6 63 6 Sempra Renewables 6 ― 5 ― 21 2 Sempra Natural Gas 49 4 61 5 81 7 All other 10 1 10 1 12 1 Total $ 1,250 100 % $ 1,156 100 % $ 1,113 100 % INCOME TAX EXPENSE (BENEFIT) SDG&E $ 284 $ 270 $ 191 SoCalGas 138 139 116 Sempra South American Utilities 67 58 67 Sempra Mexico 11 5 60 Sempra Renewables (49) (44) (19) Sempra Natural Gas 28 (20) 40 All other (138) (108) (89) Total $ 341 $ 300 $ 366 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) At December 31 or for the years ended December 31, 2015 2014 2013 EARNINGS (LOSSES) SDG&E(2) $ 587 43 % $ 507 44 % $ 404 41 % SoCalGas(3) 419 31 332 29 364 37 Sempra South American Utilities 175 13 172 15 153 15 Sempra Mexico 213 16 192 16 122 12 Sempra Renewables 63 5 81 7 62 6 Sempra Natural Gas 44 3 50 4 64 6 All other (152) (11) (173) (15) (168) (17) Total $ 1,349 100 % $ 1,161 100 % $ 1,001 100 % ASSETS(4) SDG&E $ 16,515 40 % $ 16,260 41 % $ 15,337 41 % SoCalGas 12,104 29 10,446 26 9,138 25 Sempra South American Utilities 3,235 8 3,379 9 3,531 10 Sempra Mexico 3,783 9 3,486 9 3,243 9 Sempra Renewables 1,441 4 1,334 3 1,214 3 Sempra Natural Gas 5,566 13 6,435 16 7,199 19 All other 734 2 872 2 817 2 Intersegment receivables (2,228) (5) (2,561) (6) (3,314) (9) Total $ 41,150 100 % $ 39,651 100 % $ 37,165 100 % EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,133 36 % $ 1,100 35 % $ 978 38 % SoCalGas 1,352 43 1,104 35 762 30 Sempra South American Utilities 154 5 174 6 200 8 Sempra Mexico 302 10 325 10 371 14 Sempra Renewables 81 2 190 6 176 7 Sempra Natural Gas 87 3 212 7 83 3 All other 47 1 18 1 2 ― Total $ 3,156 100 % $ 3,123 100 % $ 2,572 100 % GEOGRAPHIC INFORMATION Long-lived assets(5): United States $ 26,132 84 % $ 24,183 84 % $ 22,654 84 % Mexico 3,160 10 2,821 10 2,597 9 South America 1,652 6 1,746 6 1,784 7 Total $ 30,944 100 % $ 28,750 100 % $ 27,035 100 % Revenues(6): United States $ 8,119 79 % $ 8,774 79 % $ 8,478 80 % South America 1,544 15 1,534 14 1,495 14 Mexico 568 6 727 7 584 6 Total $ 10,231 100 % $ 11,035 100 % $ 10,557 100 % (1) Revenues for reportable segments include intersegment revenues of $9 million, $75 million, $101 million, and $192 million for 2015, $10 million, $69 million, $91 million and $342 million for 2014, and $10 million, $70 million, $91 million and $232 million for 2013 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively. (2) For 2013, amount is after preferred dividends and call premium on preferred stock. (3) After preferred dividends. (4) December 31, 2014 and 2013 have been adjusted for the retrospective adoption of ASU 2015-03. (5) Includes net property, plant and equipment and investments. (6) Amounts are based on where the revenue originated, after intercompany eliminations.

QUARTERLY FINANCIAL DATA

QUARTERLY FINANCIAL DATA	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Quarterly Financial Data	NOTE 17 . QUARTERLY FINANCIAL DATA (UNAUDITED) We provide quarterly financial information for Sempra Energy Consolidated , SDG&E and SoCalGas below: SEMPRA ENERGY (In millions, except per share amounts) Quarters ended March 31 June 30 September 30 December 31 2015: Revenues $ 2,682 $ 2,367 $ 2,481 $ 2,701 Expenses and other income $ 2,076 $ 1,971 $ 2,211 $ 2,269 Net income $ 458 $ 320 $ 282 $ 388 Earnings attributable to Sempra Energy $ 437 $ 295 $ 248 $ 369 Basic per-share amounts(1): Net income $ 1.85 $ 1.29 $ 1.14 $ 1.56 Earnings attributable to Sempra Energy $ 1.76 $ 1.19 $ 1.00 $ 1.48 Weighted average common shares outstanding 247.7 248.1 248.4 248.7 Diluted per-share amounts(1): Net income $ 1.83 $ 1.27 $ 1.12 $ 1.54 Earnings attributable to Sempra Energy $ 1.74 $ 1.17 $ 0.99 $ 1.47 Weighted average common shares outstanding 251.2 251.5 251.0 251.5 2014: Revenues $ 2,795 $ 2,678 $ 2,815 $ 2,747 Expenses and other income $ 2,408 $ 2,302 $ 2,368 $ 2,433 Net income $ 266 $ 292 $ 383 $ 321 Earnings attributable to Sempra Energy $ 247 $ 269 $ 348 $ 297 Basic per-share amounts(1): Net income $ 1.09 $ 1.19 $ 1.56 $ 1.31 Earnings attributable to Sempra Energy $ 1.01 $ 1.10 $ 1.41 $ 1.21 Weighted average common shares outstanding 245.3 245.7 246.1 246.4 Diluted per-share amounts(1): Net income $ 1.07 $ 1.17 $ 1.53 $ 1.28 Earnings attributable to Sempra Energy $ 0.99 $ 1.08 $ 1.39 $ 1.18 Weighted average common shares outstanding 249.7 250.1 250.8 251.3 (1) Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year. In the first quarter of 2015, SoCalGas adopted a CPUC decision in the TCAP requiring SoCalGas to recognize annual authorized revenue for core natural gas customers using seasonal factors established in the TCAP, instead of recognizing such revenue ratably over the year as was previously required. While this seasonalization caused variability in co mparable revenue and earnings from quarter to quarter within the year, it did not impact full-year 2015 results, nor have any impact on cash flows. Accordingly, substantially all of SoCalGas ’ annual earnings were recognized in the first and fourth quarters of the year. Compared to the same periods in 2014, this “ seasonalization ” at SoCalGas impacted Revenues, Net Income and Earnings Attributable to Sempra Energy as follows: For the first quarter of 2015, $163 million higher Revenues and $113 million higher Net Income and Earnings Attributable to Sempra Energy For the second quarter of 2015, $72 million lower Revenues and $48 million lower Net Income and Earnings Attributable to Sempra Energy For the third quarter of 2015, $158 million lower Revenues and $113 million lower Net Income and Earnings Attributable to Sempra Energy For the fourth quarter of 2015, $67 million higher Revenues and $48 million higher Net Income and Earnings Attributable to Sempra Energy In addition to the impact of seasonalization , Reve nues and Expenses and Other Income decreased in each quarter of 2015 compared to 2014 partly due to lower average cost of natural gas at SoCalGas . In the first quarter of 2015, Revenues and Expenses and Other Income decreased due to lower demand for natura l gas primarily from warmer weather in the first quarter of 2015 compared to the same period in 2014. In the fourth quarter of 2015, Revenues and Expenses and Other Income increased due to higher demand for natural gas primarily from cooler weather in the fourth quarter of 2015 compared to the same period in 2014. In each of the quarters of 2015 compared to the same periods in 2014, Revenues and Expenses and Other Income decreased as a result of lower cost of electric fuel and purchased power at SDG&E, incl uding the impact of declining natural gas prices offset by an increase from the incremental purchase of renewable energy at higher prices. In the second quarter of 2015, Expenses and Other Income were favorably impacted by $61 million and Net Income and Ea rnings Attributable to Sempra Energy were favorably impacted by $36 million due to the sale of the remaining 625-MW block of the 1,250-MW Mesquite Power natural gas-fired power plant, as we discuss in Note 3. In the first and fourth quarters of 2015 and 20 14, SDG&E recorded adjustments to the SONGS plant closure loss, as we discuss in Note 13 under “Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII) – Accounting and Financial Impacts.” In the thir d quarter of 2014, Net Income and Earnings Attributable to Sempra Energy included $25 million tax benefit due to the release of a Louisiana state valuation allowance against a deferred tax asset associated with Cameron LNG developments. We discuss quarter ly fluctuations related to SDG&E and SoCalGas below. SDG&E (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2015: Operating revenues $ 966 $ 972 $ 1,230 $ 1,051 Operating expenses 684 745 930 802 Operating income $ 282 $ 227 $ 300 $ 249 Net income $ 151 $ 130 $ 182 $ 143 (Earnings) losses attributable to noncontrolling interest (4) (4) (12) 1 Earnings attributable to common shares $ 147 $ 126 $ 170 $ 144 2014: Operating revenues $ 987 $ 1,063 $ 1,233 $ 1,046 Operating expenses 766 821 957 826 Operating income $ 221 $ 242 $ 276 $ 220 Net income $ 101 $ 129 $ 169 $ 128 Earnings attributable to noncontrolling interest (2) (6) (12) ― Earnings attributable to common shares $ 99 $ 123 $ 157 $ 128 In each of the quarters of 2015 compared to the same periods in 2014, Operating Revenues and Operating Expenses decreased as a result of lower cost of electric fuel and purchased power, including the impact of declining natural gas prices offset by an increase from the incremental purchase of renewable energy at higher prices. The decreases in Operating Revenues were partially offset by increases from CPUC-authorized 2015 attrition and higher authorized revenues from electric transmission, both of which impacted Net Income and Earnings Attributable to Common Shares. In addition, Operating Revenues and Operating Expenses were higher due to authorized revenues, starting in 2015, for the recovery of the SONGS regulatory assets pursuant to an amended settlement agreeme nt approved by the CPUC in 2014 . In the first and fourth quar ters of 2015 and 2014, SDG&E recorded adjustments to the SONGS plant closure loss, as we discuss in Note 13 under “Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII) – Accounting and Financial Impacts.” SOCALGAS (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2015: Operating revenues $ 1,048 $ 780 $ 620 $ 1,041 Operating expenses 728 686 633 834 Operating income (loss) $ 320 $ 94 $ (13) $ 207 Net income (loss) $ 214 $ 71 $ (8) $ 143 Dividends on preferred stock ― (1) ― ― Earnings (losses) attributable to common shares $ 214 $ 70 $ (8) $ 143 2014: Operating revenues $ 1,085 $ 917 $ 855 $ 998 Operating expenses 956 795 702 881 Operating income $ 129 $ 122 $ 153 $ 117 Net income $ 78 $ 81 $ 98 $ 76 Dividends on preferred stock ― (1) ― ― Earnings attributable to common shares $ 78 $ 80 $ 98 $ 76 Compared to the same periods in 2014, Operating Revenues, Net Income and Earnings Attributable to Common Shares were impacted by seasonalization of interim period recognition of annual authorized revenue for core natural gas customers as follows: For the first quarter of 2015, $163 million higher Operating Revenues and $113 million higher Net Income and Earnings For the second quarter of 2015, $72 million lower Operating Revenues and $48 million lower Net Income and Earnings For the third quarter of 2015, $158 million lower Operating Revenues and $113 million lower Net Income and Earnings For the fourth quarter of 2015, $67 million higher Operating Revenues and $48 million higher Net Income and Earnings In addition to the impact of seasonalization , Operati ng Revenues and Operating Expenses decreased in each quarter of 2015 compared to 2014 primarily due to lower average cost of natural gas. In the first quarter of 2015, Operating Revenues and Operating Expenses decreased due to lower demand for natural gas primarily from warmer weather in the first quarter of 2015 compared to the same period in 2014. In the fourth quarter of 2015, Operating Revenues and Operating Expenses increased due to higher demand for natural gas primarily from cooler weather in the fou rth quarter of 2015 compared to the same period in 2014 In each of the quarters of 2015 compared to the same periods in 2014, Operating Revenues, Net Income and Earnings Attributable to Common Shares included higher CPUC-authorized 2015 attrition. In the third quarter of 2015, Net Loss was partially offset by favorable resolution of prior years’ income tax items.

SUBSEQUENT EVENT

SUBSEQUENT EVENT	12 Months Ended
	Dec. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Subsequent Events	NOTE 18. SUBSEQUENT EVENT SEMPRA MEXICO Asset Held for Sale, Power Plant In February 2016, management approved a plan to market and sell Sempra Mexico’s Termoeléctrica de Mexicali, a 625-MW natural gas-fired power plant located in Mexicali, Baja California, Mexico. As a result, in February 2016, we stopped depreciating the plant and classified the plant as an asset held for sale. The carrying value at December 31, 2015 was $262 million. Although we believe fair value approximates or exceeds ca rrying value of the asset, in the event that the estimated sales price from the planned sale of Termoeléctrica de Mexicali is less than the carrying value, we may recognize an impairment loss in our results of operations.

SCHEDULE I, CONDENSED FINANCIAL

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
	Dec. 31, 2015
Condensed Financial Information Of Parent (Tables) [Abstract]
Condensed Financial Information of Parent	SCHEDULE I – SEMPRA ENERGY CONDENSED FINANCIAL INFORMATION OF PARENT SEMPRA ENERGY CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts) Years ended December 31, 2015 2014 2013 Interest income $ ― $ ― $ 42 Interest expense (261) (235) (239) Operation and maintenance (66) (78) (63) Other income, net 7 50 41 Income tax benefits 150 133 117 Loss before equity in earnings of subsidiaries (170) (130) (102) Equity in earnings of subsidiaries, net of income taxes 1,519 1,291 1,103 Net income/earnings $ 1,349 $ 1,161 $ 1,001 Basic earnings per common share $ 5.43 $ 4.72 $ 4.10 Weighted-average number of shares outstanding (thousands) 248,249 245,891 243,863 Diluted earnings per common share $ 5.37 $ 4.63 $ 4.01 Weighted-average number of shares outstanding (thousands) 250,923 250,655 249,332 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, Pretax Income tax Net-of-tax amount benefit (expense) amount 2015: Net income $ 1,199 $ 150 $ 1,349 Other comprehensive income (loss): Foreign currency translation adjustments (260) ― (260) Financial instruments (80) 33 (47) Pension and other postretirement benefits (3) 1 (2) Total other comprehensive loss (343) 34 (309) Comprehensive income $ 856 $ 184 $ 1,040 2014: Net income $ 1,028 $ 133 $ 1,161 Other comprehensive income (loss): Foreign currency translation adjustments (193) ― (193) Financial instruments (106) 42 (64) Pension and other postretirement benefits (20) 8 (12) Total other comprehensive loss (319) 50 (269) Comprehensive income $ 709 $ 183 $ 892 2013: Net income $ 884 $ 117 $ 1,001 Other comprehensive income (loss): Foreign currency translation adjustments 111 ― 111 Financial instruments 13 (4) 9 Pension and other postretirement benefits 47 (19) 28 Total other comprehensive income 171 (23) 148 Comprehensive income $ 1,055 $ 94 $ 1,149 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED BALANCE SHEETS (Dollars in millions) December 31, December 31, 2015 2014(1) Assets: Cash and cash equivalents $ 4 $ 3 Due from affiliates 62 101 Deferred income taxes ― 398 Other current assets 4 15 Total current assets 70 517 Investments in subsidiaries 15,586 14,557 Due from affiliates 457 174 Deferred income taxes 2,188 1,544 Other assets 641 609 Total assets $ 18,942 $ 17,401 Liabilities and shareholders’ equity: Current portion of long-term debt $ 752 $ ― Due to affiliates 332 338 Income taxes payable 42 93 Other current liabilities 310 271 Total current liabilities 1,436 702 Long-term debt 5,195 4,644 Due to affiliates ― 230 Other long-term liabilities 502 499 Shareholders’ equity 11,809 11,326 Total liabilities and shareholders’ equity $ 18,942 $ 17,401 (1) As adjusted for the retrospective adoption of ASU 2015-03. See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2015 2014 2013 Net cash used in operating activities $ (255) $ (260) $ (131) Dividends received from subsidiaries 350 300 50 Expenditures for property, plant and equipment (43) (15) (1) Purchase of trust assets (5) (4) (5) Proceeds from sales by trust ― ― 10 Capital contribution to subsidiaries ― ― (6) (Increase) decrease in loans to affiliates, net (457) 627 962 Cash (used in) provided by investing activities (155) 908 1,010 Common stock dividends paid (628) (598) (606) Issuances of common stock 52 56 62 Repurchases of common stock (74) (38) (45) Issuances of long-term debt 1,248 499 498 Payments on long-term debt ― (800) (650) (Decrease) increase in loans from affiliates, net (230) 234 (147) Tax benefit related to share-based compensation 52 ― ― Other (9) (4) (3) Cash provided by (used in) financing activities 411 (651) (891) Increase (decrease) in cash and cash equivalents 1 (3) (12) Cash and cash equivalents, January 1 3 6 18 Cash and cash equivalents, December 31 $ 4 $ 3 $ 6 SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES Financing of build-to-suit property $ 61 $ 61 $ 14 Common dividends issued in stock 55 42 ― Dividends declared but not paid 174 163 154 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY NOTES TO CONDENSED FINANCIAL INFORMATION OF PARENT Note 1. Basis of Presentation Sempra Energy accounts for the earnings of its subsidiaries under the equity method in this unconsolidated financial information. Other Income , N et, o n the Condensed Statements of Operations include s $3 million, $27 million and $ 39 million of gains on dedicated assets in support of our executive retirement and deferred compensation plans in 2015, 2014 and 2013, respectively . Because of its nature as a holding company, Sempra Energy classifies dividends received from subsidiaries as an investing cash flow. Note 2. New Accounting Standards Accounting Standards Update (ASU) 2015-03, “Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuanc e Costs” (ASU 2015-03) and ASU 2015-15, “Interest – Imputation of Interest: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements” (ASU 2015-15): ASU 2015-03 provides guidance on the financial statement presentation of debt issuance costs and requires an entity to present debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related long-term debt liability. This guidance must be applied using a full retrospective approach for all periods presented in the period of adoption. Sempra Energy retrospectively adopted ASU 2015-03 during the annual reporting period ended December 31, 2015, and the adoption did not affect its results of operations or cash flows. The Condens ed Balance Sheet at December 31, 2014 reflects the reclassification of $22 million from Other Assets to Long-Term Debt. ASU 2015-17, “Income Taxes – Balance Sheet Classification of Deferred Taxes” (ASU 2015-17): ASU 2015-17 simplifies the financial stateme nt presentation of deferred tax assets and liabilities and requires an entity to present deferred tax assets and liabilities as noncurrent on the balance sheet. This guidance may be applied prospectively or retrospectively. Sempra Energy adopted ASU 2015- 17 on a prospective basis for the annual reporting period ended December 31, 2015, and the adoption did not affect its results of operations or cash flows. The Consolidated Balance Sheet at December 31, 2014 was not retrospectively adjusted. ASU 2016-02, “ Leases” (ASU 2016-02): ASU 2016-02 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to not recognize leases with a maximu m possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from p revious provisions of accounting principles generally accepted in the United States of America ( U.S. GAAP), other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09, “ Revenue from Contracts with Cus tomers.” ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permi tted, and is effective for interim periods in the year of adoption. The standard requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospect ive approach includes optional practical expedients that may be elected, which would allow entities to continue to account for leases that commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified , except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting. Note 3. Long-T erm Debt The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, December 31, 2015 2014(1) 6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating rate swaps effective January 2011 (4.77% at December 31, 2015) $ 750 $ 750 2.3% Notes April 1, 2017 600 600 6.15% Notes June 15, 2018 500 500 9.8% Notes February 15, 2019 500 500 2.4% Notes March 15, 2020 500 ― 2.85% Notes November 15, 2020 400 ― 2.875% Notes October 1, 2022 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 ― 6% Notes October 15, 2039 750 750 Market value adjustments for interest rate swaps, net (2) ― Build-to-suit lease 136 75 5,984 4,675 Current portion of long-term debt (752) ― Unamortized discount on long-term debt (10) (9) Unamortized debt issuance costs (27) (22) Total long-term debt $ 5,195 $ 4,644 (1) As adjusted for the retrospective adoption of ASU 2015-03. Excluding the build-to-suit lease and market value adjustments for interest rate swaps, maturities of long-term debt are $750 million in 2016, $600 million in 2017, $500 million in 2018, $500 million in 2019, $900 million in 2020 and $2.6 billion thereafter. Addition al information on Sempra Energy’ s long-term debt is provided in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report . Note 4 . Commitments and Contingencies For contingencies and guarantees related to Sempra Energy, refer to Notes 4, 5 and 15 of the Notes to Consolidated Financial Statements in the Annual Report .

SIGNIFICANT ACCOUNTING POLICI27

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Policies)	12 Months Ended
	Dec. 31, 2015
Consolidation Policy [Abstract]
Principles of Consolidation	Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to ex ercise significant influence, but not control. VARIABLE INTEREST ENTITIES (VIE) We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based upon qualitative and quantitative analyses, which assess the purpose and design of the VIE; the nature of the VIE’s risks and the risks we absorb; the power to direct activities that most significantly impact the economic performance of the VIE; and the obligation to absorb losses or right to receive benefits that could be significant to t he VIE.
Public Utilities Policy [Abstract]
Regulatory Matters, Policy	REGULATORY MATTERS Effects of Regulation The accounting policies of the California Utilities conform with U.S. GAAP for rate- regulated enterprises and reflect the policies of the California Public Utilities Commission (CPUC) and the Federal Energy Regulatory Commission (FERC). The California Utilities prepare their financial statements in accordance with U.S. GAAP provisions governing rate- regulated operations. Under these provisions, a regulated utility records regulatory asset s, which are generally costs th at would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover th ose asset s from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regula tory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, gen erally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future ra tes. In addition, the California Utilities record regulatory liabilities when the CPUC or the FERC requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery requires significant judgment by management and may include, but is not limited to, consideration of: the nature of the event giving rise to the assessment; existing statutes and regulatory code; legal precedents ; regula tory principles and analogous regulatory actions; testimony presented in regulatory hearings; proposed regulatory decisions; final regulatory orders; a commission-authorized mechanism established for the accumulation of costs; status of applications for re hearings or state court appeals; specific approval from a commission; and historical experience. Mobile Gas , Willmut Gas and Ecogas also apply U.S. GAAP for rate- regulated utilities to their operations , including the same evaluation of probability of recov ery of regulatory assets described above . Regulatory Balancing Accounts Over- and under collected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, primarily commodity costs. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. Balancing account treatment eliminates the impact on earnings from variances in the covered costs from authorized amounts. Absent balancing account treatment, variations in the cost of fuel supply and c ertain operating and maintenance costs from amounts approved by the CPUC would increase volatility in utility earnings.
Fair Value Measurements Policy [Abstract]
Fair Value Measurements, Policy	FAIR VALUE MEASUREMENTS We apply recurring fair value measurements to certain assets and liabilities, primarily nuclear decommissioning and benefit plan trust assets and derivatives. “F air 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 (exit price). A fair value measurement reflect s the assumptions market participants would us e in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an is suer ’ s credit standing when measuring its liabilities at fair value. We establish a f air value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for iden tical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Quoted prices are available in active markets for identical asset s or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily co nsist of listed e quities, U.S. government treasury securities and exchange-traded derivatives . Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporti ng date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: quoted forward prices for commodities tim e value current market and contractual prices for the underlying instruments volatility factors other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be de rived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the N uclear Decommissioning Trusts and in our pension and postretirement benefit plans, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter (OTC) forwards and options. Level 3 – Pricing inputs include significant inputs th at are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management ’ s best estimate of fair value from the perspective of a market participant.
Cash And Cash Equivalents Policy [Abstract]
Cash and Cash Equivalents, Policy	CASH AND CASH EQUIVALENTS Cash equivalents are highly liquid investments with maturities of three months or less at the date of purchase.
Allowance For Doubtfull Accounts [Abstract]
Trade And Other Accounts Receivable, Policy	COLLECTION ALLOWANCES We record allowances for the collection of trade and other accounts and notes receivable, which include allowances for doubtful customer accounts and for other receivables. We evalu ate accounts receivable collecta bility using a combination of factors, including past due status based on contractual terms, trends in write-offs, the age of the receivable, counterparty creditworthiness , economic conditions and specific events, such as bankruptcies. Adjustments to the allowance for doubtful accounts are made when necessary based on the results of analysis, the aging of receivables, and histo rical and industry trends. We write off accounts receivable in the period in which we deem the r eceivable to be uncollectible. We record recoveries of accounts receivable previously written off when it is known that they will be received.
Inventory Policy [Abstract]
Inventories, Policy	INVENTORIES The California Utilities value natural gas inventory by the last-in first-out (LIFO) method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. Materials and supplies at the California Utilities are generally valued at the lower of average cost or net realizable value . Sempra South American Utilities, Sempra Mexico and Sempra Natural Gas value natural gas inventory and materials and supplies at the lower of average cost or net realizable value . Sempra Mexico and Sempra Natural Gas value liquefied natural gas (LNG) inventory by the first-in first-out method.
Income Tax Policy [Abstract]
Income Taxes, Policy	INCOME TAXES Income tax expense includes current and deferred income taxes from operations during the year. W e record deferred income taxes for temporary differences between the book and the tax ba sis of assets and liabilities. Investment tax credits from prior years are amortized to income by the California Utilities over the estimated service lives of the properties as required by the CPUC. At our other businesses, we reduce the book basis of the related asset by the amount of investment tax credit earned. At Sempra Renewables, production tax credits are recognized in income tax expense as earned. The California Utilities and Sempra Mexico r ecognize regulatory assets to offset deferred tax liabilities if it is probabl e that the amounts will be recovered from customers; and regulatory liabilities to offset deferred tax assets if it is probable that the amount s will be returned to customers. Except for the current year Peruvian earnings for which we have accrued U.S. in come tax, w e currently do not record deferred income taxes for basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries and non-U.S. joint ventures because the related cumulative undistributed earnings are in definitely reinvested . When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a “more likely than not” chance of being sustained (based on the position’s technic al merits) upon challenge by the respective authorities. The term “more likely than not” means a likelihood of more than 50 percent. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the “more likely than not” criterion at the largest amount of tax benefit that is greater than 50 percent likely of being realized upon its effective resolution. Unrecognized tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our effective tax rate . For SDG&E and SoCalGas , t he CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the re gulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the current effect ive income tax rate. As a result , changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the effective income tax rate. The foll owing items are subject to flow- through treatment: repairs expend itures related to a certain portion of utility plant fixed assets the equity portion of AFUDC a portion of the cost of removal of utility plant assets utility self-developed software expenditures depreciation on a certain portion of utility plant assets st ate income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico has similar flow- through treatment. We use the deferral method for investment tax credits (ITC). For certain solar and wind generating assets placed into service during 2012, we elected to seek cash grants rather than ITC for which the projects also qualify. Accordingly, cash grant accounting was applied. Grant accounting for cash grants is very similar to the deferral method of accounting for ITC, the primary difference being the recording of a cash grant receivable instead of an income tax receivable. Under the deferral method of accounting for ITC and under grant accounting for cash grants, we record a deferred income tax benefit on day one, which is reflected in income tax expense , by recording a deferred income tax asset during the year the renewable energy assets are placed in service. This deferred income tax asset results from the day-one difference in the income tax basis and financial statement basis of the renewable ene rgy assets, referred to as the day - one basis difference. The financial statement ba sis of the assets is reduced by 100 percent of the ITC or grant expected; U.S. federal income tax basis is reduced by only 50 percent for both ITC and grants; and state income tax basis is reduced by 5 0 percent for grants and not at all for ITC. Conversion of ITC to cash is generally dependent on reducing income tax payments and thus the existence of a U.S. federal net operating loss (NOL) carryforw ard can result in delaying this conversion.
Emission Credits Policy [Abstract]
Emission Credits or Allowances Policy	GREENHOUSE GAS (GHG) ALLOWANCES The California Utilities, Sempra Mexico and Sempra Natural Gas are required by California Assembly Bill 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas transportation . We record GHG allowances at the lower of weighted average cost or market, and include them in Other Current Assets and Sundry on the Consolidated Balance Sheets based on the dates that they are required to be surrendered. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. We include the obligation in Other Cu rrent Liabilities and Deferred Credits and Other on the Consolidated Balance Sheets based on the dates that the allowances will be surrendered. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. The California U tilities balance costs and revenues associated with the GHG program through Regulatory Balancing Accounts on the Consolidated Balance Sheets. RENEWABLE ENERGY CERTIFICATES Renewable e nergy certificates (RECs ) represent property rights established by governmental agencies for the environmental, social, and other nonpower qualities of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable power purchase agreements, internal generation or separate purchases in the market to comply with renewable portfolio standards established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with renewa ble portfolio standards . The cost of RECs at SDG&E is recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Consolidated Statements of Operation s .
Property Plant And Equipment Policy [Abstract]
Property, Plant and Equipment, Policy	PROPERTY , PLANT AND EQUIPMENT Property, plant and equipment primarily represents the buildings, equipment and oth er facilities used by the California Utilities to provide natural gas and electric utility se rvices, and by Sempra International and Sempra U.S. Gas & Power in their operations, including construction work in progress at these operating units. Property, plant and equipment also includes lease improvements and other equipment at Parent and Other, as well as property acquired under a build-to-su it lease, which we discuss further in Note 15. Our plant costs include labor materials and contract services expenditures for replacement parts incurred during a major maintenance outage of a generating plant In addition, the cost of utility plant at our r ate-regulated businesses and non-utility regulated projects that meet the regulatory accounting requirements of U.S. GAAP at Sempra Mexico and Sempra Natural Gas includes AFUDC. We discuss AFUDC below. The cost of non-utility plant includes capitalized int erest. Maintenance c osts are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation. Depreciation expense is based on the straight-line method over the useful lives of the assets or, for the California Utilities, a shorter period prescribed by the CPUC. Depreciation expense is computed using the stra ight-line method over the asset’ s estimated original composite useful life , the CPUC-prescribed period or the remaining term of the s ite leases, whichever is shortest . The Californi a Utilities finance their construction projects with borrowed funds and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of property, plant and equipment. The California Utilities earn a return on the capitalized AFUDC after the utility property is placed in service and recover the AFUDC from their customers over the expected useful lives o f the assets. Pipeline projects currently under construction by Sempra Mexico and Sempra Natural Gas that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC related to equity. Sempra International and Sempra U.S. Gas & Power businesses capitalize interest costs incurred to finance capital projects and interest on equity method investments that have not commenced planned principal operations. The California Utilities also capitalize certain interest costs.
Goodwill And Intangible Assets, Policy [Abstract]
Goodwill and Intangible Assets, Policy	GOODWILL AND OTHER INTANGIBLE ASSETS Goodwill Goodwill is the excess of the purchase price over the fair value of the identifiable net assets of acquired companies measured at the time of acquisition . Goodwill is not amortized but we test it for impairment annually on October 1 or whenever events or changes in circumstances necessitate an evaluation . Impairment of goodwill occurs when the carrying amount (book value) of goodwill exceeds its implied fair value. If the carrying value of the reporting unit, in cluding goodwill, exceeds its fair value, and the book valu e of goodwill is greater than its fair value on the test date, we record a goodwill impairment loss. For our annual goodwill impairment testing, under current U.S. GAAP guidance we have the option to first make a qualitative assessment of whether it is more likely than not that the fair value of a reporting unit is less than its carrying amount before applying the two-step, quantitative goodwill impairment test. If we elect to perform the qualitati ve assessment, we evaluate relevant events and circumstances, including but not limited to, macroeconomic conditions, industry and market considerations, cost factors, changes in key personnel and the overall financial performance of the reporting unit. If , after assessing these qualitative factors, we determine that it is more likely than not that the fair value of a reporting unit is less than its carrying amount, then we perform the two-step goodwill impairment test. When we perform the two-step, quantit ative goodwill impairment test, we exercise judgment to develop estimates of the fair value of the reporting unit and the corresponding goodwill. Our fair value estimates are developed from the perspective of a knowledgeable market participant. We consider observable transactions in the marketplace for similar investments, if available, as well as an income-based approach such as discounted cash flow analysis . A discounted cash flow analysis may be based directly on anticipated future revenues and expenses and may be performed based on free cash flows generated within the reporting unit. Critical assumptions that affect our estimates of fair value may include consideration of market transactions future cash flows the appropriate risk-adjusted discount rate c ountry risk entity risk Other Intangible Assets Other Intangible A ssets primarily represent storage and development rights related to the natural gas storage facilities of Bay Gas Storage Company, Ltd. (Bay Gas) and Mississippi Hub , LLC (Mississippi Hub), which are being amortized over their estimated useful lives as shown in the table below.
Impairment Or Disposal Of Long Lived Assets Policy [Abstract]
Impairment or Disposal of Long-lived Assets, Policy	LONG-LIVED ASSETS W e test long-lived assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets . Long-lived assets include intangible assets subject to amortization, but do not include investments in un consolidated subsidiaries. Events or changes in circumstances that indicate that the carrying amount of a long-lived asset may not be recoverable may include significant decreases in the market p rice of an asset a significant adverse change in the extent or manner in which we use an asset or in its physical condition a significant adverse change in legal or regulatory factors or in the business climate that could affect the value of an asset a cur rent period operating or cash flow loss combined with a history of operating or cash flow losses or a projection of continuing losses associated with the use of a long-lived asset a current expectation that, more likely than not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life A long-lived asset is impaired when the estimated future undiscounted cash flows are less than the carrying amount of the asset . If that compa rison indica tes that the asset’s carrying value may not be recoverable , the impairment is measured based on the difference between the carrying amount and the fair value of the asset . This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
Asset Retirement Obligations Policy [Abstract]
Asset Retirement Obligation Policy	ASSET RETIREMENT OBLIGATIONS For tangible long-lived assets, we record asset retirement obligations for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estim ated retirement cost over the life of the related asset by depreciating the asset retirement cost (measured as the present value of the obligation at the time of the asset’s acquisition) , and accreting the obligation until the liability is settled. Rate-regulated entities, including the Califo rnia Utilities, record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with U.S. GAAP and costs recovered through the rate-making process.
Commitments And Contingencies Policy [Abstract]
Contingencies, Policy	CONTINGENCIES We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and: i nformation available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events ; and the amount of the loss can be reasonably estimated. We do not accrue conti ngencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
Legal Costs Policy [Abstract]
Legal Fees, Policy	LEGAL FEES Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred. LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could material ly adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.
Noncontrolling Interest Policy [Abstract]
Noncontrolling Interest Policy [Text Block]	NONCONTROLLING INTERESTS Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as noncontrolling interests. Noncontrolling interests are reported as a separate component of equity on the Consolidated Balance Sheets. Earnings/losses attributable to the noncontrolling interests are separately identified on the Consolidated Statements of Operations, and net income/loss and compr ehensive income/loss attributable to noncontrolling interests are separately identified on the Consolidated Statements of Comprehensive Income (Loss) and Consolidated Statements of Changes in Equity.
Revenue Recognition Policy [Abstract]
Revenues, Policy	REVENUES Utilities Our California Utilities generate revenues primarily from deliveries to their customers of electricity by SDG&E and natural gas by both SoCalGas and SDG&E and from related services. We record these revenues following the accrual method and recognize them upon delivery and performance. As described below, recorded revenues include those authorized by the CPUC to support our operations (“ decoupled revenue”), as well as commodity costs that are passed through to core gas customers and elect ric customers: Decoupled r evenue – The regulatory framework permits the California Utilities to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. Any difference between actual demand and the annual demand approved in the proceedings is r ecovered or refunded in authorized revenue in the subsequent year. This design, commonly known as “decoupling,” is intended to minimize any impact on earnings due to variability in volumetric demand for ele ctricity and natural gas. Commodity costs – The regulatory framework authorizes the California Utilities to recover the actual cost of natural gas procured and delivered to its core customers in ra tes substantially as incurred. Actual electricity procurem ent costs are recovered as power is delivered, or to the extent actual amounts vary from forecasts, generally recovered or refunded within the subsequent year. The California Utilities also record revenue from CPUC-approved incentive awards, some of which r equire approval by the CPUC prior to being recognized. We provide additional discussion on utility incentive mechanisms in Note 14. On a monthly basis, SoCalGas accrues natural gas storage contract revenues, which consist of storage reservation and variabl e charges based on negotiated agreements with terms of up to 1 5 years. Our natural gas utilities outside of California (Mobile Gas, Willmut Gas and Ecogas ) apply U.S. GAAP for revenue recognition consistent with the California Utilities. Our electric dist ribution utilities in South America, Chilquinta Energía and Luz del Sur, serve primarily regulated customers, and their revenues are based on tariffs that are set by the National Energy Commission ( Comisión Nacional de Energ í a , or CNE) in Chile and the Ene rgy and Mining Investment Supervisory Body ( Organismo Supervisor de la Inversión en Energ í a y Miner í a , or OSINERGMIN) of the National Electricity Office under the Ministry of Energy and Mines in Peru. The tariffs charged are based on an efficient model d istribution company defined by Chilean law in the case of Chilquinta Energ í a , and OSINERGMIN in the case of Luz del Sur. The tariffs include operation and maintenance costs, an internal rate of return on the new replacement value of depreciable assets, cha rges for the use of transmission systems, and a component for the value added by the distributor. Tariffs are designed to provide for a pass-through to customers of the main noncontrollable cost items (mainly power purchases and transmission charges), reco very of reasonable operating and administrative costs, incentives to reduce costs and make needed capital investments and a regulated rate of return on the distributor’s regulated asset base. Because the tariffs are based on a model and are intended to cov er the costs of the model company, but are not based on the costs of the specific utility and may not result in full cost recovery, they do not meet the requirement necessary for treatment under applicable U.S. GAAP for rate-regulated accounting. Energy-Related Businesses Sempra South American Utilities Sempra South American Utilities generate s re venues from energy-services companies that provi de electric c onstruction services and recognizes these revenues when services are provided in accordance with contractual agreements. The energy-services company in Chile also generates revenue from selling electricity to non-regulated customers. Sempra Me xico Sempra Mexico’s Termoeléctrica de Mexicali natural gas-fired power plant generates revenues from selling electricity and/or capacity to the California Independent System Operator (ISO) and to governmental, public utility and wholesale power marketing entities. Sempra Mexico recognizes t hese revenues as the electricity is delivered and capacity is provided . Sempra Mexico’s pipeline operations recognize reven ues from the sale and transportation of natural gas as deliveries are made and from fixed capacit y payments. Sempra Mexico also recognizes revenues from (1) the sale of LNG and natural gas as deliveries are made to counterparties and (2) from reservation and usage fees under terminal capacity agreements , nitrogen injection service agreements and tug s ervice agreements. It reports revenue net of value added taxes in Mexico. Sempra Mexico’s revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for natural gas. Semp ra Renewables For consolidated entities, Sempra Renewables generates revenues from the sale of solar power pursuant to power purchase agreements, and recognizes these revenues when the power is delivered. It also g enerates revenues for managing certain of its solar and wind project joint ventures. Sempra Natural Gas Sempra Natural Gas recognizes revenue on natural gas storage and transportation operations when services are provided in accordance with contractual agreements for the storage and transportation services. Sempra Natural Gas also records revenues from contractual counterparty obligations for non-delivery of LNG cargoes, as well as revenues from the sale of LNG and natural gas as deliveries are made to counterparties. Sempra Natural Gas revenues also include net realized gains and losses and the net change in the fair value of unrealized gains and losses on derivative contracts for power and natural gas. Prior to April 2015, Sempra Natural Gas generated revenues from selling electrici ty and/or capacity from its Mesquite Power facility (see Note 3) to the California ISO and to governmental, public utility and wholesale power marketing entities. Sempra Natural Gas recognized t hese revenues as the electricity was delivered and capacity wa s provided. Related to its LNG terminal, prior to October 1, 2014 , the effective date of Cameron LNG JV, Sempra Natural Gas recognized revenues from reservation and usage fees. We discuss the deconsolidation of Cameron LNG, LLC and related assets further i n Note 3.
Cost Of Sales Policy [Abstract]
Other Cost of Sales, Policy	OTHER COST OF SALES Other Cost of Sales primarily includes pipeline capacity costs, and pipeline transportation and natural gas marketing costs at Sempra Natural Gas ; electric construction services costs at Sempra South American Utilities ’ energy-services companies; and energy management service fees and costs associated with construction of a pipeline interconnect at Sempra Mexico
Selling General And Administrative Expenses Policy [Abstract]
Operation and Maintenance Expenses, Policy	OPERATION AND MAINTENANCE EXPENSES Operation and Maintenance includes operating and maintenance costs, and general and administrative costs, consisting primarily of personnel costs, purchased materials and services, litigation expense and rent.
Foreign Currency Transactions And Translations Policy [Abstract]
Foreign Currency Translation, Policy	FOREIGN CURRENCY TRANSLATION Our operations in South America and our natural gas distribution utility in Mexico use their local currency as their functional currency. The assets and liabilities of their foreign operations are translated into U.S. dollars at current exchange rates at the end of the reporting period, and revenues and expenses are translated at average exchange rates for the year. The r esulting noncash translation adjustments do not enter in to the calculation of earnings or retained earnings (unless the operation is being discontinued), but are reflected in Other Comprehensive Income (Loss) and in Accumulated Other Comprehensive Income (Loss)
Stockholders Equity Policy [Abstract]
Comprehensive Income, Policy	COMPREHENSIVE INCOME Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including: foreign currency translation adjustments changes in unamortized net actuarial gain or loss and prior service cost related to pension and other postretirement benefits plans unrealized gains or losses on available-for-sale securities certain hedging activities The Consolidated Statements of Comprehensive Inc ome show the changes in the components of other comprehensive income (loss) (OCI), including the amounts attributable to noncontrolling interests .

NEW ACCOUNTING STANDARDS (Polic

NEW ACCOUNTING STANDARDS (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Standards [Abstract]
New Accounting Standards Policy	NOTE 2. NEW ACCOUNTING STANDARDS We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures. SEMPRA ENERGY, SDG&E AND SOCALGAS Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers” (ASU 2014-09) and ASU 2015-14, “Revenue from Contracts with Customers: Deferral of the Effective Date” (ASU 2015-14): ASU 2014-09 provides accounti ng guidance for revenue from contracts with customers and affects all entities that enter into contracts to provide goods or services to the ir customers. The guidance also provides a model for the measurement and recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full re trospective approach for all periods presented in the period of adoption or a modified retrospe ctive approach. ASU 2015-14 defers the effective date of ASU 2014-09 by one year for all entities and permits early adoption on a limited basis. For public enti ties, ASU 2014-09 is effective for fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We are currently evaluating t he effect of the standard on our ongoing financial reporting and have not yet selected the year in which we will adopt the sta ndard or our transition method. ASU 2015-03, “Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Co sts” (ASU 2015-03) and ASU 2015-15, “Interest – Imputation of Interest: Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements” (ASU 2015-15) : ASU 2015-03 provides guidance on the financial statement pres entation of debt issuance costs and requires an entity to present debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related long-term debt liability. This guidance must be applied using a full retrospective appr oach for all periods presented in the period of adoption. We retrospectively adopted ASU 2015-03 during ou r annual reporting period ended December 31, 2015, and the adoption did not affect our results of operations or cash flows. The Sempra Energy, SDG&E and SoCalGas Consolidated Balance Sheets at December 31, 2014 reflect the reclassification of $81 million, $36 million, and $15 million, respectively, from Sundry to Long-Term Debt. We provide information about our long-term debt and related debt issuance costs in Note 5 . ASU 2015-15 clarifies ASU 2015-03 to provide additional guidance related to line-of-credit arrangements and states that the Securities and Exchange Commission staff would not object to an entity continuing to defer and present costs relate d to line-of-credit arrangements as an asset and subsequently amortizing the deferred costs ratably over the term of the line-of-credit arrangements, regardless of whether there are any outstanding borrowings on the line-of-credit arrangements. We adopted ASU 2015-15 for our annual reporting peri od ended December 31, 2015 and continue to include deferred costs related to our line-of-credit arrangements that are the subject of ASU 2015-15 in Sundry on the Sempra Energy, SDG&E and SoCalGas Consolidated Balanc e Sheets . ASU 2015-17, “Income Taxes – Balance Sheet Classification of Deferred Taxes” (ASU 2015-17): ASU 2015-17 simplifies the financial statement presentation of deferred tax assets and liabilities and requires an entity to present deferred tax asse ts and liabilities as noncurrent on the balance sheet. This guidance may be applied prospectively or retrospectively. We adopted ASU 2015-17 on a prospective basis for ou r annual reporting period ended December 31, 2015, and the adoption did not affect ou r result s of operations or cash flows. Prior Consolidated Balance Sheets of Sempra Energy, SDG&E and SoCalGas wer e not retrospectively adjusted. We discuss deferred tax assets and liabilities in Note 6. ASU 2016-01, “Recognition and Measurement of Financia l Assets and Financial Liabilities” (ASU 2016-01): ASU 2016-01 primarily affects the a ccounting for equity investments (except those accounted for under the equity method of accounting) , financial liabilities under the fair value option, and the presentati on and disclosure requirements for financial instruments. In addition, it clarifie s guidance related to the valuation allowance assessment when recognizing deferred tax assets resulting from unrealized losses on available-for-sale debt securities. Upon ado ption, entities must record a cumulative-effect adjustment to the balance sheet as of the beginning of the first reporting period in which the standard is adopted. The guidance on equity securities without readily determinable fair value will be applied pr ospectively to all equity investments that exist as of the date of adoption of the standard. For public entities, ASU 2016-01 is effective for fiscal years beg inning after December 15, 2017. We will adopt ASU 2016-01 on January 1, 2018 as required and do not expect it to materially affect our financial condition, resul ts of operations or cash flows. We will make the required changes to our disclosures upon adoption. ASU 2016-02, “Leases” (ASU 2016-02): ASU 2016-02 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to not recognize leases with a maximum possible term of less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP, other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures f or both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and le ssors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes optional practical expedients that may be elected, which would allow entities to c ontinue to account for leases that commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operat ing leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting.

ACQUISITION AND DIVESTITURE ACT

ACQUISITION AND DIVESTITURE ACTIVITY (Policies)	12 Months Ended
	Dec. 31, 2015
Acquisition And Divestiture Activity
Business Combinations Policy	We consolidate assets and liabilities acquired as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date.

INVESTMENTS IN UNCONSOLIDATED30

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Policies)	12 Months Ended
	Dec. 31, 2015
Investments
Investments in Unconsolidated Entities Policy	Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to ex ercise significant influence, but not control. We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. In these cases, our pro rata shares of the entities’ net assets are included in Investments on the Co nsolidated Balance Sheets. We adjust each investment for our share of each investee’s earnings or losses, dividends, and other comprehensive income or loss. We evaluate the carrying value of unconsolidated entities for impairment under the U.S. GAAP provisions for equity method investments .

EMPLOYEE BENEFIT PLANS (Policie

EMPLOYEE BENEFIT PLANS (Policies)	12 Months Ended
	Dec. 31, 2015
Pension and other postretirement benefit
Pension And Other Postretirement Plans Policy	NOTE 7 . EMPLOYEE BENEFIT PLANS We are required by applicable U.S. GAAP to: recognize an asset for a plan ’ s overfunded status or a liability for a plan ’ s underfunded status in the statement of financial position; measure a plan ’ s assets and its obligations that determine its funded status as of the end of the fiscal year (with limited exceptions); and recognize ch anges in the funded status of pension and other postretirement benefit plan s in the year in which the changes occur. Generally, those c hanges are reported in other comprehensive income and as a separate component of shareholders ’ equity. The detailed information presented below covers the employee benefit plans of Sempra Energy and its principal subsidiaries . Sempra Energy has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E and SoCalGas , which collectively cover all eligible employees, including members of the Sempra Energy board of directors who were participants i n a predecessor plan on or before June 1, 1998. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology . IEnova has an unfunded noncontributory defined benefit plan covering all employees. Chilquinta Energía has an unfunded non contributory de fined benefit plan covering all employ ees hired before October 1, 1981. In addition, IEnova and Chilquinta Energía have an unf unded noncontributory terminat ion indemnity obligation covering all employees. The plans generally provide defined benefits to retirees based on date of hire, years of service and final average earnings . Sempra Energy also has other postretirement benefit plans (PBOP) , including separate plans for SD G&E and SoCalGas , which collectively cover all domestic (except Willmut Gas) and certain foreign employees. The life insurance plans are both contributory and noncontributory , and the health care plans are contr ibutory. Participants ’ contributions are adjusted annually. Other postretirement benefits include medical benefits for retirees ’ spouses. Chilquinta Energía also has two noncontributory postretirement benefit plans which cover substantially all employees – a heal th care plan and an energy subsidy plan that provides for reduced energy rates . The health care plan includes benefits f or retirees’ spouses and depende nts . Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amo unts. These assumptions include discount rates expected return on plan assets health care cost trend rates mortality rates rate of com pensation increases termination and retirement rates utilization of postretirement welfare benefits payout elections (lump sum or annuity) lump sum interest rates We review these assumptions on an annual basis and update them as appropriate. We consider c urrent market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans. Net Assets and Liabilities The assets and liabilities of the pension and other postretirement benefit plans are affected by changing marke t conditions as well as when actual plan experience is different than assumed. S uch eve nts result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Our funded pension and other postretirement benefit plans use the asset smoothing method , except for those at SDG&E and the other postretirement benefit plan at Mobile Gas . This method develops an asset value that recognizes realized and unrealized investment gains and losses ov er a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic cost. SDG&E does not use t he asset smoothing method, but rather recognizes realized and unrealized investment gains and losses during the current year. The 10-percent corridor accounting method is used at Sempra Energy Consolidated , SDG&E a nd SoCalGas . Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10 percent of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of a ctive participants. The asset smoothing and 10-percent corridor accounting methods help mitigate volatility of net periodic costs from year to year. We recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets or liabilities, respectively; unrecognized changes in these assets and/or liabilities are normally recorded in Accumulated Other Comprehensive Income (Loss) on the balance sheet. The California Utilities and Mobile Gas record regulatory assets a nd liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on agreements with regulatory agencies. At Willmut Gas, pension contributions are recovered in rates on a prospective basis, but are not recorded as a regulatory asset pending recovery. The California Utilities record annual pension and other postretirement net periodic benefit costs equal to the contributions to their plans as authori zed by the CPUC. The annual contributions to the pension plans are limited to a minimum required funding amount as determined by the IRS. The annual contributions to the other postretirement plans are equal to the lesser of the maximum tax deductible amoun t or the net periodic cost calculated in accordance with U.S. GAAP for pension and other postretirement benefit plans. Mobile Gas records annual pension and other postretirement net periodic benefit costs based on an estimate of the net periodic cost at th e beginning of the year calculated in accordance with U.S. GAAP for pension and other postretirement benefit plans, as authorized by the Alabama Public Service Commission. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for the California Utilities are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under GAAP. Fair Value of Pension and Other Postretirement Benefit Plan Assets We classify the investments in Sempra Energy’s pension master trust and t he trusts for the California Utilities’ other postretirement benefit plans into: Level 1, for securities valued using quoted prices from active markets for identical assets; Level 2, for securities not traded on an active market but for which observable m arket inputs are readily available; and Level 3, for securities and investments valued based on significant unobservable inputs. Investments are classified in their entirety based on the lowest level of input that is significant to the fair value measureme nt.

SHARE-BASED COMPENSATION (Polic

SHARE-BASED COMPENSATION (Policies)	12 Months Ended
	Dec. 31, 2015
Share-based compensation
Share-Based Compensation Policy	SHARE - BASED AWARDS AND COMPENSATION EXPENSE W e measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant . We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for non-qualified stock options and restricted stock and stock units on a straight-line b asis over the requisite service period of the award, which is generally three or four years. However, in the year that an employee becomes eligible for retirement, the remaining expense related to the employee’ s awards is recognized immediately. Substantia lly all awards outstanding are classified as equity instruments; therefore, we recognize additional paid in capital as we recognize the compensation expense associated with the awards. We classify t he tax benefits resulting from tax deductions in excess of tax benefit s related to the co mpensation cost recognized for stock option exercises and the vesting of restricted stock and related dividend equivalents as financing cash flows. There was $52 million in realized tax benefits for share-based payment award deductions in 2015 over and above the $19 million income tax benefit shown above. We use a Black-Scholes option-pricing model (Black-Scholes model) to estimate the fair value of each non-qualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on the historical volatility of Sempra Energy’s stock price . We base the average expected life for options on the contractual term of the option and expected employee exercise and post-terminat ion behavior. SEMPRA ENERGY RESTRICTED STOCK AWARDS AND UNITS We use a Monte-Carlo simulation model to estimate the fair value of the restricted stock awards and units. Our determination of fair value is affected by the historical volatility of the stock price and the dividend yields for Sempra Energy and its peer group companies. The valuation also is affected by the risk-free rates of return, and a number of other variables.

DERIVATIVE FINANCIAL INSTRUME33

DERIVATIVE FINANCIAL INSTRUMENTS (Policies)	12 Months Ended
	Dec. 31, 2015
Derivatives Policy [Abstract]
Derivatives, Policy [Text Block]	We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines i n anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated reven ues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) undesignate d. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (loss) (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Consolidated St atements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accou nting for derivative commodity instruments, foreign currency instruments and interest rate instruments. Designating cash flow hedges is dependent on the business context in which the instrument is being used, the effectiveness of the instrument in offsetti ng the risk that the future cash flows of a given revenue or expense item may vary, and other criteria. We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest r ate to a variable rate. The combination of the derivative and debt instrument results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical loca tions where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, as follows: The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed pri ce natural gas and electricity positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting acti vity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Co nsolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. SDG&E is allocated and may purchase congestion revenue rights (CRRs), which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are r ecorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations . Sempra Mexico and Sempra Natural Gas may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: LNG, natural gas transportation, power generation, and Sempra Natural Gas’ storage. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico also uses natural gas energy derivatives with the objective of managing price risk and lowering n atural gas prices at its Mexican distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Consolidated Statements o f Operations. From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel . In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the phys ical locations of contractual obligations and assets, such as natural gas purchases and sales . INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We utiliz e interest rate swaps typically designated as fair value hedges, as a means to achieve our targeted level of variable rate debt as a percent of total debt. In addition, we may utilize interest rate swaps, typically designated as cash flow hedges, to lock i n interest rates on outstanding debt or in anticipation of future financings. Interest rate derivatives are utilized by the California Utilities as well as by other Sempra Energy subsidiaries. Interest rate derivatives are generally accounted for as hedges , and although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes. FOREIGN CURRENCY DERIVATIVES We are exposed to exchange rate movements at our Mexican subsidiaries, which have U.S. dollar denominated cash balances, receivables and payables (monetary assets and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. These subsidiaries also have deferred income tax assets and liabilities that are denominated in the Mexican peso, which must be translated into U.S. dollars for financial reporting purposes. We utilize fo reign currency derivatives at our subsidiaries and at the consolidated level as a means to manage the risk of exposure to significant fluctuations in our income tax expense from these impacts. We also utilize cross-currency swaps to hedge exposure rela ted to Mexican peso-denominated debt at our Mexican subsidiaries and joint ventures. In addition, Sempra South American Utilities uses foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. W e discuss such swaps at Chilquinta Energía’s Eletrans joint venture investment in Note 4.

FAIR VALUE MEASUREMENTS (Polici

FAIR VALUE MEASUREMENTS (Policies)	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements Policy [Abstract]
Fair Value Measurement Policy	Recurring Fair Value Measures The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2015 and 2014. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valu ation of fair value assets and liabilities, and their placement within the fair value hierarchy levels. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 9 under “Finan cial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash d eposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2015 and 2014 in the tables below include the following: Nuclear decommissioning trusts re flect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances. A third party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other i ndependent data sources. Equity and certain debt securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Ot her debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market corro borated, or generally unobservable. We have exchange-traded derivatives that are valued based on quoted prices in active markets for the identical instruments (Level 1). We also may have other commodity derivatives that are valued using industry standard m odels that consider quoted forward prices for commodities, time value, current market and contractual prices for the underlying instruments, volatility factors, and other relevant economic measures (Level 2). Level 3 recurring items relate to CRRs and long -term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.” Rabbi Trust i nvestments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identica l security is traded (Level 1). Investments in marketable securities at December 31, 2015 and 2014 were negligible. SDG&E’s Energy and Fuel Procurement department , in conjunction with SDG&E’s finance group, is responsible for determining the appropriate fair value methodolo gies used to value and classify CRRs and long-term, fixed-price electricity positions on an ongoing basis . Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness . SDG&E expects all costs related to these instruments to be recoverable through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction pric es published by the California ISO , an objective sou rce. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instrume nts are classified as Level 3 . T he fair value of these instruments is derived from auction price differences between two locations . From Januar y 1, 2015 to December 31, 2015, the auction prices ranged from $(16) per MWh to $8 per MWh at a given location, a nd from January 1, 2014 to December 31, 2014, the auction prices ranged from $(6) per MWh to $12 per MWh at a given location . Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between tw o locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement . We summarize CRR volumes in Note 9. Long-term , fixed-price electricity positions that are valued using significant unobservable data are classified as Lev el 3 because the contract terms relate to a delivery location or tenor for which observable market r ate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs . At December 31, 2015, these inputs range from $21.45 per MWh to $60.05 per MWh. A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. Realized gains and losses associated with CRRs and long-term electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. Unrealized gains and losses are recorded as regulatory assets and liabilities and therefore also do not affect earnings. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, current amounts due to/from unconsolidated affiliates, dividends and accounts pa yable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance R estoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. We base the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other noncurrent amounts due from unconsolidated affiliates of our South American Utilities using a perpetuity approach based on the obligation’s fixed interest rate, the absence of a stated maturity date and a discount rate reflecting local borrowing cost s (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3).

SHAREHOLDERS' EQUITY AND EARN35

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Policies)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share, Policy [Text Block]	Basic EPS is calculated by dividing earnings attributable to common stock by the weighted-average number of common shares outstanding for the year. Diluted EPS includes the potential dilution of common stock equivalent shares that could occur if securities or other contracts to issue common stock were exercised or converted into common stock.

SEGMENT (Policies)

SEGMENT (Policies)	12 Months Ended
	Dec. 31, 2015
Segment [Abstract]
SegmentReportingPolicyPolicyTextBlock	Common services shared by the business segments are assigned direct ly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Policies)	12 Months Ended
	Dec. 31, 2015
Concentration of Credit Risk [Abstract]
Concentration of Credit Risk, Policy	CONCENTRATION OF CREDIT RISK We maintain credit policies and systems to manage our overall credit risk. These policies include an evaluation of potential counterparties ’ financial condition and an assignment of credit limits. These credit limits are established based on risk and return considerations under terms customarily available in the industry. We grant credit to utility customers and counterparties, substantially a ll of whom are located in our service territory, which covers most of Southern California and a portion of central California for SoCalGas , and all of San Diego County and an adjacent portion of Orange County for SDG&E . We also grant credit to utility cust omers and counterparties of our other companies providing natural gas or electric services in Mexico, Chile, Peru, southwest Alabama, and Hattiesburg, Mississippi . When they become operational, projects owned or partially owned by Sempra Natural Gas, Sempr a Renewables, Sempra South American Utilities and Sempra Mexico place significant reliance on the ability of their suppliers and customers to perform on long-term agreements and on our ability to enforce contract terms in the event of nonperformance. We co nsider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects .
Environmental Policy [Abstract]
Environmental Costs, Policy	We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. At the California Utilities , costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates. We record environmental liabilities at undiscounted amounts when our liability is probable and the costs can be reasonably estimated. In many cases, however, investigations are not yet at a stage where we can determine whether we are liable or, if the liability is probable, to reasonably estimate the amount or range of amounts of the costs. Estimates of our liability are further subject to uncertainties such as the nature and extent of site contamination, evolving cleanup standards and imprecise enginee ring evaluations. We review our accruals periodically and, as investigations and cleanup s proceed, we make adjustments as necessary.
Legal Costs Policy [Abstract]
Legal Fees, Policy	LEGAL FEES Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred. LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could material ly adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.

SIGNIFICANT ACCOUNTING POLICI38

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Regulatory Balancing Accounts [Abstract]
Schedule Of Regulatory Balancing Accounts	SUMMARY OF REGULATORY BALANCING ACCOUNTS AT DECEMBER 31 (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2015 2014 2015 2014 2015 2014 Current: Overcollected $ (1,200) $ (1,730) $ (756) $ (1,195) $ (444) $ (535) Undercollected 1,473 2,476 1,063 1,906 410 570 Net current receivable (payable)(1) 273 746 307 711 (34) 35 Noncurrent: Undercollected(2) 215 173 ― ― 215 173 Total net receivable $ 488 $ 919 $ 307 $ 711 $ 181 $ 208 (1) At December 31, 2015, the net receivable at SDG&E and the net payable at SoCalGas are shown separately on Sempra Energy's Consolidated Balance Sheet. (2) Long-term undercollected balance is included in Regulatory Assets (long-term) on Sempra Energy's Consolidated Balance Sheets and Other Regulatory Assets (long-term) on SoCalGas' Consolidated Balance Sheets.
Schedule Of Regulatory Assets (Liabilities) [Abstract]
Schedule of regulatory assets and liabilities	REGULATORY ASSETS (LIABILITIES) AT DECEMBER 31 (Dollars in millions) 2015 2014 SDG&E: Fixed-price contracts and other derivatives $ 99 $ 76 Costs related to SONGS plant closure(1) 257 308 Costs related to wildfire litigation 362 373 Deferred taxes recoverable in rates 914 824 Pension and other postretirement benefit plan obligations 180 171 Removal obligations(2) (1,629) (1,557) Unamortized loss on reacquired debt 12 12 Environmental costs 16 27 Legacy meters(1) 32 47 Sunrise Powerlink fire mitigation 117 116 Other 9 10 Total SDG&E 369 407 SoCalGas: Pension and other postretirement benefit plan obligations 629 613 Employee benefit costs 51 52 Removal obligations(2) (1,145) (1,167) Deferred taxes recoverable in rates 330 195 Unamortized loss on reacquired debt 11 12 Environmental costs 22 22 Workers’ compensation 13 23 Total SoCalGas (89) (250) Other Sempra Energy: Sempra Natural Gas (7) (17) Sempra Mexico 33 23 Total Other Sempra Energy 26 6 Total Sempra Energy Consolidated $ 306 $ 163 (1) Regulatory assets earning a rate of return. (2) Represents cumulative amounts collected in rates for future nonlegal asset removal costs. NET REGULATORY ASSETS (LIABILITIES) AS PRESENTED ON THE CONSOLIDATED BALANCE SHEETS AT DECEMBER 31 (Dollars in millions) 2015 2014 Sempra Sempra Energy Energy Consolidated SDG&E SoCalGas Consolidated SDG&E SoCalGas Current regulatory assets(1) $ 115 $ 107 $ 7 $ 59 $ 54 $ 5 Noncurrent regulatory assets(2) 3,058 1,891 1,120 2,858 1,910 916 Current regulatory liabilities(3) (2) ― ― (7) ― ― Noncurrent regulatory liabilities(4) (2,865) (1,629) (1,216) (2,747) (1,557) (1,171) Total $ 306 $ 369 $ (89) $ 163 $ 407 $ (250) (1) At Sempra Energy Consolidated, included in Other Current Assets. (2) Excludes long-term undercollected balancing accounts at December 31, 2015 and 2014 of $215 million and $173 million, respectively, recorded at Sempra Energy Consolidated as Regulatory Assets (long-term) and at SoCalGas as Other Regulatory Assets (long-term). (3) Included in Other Current Liabilities. (4) At December 31, 2015 and 2014, $72 million and $6 million, respectively, at Sempra Energy Consolidated and $71 million and $4 million, respectively, at SoCalGas are included in Deferred Credits and Other.
Schedule Of Receivables Collection Allowances [Abstract]
Schedule Of Receivables Collection Allowances	COLLECTION ALLOWANCES (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Allowances for collection of receivables at January 1 $ 34 $ 29 $ 31 Provisions for uncollectible accounts 20 25 16 Write-offs of uncollectible accounts (22) (20) (18) Allowances for collection of receivables at December 31 $ 32 $ 34 $ 29 SDG&E: Allowances for collection of receivables at January 1 $ 7 $ 5 $ 6 Provisions for uncollectible accounts 7 7 4 Write-offs of uncollectible accounts (5) (5) (5) Allowances for collection of receivables at December 31 $ 9 $ 7 $ 5 SoCalGas: Allowances for collection of receivables at January 1 $ 17 $ 12 $ 14 Provisions for uncollectible accounts 11 15 7 Write-offs of uncollectible accounts (11) (10) (9) Allowances for collection of receivables at December 31 $ 17 $ 17 $ 12
Schedule Of Inventory Balances [Abstract]
Schedule of inventory	INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Natural gas LNG Materials and supplies Total 2015 2014 2015 2014 2015 2014 2015 2014 SDG&E $ 6 $ 8 $ ― $ ― $ 69 $ 65 $ 75 $ 73 SoCalGas 49 (1) 155 ― ― 30 26 79 (1) 181 Sempra South American Utilities ― ― ― ― 30 33 30 33 Sempra Mexico ― ― 3 9 10 9 13 18 Sempra Renewables ― ― ― ― 3 2 3 2 Sempra Natural Gas 94 83 3 5 1 1 98 89 Sempra Energy Consolidated $ 149 $ 246 $ 6 $ 14 $ 143 $ 136 $ 298 $ 396 (1) As of December 31, 2015, SoCalGas recorded an estimated inventory loss related to the Aliso Canyon natural gas leak of $11 million, included in Insurance Receivable for Aliso Canyon Costs on Sempra Energy's and SoCalGas' Consolidated Balance Sheets. See additional discussion about the Aliso Canyon natural gas storage facility leak in Note 15.
Schedule Of Property Plant And Equipment By Major Functional Category [Abstract]
Schedule Of Property Plant And Equipment By Major Functional Category	PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) Property, plant Depreciation rates for and equipment at years ended December 31, December 31, 2015 2014 2015 2014 2013 SDG&E: Natural gas operations $ 1,642 $ 1,535 2.52 % 2.72 % 2.35 % Electric distribution 6,151 5,795 3.79 3.79 3.36 Electric transmission(1) 4,870 4,525 2.62 2.59 2.58 Electric generation(2) 1,891 1,862 3.89 3.86 3.76 Other electric(3) 981 851 5.73 7.09 7.58 Construction work in progress(1) 923 910 NA NA NA Total SDG&E 16,458 15,478 SoCalGas: Natural gas operations(4) 13,241 12,098 3.83 3.89 3.70 Other non-utility 110 120 3.95 2.88 1.56 Construction work in progress 820 668 NA NA NA Total SoCalGas 14,171 12,886 Estimated Weighted average Other operating units and parent (5) : useful lives useful life Land and land rights 289 290 26 to 55 years(6) 40 Machinery and equipment: Utility electric distribution operations 1,362 1,434 12 to 46 years 43 Generating plants 782 596 5 to 80 years 39 LNG terminals 1,124 1,122 5 to 43 years 43 Pipelines and storage 2,311 2,003 3 to 55 years 45 Other 233 213 1 to 50 years 15 Construction work in progress 1,022 1,053 NA NA Other 448 332 2 to 80 years 35 7,571 7,043 Total Sempra Energy Consolidated $ 38,200 $ 35,407 (1) At December 31, 2015, includes $374 million in electric transmission assets and $25 million in construction work in progress related to SDG&E's 91-percent interest in the Southwest Powerlink (SWPL) transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures. (2) Includes capital lease assets of $258 million and $243 million at December 31, 2015 and 2014, respectively, primarily related to variable interest entities of which SDG&E is not the primary beneficiary. (3) Includes capital lease assets of $20 million and $19 million at December 31, 2015 and 2014, respectively. (4) Includes capital lease assets of $30 million and $27 million at December 31, 2015 and 2014, respectively. (5) The December 31, 2015 balances include $142 million, $204 million and $28 million and the December 31, 2014 balances include $150 million, $191 million and $24 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively. (6) Estimated useful lives are for land rights.
Schedule Of Accumulated Depreciation And Decommissioning Amounts [Abstract]
Schedule Of Accumulated Depreciation And Decommissioning Amounts	ACCUMULATED DEPRECIATION (Dollars in millions) December 31, 2015 2014 SDG&E: Accumulated depreciation: Electric(1) $ 3,512 $ 3,192 Natural gas 690 668 Total SDG&E 4,202 3,860 SoCalGas: Accumulated depreciation of natural gas utility plant in service(2) 4,810 4,555 Accumulated depreciation – other non-utility 90 87 Total SoCalGas 4,900 4,642 Other operating units and parent and other: Accumulated depreciation – other(3) 860 824 Accumulated depreciation of utility electric distribution operations 199 179 1,059 1,003 Total Sempra Energy Consolidated $ 10,161 $ 9,505 (1) Includes accumulated depreciation for assets under capital lease of $34 million and $28 million at December 31, 2015 and 2014, respectively. Includes $224 million at December 31, 2015 related to SDG&E's 91-percent interest in the SWPL transmission line, jointly owned by SDG&E and other utilities. (2) Includes accumulated depreciation for assets under capital lease of $29 million and $27 million at December 31, 2015 and 2014, respectively. (3) The December 31, 2015 balances include $36 million, $35 million and $3 million and the December 31, 2014 balances include $37 million, $29 million and $2 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively.
Schedule Of Capitalized Financing Costs [Abstract]
Schedule Of Capitalized Financing Costs	CAPITALIZED FINANCING COSTS (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: AFUDC related to debt $ 26 $ 22 $ 22 AFUDC related to equity 107 106 75 Other capitalized interest 68 39 22 Total Sempra Energy Consolidated $ 201 $ 167 $ 119 SDG&E: AFUDC related to debt $ 14 $ 15 $ 16 AFUDC related to equity 37 37 39 Total SDG&E $ 51 $ 52 $ 55 SoCalGas: AFUDC related to debt $ 12 $ 7 $ 6 AFUDC related to equity 36 26 17 Other capitalized interest 1 1 1 Total SoCalGas $ 49 $ 34 $ 24
Schedule Of Goodwill [Abstract]
Schedule Of Goodwill	GOODWILL (Dollars in millions) Sempra South American Sempra Sempra Utilities Mexico Natural Gas Total Balance at December 31, 2013 $ 927 $ 25 $ 72 $ 1,024 Foreign currency translation(1) (93) ― ― (93) Balance at December 31, 2014 834 25 72 931 Foreign currency translation(1) (112) ― ― (112) Balance at December 31, 2015 $ 722 $ 25 $ 72 $ 819 (1) We record the offset of this fluctuation to other comprehensive income (loss).
Schedule Of Acquired Finite Lived Intangible Assets By Major Class [Abstract]
Schedule Of Other Intangible Assets	OTHER INTANGIBLE ASSETS (Dollars in millions) Amortization period December 31, (years) 2015 2014 Storage rights 46 $ 138 $ 138 Development rights 50 322 322 Other 10 years to indefinite 17 18 477 478 Less accumulated amortization: Storage rights (22) (19) Development rights (47) (40) Other (4) (4) (73) (63) $ 404 $ 415
Schedule Of Variable Interest Entities [Abstract]
Schedule Of Variable Interest Entities	AMOUNTS ASSOCIATED WITH OTAY MESA VIE (Dollars in millions) December 31, 2015 2014(1) Cash and cash equivalents $ 5 $ 5 Restricted cash 23 8 Inventories 3 3 Other ― 1 Total current assets 31 17 Restricted cash ― 11 Property, plant and equipment, net 383 410 Total assets $ 414 $ 438 Current portion of long-term debt $ 10 $ 10 Fixed-price contracts and other derivatives 14 16 Other 5 3 Total current liabilities 29 29 Long-term debt 303 312 Fixed-price contracts and other derivatives 23 31 Deferred credits and other 6 6 Other noncontrolling interest 53 60 Total liabilities and equity $ 414 $ 438 (1) As adjusted for the retrospective adoption of ASU 2015-03, as we discuss in Note 2. Years ended December 31, 2015 2014 2013 Operating expenses Cost of electric fuel and purchased power $ (83) $ (83) $ (91) Operation and maintenance 19 19 24 Depreciation and amortization 26 27 28 Total operating expenses (38) (37) (39) Operating income 38 37 39 Interest expense (19) (17) (15) Income before income taxes/Net income 19 20 24 Earnings attributable to noncontrolling interest (19) (20) (24) Earnings attributable to common shares $ ― $ ― $ ―
Schedule Of Changes In Asset Retirement Obligations [Abstract]
Schedule Of Changes In Asset Retirement Obligations	CHANGES IN ASSET RETIREMENT OBLIGATIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2015 2014 2015 2014 2015 2014 Balance as of January 1(1) $ 2,190 $ 2,152 $ 873 $ 913 $ 1,276 $ 1,199 Accretion expense 92 97 40 43 49 52 Liabilities incurred 1 4 ― ― ― ― Reclassification(2) ― (6) ― ― ― ― Payments(3) (80) (29) (79) (29) ― ― Net revisions, other(4) 52 (28) (6) (54) 58 25 Balance at December 31(1) $ 2,255 $ 2,190 $ 828 $ 873 $ 1,383 $ 1,276 (1) The current portions of the obligations are included in Other Current Liabilities on the Consolidated Balance Sheets. (2) Reclassification to liability held for sale - asset retirement obligation which is included in Other Current Liabilities on the Consolidated Balance Sheet at December 31, 2014. (3) The increased payments at SDG&E are for the decommissioning of San Onofre Nuclear Generating Station Units 2 and 3, which we discuss in Note 13. (4) The increases at SoCalGas in 2015 and 2014 are related to revisions in estimated cash flows. The decrease in 2014 at SDG&E is due to revised estimates in an updated decommissioning cost study for the San Onofre Nuclear Generating Station, which we discuss in Note 13.
Schedule Of Changes in Accumulated Other Comprehensive Income By Component [Abstract]
Schedule Of Changes In Accumulated Other Comprehensive Income By Component	CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Foreign Pension Total currency and other accumulated other translation Financial postretirement comprehensive adjustments instruments benefits income (loss) Balance as of December 31, 2012 $ (240) $ (35) $ (101) $ (376) Other comprehensive (loss) income before reclassifications (159) 2 20 (137) Amounts reclassified from accumulated other comprehensive income 270 (2) 7 8 285 Net other comprehensive income 111 9 28 148 Balance as of December 31, 2013 (129) (26) (73) (228) Other comprehensive loss before reclassifications (193) (70) (26) (289) Amounts reclassified from accumulated other comprehensive income ― 6 14 20 Net other comprehensive loss (193) (64) (12) (269) Balance as of December 31, 2014 (322) (90) (85) (497) Other comprehensive loss before reclassifications (260) (57) (10) (327) Amounts reclassified from accumulated other comprehensive income ― 10 8 18 Net other comprehensive loss (260) (47) (2) (309) Balance as of December 31, 2015 $ (582) $ (137) $ (87) $ (806) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests. (2) Represents cumulative foreign currency translation adjustment related to the impairment of our Argentine investments in 2006, which is substantially offset by an accrued liability established at that time. We provide additional information about these investments in Note 4. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension Total and other accumulated other postretirement comprehensive benefits income (loss) Balance as of December 31, 2012 $ (11) $ (11) Amounts reclassified from accumulated other comprehensive income 2 2 Net other comprehensive income 2 2 Balance as of December 31, 2013 (9) (9) Other comprehensive loss before reclassifications (5) (5) Amounts reclassified from accumulated other comprehensive income 2 2 Net other comprehensive loss (3) (3) Balance as of December 31, 2014 (12) (12) Other comprehensive income before reclassifications 3 3 Amounts reclassified from accumulated other comprehensive income 1 1 Net other comprehensive income 4 4 Balance as of December 31, 2015 $ (8) $ (8) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension Total and other accumulated other Financial postretirement comprehensive instruments benefits income (loss) Balance as of December 31, 2012 $ (15) $ (3) $ (18) Other comprehensive loss before reclassifications ― (2) (2) Amounts reclassified from accumulated other comprehensive income 1 1 2 Net other comprehensive income (loss) 1 (1) ― Balance as of December 31, 2013 (14) (4) (18) Other comprehensive loss before reclassifications ― (3) (3) Amounts reclassified from accumulated other comprehensive income ― 3 3 Net other comprehensive income ― ― ― Balance as of December 31, 2014 (14) (4) (18) Other comprehensive loss before reclassifications ― (1) (1) Net other comprehensive loss ― (1) (1) Balance as of December 31, 2015 $ (14) $ (5) $ (19) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
Schedule Of Reclassifications Out Of Accumulated Other Comprehensive Income [Abstract]
Schedule Of Reclassifications Out Of Accumulated Other Comprehensive Income	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated Amounts reclassified from accumulated other Affected line item other comprehensive income (loss) components comprehensive income (loss) on Consolidated Statements of Operations Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Foreign currency translation adjustments $ ― $ ― $ 270 Equity Earnings, Net of Income Tax(1) Financial instruments: Interest rate and foreign exchange instruments $ 18 $ 21 $ 11 Interest Expense Interest rate instruments ― (3) ― Gain on Sale of Equity Interests and Assets Interest rate instruments 12 10 10 Equity Earnings, Before Income Tax Interest rate instruments 13 ― ― Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery (14) (8) (1) Revenues: Energy-Related Businesses Total before income tax 29 20 20 (4) (3) (4) Income Tax Expense Net of income tax 25 17 16 (15) (11) (9) Earnings Attributable to Noncontrolling Interests $ 10 $ 6 $ 7 Pension and other postretirement benefits: Net actuarial gain $ ― $ ― $ 3 See note (2) below Amortization of actuarial loss 14 23 10 See note (2) below Total before income tax 14 23 13 (6) (9) (5) Income Tax Expense Net of income tax $ 8 $ 14 $ 8 Total reclassifications for the period, net of tax $ 18 $ 20 $ 285 SDG&E: Financial instruments: Interest rate instruments $ 12 $ 11 $ 9 Interest Expense (12) (11) (9) Earnings Attributable to Noncontrolling Interest $ ― $ ― $ ― Pension and other postretirement benefits: Net actuarial gain $ ― $ ― $ 2 See note (2) below Amortization of actuarial loss 1 3 1 See note (2) below Total before income tax 1 3 3 ― (1) (1) Income Tax Expense Net of income tax $ 1 $ 2 $ 2 Total reclassifications for the period, net of tax $ 1 $ 2 $ 2 SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 $ 1 Interest Expense (1) (1) ― Income Tax Expense Net of income tax $ ― $ ― $ 1 Pension and other postretirement benefits: Amortization of actuarial loss $ ― $ 5 $ 1 See note (2) below Total before income tax ― 5 1 ― (2) ― Income Tax Expense Net of income tax $ ― $ 3 $ 1 Total reclassifications for the period, net of tax $ ― $ 3 $ 2 (1) Represents cumulative foreign currency translation adjustment related to the impairment of our Argentine investments in 2006, which is substantially offset by an accrued liability established at that time. We provide additional information about these investments in Note 4. (2) Amounts are included in the computation of net periodic benefit cost (see "Net Periodic Benefit Cost" in Note 7).
Schedule Of Noncontrolling Interests [Abstract]
Schedule Of Noncontrolling Interests	OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by others December 31, December 31, 2015 2014 2015 2014 SDG&E: Otay Mesa VIE 100 % 100 % $ 53 $ 60 Sempra South American Utilities: Chilquinta Energía subsidiaries(1) 23.5 - 43.4 23.6 - 43.4 21 23 Luz del Sur 16.4 16.4 164 177 Tecsur 9.8 9.8 4 4 Sempra Mexico: IEnova, S.A.B. de C.V. 18.9 18.9 468 452 Sempra Natural Gas: Bay Gas Storage Company, Ltd. 9.1 9.1 25 23 Liberty Gas Storage, LLC 23.2 25.0 14 14 Southern Gas Transmission Company 49.0 49.0 1 1 Total Sempra Energy $ 750 $ 754 (1) Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.
Schedule Of Utilities Revenues [Abstract]
Schedule Of Utilities Revenues	TOTAL UTILITIES REVENUES AT SEMPRA ENERGY CONSOLIDATED(1) (Dollars in millions) Years ended December 31, 2015 2014 2013 Electric revenues $ 5,158 $ 5,209 $ 4,911 Natural gas revenues 4,096 4,549 4,398 Total $ 9,254 $ 9,758 $ 9,309 (1) Excludes intercompany revenues.
Schedule Of Due To And From Affiliates [Abstract]
Schedule Of Amounts Due To and From Affiliates at SDG&E and SoCalGas	AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) December 31, 2015 2014 Sempra Energy Consolidated: Total due from various unconsolidated affiliates - current $ 6 $ 38 Sempra South American Utilities(1): Eletrans S.A.: 4% Note(2) $ 72 $ 41 Sempra Mexico(1): Affiliate of joint venture with Petróleos Mexicanos(3) Note due November 13, 2017(4)(5) 3 44 Note due November 14, 2018(4) 42 40 Note due November 14, 2018(4) 34 33 Note due November 14, 2018(4) 8 8 Energía Sierra Juárez: Note due June 15, 2018(6) 24 22 Sempra Natural Gas: Cameron LNG JV 3 ― Total due from unconsolidated affiliates - noncurrent $ 186 $ 188 Total due to various unconsolidated affiliates - current $ (14) $ (2) SDG&E: Total due from various unconsolidated affiliates - current $ 1 $ 1 Sempra Energy $ (34) $ (17) SoCalGas (13) (4) Affiliate (8) ― Total due to unconsolidated affiliates - current $ (55) $ (21) Income taxes due from Sempra Energy(7) $ 28 $ 16 SoCalGas: Sempra Energy(8) $ 35 $ ― SDG&E 13 4 Total due from unconsolidated affiliates - current $ 48 $ 4 Sempra Energy $ ― $ (13) Total due to unconsolidated affiliate - current $ ― $ (13) Income taxes due from Sempra Energy(7) $ 1 $ 9 (1) Amounts include principal balances plus accumulated interest outstanding. (2) U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A., an affiliate of Chilquinta Energía. (3) Petróleos Mexicanos (or PEMEX, the Mexican state-owned oil company). (4) U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.93 percent at December 31, 2015), to finance the Los Ramones Norte pipeline project. (5) In May 2015, $41 million was paid with proceeds from project financing at the affiliate. (6) U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.80 percent at December 31, 2015), to finance the first phase of the Energía Sierra Juárez wind project. (7) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return. (8) Net receivable includes outstanding advances to Sempra Energy of $50 million at December 31, 2015 at an interest rate of 0.11 percent.
Schedule Of Revenues From Affiliates [Abstract]
Schedule Of Revenues From Unconsolidated Affiliates	REVENUES FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated $ 26 $ 13 $ 4 SDG&E 10 13 12 SoCalGas 75 69 70
Schedule of Cost of Sales from Affiliates [Abstract]
Schedule of Cost of Sales from Unconsolidated Affiliates	COST OF SALES FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated $ 107 $ 78 $ 78 SDG&E 49 17 19
Schedule Of Other Income (Expense) [Abstract]
Schedule Of Other Income (Expense)	OTHER INCOME, NET (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 107 $ 106 $ 75 Investment gains(1) 3 27 39 Electrical infrastructure relocation income(2) 7 21 4 (Losses) gains on interest rate and foreign exchange instruments, net (4) (15) 17 Sale of other investments 11 2 ― Foreign currency transaction losses (7) (15) (3) Regulatory interest, net(3) 3 6 5 Sundry, net 6 5 3 Total $ 126 $ 137 $ 140 SDG&E: Allowance for equity funds used during construction $ 37 $ 37 $ 39 Regulatory interest, net(3) 3 6 4 Sundry, net (4) (3) (3) Total $ 36 $ 40 $ 40 SoCalGas: Allowance for equity funds used during construction $ 36 $ 26 $ 17 Regulatory interest, net(3) ― ― 1 Sundry, net (6) (6) (7) Total $ 30 $ 20 $ 11 (1) Represents investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans. (2) Income at Luz del Sur associated with the relocation of electrical infrastructure. (3) Interest on regulatory balancing accounts.

ACQUISTION AND DIVESTITURE AC39

ACQUISTION AND DIVESTITURE ACTIVITY (Tables)	12 Months Ended
	Dec. 31, 2015
Deconsolidation (Tables) [Abstract]
Schedule Of Deconsolidation [Text Block]	DECONSOLIDATION OF SUBSIDIARIES (Dollars in millions) Years ended December 31, 2014 2013 Proceeds, net of transaction costs(1) $ 152 $ 169 Cash (10) ― Restricted cash (5) ― Other current assets (23) ― Property, plant and equipment, net (1,557) (727) Other assets (65) (102) Accounts payable and accrued expenses 188 ― Due to affiliate 39 ― Long-term debt, including current portion 251 443 Other liabilities 12 50 Accumulated other comprehensive income (7) ― Gain on sale of equity interests(2) (60) (40) (Increase) in equity method investments upon deconsolidation $ (1,085) $ (207) (1) Transaction costs were negligible in 2014 and $6 million in 2013. (2) Included in Gain on Sale of Equity Interests and Assets on our Consolidated Statements of Operations.

INVESTMENTS IN UNCONSOLIDATED40

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Equity Method And Other Investments [Abstract]
Schedule Of Equity Method And Other Investments	EQUITY METHOD AND OTHER INVESTMENT BALANCES (Dollars in millions) December 31, 2015 2014 Sempra South American Utilities: Eletrans(1) $ (12) $ (8) Sempra Mexico: Energía Sierra Juárez(2) 30 25 Gasoductos de Chihuahua(3) 489 409 Sempra Renewables: Wind: Auwahi Wind 44 45 Broken Bow 2 Wind 41 44 Cedar Creek 2 Wind 75 82 Flat Ridge 2 Wind 275 284 Fowler Ridge 2 Wind 46 46 Mehoopany Wind 92 82 Solar: California solar partnership 120 125 Copper Mountain Solar 2 32 61 Copper Mountain Solar 3 44 56 Mesquite Solar 1 86 86 Sempra Natural Gas: Cameron LNG JV(4) 983 1,007 Rockies Express Pipeline LLC(5) 477 340 Parent and other: RBS Sempra Commodities LLP 67 71 Total equity method investments 2,889 2,755 Other(6) 16 93 Total $ 2,905 $ 2,848 (1) Includes losses on forward exchange contracts, which we discuss below. (2) The carrying value of our equity method investment is $12 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014 due to the remeasurement of our retained investment to fair value. (3) The carrying value of our equity method investment is $65 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014 due to equity method goodwill. (4) The carrying value of our equity method investment is $143 million and $94 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, primarily due to guarantees, which we discuss below, and interest capitalized on the investment, as the joint venture has not commenced its planned principal operations. (5) The carrying value of our equity method investment is $357 million and $369 million lower than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, due to an impairment charge recorded in 2012. (6) Other includes Sempra Natural Gas ’ $77 million investment in industrial development bonds at Mississippi Hub at December 31, 2014, which increased by $2 million and was fully redeemed in June 2015. EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2015 2014 2013 Earnings (losses) recorded before income tax: Sempra Renewables: Wind: Auwahi Wind $ 4 $ 4 $ 4 Broken Bow 2 Wind (2) ― ― Cedar Creek 2 Wind (6) (3) (4) Flat Ridge 2 Wind (12) (7) (8) Fowler Ridge 2 Wind 4 2 (3) Mehoopany Wind (1) (1) (2) Solar: California solar partnership 6 6 ― Copper Mountain Solar 2 7 3 ― Copper Mountain Solar 3 8 2 ― Mesquite Solar 1 16 14 1 Sempra Natural Gas: Cameron LNG JV 5 2 ― Rockies Express Pipeline LLC 79 60 47 Parent and other: RBS Sempra Commodities LLP (4) (2) (3) Other ― 1 (1) $ 104 $ 81 $ 31 Earnings (losses) recorded net of income tax(1): Sempra South American Utilities: Sodigas Pampeana and Sodigas Sur $ ― $ ― $ (11) Eletrans (4) (4) (4) Sempra Mexico: Energía Sierra Juárez 6 3 ― Gasoductos de Chihuahua 83 39 39 $ 85 $ 38 $ 24 (1) As the earnings (losses) from these investments are recorded net of income tax, they are presented below the income tax expense line, so as not to impact our effective income tax rate. SUMMARIZED FINANCIAL INFORMATION (Dollars in millions) Years ended December 31, 2015 2014 2013 Gross revenues $ 1,533 $ 1,296 $ 1,734 Operating expense (845) (749) (1,287) Income from operations 688 547 447 Interest expense (312) (298) (251) Net income/Earnings(1) 440 291 222 At December 31, 2015 2014 Current assets $ 750 $ 865 Noncurrent assets 15,112 13,161 Current liabilities 859 1,131 Noncurrent liabilities 7,862 6,228 (1) Except for Gasoductos de Chihuahua, Energía Sierra Juárez, Eletrans and the Argentine investments, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Long Term Debt [Abstract]
Schedule Of Long-term Debt	LONG-TERM DEBT (Dollars in millions) December 31, 2015 2014(1) SDG&E First mortgage bonds (secured by plant assets): 5.3% November 15, 2015 $ ― $ 250 Bonds at variable rates (0.68% at December 31, 2015) March 9, 2017 140 ― 1.65% July 1, 2018(2) 161 161 3% August 15, 2021 350 350 1.914% payable 2015 through February 2022 232 ― 3.6% September 1, 2023 450 450 6% June 1, 2026 250 250 5% to 5.25% payable 2015 through December 2027(2) 105 150 5.875% January and February 2034(2) 176 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039(2) 75 75 6% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.5% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.3% April 1, 2042 250 250 3,989 3,912 Other long-term debt (unsecured unless otherwise noted): 5.3% Notes July 1, 2021(2)(3) ― 39 5.5% Notes December 1, 2021(2)(3) ― 60 4.9% Notes March 1, 2023(2)(3) ― 25 5.2925% OMEC LLC loan payable 2013 through April 2019 (secured by OMEC plant assets) 315 325 366-day commercial paper borrowings May 2015, classified as long-term debt (0.40% weighted average at December 31, 2014) ― 100 Capital lease obligations: Purchased-power agreements 243 233 Other 1 1 559 783 4,548 4,695 Current portion of long-term debt (50) (365) Unamortized discount on long-term debt (10) (11) Unamortized long-term debt issuance costs (33) (36) Total SDG&E 4,455 4,283 SoCalGas First mortgage bonds (secured by plant assets): 5.45% April 15, 2018 250 250 1.55% June 15, 2018 250 ― 3.15% September 15, 2024 500 500 3.2% June 15, 2025 350 ― 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 2,500 1,900 Other long-term debt (unsecured): 4.75% Notes May 14, 2016(2) 8 8 5.67% Notes January 18, 2028 5 5 Capital lease obligations 1 1 14 14 2,514 1,914 Current portion of long-term debt (9) ― Unamortized discount on long-term debt (7) (8) Unamortized long-term debt issuance costs (17) (15) Total SoCalGas 2,481 1,891 LONG-TERM DEBT (CONTINUED) (Dollars in millions) December 31, 2015 2014(1) Sempra Energy Other long-term debt (unsecured): 6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating rate swaps effective January 2011 (4.77% at December 31, 2015) $ 750 $ 750 2.3% Notes April 1, 2017 600 600 6.15% Notes June 15, 2018 500 500 9.8% Notes February 15, 2019 500 500 2.4% Notes March 15, 2020 500 ― 2.85% Notes November 15, 2020 400 ― 2.875% Notes October 1, 2022 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 ― 6% Notes October 15, 2039 750 750 Market value adjustments for interest rate swaps, net (2) ― Build-to-suit lease(4) 136 75 Sempra South American Utilities Other long-term debt (unsecured): Chilquinta Energía 4.25% Series B Bonds payable 2014 through October 30, 2030(2) 170 192 Luz del Sur Bank loans 5.05% to 6.7% payable 2016 through December 2018 136 91 Notes at 4.75% to 8.75% payable 2014 through September 2029 292 345 Other bonds at 3.77% to 4.61% payable 2020 through May 2022 8 10 Capital lease 6 ― Sempra Mexico Other long-term debt (unsecured): Notes February 8, 2018 at variable rates (2.66% after floating-to-fixed rate cross-currency swaps effective February 2013) 75 88 6.3% Notes February 2, 2023 (4.12% after cross-currency swap) 227 265 Notes at variable rates (1.28% at December 31, 2014) August 25, 2017(2)(3) ― 51 Sempra Renewables Other long-term debt (secured by project assets): Loan at variable rates (2.24% at December 31, 2015) payable 2012 through December 2028, except for $69 at 4.54% after floating-to-fixed rate swaps effective June 2012(2) 91 97 Sempra Natural Gas First mortgage bonds (Mobile Gas, secured by plant assets): 4.14% September 30, 2021 20 20 5% September 30, 2031 42 42 Other long-term debt (unsecured unless otherwise noted): Notes at 2.87% to 3.51% October 1, 2016(2) 19 19 8.45% Notes payable 2012 through December 2017, secured by parent guarantee 11 16 3.1% Notes December 30, 2018, secured by plant assets(2) 5 5 4.5% Industrial development bonds July 1, 2024, secured by a promissory note(2)(3) ― 77 Industrial development bonds at variable rates (0.05% at December 31, 2014) August 1, 2037, secured by letter of credit(2)(3) ― 55 7,086 6,048 Current portion of long-term debt (848) (104) Unamortized discount on long-term debt (10) (9) Unamortized premium on long-term debt 5 7 Unamortized debt issuance costs (35) (30) Total other Sempra Energy 6,198 5,912 Total Sempra Energy Consolidated $ 13,134 $ 12,086 (1) As adjusted for the retrospective adoption of ASU 2015-03. (2) Callable long-term debt not subject to make-whole provisions. (3) Early redemption in 2015. (4) We discuss this lease in Note 15.
Schedule Of Maturities Of Long Term Debt [Abstract]
Schedule Of Maturities Of Long-term Debt	MATURITIES OF LONG-TERM DEBT(1) (Dollars in millions) Total Other Sempra Sempra Energy SDG&E SoCalGas Energy Consolidated 2016 $ 46 $ 8 $ 843 $ 897 2017 186 ― 668 854 2018 207 500 662 1,369 2019 320 ― 534 854 2020 36 ― 932 968 Thereafter 3,509 2,005 3,307 8,821 Total $ 4,304 $ 2,513 $ 6,946 $ 13,763 (1) Excludes capital lease obligations, build-to-suit lease and market value adjustments for interest rate swaps.
Schedule Of Callable Long Term Debt [Abstract]
Schedule Of Callable Long-term Debt	CALLABLE LONG-TERM DEBT (Dollars in millions) Total Other Sempra Sempra Energy SDG&E SoCalGas Energy Consolidated Not subject to make-whole provisions $ 517 $ 8 $ 285 $ 810 Subject to make-whole provisions 3,472 2,505 6,661 12,638
Schedule Of Segment Long Term Debt [Abstract]
Schedule of segment long-term debt	2015 BANK LOAN DRAWS – LUZ DEL SUR (Dollars in millions) Amount at Month issued issuance Interest rate Maturity date May $ 13 5.18% May 2018 June 22 5.18% June 2018 August 9 6.70% February 2018 November 15 6.55% November 2017

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2015
Summary Of Positions For Which Significant Change In Unrecognized Tax Benefits Is Reasonably Possible [Abstract]
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible	POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) At December 31, 2015 2014 2013 Sempra Energy Consolidated: Expiration of statutes of limitations on tax assessments $ (2) $ ― $ (7) Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities (32) (61) (63) $ (34) $ (61) $ (70) SDG&E: Expiration of statutes of limitations on tax assessments $ (1) $ ― $ ― Potential resolution of audit issues with various U.S. federal, state and local taxing authorities (8) (9) (14) $ (9) $ (9) $ (14) SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ (22) $ (15) $ (11)
Schedule Of Effective Income Tax Rate Reconciliation [Abstract]
Schedule Of Effective Income Tax Rate Reconciliation	RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: U.S. federal statutory income tax rate 35 % 35 % 35 % Utility depreciation 5 5 4 U.S. tax on repatriation of foreign earnings 1 2 ― Income tax restructuring related to IEnova stock offerings ― ― 4 State income taxes, net of federal income tax benefit 1 ― 1 Utility repairs expenditures (5) (5) (5) Tax credits (4) (4) (3) Self-developed software expenditures (3) (3) (3) Resolution of prior years’ income tax items (3) (1) (3) Non-U.S. earnings taxed at lower statutory income tax rates (2) (2) (3) Allowance for equity funds used during construction (2) (2) (1) Foreign exchange and inflation effects (2) (2) ― International tax reform ― (1) 1 Other, net (1) (2) (1) Effective income tax rate 20 % 20 % 26 % SDG&E: U.S. federal statutory income tax rate 35 % 35 % 35 % State income taxes, net of federal income tax benefit 5 5 3 Depreciation 4 4 5 SONGS tax regulatory asset write-off ― 2 ― Repairs expenditures (4) (4) (4) Self-developed software expenditures (3) (3) (3) Allowance for equity funds used during construction (2) (2) (2) Resolution of prior years’ income tax items (2) (2) (1) Variable interest entity (1) (1) (1) Other, net ― ― (1) Effective income tax rate 32 % 34 % 31 % SoCalGas: U.S. federal statutory income tax rate 35 % 35 % 35 % Depreciation 8 8 6 State income taxes, net of federal income tax benefit 4 4 4 Repairs expenditures (10) (9) (9) Self-developed software expenditures (6) (5) (6) Resolution of prior years’ income tax items (3) (2) (5) Allowance for equity funds used during construction (2) (2) (1) Other, net (1) ― ― Effective income tax rate 25 % 29 % 24 %
Schedule Of Geographic Components Of Income Before Income Taxes And Equity Earnings Of Certain Unconsolidated Subsidiaries [Abstract]
Schedule Of Geographic Components Of Income Before Income Taxes And Equity Earnings Of Certain Unconsolidated Subsidiaries [Text Block]	GEOGRAPHIC COMPONENTS (Dollars in millions) Years ended December 31, 2015 2014 2013 U.S. $ 1,189 $ 1,014 $ 941 Non-U.S. 515 510 489 Total $ 1,704 $ 1,524 $ 1,430
Schedule Of Components Of Income Tax Expense [Abstract]
Schedule Of Components Of Income Tax Expense	INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Current: U.S. federal $ 3 $ (10) $ (70) U.S. state (24) (7) (5) Non-U.S. 123 171 107 Total 102 154 32 Deferred: U.S. federal 242 237 275 U.S. state 34 4 15 Non-U.S. (32) (91) 48 Total 244 150 338 Deferred investment tax credits (5) (4) (4) Total income tax expense $ 341 $ 300 $ 366 SDG&E: Current: U.S. federal $ 12 $ (5) $ 9 U.S. state 77 52 11 Total 89 47 20 Deferred: U.S. federal 233 220 149 U.S. state (35) 5 24 Total 198 225 173 Deferred investment tax credits (3) (2) (2) Total income tax expense $ 284 $ 270 $ 191 SoCalGas: Current: U.S. federal $ (1) $ 2 $ 4 U.S. state 12 7 (5) Total 11 9 (1) Deferred: U.S. federal 122 117 103 U.S. state 7 15 16 Total 129 132 119 Deferred investment tax credits (2) (2) (2) Total income tax expense $ 138 $ 139 $ 116
Schedule Of Components Of Deferred Tax Assets And Liabilities [Abstract]
Schedule Of Components Of Deferred Tax Assets And Liabilities	DEFERRED INCOME TAXES FOR SEMPRA ENERGY CONSOLIDATED (Dollars in millions) December 31, 2015 2014 Deferred income tax liabilities: Differences in financial and tax bases of depreciable and amortizable assets $ 4,487 $ 4,074 Regulatory balancing accounts 745 915 Property taxes 61 57 Differences in financial and tax bases of partnership interests(1) 796 650 Other deferred income tax liabilities 100 53 Total deferred income tax liabilities 6,189 5,749 Deferred income tax assets: Tax credits 381 276 Net operating losses 1,856 1,908 Compensation-related items 252 244 Postretirement benefits 446 433 Other deferred income tax assets 179 156 Litigation and other accruals not yet deductible 72 73 Deferred income tax assets before valuation allowances 3,186 3,090 Less: valuation allowances 34 39 Total deferred income tax assets 3,152 3,051 Net deferred income tax liability(2) $ 3,037 $ 2,698 (1) Amounts primarily represent differences in financial and tax bases of depreciable and amortizable assets within our partnerships. (2) At December 31, 2015, the net deferred income tax liability includes $120 million recorded as a noncurrent asset in Sundry on the Consolidated Balance Sheet. DEFERRED INCOME TAXES FOR SDG&E AND SOCALGAS (Dollars in millions) SDG&E SoCalGas December 31, December 31, 2015 2014 2015 2014 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 2,392 $ 2,181 $ 1,473 $ 1,194 Regulatory balancing accounts 234 441 515 481 Property taxes 42 39 20 18 Other 5 5 5 10 Total deferred income tax liabilities 2,673 2,666 2,013 1,703 Deferred income tax assets: Net operating losses ― 297 110 64 Postretirement benefits 90 85 268 261 Compensation-related items 11 8 42 40 State income taxes 46 27 13 11 Litigation and other accruals not yet deductible 36 39 20 23 Other 18 36 28 39 Total deferred income tax assets 201 492 481 438 Net deferred income tax liability $ 2,472 $ 2,174 $ 1,532 $ 1,265
Income Tax Uncertainties [Abstract]
Summary of Income Tax Contingencies	SUMMARY OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated: Total $ 87 $ 117 $ 90 Of the total, amounts related to tax positions that, if recognized in future years, would decrease the effective tax rate(1) $ (83) $ (114) $ (86) increase the effective tax rate(1) 32 21 19 SDG&E: Total $ 20 $ 14 $ 17 Of the total, amounts related to tax positions that, if recognized in future years, would decrease the effective tax rate(1) $ (16) $ (11) $ (14) increase the effective tax rate(1) 11 6 11 SoCalGas: Total $ 27 $ 19 $ 13 Of the total, amounts related to tax positions that, if recognized in future years, would decrease the effective tax rate(1) $ (27) $ (19) $ (13) increase the effective tax rate(1) 21 15 8 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above. RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2015 2014 2013 Sempra Energy Consolidated: Balance as of January 1 $ 117 $ 90 $ 82 Increase in prior period tax positions 10 37 26 Decrease in prior period tax positions ― ― (24) Increase in current period tax positions 8 5 7 Settlements with taxing authorities (48) (15) (1) Balance as of December 31 $ 87 $ 117 $ 90 SDG&E: Balance as of January 1 $ 14 $ 17 $ 12 Increase in prior period tax positions 5 2 7 Decrease in prior period tax positions ― ― (4) Increase in current period tax positions 2 ― 2 Settlements with taxing authorities (1) (5) ― Balance as of December 31 $ 20 $ 14 $ 17 SoCalGas: Balance as of January 1 $ 19 $ 13 $ 5 Increase in prior period tax positions 2 2 4 Increase in current period tax positions 6 4 5 Settlements with taxing authorities ― ― (1) Balance as of December 31 $ 27 $ 19 $ 13 INTEREST AND PENALTIES ASSOCIATED WITH UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) Interest and penalties Accrued interest and penalties Years ended December 31, December 31, 2015 2014 2013 2015 2014 Sempra Energy Consolidated: Interest (income) expense $ (2) $ (4) $ 1 $ 1 $ ― Penalties ― (3) ― ― ― SDG&E: Interest income $ ― $ (1) $ ― $ ― $ ― SoCalGas: Interest income $ ― $ ― $ (1) $ ― $ ―

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Defined Benefit Plans Change In Benefit Obligation And Fair Value Of Plan Assets [Abstract]
Schedule Of Defined Benefit Plans, Change In Benefit Obligation And Fair Value Of Plan Assets	PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 3,839 $ 3,459 $ 1,115 $ 973 Service cost 114 101 26 24 Interest cost 154 161 44 49 Contributions from plan participants ― ― 19 17 Actuarial (gain) loss (180) 441 (172) 105 Benefit payments (273) (217) (60) (58) Plan amendments 5 4 (9) 1 Special termination benefits ― ― ― 5 Settlements and curtailments (10) (110) ― (1) Net obligation at December 31 3,649 3,839 963 1,115 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,807 2,789 1,054 1,012 Actual return on plan assets (73) 217 (21) 67 Employer contributions 33 128 11 16 Contributions from plan participants ― ― 19 17 Benefit payments (273) (217) (60) (58) Settlements (10) (110) ― ― Fair value of plan assets at December 31 2,484 2,807 1,003 1,054 Funded status at December 31 $ (1,165) $ (1,032) $ 40 $ (61) Net recorded (liability) asset at December 31 $ (1,165) $ (1,032) $ 40 $ (61) PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 1,011 $ 939 $ 200 $ 171 Service cost 29 30 7 7 Interest cost 39 43 8 9 Contributions from plan participants ― ― 7 6 Actuarial (gain) loss (52) 101 (43) 15 Benefit payments (56) (25) (14) (13) Special termination benefits ― ― ― 5 Settlements ― (87) ― ― Transfer of liability (to) from other plans (6) 10 ― ― Net obligation at December 31 965 1,011 165 200 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 828 819 164 146 Actual return on plan assets (24) 63 (3) 11 Employer contributions 2 56 7 14 Contributions from plan participants ― ― 7 6 Benefit payments (56) (25) (14) (13) Settlements ― (87) ― ― Transfer of assets from other plans 2 2 ― ― Fair value of plan assets at December 31 752 828 161 164 Funded status at December 31 $ (213) $ (183) $ (4) $ (36) Net recorded liability at December 31 $ (213) $ (183) $ (4) $ (36) PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,398 $ 2,110 $ 866 $ 753 Service cost 74 60 17 16 Interest cost 98 100 34 38 Contributions from plan participants ― ― 12 11 Actuarial (gain) loss (131) 300 (125) 90 Benefit payments (187) (163) (43) (43) Plan amendments 3 ― (9) 1 Settlements ― (10) ― ― Transfer of liability from other plans ― 1 ― ― Net obligation at December 31 2,255 2,398 752 866 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,763 1,758 870 848 Actual return on plan assets (45) 138 (18) 54 Employer contributions 6 39 1 ― Contributions from plan participants ― ― 12 11 Benefit payments (187) (163) (43) (43) Settlements ― (10) ― ― Transfer of assets from other plans ― 1 ― ― Fair value of plan assets at December 31 1,537 1,763 822 870 Funded status at December 31 $ (718) $ (635) $ 70 $ 4 Net recorded (liability) asset at December 31 $ (718) $ (635) $ 70 $ 4
Schedule Of Defined Benefit Plans Amounts Recognized In Balance Sheet [Abstract]
Schedule Of Defined Benefit Plans, Amounts Recognized In Balance Sheet	PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS AT DECEMBER 31 (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 Sempra Energy Consolidated: Noncurrent assets $ ― $ ― $ 70 $ 4 Current liabilities (43) (33) ― ― Noncurrent liabilities (1,122) (999) (30) (65) Net recorded (liability) asset $ (1,165) $ (1,032) $ 40 $ (61) SDG&E: Current liabilities $ (5) $ (3) $ ― $ ― Noncurrent liabilities (208) (180) (4) (36) Net recorded liability $ (213) $ (183) $ (4) $ (36) SoCalGas: Noncurrent assets $ ― $ ― $ 70 $ 4 Current liabilities (2) (2) ― ― Noncurrent liabilities (716) (633) ― ― Net recorded (liability) asset $ (718) $ (635) $ 70 $ 4
Schedule Of Defined Benefit Plans Amounts In Accumulated Other Comprehensive Income [Abstract]
Schedule Of Defined Benefit Plans, Amounts In Accumulated Other Comprehensive Income	AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2015 2014 Sempra Energy Consolidated: Net actuarial (loss) gain $ (84) $ (82) $ 2 $ (1) Prior service cost (5) (2) ― ― Total $ (89) $ (84) $ 2 $ (1) SDG&E: Net actuarial loss $ (8) $ (13) Prior service credit ― 1 Total $ (8) $ (12) SoCalGas: Net actuarial loss $ (4) $ (5) Prior service (cost) credit (1) 1 Total $ (5) $ (4)
Schedule Of Defined Benefit Plans Accumulated Benefit Obligation [Abstract]
Schedule Of Defined Benefit Plans, Accumulated Benefit Obligation	ACCUMULATED BENEFIT OBLIGATION (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2015 2014 2015 2014 2015 2014 Accumulated benefit obligation $ 3,397 $ 3,555 $ 939 $ 978 $ 2,056 $ 2,182
Schedule Of Defined Benefit Plans Pension Plans With Benefit Obligations In Excess Of Plan Assets [Abstract]
Schedule Of Defined Benefit Plans, Pension Plans With Benefit Obligations In Excess Of Plan Assets	OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) 2015 2014 Sempra Energy Consolidated: Projected benefit obligation $ 3,410 $ 3,592 Accumulated benefit obligation 3,183 3,343 Fair value of plan assets 2,484 2,807 SDG&E: Projected benefit obligation $ 927 $ 964 Accumulated benefit obligation 906 937 Fair value of plan assets 752 828 SoCalGas: Projected benefit obligation $ 2,236 $ 2,379 Accumulated benefit obligation 2,039 2,166 Fair value of plan assets 1,537 1,763
Schedule Of Defined Benefit Plans Net Periodic Benefit Cost And Amounts Recognized In Other Comprehensive Income [Abstract]
Schedule Of Defined Benefit Plans, Net Periodic Benefit Cost and Amounts Recognized in Other Comprehensive Income	NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 NET PERIODIC BENEFIT COST Service cost $ 114 $ 101 $ 109 $ 26 $ 24 $ 28 Interest cost 154 161 148 44 49 44 Expected return on assets (173) (171) (162) (68) (63) (58) Amortization of: Prior service cost (credit) 11 11 4 (4) (5) (4) Actuarial loss 38 18 54 ― ― 7 Settlement and curtailment charges 4 31 2 ― (1) ― Special termination benefits ― ― ― ― 5 5 Regulatory adjustment (110) (31) (20) 12 6 6 Total net periodic benefit cost 38 120 135 10 15 28 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) Net loss (gain) 17 38 (30) (4) 1 (8) Prior service cost 4 4 1 ― ― ― Amortization of actuarial loss (14) (23) (9) ― ― (1) Total recognized in other comprehensive income (loss) 7 19 (38) (4) 1 (9) Total recognized in net periodic benefit cost and other comprehensive income (loss) $ 45 $ 139 $ 97 $ 6 $ 16 $ 19 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 NET PERIODIC BENEFIT COST Service cost $ 29 $ 30 $ 32 $ 7 $ 7 $ 8 Interest cost 39 43 41 8 9 8 Expected return on assets (54) (55) (52) (11) (10) (8) Amortization of: Prior service cost 8 2 2 3 2 4 Actuarial loss 2 4 14 ― ― ― Settlement charge ― 19 1 ― ― ― Special termination benefits ― ― ― ― 5 2 Regulatory adjustment (20) 12 14 ― 1 ― Total net periodic benefit cost 4 55 52 7 14 14 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) Net (gain) loss (6) 8 (2) ― ― ― Amortization of actuarial loss (1) (3) (1) ― ― ― Total recognized in other comprehensive (loss) income (7) 5 (3) ― ― ― Total recognized in net periodic benefit cost and other comprehensive (loss) income $ (3) $ 60 $ 49 $ 7 $ 14 $ 14 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 NET PERIODIC BENEFIT COST Service cost $ 74 $ 60 $ 67 $ 17 $ 16 $ 17 Interest cost 98 100 90 34 38 34 Expected return on assets (106) (104) (98) (56) (51) (48) Amortization of: Prior service cost (credit) 9 9 2 (7) (8) (8) Actuarial loss 21 6 31 ― ― 6 Settlement charge ― 4 ― ― ― ― Special termination benefits ― ― ― ― ― 2 Regulatory adjustment (90) (43) (34) 12 5 6 Total net periodic benefit cost 6 32 58 ― ― 9 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OTHER COMPREHENSIVE INCOME (LOSS) Net loss ― 5 3 ― ― ― Prior service cost 2 ― ― ― ― ― Amortization of actuarial loss ― (5) (1) ― ― ― Total recognized in other comprehensive income 2 ― 2 ― ― ― Total recognized in net periodic benefit cost and other comprehensive income $ 8 $ 32 $ 60 $ ― $ ― $ 9
Schedule Of Defined Benefit Plans Assumptions Used In Calculations [Abstract]
Schedule Of Assumptions Used [Text Block]	WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31 Pension benefits Other postretirement benefits 2015 2014 2015 2014 Sempra Energy Consolidated: Discount rate 4.46 % 4.09 % 4.49 % 4.15 % Rate of compensation increase 2.00-10.00 3.50-10.00 2.00-10.00 3.50-10.00 SDG&E: Discount rate 4.35 % 4.00 % 4.50 % 4.15 % Rate of compensation increase 2.00-10.00 3.50-10.00 2.00-10.00 3.50-10.00 SoCalGas: Discount rate 4.50 % 4.15 % 4.50 % 4.15 % Rate of compensation increase 2.00-10.00 3.50-10.00 2.00-10.00 3.50-10.00 WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST FOR YEARS ENDED DECEMBER 31 Pension benefits Other postretirement benefits 2015 2014 2013 2015 2014 2013 Sempra Energy Consolidated: Discount rate 4.09 % 4.85 % 4.04 % 4.15 % 4.95 % 4.09 % Expected return on plan assets 7.00 7.00 7.00 6.98 6.97 6.96 Rate of compensation increase 2.00-10.00 3.50-10.00 3.50-9.50 2.00-10.00 3.50-10.00 3.50-9.50 SDG&E: Discount rate 4.00 % 4.69 % 3.94 % 4.15 % 5.00 % 4.10 % Expected return on plan assets 7.00 7.00 7.00 6.91 6.88 6.81 Rate of compensation increase 2.00-10.00 3.50-10.00 3.50-9.50 2.00-10.00 3.50-10.00 N/A SoCalGas: Discount rate 4.15 % 4.94 % 4.10 % 4.15 % 4.95 % 4.10 % Expected return on plan assets 7.00 7.00 7.00 7.00 7.00 7.00 Rate of compensation increase 2.00-10.00 3.50-10.00 3.50-9.50 2.00-10.00 3.50-10.00 3.50-9.50
Schedule Of Defined Benefit Plans Assumed Health Care Cost Trend Rates [Abstract]
Schedule Of Health Care Cost Trend Rates [Text Block]	ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans(1) Pre-65 retirees Retirees aged 65 years and older 2015 2014 2013 2015 2014 2013 Health care cost trend rate assumed for next year 8.10 % 7.75 % 8.25 % 5.50 % 5.25 % 5.50 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 5.00 % 5.00 % 5.00 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2022 2020 2020 2022 2020 2020 (1) Excludes Mobile Gas Plan. For Mobile Gas, the health care cost trend rate assumed for next year for all retirees was 8.10 percent, 7.75 percent and 7.50 percent in 2015, 2014 and 2013, respectively; the ultimate trend was 5.00 percent in 2015, 2014 and 2013; and the year the rate reaches the ultimate trend was 2022, 2020 and 2019 in 2015, 2014 and 2013, respectively. For Chilquinta Energía, the health care cost trend rate assumed for next year and all subsequent years was 3.00 percent in each of 2015, 2014 and 2013. EFFECT OF ONE-PERCENT CHANGE IN ASSUMED HEALTH CARE COST TREND RATES (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 1% 1% 1% 1% 1% 1% increase decrease increase decrease increase decrease Effect on total of service and interest cost components of net periodic postretirement health care benefit cost $ 7 $ (5) $ 1 $ (1) $ 5 $ (4) Effect on the health care component of the accumulated other postretirement benefit obligations 74 (62) 5 (4) 67 (55)
Schedule Of Defined Benefit Plans Fair Value Of Plan Assets By Level In Fair Value Hierarchy [Abstract]
Schedule Of Defined Benefit Plans, Fair Value Of Plan Assets By Level In Fair Value Hierarchy	FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Total SDG&E: Equity securities: Domestic(1) $ 269 $ ― $ ― $ 269 Foreign 163 ― ― 163 Domestic preferred ― 2 ― 2 Foreign preferred 1 ― ― 1 Registered investment companies 38 ― ― 38 Fixed income securities: U.S. Treasury securities 38 ― ― 38 Domestic municipal bonds ― 9 ― 9 Foreign government bonds ― 3 ― 3 Domestic corporate bonds(2) ― 103 ― 103 Foreign corporate bonds ― 30 ― 30 Common/collective trusts(3) ― 94 ― 94 Registered investment companies ― 2 ― 2 Other investments(4) ― ― 1 1 Total investment assets(5) 509 243 1 753 SoCalGas: Equity securities: Domestic(1) 552 ― ― 552 Foreign 334 ― ― 334 Domestic preferred ― 4 ― 4 Foreign preferred 2 1 ― 3 Registered investment companies 77 ― ― 77 Fixed income securities: U.S. Treasury securities 76 ― ― 76 Domestic municipal bonds ― 19 ― 19 Foreign government bonds ― 6 ― 6 Domestic corporate bonds(2) ― 209 ― 209 Foreign corporate bonds ― 62 ― 62 Common/collective trusts(3) ― 193 ― 193 Registered investment companies ― 5 ― 5 Other investments(4) 1 ― 3 4 Total investment assets(6) 1,042 499 3 1,544 Other Sempra Energy: Equity securities: Domestic(1) 72 ― ― 72 Foreign 43 ― ― 43 Domestic preferred ― 1 ― 1 Registered investment companies 9 ― ― 9 Fixed income securities: U.S. Treasury securities 10 ― ― 10 Domestic municipal bonds ― 3 ― 3 Foreign government bonds ― 1 ― 1 Domestic corporate bonds(2) ― 26 ― 26 Foreign corporate bonds ― 8 ― 8 Common/collective trusts(3) ― 25 ― 25 Total other Sempra Energy(7) 134 64 ― 198 Total Sempra Energy Consolidated(8) $ 1,685 $ 806 $ 4 $ 2,495 (1) Investments in common stock of domestic corporations. (2) Bonds of U.S. issuers from diverse industries, primarily investment-grade. (3) Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust. (4) Investments in venture capital and real estate funds, stated at net asset value, and derivative financial instruments. (5) Excludes cash and cash equivalents of $4 million, accounts payable of $7 million and transfers receivable from other plans of $2 million at SDG&E. (6) Excludes cash and cash equivalents of $9 million and accounts payable of $16 million at SoCalGas. (7) Excludes cash and cash equivalents of $1 million, accounts payable of $2 million and transfers payable to other plans of $2 million at Other Sempra Energy. (8) Excludes cash and cash equivalents of $14 million and accounts payable of $25 million at Sempra Energy Consolidated. FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2014 Level 1 Level 2 Level 3 Total SDG&E: Equity securities: Domestic(1) $ 307 $ ― $ ― $ 307 Foreign 186 ― ― 186 Domestic preferred ― 1 ― 1 Foreign preferred 1 ― ― 1 Registered investment companies 40 ― ― 40 Fixed income securities: U.S. Treasury securities 38 ― ― 38 Domestic municipal bonds ― 11 ― 11 Foreign government bonds ― 12 ― 12 Domestic corporate bonds(2) ― 117 ― 117 Foreign corporate bonds ― 36 ― 36 Common/collective trusts(3) ― 62 ― 62 Registered investment companies ― 10 ― 10 Other investments(4) ― ― 4 4 Total investment assets(5) 572 249 4 825 SoCalGas: Equity securities: Domestic(1) 651 ― ― 651 Foreign 395 ― ― 395 Domestic preferred ― 3 ― 3 Foreign preferred 3 1 ― 4 Registered investment companies 86 ― ― 86 Fixed income securities: U.S. Treasury securities 80 ― ― 80 Domestic municipal bonds ― 24 ― 24 Foreign government bonds ― 25 ― 25 Domestic corporate bonds(2) ― 249 ― 249 Foreign corporate bonds ― 77 ― 77 Common/collective trusts(3) ― 132 ― 132 Registered investment companies ― 21 ― 21 Other investments(4) 1 ― 8 9 Total investment assets(6) 1,216 532 8 1,756 Other Sempra Energy: Equity securities: Domestic(1) 81 ― ― 81 Foreign 49 ― ― 49 Foreign preferred ― 1 ― 1 Registered investment companies 10 ― ― 10 Fixed income securities: U.S. Treasury securities 9 ― ― 9 Domestic municipal bonds ― 4 ― 4 Foreign government bonds ― 3 ― 3 Domestic corporate bonds(2) ― 30 ― 30 Foreign corporate bonds ― 9 ― 9 Common/collective trusts(3) ― 16 ― 16 Registered investment companies ― 2 ― 2 Other investments(4) ― ― 1 1 Total other Sempra Energy(7) 149 65 1 215 Total Sempra Energy Consolidated(8) $ 1,937 $ 846 $ 13 $ 2,796 (1) Investments in common stock of domestic corporations include, on a combined basis at SDG&E, SoCalGas and Other Sempra Energy, 11,558 shares of Sempra Energy common stock at a value of $1 million. (2) Bonds of U.S. issuers from diverse industries, primarily investment-grade. (3) Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust. (4) Investments in venture capital and real estate funds, stated at net asset value, and derivative financial instruments. (5) Excludes cash and cash equivalents of $3 million at SDG&E. (6) Excludes cash and cash equivalents of $7 million at SoCalGas. (7) Excludes cash and cash equivalents of $1 million at Other Sempra Energy. (8) Excludes cash and cash equivalents of $11 million at Sempra Energy Consolidated. FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Total SDG&E: Equity securities: Domestic(1) $ 39 $ ― $ ― $ 39 Foreign 24 ― ― 24 Registered investment companies 41 ― ― 41 Fixed income securities: U.S. Treasury securities 5 ― ― 5 Domestic municipal bonds ― 3 ― 3 Domestic corporate bonds(2) ― 15 ― 15 Foreign corporate bonds ― 4 ― 4 Common/collective trusts(3) ― 14 ― 14 Registered investment companies ― 16 ― 16 Total investment assets(4) 109 52 ― 161 SoCalGas: Equity securities: Domestic(1) 123 ― ― 123 Foreign 74 ― ― 74 Domestic preferred ― 1 ― 1 Registered investment companies 43 ― ― 43 Broad market funds ― 216 ― 216 Fixed income securities: U.S. Treasury securities 42 ― ― 42 Domestic municipal bonds ― 7 ― 7 Domestic corporate bonds(2) ― 87 ― 87 Foreign government bonds ― 2 ― 2 Foreign corporate bonds ― 28 ― 28 Common/collective trusts(3) ― 151 ― 151 Registered investment companies ― 49 ― 49 Total investment assets(5) 282 541 ― 823 Other Sempra Energy: Equity securities: Domestic(1) 5 ― ― 5 Foreign 3 ― ― 3 Domestic preferred ― 1 ― 1 Registered investment companies 4 ― ― 4 Fixed income securities: U.S. Treasury securities 2 ― ― 2 Domestic corporate bonds(2) ― 1 ― 1 Foreign government bonds ― 1 ― 1 Foreign corporate bonds ― 1 ― 1 Common/collective trusts(3) ― 1 ― 1 Registered investment companies ― 1 ― 1 Total other Sempra Energy 14 6 ― 20 Total Sempra Energy Consolidated(6) $ 405 $ 599 $ ― $ 1,004 (1) Investments in common stock of domestic corporations. (2) Bonds of U.S. issuers from diverse industries, primarily investment-grade. (3) Investments in common/collective trusts held in PBOP plan VEBA trusts and in the pension master trust. (4) Excludes cash and cash equivalents of $1 million and accounts payable of $1 million held in SDG&E PBOP plan trusts. (5) Excludes cash and cash equivalents of $3 million and accounts payable of $4 million held in SoCalGas PBOP plan trusts. (6) Excludes cash and cash equivalents of $4 million and accounts payable of $5 million at Sempra Energy Consolidated. FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2014 Level 1 Level 2 Level 3 Total SDG&E: Equity securities: Domestic(1) $ 41 $ ― $ ― $ 41 Foreign 25 ― ― 25 Registered investment companies 43 ― ― 43 Fixed income securities: U.S. Treasury securities 5 ― ― 5 Domestic municipal bonds ― 3 ― 3 Domestic corporate bonds(2) ― 16 ― 16 Foreign government bonds ― 2 ― 2 Foreign corporate bonds ― 5 ― 5 Common/collective trusts(3) ― 8 ― 8 Registered investment companies ― 16 ― 16 Total investment assets 114 50 ― 164 SoCalGas: Equity securities: Domestic(1) 133 ― ― 133 Foreign 81 ― ― 81 Domestic preferred ― 1 ― 1 Foreign preferred 1 ― ― 1 Registered investment companies 45 ― ― 45 Broad market funds ― 222 ― 222 Fixed income securities: U.S. Treasury securities 16 ― ― 16 Domestic municipal bonds ― 5 ― 5 Domestic corporate bonds(2) ― 61 ― 61 Foreign government bonds ― 5 ― 5 Foreign corporate bonds ― 25 ― 25 Common/collective trusts(3) ― 265 ― 265 Registered investment companies ― 6 ― 6 Other investments(4) ― ― 2 2 Total investment assets(5) 276 590 2 868 Other Sempra Energy: Equity securities: Domestic(1) 6 ― ― 6 Foreign 3 ― ― 3 Registered investment companies 4 ― ― 4 Fixed income securities: U.S. Treasury securities 1 ― ― 1 Domestic corporate bonds(2) ― 2 ― 2 Common/collective trusts(3) ― 1 ― 1 Registered investment companies ― 2 ― 2 Total other Sempra Energy(6) 14 5 ― 19 Total Sempra Energy Consolidated(7) $ 404 $ 645 $ 2 $ 1,051 (1) Investments in common stock of domestic corporations include, on a combined basis at SDG&E, SoCalGas and Other Sempra Energy, 2,005 shares of Sempra Energy common stock at a value of $0.2 million. (2) Bonds of U.S. issuers from diverse industries, primarily investment-grade. (3) Investments in common/collective trusts held in PBOP plan VEBA trusts and in the pension master trust. (4) Investments in venture capital and real estate funds, stated at net asset value, and derivative financial instruments. (5) Excludes cash and cash equivalents of $2 million held in SoCalGas PBOP plan trusts. (6) Excludes cash and cash equivalents of $1 million held in Other Sempra Energy PBOP plan trusts. (7) Excludes cash and cash equivalents of $3 million at Sempra Energy Consolidated.
Schedule Of Defined Benefit Plans Level 3 Investment Plan Assets [Abstract]
Schedule Of Defined Benefit Plans, Level 3 Investment Plan Assets	LEVEL 3 INVESTMENT ASSETS (Dollars in millions) Pension plans Other postretirement benefit plans Level 3 investment assets % of total investment assets Level 3 investment assets % of total investment assets 2015 2014 2015 2014 2015 2014 2015 2014 SDG&E $ 1 $ 4 ― % ― % $ ― $ ― ― % ― % SoCalGas 3 8 ― ― ― 2 ― ― All other ― 1 ― ― ― ― ― ― Sempra Energy Consolidated $ 4 $ 13 ― ― $ ― $ 2 ― ―
Schedule Of Defined Benefit Plans Level 3 Reconciliations [Abstract]
Schedule of Effect of Significant Unobservable Inputs Changes in Plan Assets [Text Block]	LEVEL 3 RECONCILIATIONS (Dollars in millions) SDG&E SoCalGas All other Sempra Energy Consolidated PENSION PLANS Balance at January 1, 2014 $ 6 $ 13 $ 2 $ 21 Realized gains 1 2 ― 3 Unrealized losses (1) (2) ― (3) Sales (2) (5) (1) (8) Balance at December 31, 2014 4 8 1 13 Realized gains 1 1 ― 2 Unrealized gains ― 2 ― 2 Sales (4) (8) (1) (13) Balance at December 31, 2015 $ 1 $ 3 $ ― $ 4 OTHER POSTRETIREMENT BENEFIT PLANS Balance at January 1, 2014 $ 1 $ 2 $ ― $ 3 Unrealized losses (1) ― ― (1) Balance at December 31, 2014 ― 2 ― 2 Sales ― (2) ― (2) Balance at December 31, 2015 $ ― $ ― $ ― $ ―
Schedule Of Defined Benefit Plans Estimated Future Employer Contributions In Next Fiscal Year [Abstract]
Schedule Of Defined Benefit Plans, Estimated Future Employer Contributions In Next Fiscal Year	EXPECTED CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Pension plans $ 126 $ 5 $ 77 Other postretirement benefit plans 5 2 1
Schedule Of Defined Benefit Plans Estimated Future Benefit Payments [Abstract]
Schedule Of Expected Benefit Payments [Text Block]	EXPECTED BENEFIT PAYMENTS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Other Other Other Pension postretirement Pension postretirement Pension postretirement benefits benefits benefits benefits benefits benefits 2016 $ 325 $ 47 $ 86 $ 8 $ 187 $ 36 2017 310 50 84 9 187 38 2018 311 53 82 10 186 40 2019 298 56 80 10 180 42 2020 291 61 77 10 175 44 2021-2025 1,295 296 339 54 808 228
Schedule Of Defined Benefit Plans Contributions To Savings Plans [Abstract]
Schedule Of Defined Benefit Plans, Contributions To Savings Plans	CONTRIBUTIONS TO SAVINGS PLANS (Dollars in millions) 2015 2014 2013 Sempra Energy Consolidated $ 43 $ 38 $ 35 SDG&E 17 15 14 SoCalGas 21 18 17

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Employee Service Share Based Compensation Allocation Of Recognized Period Costs [Abstract]
Schedule Of Share-based Compensation Expense	SHARE-BASED COMPENSATION EXPENSE – SEMPRA ENERGY CONSOLIDATED (Dollars in millions, except per share amounts) Years ended December 31, 2015 2014 2013 Share-based compensation expense, before income taxes $ 48 $ 46 $ 38 Income tax benefit (19) (18) (15) Share-based compensation expense, net of income taxes $ 29 $ 28 $ 23 Net share-based compensation expense, per common share Basic $ 0.12 $ 0.11 $ 0.09 Diluted $ 0.12 $ 0.11 $ 0.09 SHARE-BASED COMPENSATION EXPENSE – SDG&E AND SOCALGAS (Dollars in millions) Years ended December 31, 2015 2014 2013 SDG&E: Compensation expense $ 8 $ 8 $ 8 Capitalized compensation cost 4 3 3 SoCalGas: Compensation expense $ 10 $ 8 $ 8 Capitalized compensation cost 2 2 1
Schedule Of Non Qualified Stock Options [Abstract]
Schedule Of Non-qualified Stock Options	NON-QUALIFIED STOCK OPTIONS Weighted- Weighted- average Shares average remaining Aggregate under exercise contractual term intrinsic value option price (in years) (in millions) Outstanding at January 1, 2015 757,412 $ 53.84 Exercised (227,815) $ 54.48 Forfeited/canceled (1,600) $ 36.30 Outstanding at December 31, 2015 527,997 $ 53.62 2.6 $ 21 Vested at December 31, 2015 527,997 $ 53.62 2.6 $ 21 Exercisable at December 31, 2015 527,997 $ 53.62 2.6 $ 21
Schedule Of Restricted Stock Awards And Units Valuation Assumptions [Abstract]
Schedule Of Restricted Stock Awards And Units Valuation Assumptions	2015 2014 2013 Risk-free rate of return 1.1 % 1.2 % 0.6 % Annual dividend yield(1) N/A N/A 3.3 Stock price volatility 14 16 19 (1) Annual dividend yield was not used in valuations performed in 2015 or 2014.
Schedule Of Restricted Stock Awards [Abstract]
Schedule Of Restricted Stock Awards	RESTRICTED STOCK AWARDS Weighted- average grant-date Shares fair value Nonvested at January 1, 2015 9,238 $ 63.81 Vested (7,701) $ 61.41 Nonvested at December 31, 2015 1,537 $ 75.87 Expected to vest at December 31, 2015 1,537 $ 75.87
Schedule Of Restricted Stock Units [Abstract]
Schedule Of Restricted Stock Units	RESTRICTED STOCK UNITS Performance-based Service-based restricted stock units(1) restricted stock units Weighted- Weighted- average average grant-date grant-date Units fair value Units fair value Nonvested at January 1, 2015 2,874,942 $ 54.55 303,237 $ 73.41 Granted 438,318 $ 123.30 72,835 $ 111.43 Vested (1,036,645) $ 42.34 (25,000) $ 88.71 Forfeited (4,940) $ 103.58 (2,266) $ 90.48 Nonvested at December 31, 2015(2) 2,271,675 $ 73.28 348,806 $ 80.14 Expected to vest at December 31, 2015 2,220,408 $ 72.89 338,086 $ 79.81 (1) Includes restricted stock units issued in 2015 in connection with the creation of Cameron LNG JV. (2) Each unit represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based restricted stock units, except for those issued in connection with the creation of Cameron LNG JV, up to an additional 50 percent (100 percent for awards granted during or after 2014) of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.

DERIVATIVE FINANCIAL INSTRUME45

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Commodity Derivative Volumes [Abstract]
Schedule Of Commodity Derivative Volumes	NET ENERGY DERIVATIVE VOLUMES December 31, Segment and Commodity 2015 2014 California Utilities: SDG&E: Natural gas 70 million MMBtu (1) 55 million MMBtu Electricity 1 million MWh (2) ― Congestion revenue rights 36 million MWh 27 million MWh SoCalGas – natural gas 1 million MMBtu 1 million MMBtu Energy-Related Businesses: Sempra Natural Gas – natural gas 43 million MMBtu 29 million MMBtu (1) Million British thermal units (2) Megawatt hours
Schedule Of Notional Amounts Of Interest Rate Derivatives [Abstract]
Schedule Of Notional Amounts of Interest Rate Derivatives Table	INTEREST RATE DERIVATIVES (Dollars in millions) December 31, 2015 December 31, 2014 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges(1) $ 384 2016-2028 $ 399 2015-2028 Fair value hedges 300 2016 300 2016 SDG&E: Cash flow hedge(1) 315 2016-2019 325 2015-2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.
Schedule Of Derivative Instruments In Statement Of Financial Position Fair Value [Abstract]
Schedule Of Derivative Instruments on the Consolidated Balance Sheets	DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2015 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Investments Fixed-price Fixed-price contracts and other contracts contracts and other assets: and other and other derivatives(1) Sundry derivatives(2) derivatives Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 4 $ 1 $ (15) $ (156) Commodity contracts not subject to rate recovery 13 ― ― ― Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 245 32 (239) (21) Associated offsetting commodity contracts (232) (20) 232 20 Associated offsetting cash collateral (6) ― 4 ― Commodity contracts subject to rate recovery 28 49 (61) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 50 60 (49) (193) Additional cash collateral for commodity contracts not subject to rate recovery 2 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 28 ― ― ― Total(4) $ 80 $ 60 $ (49) $ (193) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (14) $ (23) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery ― ― (1) ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 27 49 (60) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 25 47 (44) (59) Additional cash collateral for commodity contracts not subject to rate recovery 1 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 27 ― ― ― Total(4) $ 53 $ 47 $ (44) $ (59) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery $ ― $ ― $ (1) $ ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 1 ― (1) ― Net amounts presented on the balance sheet 1 ― (1) ― Additional cash collateral for commodity contracts subject to rate recovery 1 ― ― ― Total $ 2 $ ― $ (1) $ ― (1) Included in Current Assets: Other for SoCalGas. (2) Included in Current Liabilities: Other for SoCalGas. (3) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (4) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2014 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Investments Fixed-price Fixed-price contracts and other contracts contracts and other assets: and other and other derivatives(1) Sundry derivatives(2) derivatives Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 10 $ 3 $ (17) $ (109) Commodity contracts not subject to rate recovery 25 ― ― ― Derivatives not designated as hedging instruments: Interest rate instruments 8 27 (7) (22) Commodity contracts not subject to rate recovery 143 32 (135) (29) Associated offsetting commodity contracts (129) (27) 129 27 Associated offsetting cash collateral (11) ― ― ― Commodity contracts subject to rate recovery 36 76 (36) (20) Associated offsetting commodity contracts (3) (1) 3 1 Associated offsetting cash collateral ― ― 23 13 Net amounts presented on the balance sheet 79 110 (40) (139) Additional cash collateral for commodity contracts subject to rate recovery 14 ― ― ― Total(4) $ 93 $ 110 $ (40) $ (139) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (16) $ (31) Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery 32 76 (32) (20) Associated offsetting commodity contracts ― (1) ― 1 Associated offsetting cash collateral ― ― 23 13 Net amounts presented on the balance sheet 32 75 (25) (37) Additional cash collateral for commodity contracts subject to rate recovery 12 ― ― ― Total(4) $ 44 $ 75 $ (25) $ (37) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ ― $ (4) $ ― Associated offsetting commodity contracts (3) ― 3 ― Net amounts presented on the balance sheet 1 ― (1) ― Additional cash collateral for commodity contracts subject to rate recovery 2 ― ― ― Total $ 3 $ ― $ (1) $ ― (1) Included in Current Assets: Other for SoCalGas. (2) Included in Current Liabilities: Other for SoCalGas. (3) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (4) Normal purchase contracts previously measured at fair value are excluded.
Schedule Of Derivative Instruments Gain Loss In Statement Of Financial Performance [Abstract]
Schedule Of Fair Value Hedge Impact on the Consolidated Statements of Operations	FAIR VALUE HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Years ended December 31, Location 2015 2014 2013 Sempra Energy Consolidated: Interest rate instruments Interest Expense $ 6 $ 8 $ 8 Interest rate instruments Other Income, Net (5) (3) (7) Total (1) $ 1 $ 5 $ 1 (1) There was no hedge ineffectiveness in 2015 or 2013. There were gains of $9 million from hedge ineffectiveness in 2014. All other changes in the fair value of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt and recorded in Other Income, Net.
Schedule Of Cash Flow Hedges Impact On Statements Of Operations [Abstract]
Schedule Of Cash Flow Hedge Impact on the Consolidated Statements Of Operations	CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax (loss) gain Pretax (loss) gain reclassified recognized in OCI from AOCI into earnings (effective portion) (effective portion) Years ended December 31, Years ended December 31, 2015 2014 2013 Location 2015 2014 2013 Sempra Energy Consolidated: Interest rate and foreign exchange instruments(1) $ (18) $ (24) $ 1 Interest Expense $ (18) $ (21) $ (11) Gain on Sale of Equity Interest rate instruments ― 3 ― Interests and Assets ― 3 ― Equity Earnings, Interest rate instruments (80) (127) 15 Before Income Tax (12) (10) (10) Equity Earnings, Interest rate instruments (20) ― ― Net of Income Tax (13) ― ― Commodity contracts not Revenues: Energy-Related subject to rate recovery 12 19 (4) Businesses 14 8 1 Total(2) $ (106) $ (129) $ 12 $ (29) $ (20) $ (20) SDG&E: Interest rate instruments(1)(3) $ (6) $ (9) $ 8 Interest Expense $ (12) $ (11) $ (9) SoCalGas: Interest rate instrument(3) $ ― $ ― $ ― Interest Expense $ (1) $ (1) $ (1) (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. (2) There was $2 million, $1 million and $1 million of losses from ineffectiveness related to these cash flow hedges in 2015, 2014 and 2013, respectively. (3) There was negligible hedge ineffectiveness related to these cash flow hedges at SDG&E and SoCalGas in 2015, 2014 and 2013.
Schedule Of Undesignated Derivative Instruments Impact On Statements Of Operations [Abstract]
Schedule Of Undesignated Derivative Impact on the Consolidated Statements of Operations	UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Years ended December 31, Location 2015 2014 2013 Sempra Energy Consolidated: Interest rate and foreign exchange instruments Other Income, Net $ (4) $ (24) $ 17 Foreign exchange instruments Equity Earnings, Net of Income Tax (4) (5) (4) Commodity contracts not subject Revenues: Energy-Related to rate recovery Businesses 42 17 (1) Commodity contracts not subject Cost of Natural Gas, Electric to rate recovery Fuel and Purchased Power ― 3 ― Commodity contracts not subject to rate recovery Operation and Maintenance (1) (4) 1 Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power (126) (10) 53 Commodity contracts subject to rate recovery Cost of Natural Gas 1 ― ― Total $ (92) $ (23) $ 66 SDG&E: Commodity contracts not subject to rate recovery Operation and Maintenance $ ― $ (1) $ ― Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power (126) (10) 53 Total $ (126) $ (11) $ 53 SoCalGas: Commodity contracts not subject to rate recovery Operation and Maintenance $ (1) $ (2) $ 1 Commodity contracts subject to rate recovery Cost of Natural Gas 1 ― ― Total $ ― $ (2) $ 1

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Recurring Fair Value Assets Liabilities [Abstract]
Schedule Of Recurring Fair Value Measures	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Interest rate and foreign exchange instruments ― 5 ― ― 5 Commodity contracts not subject to rate recovery 22 16 ― (4) 34 Commodity contracts subject to rate recovery ― 1 72 28 101 Total $ 688 $ 404 $ 72 $ 24 $ 1,188 Liabilities: Interest rate and foreign exchange instruments $ ― $ 171 $ ― $ ― $ 171 Commodity contracts not subject to rate recovery 5 3 ― (4) 4 Commodity contracts subject to rate recovery ― 68 53 (54) 67 Total $ 5 $ 242 $ 53 $ (58) $ 242 Fair value at December 31, 2014 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 655 $ ― $ ― $ ― $ 655 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 47 ― ― 109 Municipal bonds ― 129 ― ― 129 Other securities ― 207 ― ― 207 Total debt securities 62 383 ― ― 445 Total nuclear decommissioning trusts(2) 717 383 ― ― 1,100 Interest rate and foreign exchange instruments ― 48 ― ― 48 Commodity contracts not subject to rate recovery 28 16 ― (11) 33 Commodity contracts subject to rate recovery ― 1 107 14 122 Total $ 745 $ 448 $ 107 $ 3 $ 1,303 Liabilities: Interest rate and foreign exchange instruments $ ― $ 155 $ ― $ ― $ 155 Commodity contracts not subject to rate recovery 3 9 ― (4) 8 Commodity contracts subject to rate recovery ― 52 ― (36) 16 Total $ 3 $ 216 $ ― $ (40) $ 179 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. (2) Excludes cash balances and cash equivalents. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Commodity contracts not subject to rate recovery ― ― ― 1 1 Commodity contracts subject to rate recovery ― ― 72 27 99 Total $ 666 $ 382 $ 72 $ 28 $ 1,148 Liabilities: Interest rate instruments $ ― $ 37 $ ― $ ― $ 37 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 67 53 (54) 66 Total $ 1 $ 104 $ 53 $ (55) $ 103 Fair value at December 31, 2014 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts Equity securities $ 655 $ ― $ ― $ ― $ 655 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 47 ― ― 109 Municipal bonds ― 129 ― ― 129 Other securities ― 207 ― ― 207 Total debt securities 62 383 ― ― 445 Total nuclear decommissioning trusts(2) 717 383 ― ― 1,100 Commodity contracts subject to rate recovery ― ― 107 12 119 Total $ 717 $ 383 $ 107 $ 12 $ 1,219 Liabilities: Interest rate instruments $ ― $ 47 $ ― $ ― $ 47 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 51 ― (36) 15 Total $ 1 $ 98 $ ― $ (37) $ 62 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. (2) Excludes cash balances and cash equivalents. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Commodity contracts subject to rate recovery $ ― $ 1 $ ― $ 1 $ 2 Total $ ― $ 1 $ ― $ 1 $ 2 Liabilities: Commodity contracts not subject to rate recovery $ 1 $ ― $ ― $ (1) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 1 $ 1 $ ― $ (1) $ 1 Fair value at December 31, 2014 Level 1 Level 2 Level 3 Netting(1) Total Assets: Commodity contracts subject to rate recovery $ ― $ 1 $ ― $ 2 $ 3 Total $ ― $ 1 $ ― $ 2 $ 3 Liabilities: Commodity contracts not subject to rate recovery $ 2 $ ― $ ― $ (2) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 2 $ 1 $ ― $ (2) $ 1 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
Schedule Of Recurring Fair Value Assets Liabilities Unobservable Input Reconciliation [Abstract]
Schedule Of Recurring Fair Value Measures Level 3 Rollforward	LEVEL 3 RECONCILIATIONS (Dollars in millions) Years ended December 31, 2015 2014 2013 Balance at January 1 $ 107 $ 99 $ 61 Realized and unrealized (losses) gains (134) 15 11 Allocated transmission instruments 12 19 51 Settlements 34 (26) (24) Balance at December 31 $ 19 $ 107 $ 99 Change in unrealized (losses) gains relating to instruments still held at December 31 $ (27) $ 8 $ 11
Schedule Of Fair Value Of Financial Instruments [Abstract]
Schedule Of Fair Value of Financial Instruments	FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) December 31, 2015 Carrying Fair Value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 175 $ ― $ 97 $ 69 $ 166 Total long-term debt (2)(3) 13,761 ― 13,985 648 14,633 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,304 $ ― $ 4,355 $ 315 $ 4,670 SoCalGas: Total long-term debt (5) $ 2,513 $ ― $ 2,621 $ ― $ 2,621 Preferred stock 22 ― 25 ― 25 December 31, 2014 Carrying Fair Value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 184 $ ― $ 132 $ 38 $ 170 Total long-term debt (2)(3) 12,347 ― 12,782 917 13,699 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,461 $ ― $ 4,563 $ 425 $ 4,988 SoCalGas: Total long-term debt (5) $ 1,913 $ ― $ 2,124 $ ― $ 2,124 Preferred stock 22 ― 25 ― 25 (1) Excluding accumulated interest outstanding of $11 million and $4 million at December 31, 2015 and 2014, respectively. (2) Before reductions for unamortized discount (net of premium) and debt issuance costs of $107 million and $102 million at December 31, 2015 and 2014, respectively, and excluding build-to-suit and capital leases of $387 million and $310 million at December 31, 2015 and 2014, respectively. We discuss our long-term debt in Note 5. (3) Level 3 instruments include $315 million and $325 million at December 31, 2015 and 2014, respectively, related to Otay Mesa VIE. (4) Before reductions for unamortized discount and debt issuance costs of $43 million and $47 million at December 31, 2015 and 2014, respectively, and excluding capital leases of $244 million and $234 million at December 31, 2015 and 2014, respectively. (5) Before reductions for unamortized discount and debt issuance costs of $24 million and $23 million at December 31, 2015 and 2014, respectively, and excluding capital leases of $1 million at both December 31, 2015 and 2014.
Schedule Of Cash Collateral Not Offset With Derivative Instruments [Abstract]
Schedule Of Fair Value of Cash Collateral Receivables Not Offset on the Consolidated Balance Sheets	December 31, (Dollars in millions) 2015 2014 Sempra Energy Consolidated $ 30 $ 14 SDG&E 28 12 SoCalGas 1 2
Schedule Of Non Recurring Fair Value Measures [Abstract]
Schedule Of Non Recurring Fair Value Measures	NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Estimated Fair % of Inputs used to fair value Fair value develop Range of value Valuation technique hierarchy measurement measurement inputs Investment in Energía Sierra Juárez $ 26 (1) Market approach Level 2 100% Equity sale offer price 100% (1) At measurement date of July 16, 2014. At December 31, 2015, our investment in Energía Sierra Juárez had a carrying value of $30 million, reflecting subsequent equity method activity to record distributions and earnings.

PREFERRED STOCK (Tables)

PREFERRED STOCK (Tables)	12 Months Ended
	Dec. 31, 2015
Preferred Stock (Tables) [Abstract]
Schedule Of Preferred Stock	PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2015 2014 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 SoCalGas - Total preferred stock 22 22 Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises (2) (2) Sempra Energy - Total preferred stock of subsidiary $ 20 $ 20

SHAREHOLDERS' EQUITY AND EARN48

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Earnings Per Share [Abstract]
Schedule Of Earnings Per Share Computations	EARNINGS PER SHARE COMPUTATIONS AND DIVIDENDS DECLARED (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2015 2014 2013 Numerator: Earnings/Income attributable to common shares $ 1,349 $ 1,161 $ 1,001 Denominator: Weighted-average common shares outstanding for basic EPS(1) 248,249 245,891 243,863 Dilutive effect of stock options, restricted stock awards and restricted stock units 2,674 4,764 5,469 Weighted-average common shares outstanding for diluted EPS 250,923 250,655 249,332 Earnings per share: Basic $ 5.43 $ 4.72 $ 4.10 Diluted $ 5.37 $ 4.63 $ 4.01 Dividends declared per share of common stock $ 2.80 $ 2.64 $ 2.52 (1) Includes fully vested restricted stock units held in our Deferred Compensation Plan of 491 in 2015, 212 in 2014 and none in 2013. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.
Schedule Of Common Stock Activity [Abstract]
Schedule Of Common Stock Activity	COMMON STOCK ACTIVITY Years ended December 31, 2015 2014 2013 Common shares outstanding, January 1 246,330,884 244,461,327 242,368,836 Restricted stock units vesting(1) 1,499,062 989,027 1,491,170 Stock options exercised 227,815 699,783 1,237,348 Savings plan issuance 652,631 398,042 ― Common stock investment plan(2) 249,665 205,203 ― Restricted stock issuances ― ― 21,121 Shares repurchased(3) (661,977) (422,498) (657,148) Common shares outstanding, December 31 248,298,080 246,330,884 244,461,327 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) From time to time, we purchase shares of our common stock from long-term incentive plan participants who elect to sell to us a sufficient number of vested restricted shares or units to meet minimum statutory tax withholding requirements.

NUCLEAR PLANT (Tables)

NUCLEAR PLANT (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Nuclear Decommissioning Trusts Investments [Abstract]
Schedule Of Nuclear Decommissioning Trusts Investments	NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Gross Gross Estimated unrealized unrealized fair Cost gains losses value At December 31, 2015: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 89 $ 2 $ ― $ 91 Municipal bonds (2) 148 8 ― 156 Other securities (2) 194 1 (13) 182 Total debt securities 431 11 (13) 429 Equity securities 214 412 (7) 619 Cash and cash equivalents 15 ― ― 15 Total $ 660 $ 423 $ (20) $ 1,063 At December 31, 2014: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 103 $ 6 $ ― $ 109 Municipal bonds 121 8 ― 129 Other securities 206 7 (6) 207 Total debt securities 430 21 (6) 445 Equity securities 215 444 (4) 655 Cash and cash equivalents 30 1 ― 31 Total $ 675 $ 466 $ (10) $ 1,131 (1) Maturity dates are 2016-2065. (2) Maturity dates are 2016-2115.
Schedule Of Sales Of Securities By Nuclear Decommissioning Trusts [Abstract]
Schedule Of Sales Of Securities By Nuclear Decommissioning Trusts	SALES OF SECURITIES (Dollars in millions) Years ended December 31, 2015 2014 2013 Proceeds from sales(1) $ 577 $ 601 $ 685 Gross realized gains 29 11 26 Gross realized losses (15) (11) (18) (1) Excludes securities that are held to maturity.

CALIFORNIA UTILITIES' REGULAT50

CALIFORNIA UTILITIES' REGULATORY MATTERS (Tables)	12 Months Ended
	Dec. 31, 2015
Regulatory Matters (Tables) [Abstract]
Schedule of Cost of Capital Authorized	COST OF CAPITAL AND AUTHORIZED RATE STRUCTURE SDG&E SoCalGas Authorized weighting Authorized rate of recovery Weighted authorized ROR Authorized weighting Authorized rate of recovery Weighted authorized ROR 45.25% 5.00% 2.26% Long-Term Debt 45.60% 5.77% 2.63% 2.75% 6.22% 0.17% Preferred Stock 2.40% 6.00% 0.14% 52.00% 10.30% 5.36% Common Equity 52.00% 10.10% 5.25% 100.00% 7.79% 100.00% 8.02%
Schedule of Sunrise Powerlink Total Project Cost	SUNRISE POWERLINK ELECTRIC TRANSMISSION LINE – PROPOSED REVISIONS TO TOTAL PROJECT COST CAP (Dollars in millions) Total Construction costs Undergrounding on Mitigation (2012 dollars, net and AFUDC Alpine Blvd. and monitoring costs present value basis) Final status report $ 1,490.9 $ 11.7 $ 384.8 $ 1,887.4 2008 CPUC approval decision 1,594.2 91.0 197.8 1,883.0 Difference $ (103.3) $ (79.3) $ 187.0 $ 4.4
Schedule Of Approved Increases To 2012 GRC Annual Revenue Requirement	APPROVED INCREASES TO THE 2012 GRC ANNUAL REVENUE REQUIREMENTS (Dollars in millions) Pretax After-tax 2012(1) $ 6.4 $ 3.8 2013(1) 6.3 3.7 2014(1) 6.4 3.8 2015(2) 6.6 3.9 $ 25.7 $ 15.2 (1) The approved increase to after-tax earnings was recorded in the second quarter of 2015. (2) The approved increase to after-tax earnings for the first and second quarters of 2015 of $1.4 million and $0.8 million, respectively, was recorded in the second quarter of 2015. The approved increase to after-tax earnings for the third and fourth quarters of 2015 of $0.6 million and $1.1 million, respectively, was recorded in the respective quarters.
Schedule Of California Utilities Major Projects	MAJOR PROJECTS – JOINT UTILITIES (Dollars in millions) Project description Estimated cost Status Southern Gas System Reliability Project § 2013 application seeking authority to recover the full cost of the project. $ 800 to $ 850 § In March 2015, CPUC issued a revised project scope and updated schedule. § Will enhance reliability on the southern portions of the California Utilities’ integrated natural gas transmission system (Southern System). § If approved, and subject to environmental permitting, the project could commence construction in 2017 and be in service by the end of 2019. § Also known as the North-South Gas Project. Pipeline Safety & Reliability Project § September 2015 application seeking authority to recover the full cost of the project, involving construction of an approximately 47-mile, 36-inch natural gas transmission pipeline in San Diego County. $ 600 § January 2016 ruling directing SDG&E and SoCalGas to file an amended application by March 21, 2016 and provide additional information and analysis regarding various project alternatives. § Will implement pipeline safety requirements and modernize the system; improve system reliability and resiliency by minimizing dependence on a single pipeline; and enhance operational flexibility to manage stress conditions by increasing system capacity. § After CPUC approval, and subject to timing of other approvals, will take approximately 24 to 36 months to construct. MAJOR PROJECTS – SDG&E (Dollars in millions) Project description Estimated cost Status Cleveland National Forest (CNF) Transmission Projects § 2012 application for permit to construct various transmission line replacement projects in and around CNF. $ 400 to $ 450 § Alternatives identified in July 2015 joint CPUC/USFS environmental impact report (EIR/EIS), if approved by CPUC and USFS, would result in an increase to the estimated cost of the projects. § To replace and fire-harden five existing transmission lines. § Separate USFS and CPUC decisions on the transmission projects expected in the first half of 2016. § Various phases expected to be placed in service starting in 2016 and continuing through 2019. Sycamore-Peñasquitos Transmission Project § 230-kV transmission project to provide 16.7-mile transmission connection between Sycamore Canyon and Peñasquitos substations. $ 120 to $ 150 § In March 2014, California ISO selected SDG&E in a competitively bid process to construct the project, which we originally estimated to cost $120 million to $150 million. § California ISO and state task force identified as necessary to ensure grid reliability given the closure of SONGS. § September 2015 draft EIR/EIS recommends an alternative that undergrounds more of the project than originally proposed. The CPUC may consider this alternative which has an estimated cost of $250 million to $300 million. § CPUC decision expected in the first half of 2016, with the line expected to be in service in mid-2017. South Orange County Reliability Enhancement § 2012 application for Certificate of Public Convenience and Necessity (CPCN) to enhance the capacity and reliability of electric service to the south Orange County area. $ 350 to $ 400 § Final CPUC decision expected in the first half of 2016. § Replacing and upgrading approximately eight miles of transmission lines and rebuilding and upgrading a substation at an existing site. § Planned in phases; entire project expected to be in service in 2020. South Bay Substation and Relocation Project § 2010 application with the CPUC for permit to construct new Bay Boulevard substation to replace the aging and obsolete South Bay substation. $ 145 to $ 175 § July 2014 petition filed with the CPUC requesting modifications to the prior CPUC decision to authorize additional construction activities required by the coastal development permit. § Demolish existing substation when the Bay Boulevard substation has been constructed, energized and all transmission lines have been transferred. § CPUC approved the petition for modification in January 2015. Project expected to be in service in 2017. Electric Vehicle Charging Program § April 2014 proposal for program to build and own a total of 5,500 electric vehicle charging units at estimated cost of $103 million, of which $59 million is capital investment. $ 45 § January 2016 CPUC final decision denies proposal but authorizes a 3-year, $45 million program providing up to 3,500 charging units. § Hourly Vehicle-to-Grid Integration rate to incent vehicle charging during times of the day that benefit the power grid. Distribution Resource Plan § July 2015 application filed with the CPUC submitting Distribution Resource Plan. Distributed energy resources (DER) are typically smaller power sources connected to the distribution grid and located near load centers. TBD § SDG&E expects the CPUC to address the Distribution Resource Plan in a phased manner with more than one decision issued in the 2016 to 2017 time period.

COMMITMENTS AND CONTINGENCIES51

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule Of Estimated Future Payments Under Natural Gas Contracts [Abstract]
Schedule Of Estimated Future Payments Under Natural Gas Contracts	FUTURE MINIMUM PAYMENTS – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Storage and transportation Natural gas(1) Total(1) 2016 $ 258 $ 100 $ 358 2017 243 102 345 2018 217 85 302 2019 150 5 155 2020 46 5 51 Thereafter 186 13 199 Total minimum payments $ 1,100 $ 310 $ 1,410 (1) Excludes amounts related to LNG purchase agreements discussed below. FUTURE MINIMUM PAYMENTS – SOCALGAS (Dollars in millions) Transportation Natural gas Total 2016 $ 127 $ ― $ 127 2017 114 1 115 2018 92 1 93 2019 48 1 49 2020 23 1 24 Thereafter 105 ― 105 Total minimum payments $ 509 $ 4 $ 513
Schedule Of Payments Under Natural Gas Contracts [Abstract]
Schedule Of Payments Under Natural Gas Contracts	PAYMENTS UNDER NATURAL GAS CONTRACTS (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated $ 1,200 $ 1,984 $ 1,680 SoCalGas 975 1,735 1,464
Schedule Of L N G Commitment Amounts [Abstract]
Schedule Of L N G Commitment Amounts [Text Block]	LNG COMMITMENT AMOUNTS (Dollars in millions) 2016 $ 330 2017 432 2018 456 2019 487 2020 534 Thereafter 5,524 Total $ 7,763
Schedule Of Payments Under Purchased Power Contracts [Abstract]
Schedule Of Payments Under Purchased Power Contracts	PAYMENTS UNDER PURCHASED-POWER CONTRACTS (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated $ 1,573 $ 1,574 $ 1,377 SDG&E(1) 715 710 570 (1) Excludes DWR-allocated contracts. Under an operating agreement with the DWR that expired at the end of 2013, SDG&E acted as a limited agent on behalf of the DWR in the administration of energy contracts, including natural gas procurement functions under the DWR contracts allocated to SDG&E's customers. The commodity costs associated with these contracts are not included in SDG&E's or Sempra Energy's Consolidated Statements of Operations.
Schedule Of Estimated Future Payments Under Purchased Power Contracts [Abstract]
Schedule Of Estimated Future Payments Under Purchased Power Contracts	FUTURE MINIMUM PAYMENTS – PURCHASED-POWER CONTRACTS (Dollars in millions) Sempra Energy Consolidated SDG&E 2016 $ 741 $ 521 2017 726 504 2018 781 502 2019 776 493 2020 720 430 Thereafter 7,169 6,071 Total minimum payments(1) $ 10,913 $ 8,521 (1) Excludes purchase agreements accounted for as capital leases and amounts related to Otay Mesa VIE, as it is consolidated by Sempra Energy and SDG&E.
Schedule Of Operating Leases Rent Expense [Abstract]
Schedule Of Operating Leases, Rent Expense	RENT EXPENSE – OPERATING LEASES (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated $ 78 $ 78 $ 81 SDG&E 27 26 23 SoCalGas 39 38 31
Schedule Of Operating Leases Future Minimum Payments Due [Abstract]
Schedule Of Operating Leases, Future Minimum Payments Due	FUTURE MINIMUM PAYMENTS – OPERATING LEASES (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2016 $ 71 $ 25 $ 38 2017 71 25 39 2018 63 19 36 2019 57 18 33 2020 50 16 28 Thereafter 283 70 131 Total future minimum rental commitments $ 595 $ 173 $ 305
Schedule Of Capital Leases Future Minimum Payments Present Value Of Net Minimum Payments [Abstract]
Schedule Of Capital Leases, Future Minimum Payments, Present Value Of Net Minimum Payments	FUTURE MINIMUM PAYMENTS – POWER PURCHASE AGREEMENTS (Dollars in millions) 2016 $ 39 2017 77 2018 104 2019 104 2020 104 Thereafter 1,910 Total minimum lease payments(1) 2,338 Less: estimated executory costs (523) Less: interest(2) (1,072) Present value of net minimum lease payments(3) $ 743 (1) This amount will be recorded over the lives of the leases as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs, which are recovered in rates. (2) Amount necessary to reduce net minimum lease payments to present value at the inception of the leases. (3) Includes $4 million in Current Portion of Long-Term Debt and $239 million in Long-Term Debt on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets at December 31, 2015. Of the present value of net minimum lease payments, $500 million will be recorded as a capital lease obligation when construction of the peaker plant facility is completed and delivery of contracted power commences, which is scheduled to occur in June 2017.
Schedule Of Environmental Remediation Costs Capitalized In Period [Abstract]
Schedule Of Environmental Remediation Costs, Capitalized In Period	CAPITAL EXPENDITURES FOR ENVIRONMENTAL ISSUES (Dollars in millions) Years ended December 31, 2015 2014 2013 Sempra Energy Consolidated(1) $ 64 $ 45 $ 31 SDG&E 24 23 13 SoCalGas 39 21 15 (1) In cases of non-wholly owned affiliates, includes only our share.
Schedule Of Environmental Remediation Costs Status Of Remediation Sites [Abstract]
Schedule Of Environmental Remediation Costs, Status Of Remediation Sites	STATUS OF ENVIRONMENTAL SITES # Sites # Sites completed(1) in process SDG&E: Manufactured-gas sites 3 ― Third-party waste-disposal sites 2 1 SoCalGas: Manufactured-gas sites 39 3 Third-party waste-disposal sites 5 2 (1) There may be on-going compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.
Schedule Of Environmental Loss Contingencies By Site [Abstract]
Schedule of Environmental Loss Contingencies by Site	ACCRUED LIABILITIES FOR ENVIRONMENTAL MATTERS (Dollars in millions) Waste Former fossil- Other Manufactured- disposal fueled power hazardous gas sites sites (PRP)(1) plants waste sites Total(2) SDG&E(3) $ ― $ 0.9 $ 0.7 $ 0.5 $ 2.1 SoCalGas(4) 23.1 2.0 ― ― 25.1 Other 1.8 1.1 ― 15.0 17.9 Total Sempra Energy $ 24.9 $ 4.0 $ 0.7 $ 15.5 $ 45.1 (1) Sites for which we have been identified as a Potentially Responsible Party. (2) Sempra Energy, SDG&E and SoCalGas have accrued $45 million, $2 million and $25 million, respectively, for environmental liabilities as of December 31, 2015. Of these amounts, $24 million, $1 million and $6 million were classified as current liabilities, and $21 million, $1 million and $19 million were classified as noncurrent liabilities on Sempra Energy’s, SDG&E’s and SoCalGas’ Consolidated Balance Sheets, respectively. (3) Does not include SDG&E’s liability for SONGS marine mitigation. (4) Does not include any SoCalGas accrued liabilities for environmental matters for the natural gas leak at the Aliso Canyon facility. We discuss matters related to the leak above under "Legal Proceedings – SoCalGas – Aliso Canyon Natural Gas Storage Facility Gas Leak."
Schedule Of Build To Suit Lease Future Minimum Payments Due [Abstract]
Schedule Of Build To Suit Lease Future Minimum Payments Due	FUTURE MINIMUM PAYMENTS – BUILD-TO-SUIT LEASE (Dollars in millions) 2016 $ 10 2017 10 2018 10 2019 10 2020 11 Thereafter 256 Total minimum lease payments $ 307

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Information (Tables) [Abstract]
Schedule of Segment Reporting Information, by Segment	SEGMENT INFORMATION (Dollars in millions) Years ended December 31, 2015 2014 2013 REVENUES SDG&E $ 4,219 41 % $ 4,329 39 % $ 4,066 39 % SoCalGas 3,489 34 3,855 35 3,736 35 Sempra South American Utilities 1,544 15 1,534 14 1,495 14 Sempra Mexico 669 7 818 8 675 6 Sempra Renewables 36 ― 35 ― 82 1 Sempra Natural Gas 653 6 979 9 908 9 Adjustments and eliminations (2) ― (3) ― (2) ― Intersegment revenues(1) (377) (3) (512) (5) (403) (4) Total $ 10,231 100 % $ 11,035 100 % $ 10,557 100 % INTEREST EXPENSE SDG&E $ 204 $ 202 $ 197 SoCalGas 84 69 69 Sempra South American Utilities 32 33 27 Sempra Mexico 23 17 17 Sempra Renewables 3 5 23 Sempra Natural Gas 72 111 116 All other 263 241 241 Intercompany eliminations (120) (124) (131) Total $ 561 $ 554 $ 559 INTEREST INCOME SDG&E $ ― $ ― $ 1 SoCalGas 4 ― ― Sempra South American Utilities 19 14 14 Sempra Mexico 7 4 2 Sempra Renewables 4 1 20 Sempra Natural Gas 75 115 88 All other ― 1 ― Intercompany eliminations (80) (113) (105) Total $ 29 $ 22 $ 20 DEPRECIATION AND AMORTIZATION SDG&E $ 604 48 % $ 530 46 % $ 494 44 % SoCalGas 461 37 431 37 383 35 Sempra South American Utilities 50 4 55 5 59 5 Sempra Mexico 70 6 64 6 63 6 Sempra Renewables 6 ― 5 ― 21 2 Sempra Natural Gas 49 4 61 5 81 7 All other 10 1 10 1 12 1 Total $ 1,250 100 % $ 1,156 100 % $ 1,113 100 % INCOME TAX EXPENSE (BENEFIT) SDG&E $ 284 $ 270 $ 191 SoCalGas 138 139 116 Sempra South American Utilities 67 58 67 Sempra Mexico 11 5 60 Sempra Renewables (49) (44) (19) Sempra Natural Gas 28 (20) 40 All other (138) (108) (89) Total $ 341 $ 300 $ 366 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) At December 31 or for the years ended December 31, 2015 2014 2013 EARNINGS (LOSSES) SDG&E(2) $ 587 43 % $ 507 44 % $ 404 41 % SoCalGas(3) 419 31 332 29 364 37 Sempra South American Utilities 175 13 172 15 153 15 Sempra Mexico 213 16 192 16 122 12 Sempra Renewables 63 5 81 7 62 6 Sempra Natural Gas 44 3 50 4 64 6 All other (152) (11) (173) (15) (168) (17) Total $ 1,349 100 % $ 1,161 100 % $ 1,001 100 % ASSETS(4) SDG&E $ 16,515 40 % $ 16,260 41 % $ 15,337 41 % SoCalGas 12,104 29 10,446 26 9,138 25 Sempra South American Utilities 3,235 8 3,379 9 3,531 10 Sempra Mexico 3,783 9 3,486 9 3,243 9 Sempra Renewables 1,441 4 1,334 3 1,214 3 Sempra Natural Gas 5,566 13 6,435 16 7,199 19 All other 734 2 872 2 817 2 Intersegment receivables (2,228) (5) (2,561) (6) (3,314) (9) Total $ 41,150 100 % $ 39,651 100 % $ 37,165 100 % EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,133 36 % $ 1,100 35 % $ 978 38 % SoCalGas 1,352 43 1,104 35 762 30 Sempra South American Utilities 154 5 174 6 200 8 Sempra Mexico 302 10 325 10 371 14 Sempra Renewables 81 2 190 6 176 7 Sempra Natural Gas 87 3 212 7 83 3 All other 47 1 18 1 2 ― Total $ 3,156 100 % $ 3,123 100 % $ 2,572 100 % GEOGRAPHIC INFORMATION Long-lived assets(5): United States $ 26,132 84 % $ 24,183 84 % $ 22,654 84 % Mexico 3,160 10 2,821 10 2,597 9 South America 1,652 6 1,746 6 1,784 7 Total $ 30,944 100 % $ 28,750 100 % $ 27,035 100 % Revenues(6): United States $ 8,119 79 % $ 8,774 79 % $ 8,478 80 % South America 1,544 15 1,534 14 1,495 14 Mexico 568 6 727 7 584 6 Total $ 10,231 100 % $ 11,035 100 % $ 10,557 100 % (1) Revenues for reportable segments include intersegment revenues of $9 million, $75 million, $101 million, and $192 million for 2015, $10 million, $69 million, $91 million and $342 million for 2014, and $10 million, $70 million, $91 million and $232 million for 2013 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively. (2) For 2013, amount is after preferred dividends and call premium on preferred stock. (3) After preferred dividends. (4) December 31, 2014 and 2013 have been adjusted for the retrospective adoption of ASU 2015-03. (5) Includes net property, plant and equipment and investments. (6) Amounts are based on where the revenue originated, after intercompany eliminations.

QUARTERLY FINANCIAL DATA (Table

QUARTERLY FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Data (Tables) [Abstract]
Schedule Of Quarterly Financial Data [Text Block]	SEMPRA ENERGY (In millions, except per share amounts) Quarters ended March 31 June 30 September 30 December 31 2015: Revenues $ 2,682 $ 2,367 $ 2,481 $ 2,701 Expenses and other income $ 2,076 $ 1,971 $ 2,211 $ 2,269 Net income $ 458 $ 320 $ 282 $ 388 Earnings attributable to Sempra Energy $ 437 $ 295 $ 248 $ 369 Basic per-share amounts(1): Net income $ 1.85 $ 1.29 $ 1.14 $ 1.56 Earnings attributable to Sempra Energy $ 1.76 $ 1.19 $ 1.00 $ 1.48 Weighted average common shares outstanding 247.7 248.1 248.4 248.7 Diluted per-share amounts(1): Net income $ 1.83 $ 1.27 $ 1.12 $ 1.54 Earnings attributable to Sempra Energy $ 1.74 $ 1.17 $ 0.99 $ 1.47 Weighted average common shares outstanding 251.2 251.5 251.0 251.5 2014: Revenues $ 2,795 $ 2,678 $ 2,815 $ 2,747 Expenses and other income $ 2,408 $ 2,302 $ 2,368 $ 2,433 Net income $ 266 $ 292 $ 383 $ 321 Earnings attributable to Sempra Energy $ 247 $ 269 $ 348 $ 297 Basic per-share amounts(1): Net income $ 1.09 $ 1.19 $ 1.56 $ 1.31 Earnings attributable to Sempra Energy $ 1.01 $ 1.10 $ 1.41 $ 1.21 Weighted average common shares outstanding 245.3 245.7 246.1 246.4 Diluted per-share amounts(1): Net income $ 1.07 $ 1.17 $ 1.53 $ 1.28 Earnings attributable to Sempra Energy $ 0.99 $ 1.08 $ 1.39 $ 1.18 Weighted average common shares outstanding 249.7 250.1 250.8 251.3 (1) Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year. SDG&E (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2015: Operating revenues $ 966 $ 972 $ 1,230 $ 1,051 Operating expenses 684 745 930 802 Operating income $ 282 $ 227 $ 300 $ 249 Net income $ 151 $ 130 $ 182 $ 143 (Earnings) losses attributable to noncontrolling interest (4) (4) (12) 1 Earnings attributable to common shares $ 147 $ 126 $ 170 $ 144 2014: Operating revenues $ 987 $ 1,063 $ 1,233 $ 1,046 Operating expenses 766 821 957 826 Operating income $ 221 $ 242 $ 276 $ 220 Net income $ 101 $ 129 $ 169 $ 128 Earnings attributable to noncontrolling interest (2) (6) (12) ― Earnings attributable to common shares $ 99 $ 123 $ 157 $ 128 SOCALGAS (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2015: Operating revenues $ 1,048 $ 780 $ 620 $ 1,041 Operating expenses 728 686 633 834 Operating income (loss) $ 320 $ 94 $ (13) $ 207 Net income (loss) $ 214 $ 71 $ (8) $ 143 Dividends on preferred stock ― (1) ― ― Earnings (losses) attributable to common shares $ 214 $ 70 $ (8) $ 143 2014: Operating revenues $ 1,085 $ 917 $ 855 $ 998 Operating expenses 956 795 702 881 Operating income $ 129 $ 122 $ 153 $ 117 Net income $ 78 $ 81 $ 98 $ 76 Dividends on preferred stock ― (1) ― ― Earnings attributable to common shares $ 78 $ 80 $ 98 $ 76

SCHEDULE I, CONDENSED FINANCI54

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)	12 Months Ended
	Dec. 31, 2015
Schedule of Condensed Statements of Operations [Abstract]
Schedule of Condensed Statements of Operations [Text Block]	SEMPRA ENERGY CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts) Years ended December 31, 2015 2014 2013 Interest income $ ― $ ― $ 42 Interest expense (261) (235) (239) Operation and maintenance (66) (78) (63) Other income, net 7 50 41 Income tax benefits 150 133 117 Loss before equity in earnings of subsidiaries (170) (130) (102) Equity in earnings of subsidiaries, net of income taxes 1,519 1,291 1,103 Net income/earnings $ 1,349 $ 1,161 $ 1,001 Basic earnings per common share $ 5.43 $ 4.72 $ 4.10 Weighted-average number of shares outstanding (thousands) 248,249 245,891 243,863 Diluted earnings per common share $ 5.37 $ 4.63 $ 4.01 Weighted-average number of shares outstanding (thousands) 250,923 250,655 249,332 See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Balance Sheets [Abstract]
Schedule Of Condensed Balance Sheets [Text Block]	SEMPRA ENERGY CONDENSED BALANCE SHEETS (Dollars in millions) December 31, December 31, 2015 2014(1) Assets: Cash and cash equivalents $ 4 $ 3 Due from affiliates 62 101 Deferred income taxes ― 398 Other current assets 4 15 Total current assets 70 517 Investments in subsidiaries 15,586 14,557 Due from affiliates 457 174 Deferred income taxes 2,188 1,544 Other assets 641 609 Total assets $ 18,942 $ 17,401 Liabilities and shareholders’ equity: Current portion of long-term debt $ 752 $ ― Due to affiliates 332 338 Income taxes payable 42 93 Other current liabilities 310 271 Total current liabilities 1,436 702 Long-term debt 5,195 4,644 Due to affiliates ― 230 Other long-term liabilities 502 499 Shareholders’ equity 11,809 11,326 Total liabilities and shareholders’ equity $ 18,942 $ 17,401 (1) As adjusted for the retrospective adoption of ASU 2015-03. See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Statements of Cash Flows [Abstract]
Schedule of Condensed Statements of Cash Flows [Text Block]	SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2015 2014 2013 Net cash used in operating activities $ (255) $ (260) $ (131) Dividends received from subsidiaries 350 300 50 Expenditures for property, plant and equipment (43) (15) (1) Purchase of trust assets (5) (4) (5) Proceeds from sales by trust ― ― 10 Capital contribution to subsidiaries ― ― (6) (Increase) decrease in loans to affiliates, net (457) 627 962 Cash (used in) provided by investing activities (155) 908 1,010 Common stock dividends paid (628) (598) (606) Issuances of common stock 52 56 62 Repurchases of common stock (74) (38) (45) Issuances of long-term debt 1,248 499 498 Payments on long-term debt ― (800) (650) (Decrease) increase in loans from affiliates, net (230) 234 (147) Tax benefit related to share-based compensation 52 ― ― Other (9) (4) (3) Cash provided by (used in) financing activities 411 (651) (891) Increase (decrease) in cash and cash equivalents 1 (3) (12) Cash and cash equivalents, January 1 3 6 18 Cash and cash equivalents, December 31 $ 4 $ 3 $ 6 SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES Financing of build-to-suit property $ 61 $ 61 $ 14 Common dividends issued in stock 55 42 ― Dividends declared but not paid 174 163 154 See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Long-Term Debt [Abstract]
Schedule of Condensed Long-Term Debt [Text Block]	LONG-TERM DEBT (Dollars in millions) December 31, December 31, 2015 2014(1) 6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating rate swaps effective January 2011 (4.77% at December 31, 2015) $ 750 $ 750 2.3% Notes April 1, 2017 600 600 6.15% Notes June 15, 2018 500 500 9.8% Notes February 15, 2019 500 500 2.4% Notes March 15, 2020 500 ― 2.85% Notes November 15, 2020 400 ― 2.875% Notes October 1, 2022 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 ― 6% Notes October 15, 2039 750 750 Market value adjustments for interest rate swaps, net (2) ― Build-to-suit lease 136 75 5,984 4,675 Current portion of long-term debt (752) ― Unamortized discount on long-term debt (10) (9) Unamortized debt issuance costs (27) (22) Total long-term debt $ 5,195 $ 4,644 (1) As adjusted for the retrospective adoption of ASU 2015-03.
Schedule Of Condensed Statements Of Comprehensive Income [Abstract]
Schedule Of Condensed Statements Of Comprehensive Income [Text Block]	SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, Pretax Income tax Net-of-tax amount benefit (expense) amount 2015: Net income $ 1,199 $ 150 $ 1,349 Other comprehensive income (loss): Foreign currency translation adjustments (260) ― (260) Financial instruments (80) 33 (47) Pension and other postretirement benefits (3) 1 (2) Total other comprehensive loss (343) 34 (309) Comprehensive income $ 856 $ 184 $ 1,040 2014: Net income $ 1,028 $ 133 $ 1,161 Other comprehensive income (loss): Foreign currency translation adjustments (193) ― (193) Financial instruments (106) 42 (64) Pension and other postretirement benefits (20) 8 (12) Total other comprehensive loss (319) 50 (269) Comprehensive income $ 709 $ 183 $ 892 2013: Net income $ 884 $ 117 $ 1,001 Other comprehensive income (loss): Foreign currency translation adjustments 111 ― 111 Financial instruments 13 (4) 9 Pension and other postretirement benefits 47 (19) 28 Total other comprehensive income 171 (23) 148 Comprehensive income $ 1,055 $ 94 $ 1,149 See Notes to Condensed Financial Information of Parent.

OTHER FINANCIAL DATA - RESTRICT

OTHER FINANCIAL DATA - RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Presentation Of Restricted Cash [Line Items]
Restricted cash	$ 27	$ 11	[1]
Restricted Cash and Cash Equivalents, Noncurrent	20	29	[1]
Restricted cash, current and noncurrent	47	40
Restricted Cash, Construction Financing [Member] | Sempra Mexico Segment [Member]
Presentation Of Restricted Cash [Line Items]
Restricted Cash and Cash Equivalents, Noncurrent	20	18
Restricted Cash, Construction Financing [Member] | Sempra Renewables Segment [Member]
Presentation Of Restricted Cash [Line Items]
Restricted cash	4	3
San Diego Gas and Electric Company [Member]
Presentation Of Restricted Cash [Line Items]
Restricted cash	23	8
Restricted Cash and Cash Equivalents, Noncurrent	0	11
San Diego Gas and Electric Company [Member] | Restricted Cash, Operating Requirements [Member] | S D G E Segment [Member]
Presentation Of Restricted Cash [Line Items]
Restricted cash	8	8
Restricted Cash and Cash Equivalents, Noncurrent	0	11
Restricted cash, current and noncurrent	$ 23	$ 19
[1]	As adjusted for the retrospective adoption of ASU 2015-03.

OTHER FINANCIAL DATA - INVENTOR

OTHER FINANCIAL DATA - INVENTORY (Details) - USD ($) $ in Millions	Dec. 31, 2015		Dec. 31, 2014
Inventories By Inventory Type [Line Items]
Energy Related Inventory, Natural Gas in Storage	$ 149		$ 246
Energy Related Inventory, LNG	6		14
Energy Related Inventory, Materials And Supplies	143		136
Inventories	298		396	[1]
S D G E Segment [Member]
Inventories By Inventory Type [Line Items]
Energy Related Inventory, Natural Gas in Storage	6		8
Energy Related Inventory, LNG	0		0
Energy Related Inventory, Materials And Supplies	69		65
Inventories	75		73
So Cal Gas Segment [Member]
Inventories By Inventory Type [Line Items]
Inventory loss related to Aliso Canyon	(11)
Energy Related Inventory, Natural Gas in Storage	49	[2]	155
Energy Related Inventory, LNG	0		0
Energy Related Inventory, Materials And Supplies	30		26
Inventories	79	[2]	181
Sempra South American Utilities Segment [Member]
Inventories By Inventory Type [Line Items]
Energy Related Inventory, Natural Gas in Storage	0		0
Energy Related Inventory, LNG	0		0
Energy Related Inventory, Materials And Supplies	30		33
Inventories	30		33
Sempra Mexico Segment [Member]
Inventories By Inventory Type [Line Items]
Energy Related Inventory, Natural Gas in Storage	0		0
Energy Related Inventory, LNG	3		9
Energy Related Inventory, Materials And Supplies	10		9
Inventories	13		18
Sempra Renewables Segment [Member]
Inventories By Inventory Type [Line Items]
Energy Related Inventory, Natural Gas in Storage	0		0
Energy Related Inventory, LNG	0		0
Energy Related Inventory, Materials And Supplies	3		2
Inventories	3		2
Sempra Natural Gas Segment [Member]
Inventories By Inventory Type [Line Items]
Energy Related Inventory, Natural Gas in Storage	94		83
Energy Related Inventory, LNG	3		5
Energy Related Inventory, Materials And Supplies	1		1
Inventories	$ 98		$ 89
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As of December 31, 2015, SoCalGas recorded an estimated inventory loss related to the Aliso Canyon natural gas leak of $11 million, included in Insurance Receivable for Aliso Canyon Costs on Sempra Energy's and SoCalGas' Consolidated Balance Sheets. See additional discussion about the Aliso Canyon natural gas storage facility leak in Note 15.

OTHER FINANCIAL DATA - U.S. TRE

OTHER FINANCIAL DATA - U.S. TREASURY GRANT RECEIVABLE (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
U.S. Treasury Grants Receivable [Line Items]
Proceeds from U.S. Treasury grants		$ 0	$ 0	$ 238
Reduction in tax benefit due to sequestration	$ 5
Sequestration of U.S. Treasury grants receivable		$ 0	$ 0	$ 23

OTHER FINANCIAL DATA - TRANSACT

OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		$ 6		$ 38	[1]
Due to affiliaties, current		(14)		(2)	[2]
Due from affiliaties, noncurrent		186		188	[1]
Parent Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		62		101	[3]
Due to affiliaties, current		(332)		(338)	[3]
Due from affiliaties, noncurrent		457		174	[3]
San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		1		1	[4]
Due to affiliaties, current		(55)		(21)	[4]
Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		48		4	[1]
Due to affiliaties, current		0		(13)	[1]
Due to/from Sempra Energy | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliaties, current		(34)		(17)
Income taxes due from (to) Sempra Energy	[5]	28		16
Due to/from Sempra Energy | Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		35	[6]	0
Due to affiliaties, current		0		(13)
Income taxes due from (to) Sempra Energy	[5]	$ 1		9
Interest rate on due from affiliate		0.11%
Loan to unconsolidated affiliate, principal		$ 50
Due to/from SDG&E | Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		13		4
Due to/from SoCalGas | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliaties, current		$ (13)		(4)
Joint venture with PEMEX [Member]
Transactions With Affiliates Disclosure [Line Items]
Interest rate on due from affiliate		4.93%
Pemex Four Year Loan C [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent	[7],[8],[9]	$ 8		8
Pemex Three Year Loan A [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent	[7],[8],[9]	3	[10]	44
Repayment Of Notes Receivable From Related Parties		41
Pemex Four Year Loan B [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent	[7],[8],[9]	34		33
Pemex Four Year Loan A [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent	[7],[8],[9]	42		40
ESJ joint venture [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent	[7],[11]	$ 24		22
Interest rate on due from affiliate		6.80%
Eletrans [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent	[7],[12]	$ 72		41
Interest rate on due from affiliate		4.00%
Sempra Natural Gas Segment [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliaties, noncurrent		$ 3		0
Affiliate of Investee [Member] | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliaties, current		$ (8)		$ 0
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	As adjusted for the retrospective adoption of ASU 2015-03.
[4]	As adjusted for the retrospective adoption of ASU 2015-03.
[5]	SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return.
[6]	Net receivable includes outstanding advances to Sempra Energy of $50 million at December 31, 2015 at an interest rate of 0.11 percent.
[7]	Amounts include principal balances plus accumulated interest outstanding.
[8]	Petróleos Mexicanos (or PEMEX, the Mexican state-owned oil company).
[9]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.93 percent at December 31, 2015), to finance the Los Ramones Norte pipeline project.
[10]	In May 2015, $41 million was paid with proceeds from project financing at the affiliate.
[11]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.80 percent at December 31, 2015), to finance the first phase of the Energía Sierra Juárez wind project.
[12]	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A., an affiliate of Chilquinta Energía.

OTHER FINANCIAL DATA - TRANSA59

OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES 2 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Transactions With Affiliates Disclosure [Line Items]
Revenue from Related Parties	$ 26	$ 13	$ 4
Costs and Expenses Related Party	107	78	78
San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Revenue from Related Parties	10	13	12
Costs and Expenses Related Party	49	17	19
Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Revenue from Related Parties	$ 75	$ 69	$ 70

OTHER FINANCIAL DATA - VARIABLE

OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITY (Details) - USD ($) $ in Millions		3 Months Ended									12 Months Ended
		Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014		Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
Variable Interest Entity [Line Items]
Cash and cash equivalents		$ 403				$ 570	[1]				$ 403	$ 570	[1]	$ 904	$ 475
Restricted cash		27				11	[1]				27	11	[1]
Inventories		298				396	[1]				298	396	[1]
Other current assets		267				293	[1]				267	293	[1]
Total current assets		2,891				4,184	[1]				2,891	4,184	[1]
Restricted cash, noncurrent		20				29	[1]				20	29	[1]
Sundry		761				480	[1]				761	480	[1]
Property, plant and equipment, net		28,039				25,902	[1]				28,039	25,902	[1]
Total assets	[2]	41,150				39,651	[1]				41,150	39,651	[1]	37,165
Current portion of long-term debt		907				469	[3]				907	469	[3]
Fixed-price contracts and other derivatives, current liabilities		56				55	[3]				56	55	[3]
Other current liabilities		551				649	[3]				551	649	[3]
Total current liabilities		4,612				5,069	[3]				4,612	5,069	[3]
Long-term debt		13,134				12,086	[3]				13,134	12,086	[3]
Fixed-price contracts and other derivatives, noncurrent liabilities		240				255	[3]				240	255	[3]
Deferred credits and other		1,176				1,104	[3]				1,176	1,104	[3]
Other noncontrolling interest		750				754	[3]				750	754	[3]
Total liabilities and equity		41,150				39,651	[3]				41,150	39,651	[3]
Operating expenses
Operation and maintenance											2,895	2,935		2,995
Depreciation and amortization											1,250	1,156		1,113
Other income (expense), net											126	137		140
Interest expense											(561)	(554)		(559)
Net income											1,448	1,262		1,088
Earnings attributable to noncontrolling interest											(98)	(100)		(79)
Earnings		369	$ 248	$ 295	$ 437	297		$ 348	$ 269	$ 247	1,349	1,161		1,001
Otay Mesa VIE [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		5				5	[4]				5	5	[4]
Restricted cash		23				8	[4]				23	8	[4]
Inventories		3				3	[4]				3	3	[4]
Other current assets		0				1	[4]				0	1	[4]
Total current assets		31				17	[4]				31	17	[4]
Restricted cash, noncurrent		0				11	[4]				0	11	[4]
Property, plant and equipment, net		383				410	[4]				383	410	[4]
Total assets		414				438	[4]				414	438	[4]
Current portion of long-term debt		10				10	[4]				10	10	[4]
Fixed-price contracts and other derivatives, current liabilities		14				16	[4]				14	16	[4]
Other current liabilities		5				3	[4]				5	3	[4]
Total current liabilities		29				29	[4]				29	29	[4]
Debt Instrument Carrying Amount		315									315
Long-term debt		303				312	[4]				303	312	[4]
Fixed-price contracts and other derivatives, noncurrent liabilities		23				31	[4]				23	31	[4]
Deferred credits and other		6				6	[4]				6	6	[4]
Other noncontrolling interest		53				60	[4]				53	60	[4]
Total liabilities and equity		414				438	[4]				414	438	[4]
Operating expenses
Elimination of cost of electric fuel and purchased power											(83)	(83)		(91)
Operation and maintenance											19	19		24
Depreciation and amortization											26	27		28
Elimination of total operating expenses											(38)	(37)		(39)
Operating income											38	37		39
Interest expense											(19)	(17)		(15)
Net income											19	20		24
Earnings attributable to noncontrolling interest											(19)	(20)		(24)
Earnings											0	0		$ 0
Cameron LNG JV [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	[5]	$ 983				$ 1,007					$ 983	$ 1,007
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	December 31, 2014 and 2013 have been adjusted for the retrospective adoption of ASU 2015-03.
[3]	As adjusted for the retrospective adoption of ASU 2015-03.
[4]	As adjusted for the retrospective adoption of ASU 2015-03, as we discuss in Note 2.
[5]	The carrying value of our equity method investment is $143 million and $94 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, primarily due to guarantees, which we discuss below, and interest capitalized on the investment, as the joint venture has not commenced its planned principal operations.

OTHER FINANCIAL DATA - NONCONTR

OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Mar. 31, 2013
Ownership Interests Held By Others [Line Items]
Amount of ownership interests held by others		$ 750	$ 754
Increase to Shareholders Equity for Sale of Subsidiary shares				$ 135
Ownership Interests Held By Others, Southern Gas Transmission [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		49.00%	49.00%
Amount of ownership interests held by others		$ 1	$ 1
Ownership Interests Held By Others, Bay Gas Storage Company [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		9.10%	9.10%
Amount of ownership interests held by others		$ 25	$ 23
Ownership Interests Held By Others, Liberty Gas Storage [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		23.20%	25.00%
Amount of ownership interests held by others		$ 14	$ 14
Ownership Interests Held By Others IEnova Member [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		18.90%	18.90%
Amount of ownership interests held by others		$ 468	$ 452
Proceeds from sale of noncontrolling interests, net of $25 million in offering costs				$ 574
Ownership Interests Held By Others, Tecsur [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		9.80%	9.80%
Amount of ownership interests held by others		$ 4	$ 4
Ownership Interests Held By Others, Luz Del Sur [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		16.40%	16.40%
Amount of ownership interests held by others		$ 164	$ 177
Ownership Interests Held By Others, Chilquinta Energia [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held By others, minimum	[1]	23.50%	23.60%
Percent of ownership held by others, maximum	[1]	43.40%	43.40%
Amount of ownership interests held by others	[1]	$ 21	$ 23
Ownership Interests Held By Others, Otay Mesa VIE [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others		100.00%	100.00%
Amount of ownership interests held by others		$ 53	$ 60
[1]	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

OTHER FINANCIAL DATA - NONCON62

OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS 2 (Details) - Luz Del Sur [Member] $ in Millions	Dec. 10, 2014USD ($)shares
Purchase of Noncontrolling Interests [Line Items]
Business Combination Step Acquisition Equity Interest In Acquiree Percentage	79.80%
Business Acquisition, Percentage of Voting Interests Acquired	83.60%
Business Acquisition Cash Paid Net Of Cash Acquired | $	$ 74
Business Acquistion, Additional Shares Purchased | shares	18,625,594

OTHER FINANCIAL DATA - OTHER IN

OTHER FINANCIAL DATA - OTHER INCOME (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity		$ 107	$ 106	$ 75
Investment gains	[1]	3	27	39
Electrical infrastructure relocation income	[2]	7	21	4
(Losses) gains on interest rate and foreign exchange instruments, net		(4)	(15)	17
Sale of other investments		11	2	0
Foreign currency losses		(7)	(15)	(3)
Regulatory interest, net	[3]	3	6	5
Sundry, net		6	5	3
Total		126	137	140
Parent Company [Member]
Component of Other Income, Nonoperating [Line Items]
Total		7	50	41
San Diego Gas and Electric Company [Member]
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity		37	37	39
Regulatory interest, net	[3]	3	6	4
Utility sundry, net		(4)	(3)	(3)
Total		36	40	40
Southern California Gas Company [Member]
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity		36	26	17
Regulatory interest, net	[3]	0	0	1
Utility sundry, net		(6)	(6)	(7)
Total		$ 30	$ 20	$ 11
[1]	Represents investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans.
[2]	Income at Luz del Sur associated with the relocation of electrical infrastructure.
[3]	Interest on regulatory balancing accounts.

OTHER FINANCIAL DATA - REGULATO

OTHER FINANCIAL DATA - REGULATORY MATTERS (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Regulatory Amortization Expense [Line Items]
Amortization Expense On Regulatory Assets		$ 62	$ 20	$ 28
San Diego Gas and Electric Company [Member]
Schedule Of Regulatory Amortization Expense [Line Items]
Amortization Expense On Regulatory Assets		60	18	26
Southern California Gas Company [Member]
Schedule Of Regulatory Amortization Expense [Line Items]
Amortization Expense On Regulatory Assets		2	2	$ 2
Fixed Price Contracts And Other Derivatives [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		99	76
Deferred Income Tax Charges [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		914	824
Deferred Income Tax Charges [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		330	195
Pension And Other Postretirement Benefit Obligations [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		180	171
Pension And Other Postretirement Benefit Obligations [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		629	613
Employee Benefit Costs [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		51	52
Asset Retirement Obligation Costs [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)	[1]	(1,629)	(1,557)
Asset Retirement Obligation Costs [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)	[1]	(1,145)	(1,167)
Loss on Reacquired Debt [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		$ 12	12
Loss on Reacquired Debt [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Remaining Amortization Period		12 years
Loss on Reacquired Debt [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Remaining Amortization Period		2 years
Loss on Reacquired Debt [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		$ 11	12
Loss on Reacquired Debt [Member] | Southern California Gas Company [Member] | Maximum [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Remaining Amortization Period		10 years
Loss on Reacquired Debt [Member] | Southern California Gas Company [Member] | Minimum [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Remaining Amortization Period		6 years
Environmental Restoration Costs [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		$ 16	27
Environmental Restoration Costs [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		22	22
Workers Compensation Costs [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		13	23
Wildfire Litigation Costs [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		362	373
Costs related to SONGS plant closure [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)	[2]	257	308
Legacy Meters [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)	[2]	$ 32	47
Remaining Amortization Period		2 years
Sunrise Powerlink Fire Mitigation [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		$ 117	116
Remaining Amortization Period		54 years
Other Utility Costs [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		$ 9	10
Net Regulatory Assets (Liabilities) S D G E [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		369	407
Net Regulatory Assets (Liabilities) So Cal Gas [Member] | Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		(89)	(250)
Net Regulatory Assets (Liabilities) Other [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		26	6
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		306	163
Sempra Natural Gas Segment [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		(7)	(17)
Sempra Mexico Segment [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net Regulatory Assets (Liabilities)		$ 33	$ 23
[1]	Represents cumulative amounts collected in rates for future nonlegal asset removal costs.
[2]	Regulatory assets earning a rate of return.

OTHER FINANCIAL DATA - REGULA65

OTHER FINANCIAL DATA - REGULATORY MATTERS 2 (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Regulatory Balancing Accounts [Line Items]
Overcollected		$ (1,200)	$ (1,730)
Undercollected		1,473	2,476
Net current receivable (payable)	[1]	273	746
Undercollected	[2]	215	173
Total net receviable (payable)		488	919
San Diego Gas and Electric Company [Member]
Regulatory Balancing Accounts [Line Items]
Overcollected		(756)	(1,195)
Undercollected		1,063	1,906
Net current receivable (payable)	[1]	307	711
Undercollected	[2]	0	0
Total net receviable (payable)		307	711
Southern California Gas Company [Member]
Regulatory Balancing Accounts [Line Items]
Overcollected		(444)	(535)
Undercollected		410	570
Net current receivable (payable)	[1]	(34)	35
Undercollected	[2]	215	173
Total net receviable (payable)		$ 181	$ 208
[1]	At December 31, 2015, the net receivable at SDG&E and the net payable at SoCalGas are shown separately on Sempra Energy's Consolidated Balance Sheet.
[2]	Long-term undercollected balance is included in Regulatory Assets (long-term) on Sempra Energy's Consolidated Balance Sheets and Other Regulatory Assets (long-term) on SoCalGas' Consolidated Balance Sheets.

OTHER FINANCIAL DATA - REGULA66

OTHER FINANCIAL DATA - REGULATORY MATTERS 3 (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Schedule Of Net Regulatory Assets (Liabilities), Balance Sheet Classification [Line Items]
Total Regulatory Assets, Current	[1]	$ 115	$ 59
Total Regulatory Assets, Noncurrent	[2]	3,058	2,858
Total Regulatory Liability, Current	[3]	(2)	(7)
Total Regulatory Liability, Noncurrent	[4]	(2,865)	(2,747)
Total Net Regulatory Assets (Liabilities)		306	163
Regulatory liabilities in Deferred Credits and Other		72	6
Excludes Long Term Undercollected Balancing Accounts in Regulatory Assets		215	173
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities), Balance Sheet Classification [Line Items]
Total Regulatory Assets, Current	[1]	107	54
Total Regulatory Assets, Noncurrent	[2]	1,891	1,910
Total Regulatory Liability, Current	[3]	0	0
Total Regulatory Liability, Noncurrent	[4]	(1,629)	(1,557)
Total Net Regulatory Assets (Liabilities)		369	407
Excludes Long Term Undercollected Balancing Accounts in Regulatory Assets		0	0
Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities), Balance Sheet Classification [Line Items]
Total Regulatory Assets, Current	[1]	7	5
Total Regulatory Assets, Noncurrent	[2]	1,120	916
Total Regulatory Liability, Current	[3]	0	0
Total Regulatory Liability, Noncurrent	[4]	(1,216)	(1,171)
Total Net Regulatory Assets (Liabilities)		(89)	(250)
Regulatory liabilities in Deferred Credits and Other		71	4
Excludes Long Term Undercollected Balancing Accounts in Regulatory Assets		$ 215	$ 173
[1]	At Sempra Energy Consolidated, included in Other Current Assets.
[2]	Excludes long-term undercollected balancing accounts at December 31, 2015 and 2014 of $215 million and $173 million, respectively, recorded at Sempra Energy Consolidated as Regulatory Assets (long-term) and at SoCalGas as Other Regulatory Assets (long-term).
[3]	Included in Other Current Liabilities.
[4]	At December 31, 2015 and 2014, $72 million and $6 million, respectively, at Sempra Energy Consolidated and $71 million and $4 million, respectively, at SoCalGas are included in Deferred Credits and Other.

OTHER FINANCIAL DATA - DIVIDEND

OTHER FINANCIAL DATA - DIVIDENDS AND LOANS (Details) $ in Millions	Dec. 31, 2015USD ($)
Restrictions On Dividends Loans And Advances [Line Items]
Undistributed Earnings of Equity Method Investments	$ 299
Utility Subsidiaries [Member]
Restrictions On Dividends Loans And Advances [Line Items]
Line Of Credit Facility, Maximum Ratio Of Indebtedness To Total Capitalization	65.00%
San Diego Gas and Electric Company [Member]
Restrictions On Dividends Loans And Advances [Line Items]
Amount Available For Dividend Distribution And Loans Without Prior Approval From Regulatory Agency	$ 600
FERC Requirement to maintain a common equity ratio at or Above	30.00%
Authorized Capital Structure, Common Equity	52.00%
Restricted Net Assets	$ 4,600
Southern California Gas Company [Member]
Restrictions On Dividends Loans And Advances [Line Items]
Amount Available For Dividend Distribution And Loans Without Prior Approval From Regulatory Agency	$ 447
Authorized Capital Structure, Common Equity	52.00%
Restricted Net Assets	$ 2,700

OTHER FINANCIAL DATA - DIVIDE68

OTHER FINANCIAL DATA - DIVIDENDS AND LOANS 2 (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Significant Restrictions of Subsidiaries [Line Items]
RestrictedNetAssetsOfConsolidatedSubsidiaries	$ 7,600
RestrictedNetAssetsOfUnconsolidatedSubsidiaries	3,800
Mobile Gas [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted Net Assets of Subsidiary	$ 116
Bay Gas [Member]
Significant Restrictions of Subsidiaries [Line Items]
Ownership Percentage of Subsidiary	91.00%
Luz Del Sur [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted Net Assets of Subsidiary	$ 35
Mexican Subsidiaries [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted Net Assets of Subsidiary	81
Gasoductos De Chihuahua [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted Net Assets of Subsidiary	11
Copper Mountain Solar 1 [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted Net Assets of Subsidiary	$ 9
Energia Sierra Juarez Wind Project [Member]
Significant Restrictions of Subsidiaries [Line Items]
Ownership Percentage of Equity Method Investee	50.00%
Restricted Net Assets of Subsidiary	$ 10
Sempra Renewables Segment [Member]
Significant Restrictions of Subsidiaries [Line Items]
Ownership Percentage of Equity Method Investee	50.00%
Restricted Net Assets of Subsidiary	$ 283
Cameron LNG JV [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted Net Assets of Subsidiary	$ 3,500

OTHER FINANCIAL DATA - FOREIGN

OTHER FINANCIAL DATA - FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2012
Foreign Currency Translation [Line Items]
Equity Method Investment, Functional Currency To Reporting Currency Adjustment	$ (7)	$ (15)	$ (3)

OTHER FINANCIAL DATA - REVENUES

OTHER FINANCIAL DATA - REVENUES DISCLOSURE (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues Disclosure [Abstract]
Natural gas revenues	[1]	$ 4,096	$ 4,549	$ 4,398
Electric revenues	[1]	5,158	5,209	4,911
Total Utilities Revenues at Sempra Energy Consolidated		$ 9,254	$ 9,758	$ 9,309
[1]	Excludes intercompany revenues.

OTHER FINANCIAL DATA - ACCUMULA

OTHER FINANCIAL DATA - ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	$ (497)	[2]	$ (228)		$ (376)
Other Comprehensive Income Before Reclassifications	[1]	(327)		(289)		(137)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	18		20		285
Net Other Comprehensive Income	[1]	(309)		(269)		148
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(806)		(497)	[2]	(228)
Accumulated Translation Adjustment [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(322)		(129)		(240)
Other Comprehensive Income Before Reclassifications	[1]	(260)		(193)		(159)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	0		0		270	[3]
Net Other Comprehensive Income	[1]	(260)		(193)		111
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(582)		(322)		(129)
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(90)		(26)		(35)
Other Comprehensive Income Before Reclassifications	[1]	(57)		(70)		2
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	10		6		7
Net Other Comprehensive Income	[1]	(47)		(64)		9
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(137)		(90)		(26)
Accumulated Defined Benefit Plans Adjustment Member
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(85)		(73)		(101)
Other Comprehensive Income Before Reclassifications	[1]	(10)		(26)		20
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	8		14		8
Net Other Comprehensive Income	[1]	(2)		(12)		28
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(87)		(85)		(73)
San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(12)	[4]	(9)		(11)
Other Comprehensive Income Before Reclassifications	[1]	3		(5)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	1		2		2
Net Other Comprehensive Income	[1]	4		(3)		2
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(8)		(12)	[4]	(9)
San Diego Gas and Electric Company [Member] | Accumulated Defined Benefit Plans Adjustment Member
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(12)		(9)		(11)
Other Comprehensive Income Before Reclassifications	[1]	3		(5)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	1		2		2
Net Other Comprehensive Income	[1]	4		(3)		2
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(8)		(12)		(9)
Southern California Gas Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(18)	[5]	(18)		(18)
Other Comprehensive Income Before Reclassifications	[1]	(1)		(3)		(2)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]			3		2
Net Other Comprehensive Income	[1]	(1)		0		0
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(19)		(18)	[5]	(18)
Southern California Gas Company [Member] | Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(14)		(14)		(15)
Other Comprehensive Income Before Reclassifications	[1]	0		0		0
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]			0		1
Net Other Comprehensive Income	[1]	0		0		1
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(14)		(14)		(14)
Southern California Gas Company [Member] | Accumulated Defined Benefit Plans Adjustment Member
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(4)		(4)		(3)
Other Comprehensive Income Before Reclassifications	[1]	(1)		(3)		(2)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]			3		1
Net Other Comprehensive Income	[1]	(1)		0		(1)
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	$ (5)		$ (4)		$ (4)
[1]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	Represents cumulative foreign currency translation adjustment related to the impairment of our Argentine investments in 2006, which is substantially offset by an accrued liability established at that time. We provide additional information about these investments in Note 4.
[4]	As adjusted for the retrospective adoption of ASU 2015-03.
[5]	As adjusted for the retrospective adoption of ASU 2015-03.

OTHER FINANCIAL DATA - ACCUMU72

OTHER FINANCIAL DATA - ACCUMULATED OTHER COMPREHENSIVE INCOME 2 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, net of income tax		$ 85	$ 38	$ 24
Interest expense		(561)	(554)	(559)
Equity Earnings (Losses) Recorded Before Tax		104	81	31
Revenues - energy related businesses		977	1,277	1,248
Total before income tax		1,704	1,524	1,430
Income tax (expense) benefit		(341)	(300)	(366)
Earnings attributable to noncontrolling interest		(98)	(100)	(79)
Grand total reclassifications for the period, net of tax		18	20	285
Parent Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, net of income tax		1,519	1,291	1,103
Interest expense		(261)	(235)	(239)
Income tax (expense) benefit		150	133	117
San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		(204)	(202)	(197)
Total before income tax		890	797	626
Income tax (expense) benefit		(284)	(270)	(191)
Earnings attributable to noncontrolling interest		(19)	(20)	(24)
Grand total reclassifications for the period, net of tax		1	2	2
Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		(84)	(69)	(69)
Total before income tax		558	472	481
Income tax (expense) benefit		(138)	(139)	(116)
Grand total reclassifications for the period, net of tax		0	3	2
Accumulated Defined Benefit Plans Adjustment Member
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Total before income tax		14	23	13
Income tax (expense) benefit		(6)	(9)	(5)
Total reclassifications for the period, net of tax		8	14	8
Accumulated Defined Benefit Plans Adjustment Member | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Total before income tax		1	3	3
Income tax (expense) benefit		0	(1)	(1)
Total reclassifications for the period, net of tax		1	2	2
Accumulated Defined Benefit Plans Adjustment Member | Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Total before income tax		0	5	1
Income tax (expense) benefit		0	(2)	0
Total reclassifications for the period, net of tax		0	3	1
Accumulated Defined Benefit Plans Adjustment Member | Net Actuarial Gain [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	[1]	0	0	3
Accumulated Defined Benefit Plans Adjustment Member | Net Actuarial Gain [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	[1]	0	0	2
Accumulated Defined Benefit Plans Adjustment Member | Amortization of Actuarial Loss [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	[1]	14	23	10
Accumulated Defined Benefit Plans Adjustment Member | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	[1]	1	3	1
Accumulated Defined Benefit Plans Adjustment Member | Amortization of Actuarial Loss [Member] | Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	[1]	0	5	1
Accumulated Translation Adjustment [Member] | Foreign Currency Translation Adjustments [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, net of income tax	[2]	0	0	270
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Total before income tax		29	20	20
Income tax (expense) benefit		(4)	(3)	(4)
Net of Income Tax		25	17	16
Earnings attributable to noncontrolling interest		(15)	(11)	(9)
Total reclassifications for the period, net of tax		10	6	7
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest		(12)	(11)	(9)
Total reclassifications for the period, net of tax		0	0	0
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Income tax (expense) benefit		(1)	(1)	0
Total reclassifications for the period, net of tax		0	0	1
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate and Foreign Exchange Instruments [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		18	21	11
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, net of income tax		13	0	0
Gain on sale of equity interests and assets		0	(3)	0
Equity Earnings (Losses) Recorded Before Tax		12	10	10
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		12	11	9
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member] | Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		1	1	1
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Revenues - energy related businesses		$ (14)	$ (8)	$ (1)
[1]	Amounts are included in the computation of net periodic benefit cost (see "Net Periodic Benefit Cost" in Note 7).
[2]	Represents cumulative foreign currency translation adjustment related to the impairment of our Argentine investments in 2006, which is substantially offset by an accrued liability established at that time. We provide additional information about these investments in Note 4.

OTHER FINANCIAL DATA - COLLECTI

OTHER FINANCIAL DATA - COLLECTION ALLOWANCES (Details) - Allowance for Doubtful Accounts [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance balance at January 1	$ 34	$ 29	$ 31
Provisions for uncollectible accounts	20	25	16
Write-offs of uncollectible accounts	(22)	(20)	(18)
Allowance balance at December 31	32	34	29
San Diego Gas and Electric Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance balance at January 1	7	5	6
Provisions for uncollectible accounts	7	7	4
Write-offs of uncollectible accounts	(5)	(5)	(5)
Allowance balance at December 31	9	7	5
Southern California Gas Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance balance at January 1	17	12	14
Provisions for uncollectible accounts	11	15	7
Write-offs of uncollectible accounts	(11)	(10)	(9)
Allowance balance at December 31	$ 17	$ 17	$ 12

OTHER FINANCIAL DATA - ASSET RE

OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligations [Line Items]
Asset Retirement Obligation, Balance as of January 1	[1]	$ 2,190	$ 2,152
Asset Retirement Obligation, Accretion Expense		92	97
Asset Retirement Obligation, Liabilities Incurred		1	4
Asset Retirement Obligation, Reclassification	[2]	0	(6)
Asset Retirement Obligation, Liabilities Settled	[3]	(80)	(29)
Asset Retirement Obligation, Net Revisions, Other	[4]	52	(28)
Asset Retirement Obligation, Balance as of December 31	[1]	2,255	2,190
San Diego Gas and Electric Company [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligation, Balance as of January 1	[1]	873	913
Asset Retirement Obligation, Accretion Expense		40	43
Asset Retirement Obligation, Liabilities Incurred		0	0
Asset Retirement Obligation, Reclassification	[2]	0	0
Asset Retirement Obligation, Liabilities Settled	[3]	(79)	(29)
Asset Retirement Obligation, Net Revisions, Other	[4]	(6)	(54)
Asset Retirement Obligation, Balance as of December 31	[1]	828	873
Southern California Gas Company [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligation, Balance as of January 1	[1]	1,276	1,199
Asset Retirement Obligation, Accretion Expense		49	52
Asset Retirement Obligation, Liabilities Incurred		0	0
Asset Retirement Obligation, Reclassification	[2]	0	0
Asset Retirement Obligation, Liabilities Settled		0	0
Asset Retirement Obligation, Net Revisions, Other	[4]	58	25
Asset Retirement Obligation, Balance as of December 31	[1]	$ 1,383	$ 1,276
[1]	The current portions of the obligations are included in Other Current Liabilities on the Consolidated Balance Sheets.
[2]	Reclassification to liability held for sale - asset retirement obligation which is included in Other Current Liabilities on the Consolidated Balance Sheet at December 31, 2014.
[3]	The increased payments at SDG&E are for the decommissioning of San Onofre Nuclear Generating Station Units 2 and 3, which we discuss in Note 13.
[4]	The increases at SoCalGas in 2015 and 2014 are related to revisions in estimated cash flows. The decrease in 2014 at SDG&E is due to revised estimates in an updated decommissioning cost study for the San Onofre Nuclear Generating Station, which we discuss in Note 13.

OTHER FINANCIAL DATA - OTHER 75

OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 477	$ 478
Finite-Lived Intangible Assets, Accumulated Amortization	(73)	(63)
Finite-Lived Intangible Assets, Net	404	415
Finite Lived Intangible Assets, Future Amortization Expense Per Year	$ 10
Finite Lived Intangible Assets, Storage Rights Amortization Period	46
Finite-Lived Intangible Assets Amortization Expense	$ 10	10	$ 10
Finite Lived Intangible Assets, Other Intangibles Amortization Period, Minimum	10
Finite Lived Intangible Assets, Development Rights Amortization Period	50
Storage Rights [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 138	138
Finite-Lived Intangible Assets, Accumulated Amortization	(22)	(19)
Development Rights [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	322	322
Finite-Lived Intangible Assets, Accumulated Amortization	(47)	(40)
Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	17	18
Finite-Lived Intangible Assets, Accumulated Amortization	$ (4)	$ (4)

OTHER FINANCIAL DATA - GOODWILL

OTHER FINANCIAL DATA - GOODWILL (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Goodwill [Line Items]
Goodwill, ending balance		$ 819	$ 931	[1]
Goodwill By Segment Sempra Energy Consolidated [Member]
Goodwill [Line Items]
Foreign currency translation	[2]	(112)	(93)
Goodwill, ending balance		819	931		$ 1,024
Goodwill By Segment, Sempra South American Utilities [Member]
Goodwill [Line Items]
Foreign currency translation	[2]	(112)	(93)
Goodwill, ending balance		722	834		927
Goodwill By Segment, Sempra Natural Gas [Member]
Goodwill [Line Items]
Foreign currency translation		0	0
Goodwill, ending balance		72	72		72
Goodwill By Segment, Sempra Mexico [Member]
Goodwill [Line Items]
Foreign currency translation		0	0
Goodwill, ending balance		$ 25	$ 25		$ 25
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	We record the offset of this fluctuation to other comprehensive income (loss).

OTHER FINANCIAL DATA - PROPERTY

OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 38,200		$ 35,407	[1]
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		10,161		9,505	[1]
Depreciation		1,178		1,126		$ 1,075
San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		16,458		15,478	[2]
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		4,202		3,860	[2]
Depreciation		544		512		468
Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		14,171		12,886	[1]
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		4,900		4,642	[1]
Depreciation		459		429		$ 381
Gas, Transmission and Distribution Equipment [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 1,642		$ 1,535
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		2.52%		2.72%		2.35%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		$ 690		$ 668
Gas, Transmission and Distribution Equipment [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[3]	$ 13,241		$ 12,098
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		3.83%		3.89%		3.70%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	[4]	$ 4,810		$ 4,555
Capital Leased Assets, Gross		30		27
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation		29		27
Electric Distribution [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 6,151		$ 5,795
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		3.79%		3.79%		3.36%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	[5]	$ 3,512		$ 3,192
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation		34		28
Electric Transmission [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 4,870	[6]	$ 4,525
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		2.62%		2.59%		2.58%
Utility Electric Generation Equipment [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[7]	$ 1,891		$ 1,862
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		3.89%		3.86%		3.76%
Capital Leased Assets, Gross		$ 258		$ 243
Other Utility Electric Equipment [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[8]	$ 981		$ 851
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		5.73%		7.09%		7.58%
Capital Leased Assets, Gross		$ 20		$ 19
Other Plant in Service [Member]
Property, Plant and Equipment [Line Items]
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	[9]	860		824
Other Plant in Service [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 110		$ 120
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service		3.95%		2.88%		1.56%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		$ 90		$ 87
Utility Construction In Progress [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		923	[6]	910
Utility Construction In Progress [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		820		668
Utility Electric Distribution Operations [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	1,362		1,434
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		$ 199		179
Property, Plant and Equipment Useful Life, Minimum		12
Property, Plant and Equipment Useful Life, Maximum		46
Property, Plant Equipment Weighted Average Useful Life		43
Land And Land Rights [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 289		290
Property, Plant and Equipment Useful Life, Minimum	[11]	26
Property, Plant and Equipment Useful Life, Maximum	[11]	55
Property, Plant Equipment Weighted Average Useful Life	[11]	40
Electric Generation Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 782		596
Property, Plant and Equipment Useful Life, Minimum		5
Property, Plant and Equipment Useful Life, Maximum		80
Property, Plant Equipment Weighted Average Useful Life		39
L N G Receipt Terminals [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 1,124		1,122
Property, Plant and Equipment Useful Life, Minimum		5
Property, Plant and Equipment Useful Life, Maximum		43
Property, Plant Equipment Weighted Average Useful Life		43
Pipelines And Storage Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 2,311		2,003
Property, Plant and Equipment Useful Life, Minimum		3
Property, Plant and Equipment Useful Life, Maximum		55
Property, Plant Equipment Weighted Average Useful Life		45
Other Machinery and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 233		213
Property, Plant and Equipment Useful Life, Minimum		1
Property, Plant and Equipment Useful Life, Maximum		50
Property, Plant Equipment Weighted Average Useful Life		15
Construction in Progress [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 1,022		1,053
Other Capitalized Property Plant and Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	$ 448		332
Property, Plant and Equipment Useful Life, Minimum		2
Property, Plant and Equipment Useful Life, Maximum		80
Property, Plant Equipment Weighted Average Useful Life		35
Electric Distribution Assets Of SWPL [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		$ 374
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		224
CWIP Assets Of SWPL [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		25
Plant, Pipeline And Other Distribution Assets Of Ecogas [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		142		150
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		36		37
Plant, Pipeline And Other Distribution Assets Of Mobile Gas [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		204		191
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		35		29
Plant, Pipeline And Other Distribution Assets Of Willmut Gas [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross		28		24
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		3		2
Total Other Operating Units And Parent [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Gross	[10]	7,571		7,043
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment		$ 1,059		$ 1,003
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	Includes capital lease assets of $30 million and $27 million at December 31, 2015 and 2014, respectively.
[4]	Includes accumulated depreciation for assets under capital lease of $29 million and $27 million at December 31, 2015 and 2014, respectively.
[5]	Includes accumulated depreciation for assets under capital lease of $34 million and $28 million at December 31, 2015 and 2014, respectively. Includes $224 million at December 31, 2015 related to SDG&E's 91-percent interest in the SWPL transmission line, jointly owned by SDG&E and other utilities.
[6]	At December 31, 2015, includes $374 million in electric transmission assets and $25 million in construction work in progress related to SDG&E's 91-percent interest in the Southwest Powerlink (SWPL) transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures.
[7]	Includes capital lease assets of $258 million and $243 million at December 31, 2015 and 2014, respectively, primarily related to variable interest entities of which SDG&E is not the primary beneficiary.
[8]	Includes capital lease assets of $20 million and $19 million at December 31, 2015 and 2014, respectively.
[9]	The December 31, 2015 balances include $36 million, $35 million and $3 million and the December 31, 2014 balances include $37 million, $29 million and $2 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively.
[10]	The December 31, 2015 balances include $142 million, $204 million and $28 million and the December 31, 2014 balances include $150 million, $191 million and $24 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively.
[11]	Estimated useful lives are for land rights.

OTHER FINANCIAL DATA - CAPITALI

OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	$ 26,000,000	$ 22,000,000	$ 22,000,000
AFUDC related to equity	107,000,000	106,000,000	75,000,000
Other capitalized financing costs	68,000,000	39,000,000	22,000,000
Total capitalized financing costs	201,000,000	167,000,000	119,000,000
Sempra Mexico Sonora Pipeline AFUDC equity	33,000,000	43,000,000	19,000,000
Sempra Natural Gas Misc AFUDC equity	1,000,000	0	0
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	14,000,000	15,000,000	16,000,000
AFUDC related to equity	37,000,000	37,000,000	39,000,000
Other capitalized financing costs	0	0	0
Total capitalized financing costs	51,000,000	52,000,000	55,000,000
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	12,000,000	7,000,000	6,000,000
AFUDC related to equity	36,000,000	26,000,000	17,000,000
Other capitalized financing costs	1,000,000	1,000,000	1,000,000
Total capitalized financing costs	$ 49,000,000	$ 34,000,000	$ 24,000,000

NEW ACCOUNTING STANDARDS (Detai

NEW ACCOUNTING STANDARDS (Details) $ in Millions	Dec. 31, 2014USD ($)
New Accounting Policy [Line Items]
Deferred Finance Costs Net	$ 81
San Diego Gas and Electric Company [Member]
New Accounting Policy [Line Items]
Deferred Finance Costs Net	36
Southern California Gas Company [Member]
New Accounting Policy [Line Items]
Deferred Finance Costs Net	$ 15

ACQUISTION AND DIVESTITURE AC80

ACQUISTION AND DIVESTITURE ACTIVITY (Details) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)BcfMtpa	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Jul. 31, 2015
Business Acquisition [Line Items]
Liabilities assumed		$ (2)	$ 0	$ (2)
Purchase of noncontrolling interests		$ 0	(74)	0
Transaction Costs Related To Sale			0	$ 6
Cameron LNG [Member]
Gas Volumes Capacity [Line Items]
LNG Vaporization Capability | Bcf		1.5
LNG Nameplate Capacity | Mtpa		13.9
LNG Expected Export Capacity | Mtpa		12
LNG Expected Export Capacity Per Day | Bcf		1.7
Energia Sierra Juarez Wind Project [Member]
Business Acquisition [Line Items]
Equity Method Investment Ownership Percentage		50.00%
California Solar Partnership [Member]
Business Acquisition [Line Items]
Equity Method Investment Ownership Percentage		50.00%
Business acquisition, Cash paid, net of cash acquired			$ 121
PEMEX [Member]
Business Acquisition [Line Items]
Ownership Percentage in consolidated entity	50.00%
IEnova [Member]
Business Acquisition [Line Items]
Ownership percentage before acquisition					50.00%
Acquired percentage interest in joint venture					100.00%
Ownership Percentage in consolidated entity	25.00%
Equity Method Investment Ownership Percentage					50.00%
Net debt not assumed by investee	$ 170
Business acquisition purchase price allocation equity method investment	$ 1,325
Black Oak Gety Wind [Member]
Business Acquisition [Line Items]
Ownership Percentage in consolidated entity		100.00%
Total Business Acquisition Costs		$ 8

ACQUISTION AND DIVESTITURE AC81

ACQUISTION AND DIVESTITURE ACTIVITY 2 (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2013
Deconsolidation of Business [Line Items]
Proceeds From Sale Net Transaction Costs	[1]			$ 152	$ 169
Cash				(10)	0
Restricted Cash				(5)	0
Other current assets				(23)	0
Property, plant and equipment, net				(1,557)	(727)
Other assets				(65)	(102)
Accounts payable and accrued expenses				188	0
Due to affiliate				39	0
Long-term debt, including current portion				251	443
Other liabilities				12	50
Accumulated other comprehensive income				(7)	0
Gain on sale of equity interests	[2]			(60)	(40)
Increase in equity method investments upon deconsolidation				(1,085)	(207)
Transaction costs				0	6
Equity Method Investment Ownership Percentage Of Minority Partner			25.00%			43.00%
Mesquite Solar 1 [Member]
Deconsolidation of Business [Line Items]
Property, plant and equipment, net					461
Long-term debt, including current portion					297
Gain on sale of equity interests					$ 36
Ownership percentage in equity method investee					50.00%
Gain on sale of assets, after tax					$ 22
Proceeds from sale					103
Copper Mountain Solar 2 [Member]
Deconsolidation of Business [Line Items]
Property, plant and equipment, net					266
Long-term debt, including current portion					146
Gain on sale of equity interests					$ 4
Ownership percentage in equity method investee					50.00%
Gain on sale of assets, after tax					$ 2
Proceeds from sale					72
Broken Bow 2 Wind [Member]
Deconsolidation of Business [Line Items]
Property, plant and equipment, net				151
Long-term debt, including current portion				72
Gain on sale of equity interests				$ 14
Ownership percentage in equity method investee				50.00%
Gain on sale of assets, after tax				$ 8
Proceeds from sale				58
Cameron LNG [Member]
Deconsolidation of Business [Line Items]
Property, plant and equipment, net				$ 1,000
Ownership percentage in equity method investee				50.20%
Equity Method Investment Ownership Percentage Of Minority Partner				49.80%
Energia Sierra Juarez Wind Project [Member]
Deconsolidation of Business [Line Items]
Cash				$ 2
Property, plant and equipment, net				137
Long-term debt, including current portion				82
Gain on sale of equity interests				$ 19
Ownership percentage in equity method investee				50.00%
Gain on sale of assets, after tax				$ 14
Proceeds from sale, net of cash sold				24
Gain attributable to remeasurement, after tax				7
Copper Mountain Solar 3 [Member]
Deconsolidation of Business [Line Items]
Cash				2
Property, plant and equipment, net				247
Long-term debt, including current portion				97
Gain on sale of equity interests				$ 27
Ownership percentage in equity method investee				50.00%
Gain on sale of assets, after tax				$ 16
Proceeds from sale, net of cash sold				$ 66
Mesquite Power [Member]
Deconsolidation of Business [Line Items]
Gain on sale of equity interests		$ 61			74
Gain on sale of assets, after tax		36			44
Proceeds from sale		$ 347			$ 371
Rosamond Solar [Member]
Deconsolidation of Business [Line Items]
Property, plant and equipment, net			$ 18
Gain on sale of equity interests			$ 8
Ownership percentage in equity method investee			100.00%
Gain on sale of assets, after tax			$ 5
Proceeds from sale			$ 26
[1]	Transaction costs were negligible in 2014 and $6 million in 2013.
[2]	Included in Gain on Sale of Equity Interests and Assets on our Consolidated Statements of Operations.

INVESTMENTS IN UNCONSOLIDATED82

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) - USD ($) $ in Millions		3 Months Ended		12 Months Ended
		Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Equity Method And Other Investments [Line Items]
Ownership percentage of operating partner in equity method investee				50.00%
Equity Earnings (Losses) Recorded Before Tax				$ 104	$ 81	$ 31
Ownership percentage of minority partner in equity method investee		43.00%		25.00%
Equity Method Investment, Realized Gain (Loss) on Disposal		$ (7)
Undistributed Earnings, Equity Method Investments				$ 299	187
Equity Method Investment, Cumulative Foreign Currency Translation Adjustments		270
Industrial Development Bonds at Mississippi Hub					77
Increase In Industrial Development Bonds				2
Aftertax loss on sale of Argentina		(4)	$ (7)
Proceeds From Sale Of Equity Method Investments		13
Accrued Liabilities, Argentina		$ 250
Equity Method Investment, Other Than Temporary Impairment			$ (10)
Other Equity Method Investments And Other Investments [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				2,905	2,848
Other Equity Method Investments [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				2,889	2,755
Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax	[1]			85	38	24
Equity Earnings (Losses) Recorded Before Tax				104	81	31
Sodigas Pampeana And Sodigas Sur [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax	[1]			0	0	(11)
Rockies Express [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Contributions to equity method investees				113
Equity Method And Other Investments	[2]			477	340
Equity Earnings (Losses) Recorded Before Tax				79	60	47
Equity Method Investment Basis Difference				$ 357	369
Ownership percentage in equity method investee				25.00%
R B S Sempra Commodities [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				$ 67	71
Equity Earnings (Losses) Recorded Before Tax				(4)	(2)	(3)
Auwahi Wind [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				44	45
Equity Earnings (Losses) Recorded Before Tax				4	4	4
Mesquite Solar 1 [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				86	86
Equity Earnings (Losses) Recorded Before Tax				16	14	1
Copper Mountain Solar 2 [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				32	61
Equity Earnings (Losses) Recorded Before Tax				7	3	0
Mehoopany Wind Farm [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				92	82
Equity Earnings (Losses) Recorded Before Tax				(1)	(1)	(2)
Eletrans [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	[3]			(12)	(8)
Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax	[1]			(4)	(4)	$ (4)
Ownership percentage in equity method investee						50.00%
Cedar Creek I I Wind Farm [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				75	82
Equity Earnings (Losses) Recorded Before Tax				(6)	(3)	$ (4)
Fowler Ridge I I Wind Farm [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				46	46
Equity Earnings (Losses) Recorded Before Tax				4	2	(3)
Flat Ridge 2 Wind Farm [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				275	284
Equity Earnings (Losses) Recorded Before Tax				(12)	(7)	(8)
Gasoductos De Chihuahua [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	[4]			489	409
Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax	[1]			83	39	39
Equity Method Investment Basis Difference				$ 65	65
Ownership percentage in equity method investee				50.00%
Energia Sierra Juarez Wind Project [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	[5]			$ 30	25
Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax	[1]			6	3	0
Equity Method Investment Basis Difference				$ 12	12
Ownership percentage in equity method investee				50.00%
California Solar Partnership [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				$ 120	125
Equity Earnings (Losses) Recorded Before Tax				6	6	0
Copper Mountain Solar 3 [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				44	56
Equity Earnings (Losses) Recorded Before Tax				8	2	0
Cameron LNG JV [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	[6]			983	1,007
Equity Earnings (Losses) Recorded Before Tax				5	2	0
Equity Method Investment Basis Difference				143	94
Other Equity Investments [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Earnings (Losses) Recorded Before Tax				0	1	(1)
Broken Bow 2 Wind [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments				41	44
Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax				(2)	0	$ 0
Other Investments [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	[7]			$ 16	$ 93
[1]	As the earnings (losses) from these investments are recorded net of income tax, they are presented below the income tax expense line, so as not to impact our effective income tax rate.
[2]	The carrying value of our equity method investment is $357 million and $369 million lower than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, due to an impairment charge recorded in 2012.
[3]	Includes losses on forward exchange contracts, which we discuss below.
[4]	The carrying value of our equity method investment is $65 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014 due to equity method goodwill.
[5]	The carrying value of our equity method investment is $12 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014 due to the remeasurement of our retained investment to fair value.
[6]	The carrying value of our equity method investment is $143 million and $94 million higher than the underlying equity in the net assets of the investee at December 31, 2015 and 2014, respectively, primarily due to guarantees, which we discuss below, and interest capitalized on the investment, as the joint venture has not commenced its planned principal operations.
[7]	Other includes Sempra Natural Gas’ $77 million investment in industrial development bonds at Mississippi Hub at December 31, 2014, which increased by $2 million and was fully redeemed in June 2015.

INVESTMENTS IN UNCONSOLIDATED83

INVESTMENTS IN UNCONSOLIDATED ENTITIES 2 (Details) $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
Investments In Unconsolidated Entities (Details) [Abstract]
Distributions from RBS Sempra Commodities LLP, operating activities	$ 50

INVESTMENTS IN UNCONSOLIDATED84

INVESTMENTS IN UNCONSOLIDATED ENTITIES 3 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Equity Method Investment Summarized Financial Information [Abstract]
Gross revenue		$ 1,533	$ 1,296	$ 1,734
Operating expense		(845)	(749)	(1,287)
Income from operations		688	547	447
Interest expense		(312)	(298)	(251)
Net income/earnings	[1]	440	291	$ 222
Current assets		750	865
Noncurrent assets		15,112	13,161
Current liabilities		859	1,131
Noncurrent liabilities		$ 7,862	$ 6,228
[1]	Except for Gasoductos de Chihuahua, Energía Sierra Juárez, Eletrans and the Argentine investments, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

INVESTMENTS IN UNCONSOLIDATED85

INVESTMENTS IN UNCONSOLIDATED ENTITIES 4 (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2015	Nov. 30, 2014	Oct. 01, 2014
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method Investments in Joint Ventures, capitalized interest	$ 68,000,000	$ 39,000,000	$ 22,000,000
Indirect economic and benefical and ownership interest prior to financial completion	37.65%
Other Long Term Debt, Due July 2030 [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Completion guarantees	50.20%
Debt instrument, maximum borrowing amount	$ 3,700,000,000
Cameron LNG [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Contributions to equity method investees	10,000,000
Equity Method Investments in Joint Ventures, capitalized interest	$ 49,000,000
Fair Value At Origin Guarantee Obligation Associated With Cash Flow Requirements						$ 82,000,000
Indirect economic and benefical and ownership interest after financial completion	10.00%
Cameron LNG [Member] | Other Long Term Debt, Due July 2030 [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Debt instrument face amount	$ 7,400,000,000
Derivative Notional Amount				$ 1,500,000,000	$ 3,700,000,000
Derivative Fixed Interest Rate				3.32%	3.19%
Percentage Of Debt Hedged By Interest Rate Derivatives	50.00%
Cameron LNG [Member] | Per Annum Over Libor Prior To Financial Completion [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Weighted average all in cost of Loans outstanding	1.59%
Cameron LNG [Member] | Per Annum Over Libor Following Financial Completion [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Weighted average all in cost of Loans outstanding	1.78%
Other Project Partners [Member] | Other Long Term Debt, Due July 2030 [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Completion guarantees	49.80%

INVESTMENTS IN UNCONSOLIDATED86

INVESTMENTS IN UNCONSOLIDATED ENTITIES 5 (Details) - Sempra Renewables Segment [Member] $ in Millions	Dec. 31, 2015USD ($)
Debt Service Operations [Member]
Long-term Purchase Commitment [Line Items]
Guarantee Obligations Maximum Exposure	$ 332
Guarantee Obligations Current Carrying Value	10
Purchased Power Contracts [Member]
Long-term Purchase Commitment [Line Items]
Guarantee Obligations Maximum Exposure	170
Guarantee Obligations Current Carrying Value	$ 2

DEBT AND CREDIT FACILITIES (Det

DEBT AND CREDIT FACILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Line Of Credit Facility, Sempra Energy Consolidated [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 4,200
Committed lines of credit, remaining borrowing capacity	$ 3,700
Weighted average interest rate on total short-term debt outstanding	1.09%	0.70%
Line Of Credit Facility, Sempra Energy [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 1,000
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, capacity for issuance of letters of credit	$ 400
Committed lines of credit, outstanding borrowings	0
Line of Credit Facility Maximum Borrowing Capacity Prior Limit	1,067
Line Of Credit Facility, Sempra Global [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 2,210
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 1,870
Outstanding commercial paper supported by committed lines of credit	335
Line of Credit Facility Maximum Borrowing Capacity Prior Limit	2,189
Line Of Credit Facility, S D G E [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 750
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 582
Outstanding commercial paper supported by committed lines of credit	$ 168
Weighted average interest rate on total short-term debt outstanding	1.01%	0.27%
Weighted average interest rate on commercial paper noncurrent		0.40%
Line Of Credit Facility, So Cal Gas [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 750
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 750
Outstanding commercial paper supported by committed lines of credit	0
Weighted average interest rate on total short-term debt outstanding		0.25%
Line Of Credit Facility, California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	1,000
Committed lines of credit, capacity for issuance of letters of credit	250
Line of Credit Facility Maximum Borrowing Capacity Prior Limit	877
Line Of Credit Facility, South American Utilities And Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	1,100
Committed lines of credit, remaining borrowing capacity	889
Line Of Credit Facility, IEnova Santander [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility Maximum Borrowing Capacity Prior Limit	200
Line Of Credit Facility, IEnova Sumitomo [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility Maximum Borrowing Capacity Prior Limit	100
Line Of Credit Facility Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	600
Committed lines of credit, remaining borrowing capacity	509
Committed lines of credit, outstanding borrowings	91
Retired Debt Instrument Face Amount	210
Line of Credit Facility Maximum Borrowing Capacity Prior Limit	400
Line Of Credit Facility Sempra South America [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 544
Line Of Credit Facility Peruvian Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility Maximum Ratio Of Debt To Equity	170.00%
Committed lines of credit, remaining borrowing capacity	$ 270
Committed lines of credit, outstanding borrowings	154
Bank Guarantee	10
Line Of Credit Facility Chilean Facility [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, remaining borrowing capacity	110
Committed lines of credit, outstanding borrowings	$ 0

DEBT AND CREDIT FACILITIES 2 (D

DEBT AND CREDIT FACILITIES 2 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Capital Lease Obligations		$ 387	$ 310
Current portion of long-term debt		(907)	(469)	[1]
Debt Instrument, Unamortized Discount		(107)	(102)
Long-term debt		13,134	12,086	[1]
Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		3,989	3,912	[2]
Long Term Debt And Capital Lease Obligations, Including Current Portion		4,548	4,695	[2]
Current portion of long-term debt		(50)	(365)	[2]
Debt Instrument, Unamortized Discount		(10)	(11)	[2]
Long-term debt		4,455	4,283	[2]
Unamortized Debt Issuance Expense		(33)	(36)	[2]
Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		2,500	1,900	[2]
Capital Lease Obligations		1	1	[2]
Long Term Debt And Capital Lease Obligations, Including Current Portion		2,514	1,914	[2]
Current portion of long-term debt		(9)	0	[2]
Debt Instrument, Unamortized Discount		(7)	(8)	[2]
Long-term debt		2,481	1,891	[2]
Unamortized Debt Issuance Expense		(17)	(15)	[2]
Debt Instrument, Other Sempra Energy [Member]
Debt Instrument [Line Items]
Long Term Debt And Capital Lease Obligations, Including Current Portion		7,086	6,048	[2]
Current portion of long-term debt		(848)	(104)	[2]
Debt Instrument, Unamortized Discount		(10)	(9)	[2]
Debt Instrument Unamortized Premium		5	7	[2]
Long-term debt		6,198	5,912	[2]
Unamortized Debt Issuance Expense		(35)	(30)	[2]
Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Build to suit lease	[3]	136	75	[2]
Debt Instrument, Luz Del Sur [Member]
Debt Instrument [Line Items]
Capital Lease Obligations		6	0	[2]
First Mortgage Bonds, Due November 2015 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.30%
First Mortgage Bonds Due March 2017 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 140	0	[2]
Debt Instrument, Interest Rate at Period End		0.68%
First Mortgage Bonds, Due April 2018 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.45%
First Mortgage Bonds Due June 2018 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	0	[2]
Debt Instrument, Interest Rate, Stated Percentage		1.55%
First Mortgage Bonds, Due July 2018 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 161	161	[2]
Debt Instrument, Interest Rate, Stated Percentage		1.65%
First Mortgage Bonds, Due August 2021 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 350	350	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.00%
First Mortgage Bonds, Due September 2021 [Member] | Debt Instrument, Mobile Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 20	20	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.14%
First Mortgage Bonds Due February 2022 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 232	0	[2]
Debt Instrument, Interest Rate, Stated Percentage		1.914%
First Mortgage Bonds Issuance Amount, Due February 2022 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250
First Mortgage Bonds, Due September 2023 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 450	450	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.60%
First Mortgage Bonds, Due September 2024 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.15%
First Mortgage Bonds Due June 2025 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 350	0	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.20%
First Mortgage Bonds, Due June 2026 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.00%
First Mortgage Bonds, Due December 2027 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 105	150	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum		5.00%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum		5.25%
First Mortgage Bonds, Due September 2031 [Member] | Debt Instrument, Mobile Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 42	42	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.00%
First Mortgage Bonds, Due January And February 2034 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 176	176	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.875%
First Mortgage Bonds, Due May 2035 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.35%
First Mortgage Bonds, Due November 2035 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.75%
First Mortgage Bonds, Due September 2037 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.125%
First Mortgage Bonds, Due May 2039 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 75	75	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.00%
First Mortgage Bonds, Due June 2039 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 300	300	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.00%
First Mortgage Bonds, Due May 2040 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.35%
First Mortgage Bonds, Due August 2040 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.50%
First Mortgage Bonds, Due November 2040 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 300	300	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.125%
First Mortgage Bonds, Due November 2041 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.95%
First Mortgage Bonds, Due April 2042 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.30%
First Mortgage Bonds, Due September 2042 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 350	350	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.75%
First Mortgage Bonds, Due March 2044 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 250	250	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.45%
Other Long-term Debt [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long Term Debt And Capital Lease Obligations, Including Current Portion		$ 559	783	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum		4.90%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum		5.50%
Retired Debt Instrument Face Amount		$ 169
Other Long-term Debt [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long Term Debt And Capital Lease Obligations, Including Current Portion		14	14	[2]
Commercial Paper [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		0	100	[2]
Other Long-term Debt, Due May 2016 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 8	8	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.75%
Other Long-term Debt, Due June 2016 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 750	750	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Other Long-term Debt, Due June 2018 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.15%
Other Long-term Debt, Due February 2019 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		9.80%
Other Long-term Debt, Due July 2021 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	39	[2],[4],[5]
Debt Instrument, Interest Rate, Stated Percentage		5.30%
Other Long-term Debt, Due December 2021 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	60	[2],[4],[5]
Debt Instrument, Interest Rate, Stated Percentage		5.50%
Other Long-term Debt, Due March 2023 [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	25	[2],[4],[5]
Debt Instrument, Interest Rate, Stated Percentage		4.90%
Other Long-term Debt, Due July 2024 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	77	[2],[4],[5]
Debt Instrument, Interest Rate, Stated Percentage		4.50%
Other Long-term Debt, Due January 2028 [Member] | Debt Instrument, So Cal Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 5	5	[2]
Debt Instrument, Interest Rate, Stated Percentage		5.67%
Other Long-term Debt, Due October 2039 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 750	750	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.00%
Industrial Development Bonds, Due August 2037 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	55	[2],[4],[5]
Debt Instrument, Interest Rate at Period End		0.05%
Capital Lease Obligations, Purchased Power Agreements [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Capital Lease Obligations		$ 243	233	[2]
Capital Lease Obligations, Other [Member] | Debt Instrument, S D G E [Member]
Debt Instrument [Line Items]
Capital Lease Obligations		1	1	[2]
Market Value Adjustment For Interest Rate Swap [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		(2)	0	[2]
Other Long-term Debt, Due October 2030 [Member] | Debt Instrument, Chilquinta Energia [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 170	192	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.25%
Other Long-term Debt, Due February 2018 [Member] | Debt Instrument, Sempra Mexico [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 75	88	[2]
Debt Instrument, Interest Rate, Stated Percentage		2.66%
Other Long-term Debt, Due February 2023 [Member] | Debt Instrument, Sempra Mexico [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 227	265	[2]
Debt Instrument, Interest Rate, Stated Percentage		6.30%
Debt Instrument, Interest Rate at Period End		4.12%
Other Long-term Debt, Due December 2023 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		4.05%
Other Long-term Debt, Due June 2024 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.55%
Other Long-term Debt, Due December 2018 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 5	5	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.10%
Other Long Term Debt, Variable Rate Notes Due June 2016 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate at Period End		4.77%
Debt Instrument, Amount At Variable Rates After Fixed To Floating Swap Effective January 2011		$ 300
Otay Mesa Energy Center Loan Payable Currently Through April 2019 [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 315	325
Debt Instrument, Interest Rate, Stated Percentage		5.2925%
Other Long-term Debt, Currently Through October 2016 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 19	19	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	[2]	2.87%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	[2]	3.51%
Other Long Term Debt, Payable Currently Through May 2022 [Member] | Debt Instrument, Luz Del Sur [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 8	10	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum		3.77%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum		4.61%
Other LongTerm Debt, Variable Rate Loan Payable Currently Through December 2028 [Member] | Debt Instrument, Sempra Renewables [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross	[4]	$ 91	97	[2]
Debt Instrument, Interest Rate at Period End	[2]	2.24%
Other LongTerm Debt, Fixed Rate Loan Payable Currently Through December 2028 [Member] | Debt Instrument, Sempra Renewables [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	[2]	4.54%
Debt Instrument, Amount At Fixed Rates After Floating to Fixed Swap	[2]	$ 69
Other Long Term Debt, Payable Currently Through December 2017 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 11	16	[2]
Debt Instrument, Interest Rate, Stated Percentage		8.45%
Other Long Term Debt Due April 2017 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 600	600	[2]
Debt Instrument, Interest Rate, Stated Percentage		2.30%
Other Long Term Debt, Due October 2022 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	500	[2]
Debt Instrument, Interest Rate, Stated Percentage		2.875%
Other Long-term Debt, Currently Through December 2018 [Member] | Debt Instrument, Luz Del Sur [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 136	91	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum		5.05%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum		6.70%
Other Long Term Debt, Payable Currently Through September 2029 [Member] | Debt Instrument, Luz Del Sur [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 292	345	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum		4.75%
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum		8.75%
Other Long Term Debt Variable Rate Loan Payable Currently Through August 2017 [Member] | Debt Instrument, Sempra Mexico [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 0	51	[2],[4],[5]
Debt Instrument, Interest Rate at Period End		1.28%
Other Long Term Debt Due November 2025 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 350	0	[2]
Debt Instrument, Interest Rate, Stated Percentage		3.75%
Other Long Term Debt Due November 2020 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 400	0	[2]
Debt Instrument, Interest Rate, Stated Percentage		2.85%
Other Long Term Debt Due March 2020 [Member] | Debt Instrument, Parent [Member]
Debt Instrument [Line Items]
Long-term Debt, Gross		$ 500	$ 0	[2]
Debt Instrument, Interest Rate, Stated Percentage		2.40%
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	We discuss this lease in Note 15.
[4]	Callable long-term debt not subject to make-whole provisions.
[5]	Early redemption in 2015.

DEBT AND CREDIT FACILITIES 3 (D

DEBT AND CREDIT FACILITIES 3 (Details) $ in Millions	Dec. 31, 2015USD ($)	[1]
Schedule Of Long Term Debt Maturities [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$ 897
Long-term Debt, Maturities, Repayments of Principal in Year Two	854
Long-term Debt, Maturities, Repayments of Principal in Year Three	1,369
Long-term Debt, Maturities, Repayments of Principal in Year Four	854
Long-term Debt, Maturities, Repayments of Principal in Year Five	968
Long-term Debt, Maturities, Repayments of Principal after Year Five	8,821
Long-term Debt Maturities, Total Repayments Of Principal	13,763
Schedule Of Long-term Debt Maturities, S D G E [Member]
Schedule Of Long Term Debt Maturities [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	46
Long-term Debt, Maturities, Repayments of Principal in Year Two	186
Long-term Debt, Maturities, Repayments of Principal in Year Three	207
Long-term Debt, Maturities, Repayments of Principal in Year Four	320
Long-term Debt, Maturities, Repayments of Principal in Year Five	36
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,509
Long-term Debt Maturities, Total Repayments Of Principal	4,304
Schedule Of Long-term Debt Maturities, So Cal Gas [Member]
Schedule Of Long Term Debt Maturities [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	8
Long-term Debt, Maturities, Repayments of Principal in Year Two	0
Long-term Debt, Maturities, Repayments of Principal in Year Three	500
Long-term Debt, Maturities, Repayments of Principal in Year Four	0
Long-term Debt, Maturities, Repayments of Principal in Year Five	0
Long-term Debt, Maturities, Repayments of Principal after Year Five	2,005
Long-term Debt Maturities, Total Repayments Of Principal	2,513
Schedule Of Long-term Debt Maturities, Other Sempra Energy [Member]
Schedule Of Long Term Debt Maturities [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	843
Long-term Debt, Maturities, Repayments of Principal in Year Two	668
Long-term Debt, Maturities, Repayments of Principal in Year Three	662
Long-term Debt, Maturities, Repayments of Principal in Year Four	534
Long-term Debt, Maturities, Repayments of Principal in Year Five	932
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,307
Long-term Debt Maturities, Total Repayments Of Principal	$ 6,946
[1]	Excludes capital lease obligations, build-to-suit lease and market value adjustments for interest rate swaps.

DEBT AND CREDIT FACILITIES 4 (D

DEBT AND CREDIT FACILITIES 4 (Details) $ in Millions	Dec. 31, 2015USD ($)
Unsecured Debt [Line Items]
Long-term Debt, Unsecured	$ 6,800
San Diego Gas and Electric Company [Member]
Unsecured Debt [Line Items]
Long-term Debt, Unsecured	0
Southern California Gas Company [Member]
Unsecured Debt [Line Items]
Long-term Debt, Unsecured	$ 13

DEBT AND CREDIT FACILITIES 5 (D

DEBT AND CREDIT FACILITIES 5 (Details) $ in Millions	Dec. 31, 2015USD ($)
Schedule Of Callable Long-term Debt [Line Items]
Callable Long-term Debt	$ 810
Callable Long term Debt Subject To Make Whole Provisions	12,638
Schedule Of Callable Long-term Debt, S D G E [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable Long-term Debt	517
Callable Long term Debt Subject To Make Whole Provisions	3,472
Schedule Of Callable Long-term Debt, So Cal Gas [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable Long-term Debt	8
Callable Long term Debt Subject To Make Whole Provisions	2,505
Schedule Of Callable Long-term Debt, Other Sempra Energy [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable Long-term Debt	285
Callable Long term Debt Subject To Make Whole Provisions	6,661
Schedule Of Callable Long-Term Debt, Otay Mesa Energy Center [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable Long-term Debt	$ 315

DEBT AND CREDIT FACILITIES 6 (D

DEBT AND CREDIT FACILITIES 6 (Details) $ in Millions	Dec. 31, 2015USD ($)
San Diego Gas and Electric Company [Member]
First Mortgage Bonds [Line Items]
First Mortgage Bonds, Amount Available For Future Issuance	$ 4,100
Southern California Gas Company [Member]
First Mortgage Bonds [Line Items]
First Mortgage Bonds, Amount Available For Future Issuance	$ 800

DEBT AND CREDIT FACILITIES 7 (D

DEBT AND CREDIT FACILITIES 7 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Industrial Development Bonds [Line Items]
Redemption of industrial development bonds	$ 79	$ 0	$ 0
Maximum Long-term Debt Available, Industrial Development Bonds	265
Total Payments To Acquire Industrial Development Bonds	259
Industrial Development Bonds Redeemed 2011 [Member]
Industrial Development Bonds [Line Items]
Redemption of industrial development bonds	$ 180
Industrial Development Bonds Redeemed 2015 [Member]
Industrial Development Bonds [Line Items]
Industrial Development Bonds, Interest Rate, Stated Percentage	4.50%
Redemption of industrial development bonds	$ 79
Industrial Development Bonds Bay Gas [Member]
Industrial Development Bonds [Line Items]
Redemption of industrial development bonds	$ 55

DEBT AND CREDIT FACILITIES 8 (D

DEBT AND CREDIT FACILITIES 8 (Details) - Debt Instrument, Luz Del Sur [Member] $ in Millions	Dec. 31, 2015USD ($)
Other Long Term Debt Due November 14 2017 [Member]
Debt Instrument Segment [Line Items]
Long-Term Debt, Luz Del Sur	$ 15
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	6.55%
Other Long Term Debt Due February 27 2018 [Member]
Debt Instrument Segment [Line Items]
Long-Term Debt, Luz Del Sur	$ 9
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	6.70%
Other Long Term Debt Due May 18 2018 [Member]
Debt Instrument Segment [Line Items]
Long-Term Debt, Luz Del Sur	$ 13
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	5.18%
Other Long Term Debt Due June 1 2018 [Member]
Debt Instrument Segment [Line Items]
Long-Term Debt, Luz Del Sur	$ 22
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	5.18%
Other Long Term Debt Due September 3 2026 [Member]
Debt Instrument Segment [Line Items]
Long-Term Debt, Luz Del Sur	$ 25
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	8.75%

INCOME TAXES (Details)

INCOME TAXES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
U.S. federal statutory income tax rate	35.00%	35.00%	35.00%
Utility depreciation	5.00%	5.00%	4.00%
U.S. tax on repatriation of foreign earnings	1.00%	2.00%	0.00%
Income tax restructuring related to IEnova stock offerings	0.00%	0.00%	4.00%
State income taxes, net of federal income tax benefit	1.00%	0.00%	1.00%
Utility repair allowance	(5.00%)	(5.00%)	(5.00%)
Tax credits	(4.00%)	(4.00%)	(3.00%)
Self-developed software expenditures	(3.00%)	(3.00%)	(3.00%)
Resolution of prior years' income tax items	(3.00%)	(1.00%)	(3.00%)
Non-U.S. earnings taxed at lower statutory income tax rates	(2.00%)	(2.00%)	(3.00%)
Allowance for equity funds used during construction	(2.00%)	(2.00%)	(1.00%)
Foreign exchange and inflation effects	(2.00%)	(2.00%)	0.00%
International tax reform	0.00%	(1.00%)	1.00%
Other, net	(1.00%)	(2.00%)	(1.00%)
Effective income tax rate	20.00%	20.00%	26.00%
Income (Loss) from Continuing Operations before Income Taxes, Domestic	$ 1,189	$ 1,014	$ 941
Income (Loss) from Continuing Operations before Income Taxes, Foreign	515	510	489
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	$ 1,704	1,524	1,430
Income tax expense related to corporate reorganization			$ 63
Income Tax Expense Louisiana valuation allowance release		25
SONGS tax regulatory asset write-off		$ 17
San Diego Gas and Electric Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
U.S. federal statutory income tax rate	35.00%	35.00%	35.00%
Utility depreciation	4.00%	4.00%	5.00%
SONGS tax regulatory asset write-off	0.00%	2.00%	0.00%
State income taxes, net of federal income tax benefit	5.00%	5.00%	3.00%
Utility repair allowance	(4.00%)	(4.00%)	(4.00%)
Self-developed software expenditures	(3.00%)	(3.00%)	(3.00%)
Resolution of prior years' income tax items	(2.00%)	(2.00%)	(1.00%)
Allowance for equity funds used during construction	(2.00%)	(2.00%)	(2.00%)
Variable interest entities	(1.00%)	(1.00%)	(1.00%)
Other, net	0.00%	0.00%	(1.00%)
Effective income tax rate	32.00%	34.00%	31.00%
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	$ 890	$ 797	$ 626
Southern California Gas Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
U.S. federal statutory income tax rate	35.00%	35.00%	35.00%
Utility depreciation	8.00%	8.00%	6.00%
State income taxes, net of federal income tax benefit	4.00%	4.00%	4.00%
Utility repair allowance	(10.00%)	(9.00%)	(9.00%)
Self-developed software expenditures	(6.00%)	(5.00%)	(6.00%)
Resolution of prior years' income tax items	(3.00%)	(2.00%)	(5.00%)
Allowance for equity funds used during construction	(2.00%)	(2.00%)	(1.00%)
Other, net	(1.00%)	0.00%	0.00%
Effective income tax rate	25.00%	29.00%	24.00%
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	$ 558	$ 472	$ 481

INCOME TAXES 2 (Details)

INCOME TAXES 2 (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Assets And Liabilities [Line Items]
Deferred Tax Liabilities, Property, Plant and Equipment		$ 4,487	$ 4,074
Deferred Tax Liabilities, Regulatory Balancing Accounts		745	915
Deferred Tax Liabilities, Property Taxes		61	57
Deferred Tax Liabilities, Investment in Noncontrolled Affiliates	[1]	796	650
Deferred Tax Liabilities, Other		100	53
Deferred Tax Liabilities		6,189	5,749
Deferred Tax Assets, Tax Credit Carryforwards, General Business		381	276
Deferred Tax Assets, Net Operating Loss		1,856	1,908
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other		252	244
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits		446	433
Deferred Tax Assets, Other		179	156
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Loss Reserves		72	73
Deferred Tax Assets, Gross		3,186	3,090
Deferred Tax Assets, Valuation Allowance		34	39
Deferred Tax Assets, Net		3,152	3,051
Net deferred income tax liability	[2]	3,037	2,698
Sundry, net noncurrent asset		120
San Diego Gas and Electric Company [Member]
Deferred Tax Assets And Liabilities [Line Items]
Deferred Tax Liabilities, Property, Plant and Equipment		2,392	2,181
Deferred Tax Liabilities, Regulatory Balancing Accounts		234	441
Deferred Tax Liabilities, Property Taxes		42	39
Deferred Tax Liabilities, Other		5	5
Deferred Tax Liabilities		2,673	2,666
Deferred Tax Assets, Net Operating Loss		0	297
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other		11	8
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits		90	85
Deferred Tax Assets, Other		18	36
Deferred Tax Assets, State Income Taxes		46	27
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Loss Reserves		36	39
Deferred Tax Assets, Net		201	492
Net deferred income tax liability		2,472	2,174
Southern California Gas Company [Member]
Deferred Tax Assets And Liabilities [Line Items]
Deferred Tax Liabilities, Property, Plant and Equipment		1,473	1,194
Deferred Tax Liabilities, Regulatory Balancing Accounts		515	481
Deferred Tax Liabilities, Property Taxes		20	18
Deferred Tax Liabilities, Other		5	10
Deferred Tax Liabilities		2,013	1,703
Deferred Tax Assets, Net Operating Loss		110	64
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other		42	40
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits		268	261
Deferred Tax Assets, Other		28	39
Deferred Tax Assets, State Income Taxes		13	11
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Loss Reserves		20	23
Deferred Tax Assets, Net		481	438
Net deferred income tax liability		$ 1,532	$ 1,265
[1]	Amounts primarily represent differences in financial and tax bases of depreciable and amortizable assets within our partnerships.
[2]	At December 31, 2015, the net deferred income tax liability includes $120 million recorded as a noncurrent asset in Sundry on the Consolidated Balance Sheet.

INCOME TAXES 3 (Details)

INCOME TAXES 3 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Expense (Benefit), Continuing Operations [Line Items]
Current Federal Tax Expense (Benefit)	$ 3	$ (10)	$ (70)
Current State and Local Tax Expense (Benefit)	(24)	(7)	(5)
Current Foreign Tax Expense (Benefit)	123	171	107
Current Income Tax Expense (Benefit)	102	154	32
Deferred Federal Income Tax Expense (Benefit)	242	237	275
Deferred State and Local Income Tax Expense (Benefit)	34	4	15
Deferred Foreign Income Tax Expense (Benefit)	(32)	(91)	48
Deferred Income Tax Expense (Benefit)	244	150	338
Investment Tax Credit	(5)	(4)	(4)
Income tax expense (benefit)	341	300	366
Parent Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Line Items]
Income tax expense (benefit)	(150)	(133)	(117)
San Diego Gas and Electric Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Line Items]
Current Federal Tax Expense (Benefit)	12	(5)	9
Current State and Local Tax Expense (Benefit)	77	52	11
Current Income Tax Expense (Benefit)	89	47	20
Deferred Federal Income Tax Expense (Benefit)	233	220	149
Deferred State and Local Income Tax Expense (Benefit)	(35)	5	24
Deferred Income Tax Expense (Benefit)	198	225	173
Investment Tax Credit	(3)	(2)	(2)
Income tax expense (benefit)	284	270	191
Southern California Gas Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Line Items]
Current Federal Tax Expense (Benefit)	(1)	2	4
Current State and Local Tax Expense (Benefit)	12	7	(5)
Current Income Tax Expense (Benefit)	11	9	(1)
Deferred Federal Income Tax Expense (Benefit)	122	117	103
Deferred State and Local Income Tax Expense (Benefit)	7	15	16
Deferred Income Tax Expense (Benefit)	129	132	119
Investment Tax Credit	(2)	(2)	(2)
Income tax expense (benefit)	$ 138	$ 139	$ 116

INCOME TAXES 4 (Details)

INCOME TAXES 4 (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Valuation Allowance [Line Items]
Deferred Tax Assets, Valuation Allowance	$ 34	$ 39
Deferred Tax Asset Valuation Allowance, Foreign Net Operating Losses [Member]
Valuation Allowance [Line Items]
Deferred Tax Assets, Valuation Allowance	6	8
Deferred Tax Asset Valuation Allowance, Federal State And Local Net Operating Losses [Member]
Valuation Allowance [Line Items]
Deferred Tax Assets, Valuation Allowance	$ 28	$ 31

INCOME TAXES 5 (Details)

INCOME TAXES 5 (Details) $ in Millions	Dec. 31, 2015USD ($)
Unused Domestic NOL Expiring 2032 [Member] | Southern California Gas Company [Member]
Operating Loss Carryforwards [Line Items]
Net Operating Loss Carryforwards	$ 363
Net Operating Loss Carryforward Foreign [Member]
Operating Loss Carryforwards [Line Items]
Net Operating Loss Carryforwards	468
Net Operating Loss Carryforward NOLs Unused US State NOLs Expiring Between 2016 And 2035 [Member]
Operating Loss Carryforwards [Line Items]
Net Operating Loss Carryforwards	2,800
Net Operating Loss Unused US State NOLs From Excess Tax Deductions Related To Employee Stock Expense [Member]
Operating Loss Carryforwards [Line Items]
Net Operating Loss Carryforwards	222
Net Operating Loss Unused U.S. Federal Consolidated NOLs From Excess Tax Deductions Related To Employee Stock Expense [Member]
Operating Loss Carryforwards [Line Items]
Net Operating Loss Carryforwards	265
Unused NOL Expiring, Starting In 2031 [Member]
Operating Loss Carryforwards [Line Items]
Net Operating Loss Carryforwards	4,900
State Tax Credits Expiring Starting in 2016 [Member]
Operating Loss Carryforwards [Line Items]
Unused State General Business Tax Credits	44
Federal Tax Credits Expiring Starting in 2031 [Member] | Southern California Gas Company [Member]
Operating Loss Carryforwards [Line Items]
Unused Federal General Business Tax Credits	7
Federal Tax Credits Expiring Starting in 2032 [Member]
Operating Loss Carryforwards [Line Items]
Unused Federal General Business Tax Credits	279
Unused Foreign Tax Credits Starting in 2024 [Member]
Operating Loss Carryforwards [Line Items]
Unused Foreign Tax Credits	$ 58

INCOME TAXES 6 (Details)

INCOME TAXES 6 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Unrecognized Tax Benefits [Line Items]
Unrecognized Tax Benefits, Balance as of January 1	$ 117	$ 90	$ 82
Unrecognized Tax Benefits, Increases Resulting from Prior Period Tax Positions	10	37	26
Unrecognized Tax Benefits, Decreases Resulting from Prior Period Tax Positions	0	0	(24)
Unrecognized Tax Benefits, Increases Resulting from Current Period Tax Positions	8	5	7
Unrecognized Tax Benefits, Decreases Resulting from Settlements with Taxing Authorities	(48)	(15)	(1)
Unrecognized Tax Benefits, Balance as of December 31	87	117	90
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(83)	(114)	(86)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	32	21	19
Unrecognized Tax Benefits, Interest on Income Taxes Expense	(2)	(4)	1
Unrecognized Tax Benefits, Income Tax Penalties Expense	0	(3)	0
Unrecognized Tax Benefits Interest On Income Taxes Accrued	1	0
Unrecognized Tax Benefits Income Tax Penalties Accrued	0	0
Unrecognized Deferred Tax Liability Related to basis difference and consisting of cumulative undistributed earnings	3,900
San Diego Gas and Electric Company [Member]
Unrecognized Tax Benefits [Line Items]
Unrecognized Tax Benefits, Balance as of January 1	14	17	12
Unrecognized Tax Benefits, Increases Resulting from Prior Period Tax Positions	5	2	7
Unrecognized Tax Benefits, Decreases Resulting from Prior Period Tax Positions	0	0	(4)
Unrecognized Tax Benefits, Increases Resulting from Current Period Tax Positions	2	0	2
Unrecognized Tax Benefits, Decreases Resulting from Settlements with Taxing Authorities	(1)	(5)	0
Unrecognized Tax Benefits, Balance as of December 31	20	14	17
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(16)	(11)	(14)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	11	6	11
Unrecognized Tax Benefits, Interest on Income Taxes Expense	0	(1)	0
Unrecognized Tax Benefits Interest On Income Taxes Accrued	0	0
Southern California Gas Company [Member]
Unrecognized Tax Benefits [Line Items]
Unrecognized Tax Benefits, Balance as of January 1	19	13	5
Unrecognized Tax Benefits, Increases Resulting from Prior Period Tax Positions	2	2	4
Unrecognized Tax Benefits, Increases Resulting from Current Period Tax Positions	6	4	5
Unrecognized Tax Benefits, Decreases Resulting from Settlements with Taxing Authorities	0	0	(1)
Unrecognized Tax Benefits, Balance as of December 31	27	19	13
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(27)	(19)	(13)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	21	15	8
Unrecognized Tax Benefits, Interest on Income Taxes Expense	0	0	$ (1)
Unrecognized Tax Benefits Interest On Income Taxes Accrued	$ 0	$ 0

INCOME TAXES 7 (Details)

INCOME TAXES 7 (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	$ (34)	$ (61)	$ (70)
San Diego Gas and Electric Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	(9)	(9)	(14)
Expiration Of Statute Of Limitations [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	(2)	0	(7)
Expiration Of Statute Of Limitations [Member] | San Diego Gas and Electric Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	(1)	0	0
Potential Resolution Of Audit Issues [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	(32)	(61)	(63)
Potential Resolution Of Audit Issues [Member] | San Diego Gas and Electric Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	(8)	(9)	(14)
Potential Resolution Of Audit Issues [Member] | Southern California Gas Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	$ (22)	$ (15)	$ (11)

EMPLOYEE BENEFIT PLANS (Details

EMPLOYEE BENEFIT PLANS (Details) - USD ($)		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Employee Benefit Plans (Details) [Abstract]
Dedicated Assets Supporting Supplemental Benefit Plans			$ 464,000,000	$ 512,000,000
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(1,152,000,000)	(1,064,000,000)	[1]
Defined Benefit Plan, Amounts that Will be Amortized from Accumulated Other Comprehensive Income (Loss) in Next Fiscal Year [Abstract]
Defined Benefit Plan, Amortization of Net Gains (Losses)			8,000,000
Defined Benefit Plan Future Amortization Of Prior Service Cost (Credit)			1,000,000
San Diego Gas and Electric Company [Member]
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(212,000,000)	(216,000,000)	[2]
Defined Benefit Plan, Amounts that Will be Amortized from Accumulated Other Comprehensive Income (Loss) in Next Fiscal Year [Abstract]
Defined Benefit Plan, Amortization of Net Gains (Losses)			1,000,000
Defined Benefit Plan Future Amortization Of Prior Service Cost (Credit)			0
Southern California Gas Company [Member]
Defined Benefit Plan, Amounts that Will be Amortized from Accumulated Other Comprehensive Income (Loss) in Next Fiscal Year [Abstract]
Defined Benefit Plan, Amortization of Net Gains (Losses)			0
Defined Benefit Plan Future Amortization Of Prior Service Cost (Credit)			0
Pension Benefits
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation			5,000,000	4,000,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance		$ 3,649,000,000	3,839,000,000	3,459,000,000
Defined Benefit Plan, Service Cost			114,000,000	101,000,000		$ 109,000,000
Defined Benefit Plan, Interest Cost			154,000,000	161,000,000		148,000,000
Defined Benefit Plan, Contributions By Plan Participants			0	0
Defined Benefit Plan, Actuarial Loss (Gain)			(180,000,000)	441,000,000
Defined Benefit Plan, Plan Amendments			5,000,000	4,000,000
Defined Benefit Plan, Special Termination Benefits			0	0
Defined Benefit Plan, Settlements, Benefit Obligation			(10,000,000)	(110,000,000)
Defined Benefit Plan, Benefits Paid			(273,000,000)	(217,000,000)
Defined Benefit Plan, Benefit Obligation, Ending Balance			3,649,000,000	3,839,000,000		3,459,000,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance		2,484,000,000	2,807,000,000	2,789,000,000
Defined Benefit Plan, Actual Return on Plan Assets			(73,000,000)	217,000,000
Defined Benefit Plan, Contributions by Employer			33,000,000	128,000,000
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets			0	0
Defined Benefit Plan, Benefits Paid, Plan Assets			(273,000,000)	(217,000,000)
Defined Benefit Plan, Settlements, Plan Assets			(10,000,000)	(110,000,000)
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance			2,484,000,000	2,807,000,000		2,789,000,000
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan			(1,165,000,000)	(1,032,000,000)
Defined Benefit Plan, Amounts Recognized in Balance Sheet			(1,165,000,000)	(1,032,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Other Postretirement Defined Benefit Plans, Asset Noncurrent			0	0
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities			(43,000,000)	(33,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(1,122,000,000)	(999,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax			(84,000,000)	(82,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax			(5,000,000)	(2,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax			(89,000,000)	(84,000,000)
Defined Benefit Plan, Accumulated Benefit Obligation			3,397,000,000	3,555,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets [Abstract]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation			3,410,000,000	3,592,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation			3,183,000,000	3,343,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets			2,484,000,000	2,807,000,000
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Service Cost			114,000,000	101,000,000		109,000,000
Defined Benefit Plan, Interest Cost			154,000,000	161,000,000		148,000,000
Defined Benefit Plan, Expected Return on Plan Assets			(173,000,000)	(171,000,000)		(162,000,000)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			11,000,000	11,000,000		4,000,000
Defined Benefit Plan, Amortization of (Gains) Losses			38,000,000	18,000,000		54,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements			4,000,000	31,000,000		2,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits			0	0		0
Defined Benefit Plan, Regulatory Adjustment			(110,000,000)	(31,000,000)		(20,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost, Total			38,000,000	120,000,000		135,000,000
Other Comprehensive Income, Defined Benefit Plan's Adjustment, before Tax, [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			17,000,000	38,000,000		(30,000,000)
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax			4,000,000	4,000,000		1,000,000
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax			(14,000,000)	(23,000,000)		(9,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total			7,000,000	19,000,000		(38,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total			$ 45,000,000	$ 139,000,000		$ 97,000,000
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate			4.46%	4.09%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate			4.09%	4.85%		4.04%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets			7.00%	7.00%		7.00%
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year		126,000,000
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months			$ 325,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Two			310,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Three			311,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Four			298,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Five			291,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter			$ 1,295,000,000
Pension Benefits | Maximum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			10.00%	10.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			10.00%	10.00%		9.50%
Pension Benefits | Minimum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			2.00%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			2.00%	3.50%		3.50%
Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance		965,000,000	$ 1,011,000,000	$ 939,000,000
Defined Benefit Plan, Service Cost			29,000,000	30,000,000		$ 32,000,000
Defined Benefit Plan, Interest Cost			39,000,000	43,000,000		41,000,000
Defined Benefit Plan, Contributions By Plan Participants			0	0
Defined Benefit Plan, Actuarial Loss (Gain)			(52,000,000)	101,000,000
Defined Benefit Plan, Transfers, Benefit Obligation			(6,000,000)	10,000,000
Defined Benefit Plan, Special Termination Benefits			0	0
Defined Benefit Plan, Settlements, Benefit Obligation			0	(87,000,000)
Defined Benefit Plan, Benefits Paid			(56,000,000)	(25,000,000)
Defined Benefit Plan, Benefit Obligation, Ending Balance			965,000,000	1,011,000,000		939,000,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance		752,000,000	828,000,000	819,000,000
Defined Benefit Plan, Actual Return on Plan Assets			(24,000,000)	63,000,000
Defined Benefit Plan, Contributions by Employer			2,000,000	56,000,000
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets			0	0
Defined Benefit Plan, Benefits Paid, Plan Assets			(56,000,000)	(25,000,000)
Defined Benefit Plan, Transfers, Plan Assets			2,000,000	2,000,000
Defined Benefit Plan, Settlements, Plan Assets			0	(87,000,000)
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance			752,000,000	828,000,000		819,000,000
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan			(213,000,000)	(183,000,000)
Defined Benefit Plan, Amounts Recognized in Balance Sheet			(213,000,000)	(183,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities			(5,000,000)	(3,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(208,000,000)	(180,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax			(8,000,000)	(13,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax			0	1,000,000
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax			(8,000,000)	(12,000,000)
Defined Benefit Plan, Accumulated Benefit Obligation			939,000,000	978,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets [Abstract]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation			927,000,000	964,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation			906,000,000	937,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets			752,000,000	828,000,000
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Service Cost			29,000,000	30,000,000		32,000,000
Defined Benefit Plan, Interest Cost			39,000,000	43,000,000		41,000,000
Defined Benefit Plan, Expected Return on Plan Assets			(54,000,000)	(55,000,000)		(52,000,000)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			8,000,000	2,000,000		2,000,000
Defined Benefit Plan, Amortization of (Gains) Losses			2,000,000	4,000,000		14,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements			0	19,000,000		1,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits			0	0		0
Defined Benefit Plan, Regulatory Adjustment			(20,000,000)	12,000,000		14,000,000
Defined Benefit Plan, Net Periodic Benefit Cost, Total			4,000,000	55,000,000		52,000,000
Other Comprehensive Income, Defined Benefit Plan's Adjustment, before Tax, [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			(6,000,000)	8,000,000		(2,000,000)
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax			(1,000,000)	(3,000,000)		(1,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total			(7,000,000)	5,000,000		(3,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total			$ (3,000,000)	$ 60,000,000		$ 49,000,000
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate			4.35%	4.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate			4.00%	4.69%		3.94%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets			7.00%	7.00%		7.00%
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year		5,000,000
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months			$ 86,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Two			84,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Three			82,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Four			80,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Five			77,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter			$ 339,000,000
Pension Benefits | San Diego Gas and Electric Company [Member] | Maximum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			10.00%	10.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			10.00%	10.00%		9.50%
Pension Benefits | San Diego Gas and Electric Company [Member] | Minimum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			2.00%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			2.00%	3.50%		3.50%
Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation			$ 3,000,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance		2,255,000,000	2,398,000,000	$ 2,110,000,000
Defined Benefit Plan, Service Cost			74,000,000	60,000,000		$ 67,000,000
Defined Benefit Plan, Interest Cost			98,000,000	100,000,000		90,000,000
Defined Benefit Plan, Contributions By Plan Participants			0	0
Defined Benefit Plan, Actuarial Loss (Gain)			(131,000,000)	300,000,000
Defined Benefit Plan, Plan Amendments			3,000,000	0
Defined Benefit Plan, Transfers, Benefit Obligation			0	1,000,000
Defined Benefit Plan, Settlements, Benefit Obligation			0	(10,000,000)
Defined Benefit Plan, Benefits Paid			(187,000,000)	(163,000,000)
Defined Benefit Plan, Benefit Obligation, Ending Balance			2,255,000,000	2,398,000,000		2,110,000,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance		1,537,000,000	1,763,000,000	1,758,000,000
Defined Benefit Plan, Actual Return on Plan Assets			(45,000,000)	138,000,000
Defined Benefit Plan, Contributions by Employer			6,000,000	39,000,000
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets			0	0
Defined Benefit Plan, Benefits Paid, Plan Assets			(187,000,000)	(163,000,000)
Defined Benefit Plan, Transfers, Plan Assets			0	1,000,000
Defined Benefit Plan, Settlements, Plan Assets			0	(10,000,000)
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance			1,537,000,000	1,763,000,000		1,758,000,000
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan			(718,000,000)	(635,000,000)
Defined Benefit Plan, Amounts Recognized in Balance Sheet			(718,000,000)	(635,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Other Postretirement Defined Benefit Plans, Asset Noncurrent			0	0
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities			(2,000,000)	(2,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(716,000,000)	(633,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax			(4,000,000)	(5,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax			(1,000,000)	1,000,000
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax			(5,000,000)	(4,000,000)
Defined Benefit Plan, Accumulated Benefit Obligation			2,056,000,000	2,182,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets [Abstract]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation			2,236,000,000	2,379,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation			2,039,000,000	2,166,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets			1,537,000,000	1,763,000,000
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Service Cost			74,000,000	60,000,000		67,000,000
Defined Benefit Plan, Interest Cost			98,000,000	100,000,000		90,000,000
Defined Benefit Plan, Expected Return on Plan Assets			(106,000,000)	(104,000,000)		(98,000,000)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			9,000,000	9,000,000		2,000,000
Defined Benefit Plan, Amortization of (Gains) Losses			21,000,000	6,000,000		31,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements			0	4,000,000		0
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits			0	0		0
Defined Benefit Plan, Regulatory Adjustment			(90,000,000)	(43,000,000)		(34,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost, Total			6,000,000	32,000,000		58,000,000
Other Comprehensive Income, Defined Benefit Plan's Adjustment, before Tax, [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			0	5,000,000		3,000,000
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax			2,000,000	0		0
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax			0	(5,000,000)		(1,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total			2,000,000	0		2,000,000
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total			$ 8,000,000	$ 32,000,000		$ 60,000,000
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate			4.50%	4.15%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate			4.15%	4.94%		4.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets			7.00%	7.00%		7.00%
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year		77,000,000
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months			$ 187,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Two			187,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Three			186,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Four			180,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Five			175,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter			$ 808,000,000
Pension Benefits | Southern California Gas Company [Member] | Maximum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			10.00%	10.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			10.00%	10.00%		9.50%
Pension Benefits | Southern California Gas Company [Member] | Minimum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			2.00%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			2.00%	3.50%		3.50%
Other Postretirement Benefits
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation			$ 9,000,000	$ 1,000,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance		963,000,000	1,115,000,000	973,000,000
Defined Benefit Plan, Service Cost			26,000,000	24,000,000		$ 28,000,000
Defined Benefit Plan, Interest Cost			44,000,000	49,000,000		44,000,000
Defined Benefit Plan, Contributions By Plan Participants			19,000,000	17,000,000
Defined Benefit Plan, Actuarial Loss (Gain)			(172,000,000)	105,000,000
Defined Benefit Plan, Plan Amendments			(9,000,000)	1,000,000
Defined Benefit Plan, Special Termination Benefits			0	5,000,000
Defined Benefit Plan, Settlements, Benefit Obligation			0	(1,000,000)
Defined Benefit Plan, Benefits Paid			(60,000,000)	(58,000,000)
Defined Benefit Plan, Benefit Obligation, Ending Balance			963,000,000	1,115,000,000		973,000,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance		1,003,000,000	1,054,000,000	1,012,000,000
Defined Benefit Plan, Actual Return on Plan Assets			(21,000,000)	67,000,000
Defined Benefit Plan, Contributions by Employer			11,000,000	16,000,000
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets			19,000,000	17,000,000
Defined Benefit Plan, Benefits Paid, Plan Assets			(60,000,000)	(58,000,000)
Defined Benefit Plan, Settlements, Plan Assets			0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance			1,003,000,000	1,054,000,000		1,012,000,000
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan			40,000,000	(61,000,000)
Defined Benefit Plan, Amounts Recognized in Balance Sheet			40,000,000	(61,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Other Postretirement Defined Benefit Plans, Asset Noncurrent			70,000,000	4,000,000
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities			0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(30,000,000)	(65,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax			2,000,000	(1,000,000)
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax			0	0
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax			2,000,000	(1,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Service Cost			26,000,000	24,000,000		28,000,000
Defined Benefit Plan, Interest Cost			44,000,000	49,000,000		44,000,000
Defined Benefit Plan, Expected Return on Plan Assets			(68,000,000)	(63,000,000)		(58,000,000)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			(4,000,000)	(5,000,000)		(4,000,000)
Defined Benefit Plan, Amortization of (Gains) Losses			0	0		7,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements			0	(1,000,000)		0
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits			0	5,000,000		5,000,000
Defined Benefit Plan, Regulatory Adjustment			12,000,000	6,000,000		6,000,000
Defined Benefit Plan, Net Periodic Benefit Cost, Total			10,000,000	15,000,000		28,000,000
Other Comprehensive Income, Defined Benefit Plan's Adjustment, before Tax, [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			(4,000,000)	1,000,000		(8,000,000)
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax			0	0		0
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax			0	0		(1,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total			(4,000,000)	1,000,000		(9,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total			$ 6,000,000	$ 16,000,000		$ 19,000,000
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate			4.49%	4.15%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate			4.15%	4.95%		4.09%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets			6.98%	6.97%		6.96%
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components			$ 7,000,000
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components			(5,000,000)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation			74,000,000
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation			(62,000,000)
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year		5,000,000
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months			47,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Two			50,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Three			53,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Four			56,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Five			61,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter			$ 296,000,000
Other Postretirement Benefits | Pre-65Retiree [Member]
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	[3]		8.10%	7.75%		8.25%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	[3]		5.00%	5.00%		5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate			2,022	2,020	[3]	2,020	[3]
Other Postretirement Benefits | Retiree Aged 65 or Older [Member]
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	[3]		5.50%	5.25%		5.50%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	[3]		4.50%	4.50%		4.50%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate			2,022	2,020	[3]	2,020	[3]
Other Postretirement Benefits | Maximum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			10.00%	10.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			10.00%	10.00%		9.50%
Other Postretirement Benefits | Minimum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			2.00%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			2.00%	3.50%		3.50%
Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation			$ 0	$ 0
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance		165,000,000	200,000,000	171,000,000
Defined Benefit Plan, Service Cost			7,000,000	7,000,000		$ 8,000,000
Defined Benefit Plan, Interest Cost			8,000,000	9,000,000		8,000,000
Defined Benefit Plan, Contributions By Plan Participants			7,000,000	6,000,000
Defined Benefit Plan, Actuarial Loss (Gain)			(43,000,000)	15,000,000
Defined Benefit Plan, Transfers, Benefit Obligation			0	0
Defined Benefit Plan, Special Termination Benefits			0	5,000,000
Defined Benefit Plan, Settlements, Benefit Obligation			0	0
Defined Benefit Plan, Benefits Paid			(14,000,000)	(13,000,000)
Defined Benefit Plan, Benefit Obligation, Ending Balance			165,000,000	200,000,000		171,000,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance		161,000,000	164,000,000	146,000,000
Defined Benefit Plan, Actual Return on Plan Assets			(3,000,000)	11,000,000
Defined Benefit Plan, Contributions by Employer			7,000,000	14,000,000
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets			7,000,000	6,000,000
Defined Benefit Plan, Benefits Paid, Plan Assets			(14,000,000)	(13,000,000)
Defined Benefit Plan, Transfers, Plan Assets			0	0
Defined Benefit Plan, Settlements, Plan Assets			0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance			161,000,000	164,000,000		146,000,000
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan			(4,000,000)	(36,000,000)
Defined Benefit Plan, Amounts Recognized in Balance Sheet			(4,000,000)	(36,000,000)
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities			0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			(4,000,000)	(36,000,000)
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Service Cost			7,000,000	7,000,000		8,000,000
Defined Benefit Plan, Interest Cost			8,000,000	9,000,000		8,000,000
Defined Benefit Plan, Expected Return on Plan Assets			(11,000,000)	(10,000,000)		(8,000,000)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			3,000,000	2,000,000		4,000,000
Defined Benefit Plan, Amortization of (Gains) Losses			0	0		0
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements			0	0		0
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits			0	5,000,000		2,000,000
Defined Benefit Plan, Regulatory Adjustment			0	1,000,000		0
Defined Benefit Plan, Net Periodic Benefit Cost, Total			7,000,000	14,000,000		14,000,000
Other Comprehensive Income, Defined Benefit Plan's Adjustment, before Tax, [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			0	0		0
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax			0	0		0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total			0	0		0
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total			$ 7,000,000	$ 14,000,000		$ 14,000,000
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate			4.50%	4.15%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate			4.15%	5.00%		4.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets			6.91%	6.88%		6.81%
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components			$ 1,000,000
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components			(1,000,000)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation			5,000,000
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation			(4,000,000)
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year		2,000,000
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months			8,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Two			9,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Three			10,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Four			10,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Five			10,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter			$ 54,000,000
Other Postretirement Benefits | San Diego Gas and Electric Company [Member] | Maximum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			10.00%	10.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			10.00%	10.00%
Other Postretirement Benefits | San Diego Gas and Electric Company [Member] | Minimum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			2.00%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			2.00%	3.50%
Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation			$ 9,000,000	$ 1,000,000
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]
Defined Benefit Plan, Benefit Obligation, Beginning Balance		752,000,000	866,000,000	753,000,000
Defined Benefit Plan, Service Cost			17,000,000	16,000,000		$ 17,000,000
Defined Benefit Plan, Interest Cost			34,000,000	38,000,000		34,000,000
Defined Benefit Plan, Contributions By Plan Participants			12,000,000	11,000,000
Defined Benefit Plan, Actuarial Loss (Gain)			(125,000,000)	90,000,000
Defined Benefit Plan, Plan Amendments			(9,000,000)	1,000,000
Defined Benefit Plan, Transfers, Benefit Obligation			0	0
Defined Benefit Plan, Settlements, Benefit Obligation			0	0
Defined Benefit Plan, Benefits Paid			(43,000,000)	(43,000,000)
Defined Benefit Plan, Benefit Obligation, Ending Balance			752,000,000	866,000,000		753,000,000
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance		822,000,000	870,000,000	848,000,000
Defined Benefit Plan, Actual Return on Plan Assets			(18,000,000)	54,000,000
Defined Benefit Plan, Contributions by Employer			1,000,000	0
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets			12,000,000	11,000,000
Defined Benefit Plan, Benefits Paid, Plan Assets			(43,000,000)	(43,000,000)
Defined Benefit Plan, Transfers, Plan Assets			0	0
Defined Benefit Plan, Settlements, Plan Assets			0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance			822,000,000	870,000,000		848,000,000
Defined Benefit Plan, Funded Status of Plan [Abstract]
Defined Benefit Plan, Funded Status of Plan			70,000,000	4,000,000
Defined Benefit Plan, Amounts Recognized in Balance Sheet			70,000,000	4,000,000
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]
Other Postretirement Defined Benefit Plans, Asset Noncurrent			70,000,000	4,000,000
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities			0	0
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent			0	0
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Service Cost			17,000,000	16,000,000		17,000,000
Defined Benefit Plan, Interest Cost			34,000,000	38,000,000		34,000,000
Defined Benefit Plan, Expected Return on Plan Assets			(56,000,000)	(51,000,000)		(48,000,000)
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)			(7,000,000)	(8,000,000)		(8,000,000)
Defined Benefit Plan, Amortization of (Gains) Losses			0	0		6,000,000
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements			0	0		0
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits			0	0		2,000,000
Defined Benefit Plan, Regulatory Adjustment			12,000,000	5,000,000		6,000,000
Defined Benefit Plan, Net Periodic Benefit Cost, Total			0	0		9,000,000
Other Comprehensive Income, Defined Benefit Plan's Adjustment, before Tax, [Abstract]
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, before Tax			0	0		0
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax			0	0		0
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax			0	0		0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total			0	0		0
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total			$ 0	$ 0		$ 9,000,000
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate			4.50%	4.15%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate			4.15%	4.95%		4.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets			7.00%	7.00%		7.00%
Defined Benefit Plan, Effect of One-Percentage Point Change in Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components			$ 5,000,000
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components			(4,000,000)
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation			67,000,000
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation			(55,000,000)
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year		$ 1,000,000
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months			36,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Two			38,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Three			40,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Four			42,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Year Five			44,000,000
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter			$ 228,000,000
Other Postretirement Benefits | Southern California Gas Company [Member] | Maximum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			10.00%	10.00%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			10.00%	10.00%		9.50%
Other Postretirement Benefits | Southern California Gas Company [Member] | Minimum [Member]
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Rate of Compensation Increase			2.00%	3.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase			2.00%	3.50%		3.50%
Life Insurance, Health Reimbursement Arrangement Benefits [Member]
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation				$ 5,000,000
Life Insurance, Health Reimbursement Arrangement Benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Plan Amendment [Abstract]
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation				$ 5,000,000
Mobile Gas Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year			8.10%	7.75%		7.50%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate			5.00%	5.00%		5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate			2,022	2,020		2,019
Chilquinta Energia Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year			3.00%	3.00%		3.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate			3.00%	3.00%		3.00%
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	Excludes Mobile Gas Plan. For Mobile Gas, the health care cost trend rate assumed for next year for all retirees was 8.10 percent, 7.75 percent and 7.50 percent in 2015, 2014 and 2013, respectively; the ultimate trend was 5.00 percent in 2015, 2014 and 2013; and the year the rate reaches the ultimate trend was 2022, 2020 and 2019 in 2015, 2014 and 2013, respectively. For Chilquinta Energía, the health care cost trend rate assumed for next year and all subsequent years was 3.00 percent in each of 2015, 2014 and 2013.

EMPLOYEE BENEFIT PLANS PART 2 (

EMPLOYEE BENEFIT PLANS PART 2 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Pension Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 13	$ 21
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	2	3
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	2	(3)
Private Equity Funds, Investment Plan Assets, Sales	(13)	(8)
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 4	$ 13
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Other Postretirement Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 2	$ 3
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)		(1)
Private Equity Funds, Investment Plan Assets, Sales	(2)
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 0	$ 2
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Private Equity Funds, S D G E [Member] | Pension Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 4	$ 6
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	1	1
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	0	(1)
Private Equity Funds, Investment Plan Assets, Sales	(4)	(2)
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 1	$ 4
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Private Equity Funds, S D G E [Member] | Other Postretirement Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 0	$ 1
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)		(1)
Private Equity Funds, Investment Plan Assets, Sales	0
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 0	$ 0
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Private Equity Funds, So Cal Gas [Member] | Pension Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 8	$ 13
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	1	2
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	2	(2)
Private Equity Funds, Investment Plan Assets, Sales	(8)	(5)
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 3	$ 8
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Private Equity Funds, So Cal Gas [Member] | Other Postretirement Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 2	$ 2
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)		0
Private Equity Funds, Investment Plan Assets, Sales	(2)
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 0	$ 2
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Private Equity Funds, All Other Sempra Energy [Member] | Pension Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 1	$ 2
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	0	0
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	0	0
Private Equity Funds, Investment Plan Assets, Sales	(1)	(1)
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 0	$ 1
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%
Private Equity Funds, All Other Sempra Energy [Member] | Other Postretirement Benefits
Private Equity Funds [Line Items]
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$ 0	$ 0
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)		0
Private Equity Funds, Investment Plan Assets, Sales	0
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$ 0	$ 0
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	0.00%	0.00%

EMPLOYEE BENEFIT PLANS PART 3 (

EMPLOYEE BENEFIT PLANS PART 3 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Chilquinta Energia Profit Sharing [Member]
Profit Sharing Plans [Line Items]
Recorded Annual Profit Sharing Expense	$ 3	$ 4	$ 4
Luz del Sur Profit Sharing [Member]
Profit Sharing Plans [Line Items]
Recorded Annual Profit Sharing Expense	$ 10	$ 10	$ 9

EMPLOYEE BENEFIT PLANS PART 4 (

EMPLOYEE BENEFIT PLANS PART 4 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Savings Plan [Line Items]
Defined Contribution Plan Employer Matching Amount	$ 43	$ 38	$ 35
Savings Plan, Market Value Of Employer Stock Held By Plan	1,100	1,400
San Diego Gas and Electric Company [Member]
Savings Plan [Line Items]
Defined Contribution Plan Employer Matching Amount	17	15	14
Southern California Gas Company [Member]
Savings Plan [Line Items]
Defined Contribution Plan Employer Matching Amount	$ 21	$ 18	$ 17

EMPLOYEE BENEFIT PLANS PART 5 (

EMPLOYEE BENEFIT PLANS PART 5 (Details) - USD ($)		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Pension Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		$ 2,484,000,000		$ 2,807,000,000		$ 2,789,000,000
Sempra Energy Common Stock Held in Pension Master Trust Shares				11,558
Sempra Energy Common Stock Held in Pension Master Trust Value				$ 1,000,000
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		14,000,000		11,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		25,000,000
Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		752,000,000		828,000,000		819,000,000
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		4,000,000		3,000,000
Transfers Receivable, Excluded From Fair Value of Defined Benefit Plan Assets		2,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		7,000,000
Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,537,000,000		1,763,000,000		1,758,000,000
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		9,000,000		7,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		16,000,000
All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		1,000,000		1,000,000
Transfers Payable, Excluded From Fair Value of Defined Benefit Plan Assets		2,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		2,000,000
Other Postretirement Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,003,000,000		$ 1,054,000,000		1,012,000,000
Sempra Energy Common Stock Held in Pension Master Trust Shares				2,005
Sempra Energy Common Stock Held in Pension Master Trust Value				$ 200,000
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		4,000,000		3,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		5,000,000
Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		161,000,000		164,000,000		146,000,000
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		1,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		1,000,000
Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		822,000,000		870,000,000		$ 848,000,000
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets		3,000,000		2,000,000
Accounts Payable Excluded From Fair Value of Defined Benefit Plan Assets		4,000,000
All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets				1,000,000
Equity Securities, Broad Market Fund [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		216,000,000		222,000,000
Equity Securities, Broad Market Fund [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Broad Market Fund [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		216,000,000		222,000,000
Equity Securities, Broad Market Fund [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Foreign Preferred [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		1,000,000
Equity Securities, Foreign Preferred [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		4,000,000
Equity Securities, Foreign Preferred [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				1,000,000
Equity Securities, Foreign Preferred [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				1,000,000
Equity Securities, Foreign Preferred [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		1,000,000
Equity Securities, Foreign Preferred [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		3,000,000
Equity Securities, Foreign Preferred [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Equity Securities, Foreign Preferred [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				1,000,000
Equity Securities, Foreign Preferred [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Foreign Preferred [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		1,000,000
Equity Securities, Foreign Preferred [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				1,000,000
Equity Securities, Foreign Preferred [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Equity Securities, Foreign Preferred [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Foreign Preferred [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Foreign Preferred [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Equity Securities, Foreign Preferred [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Equity Securities, Registered Investment Company [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		38,000,000		40,000,000
Equity Securities, Registered Investment Company [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		77,000,000		86,000,000
Equity Securities, Registered Investment Company [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		9,000,000		10,000,000
Equity Securities, Registered Investment Company [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		41,000,000		43,000,000
Equity Securities, Registered Investment Company [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		43,000,000		45,000,000
Equity Securities, Registered Investment Company [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000		4,000,000
Equity Securities, Registered Investment Company [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		38,000,000		40,000,000
Equity Securities, Registered Investment Company [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		77,000,000		86,000,000
Equity Securities, Registered Investment Company [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		9,000,000		10,000,000
Equity Securities, Registered Investment Company [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		41,000,000		43,000,000
Equity Securities, Registered Investment Company [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		43,000,000		45,000,000
Equity Securities, Registered Investment Company [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000		4,000,000
Equity Securities, Registered Investment Company [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		38,000,000		38,000,000
US Treasury Securities [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		76,000,000		80,000,000
US Treasury Securities [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10,000,000		9,000,000
US Treasury Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,000,000		5,000,000
US Treasury Securities [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		42,000,000		16,000,000
US Treasury Securities [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		1,000,000
US Treasury Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		38,000,000		38,000,000
US Treasury Securities [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		76,000,000		80,000,000
US Treasury Securities [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		10,000,000		9,000,000
US Treasury Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,000,000		5,000,000
US Treasury Securities [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		42,000,000		16,000,000
US Treasury Securities [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		1,000,000
US Treasury Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
US Treasury Securities [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		9,000,000		11,000,000
Municipal Bonds | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19,000,000		24,000,000
Municipal Bonds | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		4,000,000
Municipal Bonds | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		3,000,000
Municipal Bonds | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		7,000,000		5,000,000
Municipal Bonds | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		9,000,000		11,000,000
Municipal Bonds | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		19,000,000		24,000,000
Municipal Bonds | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		4,000,000
Municipal Bonds | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		3,000,000
Municipal Bonds | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		7,000,000		5,000,000
Municipal Bonds | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Municipal Bonds | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		10,000,000
Fixed Income, Registered Investment Company [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,000,000		21,000,000
Fixed Income, Registered Investment Company [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				2,000,000
Fixed Income, Registered Investment Company [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		16,000,000		16,000,000
Fixed Income, Registered Investment Company [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		49,000,000		6,000,000
Fixed Income, Registered Investment Company [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		2,000,000
Fixed Income, Registered Investment Company [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Fixed Income, Registered Investment Company [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		10,000,000
Fixed Income, Registered Investment Company [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,000,000		21,000,000
Fixed Income, Registered Investment Company [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				2,000,000
Fixed Income, Registered Investment Company [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		16,000,000		16,000,000
Fixed Income, Registered Investment Company [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		49,000,000		6,000,000
Fixed Income, Registered Investment Company [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		2,000,000
Fixed Income, Registered Investment Company [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Fixed Income, Registered Investment Company [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Fixed Income, Registered Investment Company [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		12,000,000
Foreign Government Debt Securities [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6,000,000		25,000,000
Foreign Government Debt Securities [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		3,000,000
Foreign Government Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				2,000,000
Foreign Government Debt Securities [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		5,000,000
Foreign Government Debt Securities [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
Foreign Government Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Foreign Government Debt Securities [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
Foreign Government Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		12,000,000
Foreign Government Debt Securities [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6,000,000		25,000,000
Foreign Government Debt Securities [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		3,000,000
Foreign Government Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				2,000,000
Foreign Government Debt Securities [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		5,000,000
Foreign Government Debt Securities [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
Foreign Government Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets				0
Foreign Government Debt Securities [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Government Debt Securities [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
Domestic Corporate Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	103,000,000		117,000,000
Domestic Corporate Debt Securities [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	209,000,000		249,000,000
Domestic Corporate Debt Securities [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	26,000,000		30,000,000
Domestic Corporate Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	15,000,000		16,000,000
Domestic Corporate Debt Securities [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	87,000,000		61,000,000
Domestic Corporate Debt Securities [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,000,000		2,000,000
Domestic Corporate Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	103,000,000		117,000,000
Domestic Corporate Debt Securities [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	209,000,000		249,000,000
Domestic Corporate Debt Securities [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	26,000,000		30,000,000
Domestic Corporate Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	15,000,000		16,000,000
Domestic Corporate Debt Securities [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	87,000,000		61,000,000
Domestic Corporate Debt Securities [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	1,000,000		2,000,000
Domestic Corporate Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Domestic Corporate Debt Securities [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[1]	0		0
Foreign Corporate Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		30,000,000		36,000,000
Foreign Corporate Debt Securities [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		62,000,000		77,000,000
Foreign Corporate Debt Securities [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		8,000,000		9,000,000
Foreign Corporate Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000		5,000,000
Foreign Corporate Debt Securities [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		28,000,000		25,000,000
Foreign Corporate Debt Securities [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
Foreign Corporate Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
Foreign Corporate Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		30,000,000		36,000,000
Foreign Corporate Debt Securities [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		62,000,000		77,000,000
Foreign Corporate Debt Securities [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		8,000,000		9,000,000
Foreign Corporate Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000		5,000,000
Foreign Corporate Debt Securities [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		28,000,000		25,000,000
Foreign Corporate Debt Securities [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
Foreign Corporate Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Foreign Corporate Debt Securities [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
Debt Securities, Common Collective Trusts [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	94,000,000		62,000,000
Debt Securities, Common Collective Trusts [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	193,000,000		132,000,000
Debt Securities, Common Collective Trusts [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	25,000,000		16,000,000
Debt Securities, Common Collective Trusts [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	14,000,000		8,000,000
Debt Securities, Common Collective Trusts [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	151,000,000		265,000,000
Debt Securities, Common Collective Trusts [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	1,000,000		1,000,000
Debt Securities, Common Collective Trusts [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	94,000,000		62,000,000
Debt Securities, Common Collective Trusts [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	193,000,000		132,000,000
Debt Securities, Common Collective Trusts [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	25,000,000		16,000,000
Debt Securities, Common Collective Trusts [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	14,000,000		8,000,000
Debt Securities, Common Collective Trusts [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	151,000,000		265,000,000
Debt Securities, Common Collective Trusts [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	1,000,000		1,000,000
Debt Securities, Common Collective Trusts [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[2]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Debt Securities, Common Collective Trusts [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[3]	0		0
Total Investment Plan Assets [Member] | Pension Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,495,000,000	[4]	2,796,000,000	[5]
Total Investment Plan Assets [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		753,000,000	[6]	825,000,000	[7]
Total Investment Plan Assets [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,544,000,000	[8]	1,756,000,000	[9]
Total Investment Plan Assets [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		198,000,000	[10]	215,000,000	[11]
Total Investment Plan Assets [Member] | Other Postretirement Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,004,000,000	[12]	1,051,000,000	[13]
Total Investment Plan Assets [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		161,000,000	[14]	164,000,000
Total Investment Plan Assets [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		823,000,000	[15]	868,000,000	[16]
Total Investment Plan Assets [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		20,000,000		19,000,000	[17]
Total Investment Plan Assets [Member] | Level 1 | Pension Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,685,000,000	[4]	1,937,000,000	[5]
Total Investment Plan Assets [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		509,000,000	[6]	572,000,000	[7]
Total Investment Plan Assets [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,042,000,000	[8]	1,216,000,000	[9]
Total Investment Plan Assets [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		134,000,000	[10]	149,000,000	[11]
Total Investment Plan Assets [Member] | Level 1 | Other Postretirement Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		405,000,000	[12]	404,000,000	[13]
Total Investment Plan Assets [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		109,000,000	[14]	114,000,000
Total Investment Plan Assets [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		282,000,000	[15]	276,000,000	[16]
Total Investment Plan Assets [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		14,000,000		14,000,000	[17]
Total Investment Plan Assets [Member] | Level 2 | Pension Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		806,000,000	[4]	846,000,000	[5]
Total Investment Plan Assets [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		243,000,000	[6]	249,000,000	[7]
Total Investment Plan Assets [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		499,000,000	[8]	532,000,000	[9]
Total Investment Plan Assets [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		64,000,000	[10]	65,000,000	[11]
Total Investment Plan Assets [Member] | Level 2 | Other Postretirement Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		599,000,000	[12]	645,000,000	[13]
Total Investment Plan Assets [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		52,000,000	[14]	50,000,000
Total Investment Plan Assets [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		541,000,000	[15]	590,000,000	[16]
Total Investment Plan Assets [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		6,000,000		5,000,000	[17]
Total Investment Plan Assets [Member] | Level 3 | Pension Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000	[4]	13,000,000	[5]
Total Investment Plan Assets [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000	[6]	4,000,000	[7]
Total Investment Plan Assets [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000	[8]	8,000,000	[9]
Total Investment Plan Assets [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0	[10]	1,000,000	[11]
Total Investment Plan Assets [Member] | Level 3 | Other Postretirement Benefits
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0	[12]	2,000,000	[13]
Total Investment Plan Assets [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0	[14]	0
Total Investment Plan Assets [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0	[15]	2,000,000	[16]
Total Investment Plan Assets [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[17]
Equity Securities Domestic [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		269,000,000		307,000,000	[18]
Equity Securities Domestic [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		552,000,000		651,000,000	[18]
Equity Securities Domestic [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		72,000,000		81,000,000	[18]
Equity Securities Domestic [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39,000,000		41,000,000	[19]
Equity Securities Domestic [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		123,000,000		133,000,000	[19]
Equity Securities Domestic [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,000,000		6,000,000	[19]
Equity Securities Domestic [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		269,000,000		307,000,000	[18]
Equity Securities Domestic [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		552,000,000		651,000,000	[18]
Equity Securities Domestic [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		72,000,000		81,000,000	[18]
Equity Securities Domestic [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		39,000,000		41,000,000	[19]
Equity Securities Domestic [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		123,000,000		133,000,000	[19]
Equity Securities Domestic [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		5,000,000		6,000,000	[19]
Equity Securities Domestic [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[18]
Equity Securities Domestic [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[18]
Equity Securities Domestic [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[18]
Equity Securities Domestic [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[19]
Equity Securities Domestic [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[19]
Equity Securities Domestic [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[19]
Equity Securities Domestic [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[18]
Equity Securities Domestic [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[18]
Equity Securities Domestic [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[18]
Equity Securities Domestic [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[19]
Equity Securities Domestic [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[19]
Equity Securities Domestic [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0	[19]
Equity Securities Foreign [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		163,000,000		186,000,000
Equity Securities Foreign [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		334,000,000		395,000,000
Equity Securities Foreign [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		43,000,000		49,000,000
Equity Securities Foreign [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		24,000,000		25,000,000
Equity Securities Foreign [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		74,000,000		81,000,000
Equity Securities Foreign [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		3,000,000
Equity Securities Foreign [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		163,000,000		186,000,000
Equity Securities Foreign [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		334,000,000		395,000,000
Equity Securities Foreign [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		43,000,000		49,000,000
Equity Securities Foreign [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		24,000,000		25,000,000
Equity Securities Foreign [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		74,000,000		81,000,000
Equity Securities Foreign [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		3,000,000		3,000,000
Equity Securities Foreign [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
Equity Securities Foreign [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000		3,000,000
EquitySecuritiesDomesticPreferred [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		1,000,000
EquitySecuritiesDomesticPreferred [Member] | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
EquitySecuritiesDomesticPreferred [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Level 1 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
EquitySecuritiesDomesticPreferred [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		2,000,000		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		4,000,000		3,000,000
EquitySecuritiesDomesticPreferred [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Level 2 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		1,000,000
EquitySecuritiesDomesticPreferred [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
EquitySecuritiesDomesticPreferred [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0		0
EquitySecuritiesDomesticPreferred [Member] | Level 3 | All Other Postretirement Benefit Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets		0
OtherPlanAssets [Member] | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	1,000,000		4,000,000
OtherPlanAssets [Member] | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	4,000,000		9,000,000
OtherPlanAssets [Member] | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			1,000,000
OtherPlanAssets [Member] | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			2,000,000
OtherPlanAssets [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	0		0
OtherPlanAssets [Member] | Level 1 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	1,000,000		1,000,000
OtherPlanAssets [Member] | Level 1 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			0
OtherPlanAssets [Member] | Level 1 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			0
OtherPlanAssets [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	0		0
OtherPlanAssets [Member] | Level 2 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	0		0
OtherPlanAssets [Member] | Level 2 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			0
OtherPlanAssets [Member] | Level 2 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			0
OtherPlanAssets [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	1,000,000		4,000,000
OtherPlanAssets [Member] | Level 3 | Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]	$ 3,000,000		8,000,000
OtherPlanAssets [Member] | Level 3 | All Other Pension Plans [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			1,000,000
OtherPlanAssets [Member] | Level 3 | Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]
Defined Benefit Plan, Fair Value of Plan Assets	[20]			$ 2,000,000
[1]	Bonds of U.S. issuers from diverse industries, primarily investment-grade.
[2]	Investments in common/collective trusts held in Sempra Energy’s Pension Master Trust.
[3]	Investments in common/collective trusts held in PBOP plan VEBA trusts and in the pension master trust.
[4]	Excludes cash and cash equivalents of $14 million and accounts payable of $25 million at Sempra Energy Consolidated.
[5]	Excludes cash and cash equivalents of $11 million at Sempra Energy Consolidated.
[6]	Excludes cash and cash equivalents of $4 million, accounts payable of $7 million and transfers receivable from other plans of $2 million at SDG&E.
[7]	Excludes cash and cash equivalents of $3 million at SDG&E.
[8]	Excludes cash and cash equivalents of $9 million and accounts payable of $16 million at SoCalGas.
[9]	Excludes cash and cash equivalents of $7 million at SoCalGas.
[10]	Excludes cash and cash equivalents of $1 million, accounts payable of $2 million and transfers payable to other plans of $2 million at Other Sempra Energy.
[11]	Excludes cash and cash equivalents of $1 million at Other Sempra Energy.
[12]	Excludes cash and cash equivalents of $4 million and accounts payable of $5 million at Sempra Energy Consolidated.
[13]	Excludes cash and cash equivalents of $3 million at Sempra Energy Consolidated.
[14]	Excludes cash and cash equivalents of $1 million and accounts payable of $1 million held in SDG&E PBOP plan trusts.
[15]	Excludes cash and cash equivalents of $3 million and accounts payable of $4 million held in SoCalGas PBOP plan trusts.
[16]	Excludes cash and cash equivalents of $2 million held in SoCalGas PBOP plan trusts.
[17]	Excludes cash and cash equivalents of $1 million held in Other Sempra Energy PBOP plan trusts.
[18]	Investments in common stock of domestic corporations include, on a combined basis at SDG&E, SoCalGas and Other Sempra Energy, 11,558 shares of Sempra Energy common stock at a value of $1 million.
[19]	Investments in common stock of domestic corporations include, on a combined basis at SDG&E, SoCalGas and Other Sempra Energy, 2,005 shares of Sempra Energy common stock at a value of $0.2 million.
[20]	Investments in venture capital and real estate funds, stated at net asset value, and derivative financial instruments.

EMPLOYEE BENEFIT PLANS PART 6 (

EMPLOYEE BENEFIT PLANS PART 6 (Details)	12 Months Ended
	Dec. 31, 2015
Domestic Equity [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	38.00%
International Equity [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	26.00%
High Yield Credit [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	5.00%
Long Credit [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	18.00%
Real Assets [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	5.00%
STRIPS [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	4.00%
LongGovernment [Member]
Defined Benefit Plan Assets Target Allocations [Line Items]
Defined Benefit Plan Assets Target Allocations Percentage	4.00%

SHARE-BASED COMPENSATION (Detai

SHARE-BASED COMPENSATION (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014USD ($)$ / sharesshares	Dec. 31, 2013USD ($)$ / sharesshares
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated Share-based Compensation Expense	$ 48	$ 46	$ 38
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	(19)	(18)	(15)
Employee Service Share-Based Compensation, Compensation Expense, Net Of Tax	$ 29	$ 28	$ 23
Employee Service Share-Based Compensation, Compensation Expense, Net Of Tax, Per Basic Share | $ / shares	$ 0.12	$ 0.11	$ 0.09
Employee Service Share-Based Compensation, Compensation Expense, Net Of Tax, Per Diluted Share | $ / shares	$ 0.12	$ 0.11	$ 0.09
Employee Service Share-based Compensation, Allocation of Recognized Period Costs, Capitalized Amount	$ 6	$ 5	$ 4
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Beginning Balance | shares	757,412
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price, Beginning of Period | $ / shares	$ 53.84
Share-based Compensation Arrangement by Share-based Payment Award, Options, Grants in Period | shares	0	0	0
Exercised Stock Options | shares	(227,815)
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price | $ / shares	$ 54.48
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Total Intrinsic Value	$ 12	$ 33	$ 41
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period | shares	(1,600)
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price | $ / shares	$ 36.3
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance | shares	527,997	757,412
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price, End of Period | $ / shares	$ 53.62	$ 53.84
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term	2.6
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	$ 21
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number | shares	527,997
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price | $ / shares	$ 53.62
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Term	2.6
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value	$ 21
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number | shares	527,997
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Exercise Price | $ / shares	$ 53.62
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Remaining Contractual Term	2.6
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Aggregate Intrinsic Value	$ 21
Share-Based Compensation Arrangement By Share-Based Payment Award, Options, Vested In Period, Total Fair Value		$ 1	$ 2
Restricted Stock Units Issued By Subsidiary, Outstanding | shares	570,218
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized | shares	6,148,009
Employee Service Share-based Compensation, Cash Received from Exercise of Stock Options	$ 12
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant | shares	6,148,009
Restricted stock units issued by subsidary | shares	278,538	468,339	1,014,899
Employee Service Share-based Compensation, Tax Benefit Realized from Exercise of Stock Options	$ 52
IENova Plans [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Share-based Liabilities Paid	4	$ 3	$ 0
San Diego Gas and Electric Company [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated Share-based Compensation Expense	8	8	8
Employee Service Share-based Compensation, Allocation of Recognized Period Costs, Capitalized Amount	4	3	3
Southern California Gas Company [Member]
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]
Allocated Share-based Compensation Expense	10	8	8
Employee Service Share-based Compensation, Allocation of Recognized Period Costs, Capitalized Amount	$ 2	$ 2	$ 1

SHARE-BASED COMPENSATION 2 (Det

SHARE-BASED COMPENSATION 2 (Details) - USD ($) $ / shares in Units, $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Maximum Performance Based RSU Target Performance Conditions Exceeded Through 2013		50.00%
Maximum Performance Based RSU Target Performance Conditions Exceeded For Awards Granted during or after 2014		100.00%
Share-Based Compensation, Restricted Stock Awards And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Volatility Rate		14.00%		16.00%	19.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate		1.10%		1.20%	0.60%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate		0.00%		0.00%	3.30%
Share-Based Compensation, Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		$ 39
Weighted average period over which unrecognized compensation cost will be recognized		1.9 years
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Total Fair Value		$ 46		$ 33	$ 33
Share-Based Compensation, Restricted Stock Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Beginning Balance		9,238
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period		$ 63.81
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		0		0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value					$ 75.82
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period		(7,701)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value		$ 61.41
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Ending Balance		1,537		9,238
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, End of Period		$ 75.87		$ 63.81
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Outstanding, Number		1,537
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Weighted Average Grant Date Fair Value		$ 75.87
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized		$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Total Fair Value		$ 1		$ 1	$ 1
Share-Based Compensation, Performance Based Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Beginning Balance		2,874,942
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period		$ 54.55
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	[1]	438,318
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value		$ 123.3	[1]	$ 88.01	$ 57.55
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period		(1,036,645)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value		$ 42.34
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		(4,940)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value		$ 103.58
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Ending Balance		2,271,675	[1],[2]	2,874,942
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, End of Period		$ 73.28	[1],[2]	$ 54.55
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Outstanding, Number	[1]	2,220,408
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Weighted Average Grant Date Fair Value	[1]	$ 72.89
Share-Based Compensation, Service Based Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Beginning Balance		303,237
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period		$ 73.41
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period		72,835
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value		$ 111.43		$ 91.54	$ 72.71
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period		(25,000)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value		$ 88.71
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period		(2,266)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value		$ 90.48
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Ending Balance		348,806	[2]	303,237
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, End of Period		$ 80.14	[2]	$ 73.41
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Outstanding, Number		338,086
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Weighted Average Grant Date Fair Value		$ 79.81
[1]	Includes restricted stock units issued in 2015 in connection with the creation of Cameron LNG JV.
[2]	Each unit represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based restricted stock units, except for those issued in connection with the creation of Cameron LNG JV, up to an additional 50 percent (100 percent for awards granted during or after 2014) of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.

DERIVATIVE FINANCIAL INSTRUM110

DERIVATIVE FINANCIAL INSTRUMENTS (Details)		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
S D G E Segment [Member]
Schedule Of Commodity Derivative Volumes [Line Items]
Commodity derivative volumes, natural gas (in millions of million British thermal units)	[1]	70	55
Commodity derivative volumes, congestion revenue rights (in millions of megawatt hours)	[2]	36	27
Commodity derivative volumes, electric power (in millions of megawatt hours)		1	0
So Cal Gas Segment [Member]
Schedule Of Commodity Derivative Volumes [Line Items]
Commodity derivative volumes, natural gas (in millions of million British thermal units)	[1]	1	1
Sempra Natural Gas Segment [Member]
Schedule Of Commodity Derivative Volumes [Line Items]
Commodity derivative volumes, natural gas (in millions of million British thermal units)	[1]	43	29
[1]	Million British thermal units
[2]	Megawatt hours

DERIVATIVE FINANCIAL INSTRUM111

DERIVATIVE FINANCIAL INSTRUMENTS 2 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Cash Flow Hedges
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Notional Amount Of Interest Rate Derivatives	[1]	$ 384	$ 399
Cash Flow Hedges | Maximum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	[1]	2,028	2,028
Cash Flow Hedges | Minimum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	[1]	2,016	2,015
Fair Value Hedges
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Notional Amount Of Interest Rate Derivatives		$ 300	$ 300
Fair Value Hedges | Maximum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives		2,016	2,016
San Diego Gas and Electric Company [Member] | Cash Flow Hedges
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Notional Amount Of Interest Rate Derivatives	[1]	$ 315	$ 325
San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Maximum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	[2]	2,019	2,019
San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Minimum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	[2]	2,016	2,015
[1]	Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.
[2]	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

DERIVATIVE FINANCIAL INSTRUM112

DERIVATIVE FINANCIAL INSTRUMENTS 3 (Details) - USD ($) $ in Millions		Dec. 31, 2015		Dec. 31, 2014
Fixed Price Contracts And Other Derivatives, Current Assets [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[1],[2]	$ 4		$ 10
Commodity contracts not subject to rate recovery	[1]	13		25
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments	[1]			8
Commodity contracts not subject to rate recovery	[1]	245		143
Associated offsetting commodity contracts not subject to rate recovery	[1]	(232)		(129)
Associated cash collateral commodity contracts not subject to rate recovery	[1]	(6)		(11)
Commodity contracts subject to rate recovery	[1]	28		36
Associated cash collateral commodity contracts subject to rate recovery	[1]	0		0
Associated offsetting commodity contracts subject to rate recovery	[1]	(2)		(3)
Net amount presented on balance sheet	[1]	50		79
Additional margin posted for commodity contracts not subject to rate recovery	[1]	2
Additional margin posted for commodity contracts subject to rate recovery	[1]	28		14
Total	[1],[3]	80		93
Fixed Price Contracts And Other Derivatives, Current Assets [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	0	[1]	0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[1]	0
Associated cash collateral commodity contracts not subject to rate recovery	[1]	0
Commodity contracts subject to rate recovery	[1]	27		32
Associated cash collateral commodity contracts subject to rate recovery	[1]	0		0
Associated offsetting commodity contracts subject to rate recovery	[1]	(2)		0
Net amount presented on balance sheet	[1]	25		32
Additional margin posted for commodity contracts not subject to rate recovery	[1]	1
Additional margin posted for commodity contracts subject to rate recovery	[1]	27		12
Total	[3]	53	[1]	44
Fixed Price Contracts And Other Derivatives, Current Assets [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[1]	0
Associated cash collateral commodity contracts not subject to rate recovery	[1]	0
Commodity contracts subject to rate recovery	[1]	1		4
Associated offsetting commodity contracts subject to rate recovery	[1]			(3)
Net amount presented on balance sheet	[1]	1		1
Additional margin posted for commodity contracts subject to rate recovery	[1]	1		2
Total	[1]	2		3
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	1		3
Commodity contracts not subject to rate recovery		0		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments				27
Commodity contracts not subject to rate recovery		32		32
Associated offsetting commodity contracts not subject to rate recovery		(20)		(27)
Associated cash collateral commodity contracts not subject to rate recovery		0		0
Commodity contracts subject to rate recovery		49		76
Associated cash collateral commodity contracts subject to rate recovery		0		0
Associated offsetting commodity contracts subject to rate recovery		(2)		(1)
Net amount presented on balance sheet		60		110
Additional margin posted for commodity contracts not subject to rate recovery		0
Additional margin posted for commodity contracts subject to rate recovery		0		0
Total	[3]	60		110
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	0		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0
Associated cash collateral commodity contracts not subject to rate recovery		0
Commodity contracts subject to rate recovery		49		76
Associated cash collateral commodity contracts subject to rate recovery		0		0
Associated offsetting commodity contracts subject to rate recovery		(2)		(1)
Net amount presented on balance sheet		47		75
Additional margin posted for commodity contracts not subject to rate recovery		0
Additional margin posted for commodity contracts subject to rate recovery		0		0
Total	[3]	47		75
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0
Associated cash collateral commodity contracts not subject to rate recovery		0
Commodity contracts subject to rate recovery		0		0
Associated offsetting commodity contracts subject to rate recovery				0
Net amount presented on balance sheet		0		0
Additional margin posted for commodity contracts subject to rate recovery		0		0
Total		0		0
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2],[4]	(15)		(17)
Commodity contracts not subject to rate recovery	[4]	0		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments	[4]			(7)
Commodity contracts not subject to rate recovery	[4]	(239)		(135)
Associated offsetting commodity contracts not subject to rate recovery	[4]	232		129
Associated cash collateral commodity contracts not subject to rate recovery	[4]	4		0
Commodity contracts subject to rate recovery	[4]	(61)		(36)
Associated cash collateral commodity contracts subject to rate recovery	[4]	28		23
Associated offsetting commodity contracts subject to rate recovery	[4]	2		3
Net amount presented on balance sheet	[4]	(49)		(40)
Additional margin posted for commodity contracts not subject to rate recovery	[4]	0
Additional margin posted for commodity contracts subject to rate recovery	[4]	0		0
Total	[3],[4]	(49)		(40)
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	(14)	[4]	(16)
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[4]	(1)
Associated cash collateral commodity contracts not subject to rate recovery	[4]	1
Commodity contracts subject to rate recovery	[4]	(60)		(32)
Associated cash collateral commodity contracts subject to rate recovery	[4]	28		23
Associated offsetting commodity contracts subject to rate recovery	[4]	2		0
Net amount presented on balance sheet	[4]	(44)		(25)
Additional margin posted for commodity contracts not subject to rate recovery	[4]	0
Additional margin posted for commodity contracts subject to rate recovery	[4]	0		0
Total	[3],[4]	(44)		(25)
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[4]	(1)
Associated cash collateral commodity contracts not subject to rate recovery	[4]	1
Commodity contracts subject to rate recovery	[4]	(1)		(4)
Associated offsetting commodity contracts subject to rate recovery	[4]			3
Net amount presented on balance sheet	[4]	(1)		(1)
Additional margin posted for commodity contracts subject to rate recovery	[4]	0		0
Total	[4]	(1)		(1)
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	(156)		(109)
Commodity contracts not subject to rate recovery		0		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments				(22)
Commodity contracts not subject to rate recovery		(21)		(29)
Associated offsetting commodity contracts not subject to rate recovery		20		27
Associated cash collateral commodity contracts not subject to rate recovery		0		0
Commodity contracts subject to rate recovery		(64)		(20)
Associated cash collateral commodity contracts subject to rate recovery		26		13
Associated offsetting commodity contracts subject to rate recovery		2		1
Net amount presented on balance sheet		(193)		(139)
Additional margin posted for commodity contracts not subject to rate recovery		0
Additional margin posted for commodity contracts subject to rate recovery		0		0
Total	[3]	(193)		(139)
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	(23)		(31)
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0
Associated cash collateral commodity contracts not subject to rate recovery		0
Commodity contracts subject to rate recovery		(64)		(20)
Associated cash collateral commodity contracts subject to rate recovery		26		13
Associated offsetting commodity contracts subject to rate recovery		2		1
Net amount presented on balance sheet		(59)		(37)
Additional margin posted for commodity contracts not subject to rate recovery		0
Additional margin posted for commodity contracts subject to rate recovery		0		0
Total	[3]	(59)		(37)
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0
Associated cash collateral commodity contracts not subject to rate recovery		0
Commodity contracts subject to rate recovery		0		0
Associated offsetting commodity contracts subject to rate recovery				0
Net amount presented on balance sheet		0		0
Additional margin posted for commodity contracts subject to rate recovery		0		0
Total		$ 0		$ 0
[1]	Included in Current Assets: Other for SoCalGas.
[2]	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
[3]	Normal purchase contracts previously measured at fair value are excluded.
[4]	Included in Current Liabilities: Other for SoCalGas.

DERIVATIVE FINANCIAL INSTRUM113

DERIVATIVE FINANCIAL INSTRUMENTS 4 (Details) - USD ($)		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		$ 10,000,000		$ 25,000,000	$ 21,000,000
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		4,000,000		6,000,000	8,000,000
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[1]	(106,000,000)		(129,000,000)	12,000,000
Gain (loss) reclassified from AOCI into earnings (effective portion)	[1]	(29,000,000)		(20,000,000)	(20,000,000)
Cash Flow Hedges | Interest Expense | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[2]	(18,000,000)	[1]	(24,000,000)	1,000,000
Gain (loss) reclassified from AOCI into earnings (effective portion)	[2]	(18,000,000)	[1]	(21,000,000)	(11,000,000)
Cash Flow Hedges | Interest Expense | Interest Rate Contract [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[2],[3]	(6,000,000)		(9,000,000)	8,000,000
Gain (loss) reclassified from AOCI into earnings (effective portion)	[2],[3]	(12,000,000)		(11,000,000)	(9,000,000)
Cash Flow Hedges | Interest Expense | Interest Rate Contract [Member] | Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[3]	0		0	0
Gain (loss) reclassified from AOCI into earnings (effective portion)	[3]	(1,000,000)		(1,000,000)	(1,000,000)
Cash Flow Hedges | Equity Earnings, Net Of Income Tax [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)		(20,000,000)		0	0
Gain (loss) reclassified from AOCI into earnings (effective portion)		(13,000,000)		0	0
Cash Flow Hedges | Equity Earnings Before Income Tax [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)		(80,000,000)		(127,000,000)	15,000,000
Gain (loss) reclassified from AOCI into earnings (effective portion)		(12,000,000)		(10,000,000)	(10,000,000)
Cash Flow Hedges | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)		12,000,000		19,000,000	(4,000,000)
Gain (loss) reclassified from AOCI into earnings (effective portion)		14,000,000		8,000,000	1,000,000
Cash Flow Hedges | Gain on Sale of Assets [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)		0		3,000,000	0
Gain (loss) reclassified from AOCI into earnings (effective portion)		0		3,000,000	0
Fair Value Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	[4]	1,000,000		5,000,000	1,000,000
Fair Value Hedges | Interest Expense | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		6,000,000		8,000,000	8,000,000
Fair Value Hedges | Other Income, Net | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(5,000,000)		(3,000,000)	(7,000,000)
Undesignated Derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(92,000,000)		(23,000,000)	66,000,000
Undesignated Derivatives | San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(126,000,000)		(11,000,000)	53,000,000
Undesignated Derivatives | Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		0		(2,000,000)	1,000,000
Undesignated Derivatives | Other Income, Net | Interest Rate and Foreign Exchange Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(4,000,000)		(24,000,000)	17,000,000
Undesignated Derivatives | Equity Earnings, Net Of Income Tax [Member] | Interest Rate and Foreign Exchange Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(4,000,000)		(5,000,000)	(4,000,000)
Undesignated Derivatives | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		42,000,000		17,000,000	(1,000,000)
Undesignated Derivatives | Cost of Natural Gas, Electric Fuel and Purchased Power [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		0		3,000,000	0
Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(126,000,000)		(10,000,000)	53,000,000
Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(126,000,000)		(10,000,000)	53,000,000
Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		1,000,000		0	0
Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member] | Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		1,000,000		0	0
Undesignated Derivatives | Operation And Maintenance [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(1,000,000)		(4,000,000)	1,000,000
Undesignated Derivatives | Operation And Maintenance [Member] | Commodity Contracts Not Subject To Rate Recovery [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		0		(1,000,000)	0
Undesignated Derivatives | Operation And Maintenance [Member] | Commodity Contracts Not Subject To Rate Recovery [Member] | Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		$ (1,000,000)		$ (2,000,000)	$ 1,000,000
[1]	There was $2 million, $1 million and $1 million of losses from ineffectiveness related to these cash flow hedges in 2015, 2014 and 2013, respectively.
[2]	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
[3]	There was negligible hedge ineffectiveness related to these cash flow hedges at SDG&E and SoCalGas in 2015, 2014 and 2013.
[4]	There was no hedge ineffectiveness in 2015 or 2013. There were gains of $9 million from hedge ineffectiveness in 2014. All other changes in the fair value of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt and recorded in Other Income, Net.

DERIVATIVE FINANCIAL INSTRUM114

DERIVATIVE FINANCIAL INSTRUMENTS 5 (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Reclassification Of Cash Flow Hedge Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ (16)
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	(12)
San Diego Gas and Electric Company [Member]
Reclassification Of Cash Flow Hedge Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	(12)
Southern California Gas Company [Member]
Reclassification Of Cash Flow Hedge Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 0

DERIVATIVE FINANCIAL INSTRUM115

DERIVATIVE FINANCIAL INSTRUMENTS 6 (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative Credit Risk Related Contingent Features [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 6	$ 9
Additional Collateral Aggregate Fair Value	6
San Diego Gas and Electric Company [Member]
Derivative Credit Risk Related Contingent Features [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	5	$ 2
Additional Collateral Aggregate Fair Value	$ 6

DERIVATIVE FINANCIAL INSTRUM116

DERIVATIVE FINANCIAL INSTRUMENTS 7 (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Hedge Ineffectiveness [Line Items]
Loss on Cash Flow Hedge Ineffectiveness	$ 2	$ 1	$ 1
Loss on Fair Value Hedge Ineffectiveness	$ 0	$ 9	$ 0

FAIR VALUE MEASUREMENTS (Detail

FAIR VALUE MEASUREMENTS (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Due From Affiliate Accrued Interest		$ 11	$ 4
Fair value of financial instruments, debt instrument, unamortized amount		107	102
Fair value of financial instruments, capital Lease obligations		387	310
Otay Mesa Energy Center Loan Payable Currently Through April 2019 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument Carrying Amount		315	325
Level 3 | Otay Mesa Energy Center Loan Payable Currently Through April 2019 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument Carrying Amount		315	325
Parent Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, debt instrument, unamortized amount		(10)	(9)	[1]
Unamortized Debt Issuance Expense		(27)	(22)	[1]
San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, debt instrument, unamortized amount		43	47
Fair value of financial instruments, capital Lease obligations		244	234
Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, debt instrument, unamortized amount		24	23
Fair value of financial instruments, capital Lease obligations		1	1
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[3]	13,761	12,347
Due From Affiliate Noncurrent Fair Value Disclosure	[2]	175	184
Fair value of financial instruments, Preferred stock of subsidiaries		20	20
Carrying Amount | San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[3],[4]	4,304	4,461
Carrying Amount | Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	2,513	1,913
Fair value of financial instruments, Preferred stock		22	22
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[3]	14,633	13,699
Due From Affiliate Noncurrent Fair Value Disclosure	[2]	166	170
Fair value of financial instruments, Preferred stock of subsidiaries		23	23
Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[3]	0	0
Due From Affiliate Noncurrent Fair Value Disclosure	[2]	0	0
Fair value of financial instruments, Preferred stock of subsidiaries		0	0
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[3]	13,985	12,782
Due From Affiliate Noncurrent Fair Value Disclosure	[2]	97	132
Fair value of financial instruments, Preferred stock of subsidiaries		23	23
Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[3]	648	917
Due From Affiliate Noncurrent Fair Value Disclosure	[2]	69	38
Fair value of financial instruments, Preferred stock of subsidiaries		0	0
Fair Value | San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[3],[4]	4,670	4,988
Fair Value | San Diego Gas and Electric Company [Member] | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[3],[4]	0	0
Fair Value | San Diego Gas and Electric Company [Member] | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[3],[4]	4,355	4,563
Fair Value | San Diego Gas and Electric Company [Member] | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[3],[4]	315	425
Fair Value | Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	2,621	2,124
Fair value of financial instruments, Preferred stock		25	25
Fair Value | Southern California Gas Company [Member] | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	0	0
Fair value of financial instruments, Preferred stock		0	0
Fair Value | Southern California Gas Company [Member] | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	2,621	2,124
Fair value of financial instruments, Preferred stock		25	25
Fair Value | Southern California Gas Company [Member] | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	0	0
Fair value of financial instruments, Preferred stock		$ 0	$ 0
[1]	(1) As adjusted for the retrospective adoption of ASU 2015-03.
[2]	Excluding accumulated interest outstanding of $11 million and $4 million at December 31, 2015 and 2014, respectively.
[3]	Level 3 instruments include $315 million and $325 million at December 31, 2015 and 2014, respectively, related to Otay Mesa VIE.
[4]	Before reductions for unamortized discount and debt issuance costs of $43 million and $47 million at December 31, 2015 and 2014, respectively, and excluding capital leases of $244 million and $234 million at December 31, 2015 and 2014, respectively.
[5]	Before reductions for unamortized discount and debt issuance costs of $24 million and $23 million at December 31, 2015 and 2014, respectively, and excluding capital leases of $1 million at both December 31, 2015 and 2014.

FAIR VALUE MEASUREMENTS 2 (Deta

FAIR VALUE MEASUREMENTS 2 (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net [Line Items]
Fair value of cash collateral receivables not offset against derivatives	$ 30	$ 14
San Diego Gas and Electric Company [Member]
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net [Line Items]
Fair value of cash collateral receivables not offset against derivatives	28	12
Southern California Gas Company [Member]
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net [Line Items]
Fair value of cash collateral receivables not offset against derivatives	$ 1	$ 2

FAIR VALUE MEASUREMENTS 3 (Deta

FAIR VALUE MEASUREMENTS 3 (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		$ 619	$ 655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		91	109
Nuclear decomissioning trusts - Municipal debt securities		156	129
Nuclear decommissioning trusts - Other debt securities		182	207
Nuclear decommissioning trusts - Total debt securities		429	445
Total nuclear decommissioning trusts	[1]	1,048	1,100
Interest rate instruments, assets		5	48
Commodity contracts not subject to rate recovery, assets		34	33
Commodity contracts subject to rate recovery, assets		101	122
Assets fair value disclosure, total		1,188	1,303
Interest rate instruments, liabilities		171	155
Commodity contracts not subject to rate recovery, liabilities		67	16
Commodity contracts subject to rate recovery, liabilities		4	8
Liabilities fair value disclosure, total		242	179
San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		619	655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		91	109
Nuclear decomissioning trusts - Municipal debt securities		156	129
Nuclear decommissioning trusts - Other debt securities		182	207
Nuclear decommissioning trusts - Total debt securities		429	445
Total nuclear decommissioning trusts	[1]	1,048	1,100
Commodity contracts not subject to rate recovery, assets		1
Commodity contracts subject to rate recovery, assets		99	119
Assets fair value disclosure, total		1,148	1,219
Interest rate instruments, liabilities		37	47
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		66	15
Liabilities fair value disclosure, total		103	62
Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts subject to rate recovery, assets		2	3
Assets fair value disclosure, total		2	3
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		1	1
Liabilities fair value disclosure, total		1	1
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		619	655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		47	62
Nuclear decomissioning trusts - Municipal debt securities		0	0
Nuclear decommissioning trusts - Other debt securities		0	0
Nuclear decommissioning trusts - Total debt securities		47	62
Total nuclear decommissioning trusts	[1]	666	717
Interest rate instruments, assets		0	0
Commodity contracts not subject to rate recovery, assets		22	28
Commodity contracts subject to rate recovery, assets		0	0
Assets fair value disclosure, total		688	745
Interest rate instruments, liabilities		0	0
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		5	3
Liabilities fair value disclosure, total		5	3
Level 1 | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		619	655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		47	62
Nuclear decomissioning trusts - Municipal debt securities		0	0
Nuclear decommissioning trusts - Other debt securities		0	0
Nuclear decommissioning trusts - Total debt securities		47	62
Total nuclear decommissioning trusts	[1]	666	717
Commodity contracts not subject to rate recovery, assets		0
Commodity contracts subject to rate recovery, assets		0	0
Assets fair value disclosure, total		666	717
Interest rate instruments, liabilities		0	0
Commodity contracts not subject to rate recovery, liabilities		1	1
Commodity contracts subject to rate recovery, liabilities		0	0
Liabilities fair value disclosure, total		1	1
Level 1 | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts subject to rate recovery, assets		0	0
Assets fair value disclosure, total		0	0
Commodity contracts not subject to rate recovery, liabilities		1	2
Commodity contracts subject to rate recovery, liabilities		0	0
Liabilities fair value disclosure, total		1	2
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		44	47
Nuclear decomissioning trusts - Municipal debt securities		156	129
Nuclear decommissioning trusts - Other debt securities		182	207
Nuclear decommissioning trusts - Total debt securities		382	383
Total nuclear decommissioning trusts	[1]	382	383
Interest rate instruments, assets		5	48
Commodity contracts not subject to rate recovery, assets		16	16
Commodity contracts subject to rate recovery, assets		1	1
Assets fair value disclosure, total		404	448
Interest rate instruments, liabilities		171	155
Commodity contracts not subject to rate recovery, liabilities		68	52
Commodity contracts subject to rate recovery, liabilities		3	9
Liabilities fair value disclosure, total		242	216
Level 2 | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		44	47
Nuclear decomissioning trusts - Municipal debt securities		156	129
Nuclear decommissioning trusts - Other debt securities		182	207
Nuclear decommissioning trusts - Total debt securities		382	383
Total nuclear decommissioning trusts	[1]	382	383
Commodity contracts not subject to rate recovery, assets		0
Commodity contracts subject to rate recovery, assets		0	0
Assets fair value disclosure, total		382	383
Interest rate instruments, liabilities		37	47
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		67	51
Liabilities fair value disclosure, total		104	98
Level 2 | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts subject to rate recovery, assets		1	1
Assets fair value disclosure, total		1	1
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		1	1
Liabilities fair value disclosure, total		1	1
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		0	0
Nuclear decomissioning trusts - Municipal debt securities		0	0
Nuclear decommissioning trusts - Other debt securities		0	0
Nuclear decommissioning trusts - Total debt securities		0	0
Total nuclear decommissioning trusts	[1]	0	0
Interest rate instruments, assets		0	0
Commodity contracts not subject to rate recovery, assets		0	0
Commodity contracts subject to rate recovery, assets		72	107
Assets fair value disclosure, total		72	107
Interest rate instruments, liabilities		0	0
Commodity contracts not subject to rate recovery, liabilities		53	0
Commodity contracts subject to rate recovery, liabilities		0	0
Liabilities fair value disclosure, total		53	0
Level 3 | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		0	0
Nuclear decomissioning trusts - Municipal debt securities		0	0
Nuclear decommissioning trusts - Other debt securities		0	0
Nuclear decommissioning trusts - Total debt securities		0	0
Total nuclear decommissioning trusts	[1]	0	0
Commodity contracts not subject to rate recovery, assets		0
Commodity contracts subject to rate recovery, assets		72	107
Assets fair value disclosure, total		72	107
Interest rate instruments, liabilities		0	0
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		53	0
Liabilities fair value disclosure, total		53	0
Level 3 | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts subject to rate recovery, assets		0	0
Assets fair value disclosure, total		0	0
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		0	0
Liabilities fair value disclosure, total		0	0
Collateral Netted [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	[2]	0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	[2]	0	0
Nuclear decomissioning trusts - Municipal debt securities	[2]	0	0
Nuclear decommissioning trusts - Other debt securities	[2]	0	0
Nuclear decommissioning trusts - Total debt securities	[2]	0	0
Total nuclear decommissioning trusts	[1],[2]	0	0
Interest rate instruments, assets	[2]	0	0
Commodity contracts not subject to rate recovery, assets	[2]	(4)	(11)
Commodity contracts subject to rate recovery, assets	[2]	28	14
Assets fair value disclosure, total	[2]	24	3
Interest rate instruments, liabilities	[2]	0	0
Commodity contracts not subject to rate recovery, liabilities	[2]	(54)	(36)
Commodity contracts subject to rate recovery, liabilities	[2]	(4)	(4)
Liabilities fair value disclosure, total	[2]	(58)	(40)
Collateral Netted [Member] | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	[2]	0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	[2]	0	0
Nuclear decomissioning trusts - Municipal debt securities	[2]	0	0
Nuclear decommissioning trusts - Other debt securities	[2]	0	0
Nuclear decommissioning trusts - Total debt securities	[2]	0	0
Total nuclear decommissioning trusts	[1],[2]	0	0
Commodity contracts not subject to rate recovery, assets	[2]	1
Commodity contracts subject to rate recovery, assets	[2]	27	12
Assets fair value disclosure, total	[2]	28	12
Interest rate instruments, liabilities	[2]	0	0
Commodity contracts not subject to rate recovery, liabilities	[2]	(1)	(1)
Commodity contracts subject to rate recovery, liabilities	[2]	(54)	(36)
Liabilities fair value disclosure, total	[2]	(55)	(37)
Collateral Netted [Member] | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts subject to rate recovery, assets	[2]	1	2
Assets fair value disclosure, total	[2]	1	2
Commodity contracts not subject to rate recovery, liabilities	[2]	(1)	(2)
Commodity contracts subject to rate recovery, liabilities	[2]	0	0
Liabilities fair value disclosure, total	[2]	$ (1)	$ (2)
[1]	Excludes cash balances and cash equivalents.
[2]	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.

FAIR VALUE MEASUREMENTS 4 (Deta

FAIR VALUE MEASUREMENTS 4 (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	$ 107,000,000	$ 99,000,000	$ 61,000,000
Realized and unrealized gains (losses)	(134,000,000)	15,000,000	11,000,000
Issuances	12,000,000	19,000,000	51,000,000
Settlements	34,000,000	(26,000,000)	(24,000,000)
Balance at end of period	19,000,000	107,000,000	99,000,000
Change in unrealized gains relating to instruments still held at the end of the period	(27,000,000)	8,000,000	$ 11,000,000
San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Congestion Revenue Rights	8	12
Market Electricity Forward Price Inputs	60.05
San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Congestion Revenue Rights	(16)	$ (6)
Market Electricity Forward Price Inputs	$ 21.45

FAIR VALUE MEASUREMENTS 5 (Deta

FAIR VALUE MEASUREMENTS 5 (Details) - USD ($)		3 Months Ended
		Sep. 30, 2015	Dec. 31, 2015
Fai rValue Inputs Assets Quantitative Information [Line Items]
Fair value measurement percentage, of level two hierarchy, for Rockies Express		100.00%
Investment in Energia Sierra Juarez	[1]	$ 26,000,000
Equity Method Investments [Member] | Market Approach Valuation Technique [Member]
Fai rValue Inputs Assets Quantitative Information [Line Items]
Investment in Energia Sierra Juarez			$ 30,000,000
Equity Method Investments [Member] | Market Approach Valuation Technique [Member] | Level 2 | One Hundred Percent [Member]
Fai rValue Inputs Assets Quantitative Information [Line Items]
Fair value inputs, equity sale offer price		100.00%
[1]	At measurement date of July 16, 2014. At December 31, 2015, our investment in Energía Sierra Juárez had a carrying value of $30 million, reflecting subsequent equity method activity to record distributions and earnings.

FAIR VALUE MEASUREMENTS 6 (Deta

FAIR VALUE MEASUREMENTS 6 (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method Investment, Other Than Temporary Impairment		$ (10)
Deconsolidation Gain Or Loss Amount	[1]			$ (60)	$ (40)
Energia Sierra Juarez Wind Project [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Gain on sale of assets, after tax			$ 14
Gain attributable to remeasurement, after tax			7
Proceeds from sale			26
Deconsolidation Gain Or Loss Amount			19
Net of Cash Sold			2
Proceeds from sale, net of cash sold			$ 24
[1]	Included in Gain on Sale of Equity Interests and Assets on our Consolidated Statements of Operations.

PREFERRED STOCK (Details)

PREFERRED STOCK (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Preferred Stock [Line Items]
Preferred Stock, Shares Authorized	50,000,000	50,000,000
San Diego Gas and Electric Company [Member]
Preferred Stock [Line Items]
Preferred Stock, Shares Authorized	45,000,000
Preferred stock redeemed			$ 82
Accrued preferred stock dividends at redemption date			1
Contingently redeemable preferred stock, call premium	$ 0	$ 0	$ 3
San Diego Gas and Electric Company [Member] | Maximum [Member]
Preferred Stock [Line Items]
Preferred Stock, Redemption Price Per Share			$ 20.25
San Diego Gas and Electric Company [Member] | Minimum [Member]
Preferred Stock [Line Items]
Preferred Stock, Redemption Price Per Share			$ 26
Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred Stock, Shares Authorized	1,000,000
So Cal Gas Series Preferred Stock [Member]
Preferred Stock [Line Items]
Preferred Stock, Shares Authorized	5,000,000
So Cal Gas Series Preferred Stock [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred Stock, Shares Authorized	5,000,000
Preferred Stock, Value, Outstanding	$ 22	22
Twenty Five Dollar Par, Six Percent Series [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred Stock, Par or Stated Value Per Share	$ 25
Preferred Stock, Shares Outstanding	79,011
Preferred Stock, Value, Outstanding	$ 3	3
Twenty Five Dollar Par, Six Percent Seriesa [Member] | Utility Subsidiaries [Member]
Preferred Stock [Line Items]
Preferred Stock, Shares Outstanding	783,032
Twenty Five Dollar Par, Six Percent Seriesa [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred Stock, Par or Stated Value Per Share	$ 25
Preferred Stock, Value, Outstanding	$ 19	19
Preferred Stock, Liquidation Preference Per Share	$ 25
So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member]
Preferred Stock [Line Items]
Preferred Stock, Value, Outstanding	$ (2)	(2)
So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred Stock, Shares Outstanding	50,970
Preferred Stock Of Subsidiaries [Member]
Preferred Stock [Line Items]
Preferred Stock, Value, Outstanding	$ 20	$ 20

SHAREHOLDERS' EQUITY AND EAR124

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015		Mar. 31, 2015		Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Earnings Per Share Numerator [Abstract]
Earnings	$ 369		$ 248		$ 295		$ 437		$ 297		$ 348		$ 269		$ 247		$ 1,349		$ 1,161		$ 1,001
Earnings Per Share Denominator [Abstract]
Weighted-average common shares outstanding for basic EPS	248,700		248,400		248,100		247,700		246,400		246,100		245,700		245,300		248,249	[1]	245,891	[1]	243,863	[1]
Vested RSUs Included In Basic WASO																	491		212		0
Dilutive effect of stock options, restricted stock awards and restricted stock units																	2,674		4,764		5,469
Weighted-average common shares outstanding for diluted EPS	251,500		251,000		251,500		251,200		251,300		250,800		250,100		249,700		250,923		250,655		249,332
Earnings Per Share [Abstract]
Basic earnings per common share	$ 1.48	[2]	$ 1	[2]	$ 1.19	[2]	$ 1.76	[2]	$ 1.21	[2]	$ 1.41	[2]	$ 1.1	[2]	$ 1.01	[2]	$ 5.43		$ 4.72		$ 4.1
Diluted earnings per common share	$ 1.47	[2]	$ 0.99	[2]	$ 1.17	[2]	$ 1.74	[2]	$ 1.18	[2]	$ 1.39	[2]	$ 1.08	[2]	$ 0.99	[2]	5.37		4.63		4.01
Dividends declared per share of common stock																	$ 2.8		$ 2.64		$ 2.52
San Diego Gas and Electric Company [Member]
Earnings Per Share Numerator [Abstract]
Earnings																	$ 587		$ 507		$ 411
Southern California Gas Company [Member]
Earnings Per Share Numerator [Abstract]
Earnings																	$ 420		$ 333		$ 365
[1]	Includes fully vested restricted stock units held in our Deferred Compensation Plan of 491 in 2015, 212 in 2014 and none in 2013. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.
[2]	Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.

SHAREHOLDERS' EQUITY AND EAR125

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 2 (Details) - shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Shares Excluded From Potential Dilutive Shares	1,968,062	949,351	641,751
Out Of The Money Stock Options [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	0	0	0
In The Money Stock Options [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	0	0	0
Restricted Stock [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	0	0	0
Restricted Stock Units
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	722	4,087	0

SHAREHOLDERS' EQUITY AND EAR126

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 3 (Details) - shares		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Common Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Common Stock, Shares Authorized		750,000,000	750,000,000
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract]
Preferred Stock, Shares Authorized		50,000,000	50,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Shares, Outstanding, Beginning Balance		246,330,884	244,461,327	242,368,836
Stock Issued During Period, Shares, Savings Plan Issuance		652,631	398,042	0
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period		227,815	699,783	1,237,348
Stock Issued During Period, Shares, Restricted Stock Award, Gross		0	0	21,121
Stock Issued During Period, Shares, Dividend Reinvestment Plan	[1]	249,665	205,203	0
Stock Issued During Period, Shares, Restricted Stock Units, Vesting	[2]	1,499,062	989,027	1,491,170
Stock Repurchased and Retired During Period, Shares	[3]	661,977	422,498	657,148
Common Stock, Shares, Outstanding, Ending Balance		248,298,080	246,330,884	244,461,327
[1]	Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares.
[2]	Includes dividend equivalents.
[3]	From time to time, we purchase shares of our common stock from long-term incentive plan participants who elect to sell to us a sufficient number of vested restricted shares or units to meet minimum statutory tax withholding requirements.

SHAREHOLDERS' EQUITY AND EAR127

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 5 (Details) - shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Performance Based Restricted Shares [Line Items]
Shares excluded from potential dilutive shares	1,968,062	949,351	641,751

SHAREHOLDERS' EQUITY AND EAR128

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 6 (Details)	12 Months Ended
	Dec. 31, 2015
Performance RSU Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SharebasedCompensation Arrangement By Share based Payment Award Award Vesting Rights Percentage	0.00%
Performance RSU Max Prior To 2014 [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SharebasedCompensation Arrangement By Share based Payment Award Award Vesting Rights Percentage	150.00%
Performance RSU Max In 2014 And After [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SharebasedCompensation Arrangement By Share based Payment Award Award Vesting Rights Percentage	200.00%
Service And Other Awards Max [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SharebasedCompensation Arrangement By Share based Payment Award Award Vesting Rights Percentage	100.00%

NUCLEAR PLANT RETIREMENT (Detai

NUCLEAR PLANT RETIREMENT (Details) - USD ($) $ in Millions	3 Months Ended					12 Months Ended	24 Months Ended	36 Months Ended
	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014	Jun. 30, 2013	Dec. 31, 2015	Dec. 31, 2017	Dec. 31, 2015	Feb. 01, 2012
SONGS Plant Investment [Line Items]
Regulatory Asset, Nuclear Plant Closure	$ 257					$ 257		$ 257
Regulatory Asset, Current, Nuclear Plant Closure	42					42		42
Regulatory Asset, Noncurrent, Nuclear Plant Closure	215					215		$ 215
Loss From Plant Closure, After Tax (cumulative)					$ 119	125
Plant closure (adjustment) loss, after tax	2	$ 13	$ 12	$ 9
Nuclear Plant, Return On Ratebase							2.35%	2.35%
Portion Of Weighted Average Return On Preferred Stock Included In Nuclear Plant Return On Ratebase									50.00%
Nuclear Plant, Net Book Investment, Steam Generator Replacement									$ 160
Authorized Recovery Of Replacement Power Purchase Costs						165
Other Commitments [Line Items]
Five-year research funding commitment, annual amount	1					1		$ 1
San Diego Gas and Electric Company [Member]
SONGS Plant Investment [Line Items]
Regulatory Asset, Nuclear Plant Closure	257					257		257
Regulatory Asset, Current, Nuclear Plant Closure	42					42		42
Regulatory Asset, Noncurrent, Nuclear Plant Closure	215					215		$ 215
Loss From Plant Closure, After Tax (cumulative)					$ 119	125
Plant closure (adjustment) loss, after tax	2	$ 13	$ 12	$ 9
Nuclear Plant, Return On Ratebase							2.35%	2.35%
Portion Of Weighted Average Return On Preferred Stock Included In Nuclear Plant Return On Ratebase									50.00%
Nuclear Plant, Net Book Investment, Steam Generator Replacement									$ 160
Authorized Recovery Of Replacement Power Purchase Costs						165
Other Commitments [Line Items]
Five-year research funding commitment, annual amount	$ 1					$ 1		$ 1

NUCLEAR PLANT RETIREMENT 2 (Det

NUCLEAR PLANT RETIREMENT 2 (Details) - USD ($) $ in Millions	1 Months Ended				12 Months Ended
	Nov. 30, 2015	Oct. 31, 2015	Aug. 31, 2015	Jul. 31, 2015	Dec. 31, 2015	Dec. 31, 2014
Nuclear Plant Decommissioning And Funding [Line Items]
Nuclear decommissioning trusts					$ 1,063	$ 1,131	[1]
Year 2013 [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Current Authorized Annual Recovery Amount, Nuclear Decommissioning Trust Funding				$ 55
Withdrawal From Nuclear Decommissioning Trust Funds			$ 37
Amount funded to customers through Energy Resource Recovery Account			34
Amount Pending IRS Clarification			18
Amount To Refund Regulatory Assets			3
Year 2014 [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Current Authorized Annual Recovery Amount, Nuclear Decommissioning Trust Funding	$ 36
Withdrawal From Nuclear Decommissioning Trust Funds					23
Amount funded to customers through Energy Resource Recovery Account					19
Amount Pending IRS Clarification					13
Amount To Refund Regulatory Assets					4
San Diego Gas and Electric Company [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Nuclear decommissioning trusts					1,063	$ 1,131	[2]
San Diego Gas and Electric Company [Member] | Year 2013 [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Current Authorized Annual Recovery Amount, Nuclear Decommissioning Trust Funding				$ 55
Withdrawal From Nuclear Decommissioning Trust Funds			37
Amount funded to customers through Energy Resource Recovery Account			34
Amount Pending IRS Clarification			18
Amount To Refund Regulatory Assets			$ 3
San Diego Gas and Electric Company [Member] | Year 2014 [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Current Authorized Annual Recovery Amount, Nuclear Decommissioning Trust Funding	$ 36
Withdrawal From Nuclear Decommissioning Trust Funds					23
Amount funded to customers through Energy Resource Recovery Account					19
Amount Pending IRS Clarification					13
Amount To Refund Regulatory Assets					$ 4
Nuclear Plant Entire Ownership [Member]
Nuclear Plant Settlement [Line Items]
Nuclear Plant, Insurance Recovery		$ 400
Nuclear Plant SDGE Ownership [Member]
Nuclear Plant Settlement [Line Items]
Nuclear Plant, Insurance Recovery		$ 80
Recovery Allocation Percentage		5.00%
To Ratepayers [Member]
Nuclear Plant Settlement [Line Items]
Nuclear Plant, Insurance Recovery		$ 75
Nuclear Plant, SDGE [Member]
Nuclear Plant [Line Items]
Nuclear Plant, Ownership Percentage					20.00%
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.

SONGS NDT (Details)

SONGS NDT (Details) $ in Millions	Dec. 31, 2015USD ($)
Nuclear Decommissioning [Line Items]
Asset Retirement Obligation, Nuclear Decommissioning Costs, Units 1, 2 and 3	$ 667
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	937
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study Escalated to 2015 Dollars	956
San Diego Gas and Electric Company [Member]
Nuclear Decommissioning [Line Items]
Asset Retirement Obligation, Nuclear Decommissioning Costs, Units 1, 2 and 3	667
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	937
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study Escalated to 2015 Dollars	$ 956

SONGS NDT 2 (Details)

SONGS NDT 2 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]
Cost		$ 660		$ 675
Gross unrealized gains		423		466
Gross unrealized losses		(20)		(10)
Estimated fair value		1,063		1,131
Proceeds from sales	[1]	577		601	$ 685
Gross realized gains		29		11	26
Gross realized losses		(15)		(11)	(18)
San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		660		675
Gross unrealized gains		423		466
Gross unrealized losses		(20)		(10)
Estimated fair value		1,063		1,131
Proceeds from sales	[1]	577		601	685
Gross realized gains		29		11	26
Gross realized losses		(15)		(11)	$ (18)
Total Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Cost		431		430
Gross unrealized gains		11		21
Gross unrealized losses		(13)		(6)
Estimated fair value		429		445
Total Debt Securities | San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		431		430
Gross unrealized gains		11		21
Gross unrealized losses		(13)		(6)
Estimated fair value		429		445
Debt Securities Issued By The U.S. Treasury And Other U.S. Government Corporations And Agencies
Schedule of Available-for-sale Securities [Line Items]
Cost		89	[2]	103
Gross unrealized gains		2	[2]	6
Gross unrealized losses		0	[2]	0
Estimated fair value		91	[2]	109
Debt Securities Issued By The U.S. Treasury And Other U.S. Government Corporations And Agencies | San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		89	[2]	103
Gross unrealized gains		2	[2]	6
Gross unrealized losses		0	[2]	0
Estimated fair value		91	[2]	109
Municipal Bonds
Schedule of Available-for-sale Securities [Line Items]
Cost		148	[3]	121
Gross unrealized gains		8	[3]	8
Gross unrealized losses		0	[3]	0
Estimated fair value		156	[3]	129
Municipal Bonds | San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		148	[3]	121
Gross unrealized gains		8	[3]	8
Gross unrealized losses		0	[3]	0
Estimated fair value		156		129
Other Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Cost		194	[3]	206
Gross unrealized gains		1	[3]	7
Gross unrealized losses		(13)	[3]	(6)
Estimated fair value		182	[3]	207
Other Debt Securities | San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		194	[3]	206
Gross unrealized gains		1	[3]	7
Gross unrealized losses		(13)	[3]	(6)
Estimated fair value		182	[3]	207
Equity Securities
Schedule of Available-for-sale Securities [Line Items]
Cost		214		215
Gross unrealized gains		412		444
Gross unrealized losses		(7)		(4)
Estimated fair value		619		655
Equity Securities | San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		214		215
Gross unrealized gains		412		444
Gross unrealized losses		(7)		(4)
Estimated fair value		619		655
Cash And Cash Equivalents
Schedule of Available-for-sale Securities [Line Items]
Cost		15		30
Gross unrealized gains		0		1
Gross unrealized losses		0		0
Estimated fair value		15		31
Cash And Cash Equivalents | San Diego Gas and Electric Company [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost		15		30
Gross unrealized gains		0		1
Gross unrealized losses		0		0
Estimated fair value		$ 15		$ 31
[1]	Excludes securities that are held to maturity.
[2]	Maturity dates are 2016-2065.
[3]	Maturity dates are 2016-2115.

SONGS NDT 3 (Details)

SONGS NDT 3 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule Of Sales Of Securities [Line Items]
Proceeds from sales	[1]	$ 577	$ 601	$ 685
Gross realized gains		29	11	26
Gross realized losses		(15)	(11)	(18)
San Diego Gas and Electric Company [Member]
Schedule Of Sales Of Securities [Line Items]
Proceeds from sales	[1]	577	601	685
Gross realized gains		29	11	26
Gross realized losses		$ (15)	$ (11)	$ (18)
[1]	Excludes securities that are held to maturity.

CALIFORNIA UTILITIES' REGULA134

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 1 (Details) $ in Millions	Dec. 31, 2015USD ($)
San Diego Gas and Electric Company [Member]
Energy Resource Recovery Account [Line Items]
Authorized Energy Resource Recovery Revenue Requirement Trigger Increase Through Year End 2015	$ 221
Approved 2016 Energy Resource Recovery Revenue Requirement	1,300
Revenue Requirement Increase	$ 43
Cost Of Capital [Line Items]
Cost Of Capital Authorized Return On Rate Base	7.79%
Cost Of Capital Average Benchmark Rate	4.04%
Cost Of Capital Benchmark Rate	4.24%
Cost Of Capital Floor Rate	3.24%
Cost Of Capital Ceiling Rate	5.24%
San Diego Gas and Electric Company [Member] | Capital Structure, Long Term Debt [Member]
Cost Of Capital [Line Items]
Cost of Capital Authorized Weighting	45.25%
Cost of Capital Authorized Rate of Recovery	5.00%
Cost of Capital Weighted Authorized Return On Rate Base	2.26%
San Diego Gas and Electric Company [Member] | Capital Structure, Preferred Stock [Member]
Cost Of Capital [Line Items]
Cost of Capital Authorized Weighting	2.75%
Cost of Capital Authorized Rate of Recovery	6.22%
Cost of Capital Weighted Authorized Return On Rate Base	0.17%
San Diego Gas and Electric Company [Member] | Capital Structure, Common Equity [Member]
Cost Of Capital [Line Items]
Cost of Capital Authorized Weighting	52.00%
Cost of Capital Authorized Rate of Recovery	10.30%
Cost of Capital Weighted Authorized Return On Rate Base	5.36%
Southern California Gas Company [Member]
Cost Of Capital [Line Items]
Cost Of Capital Authorized Return On Rate Base	8.02%
Cost Of Capital Average Benchmark Rate	4.04%
Cost Of Capital Benchmark Rate	4.24%
Cost Of Capital Floor Rate	3.24%
Cost Of Capital Ceiling Rate	5.24%
Southern California Gas Company [Member] | Capital Structure, Long Term Debt [Member]
Cost Of Capital [Line Items]
Cost of Capital Authorized Weighting	45.60%
Cost of Capital Authorized Rate of Recovery	5.77%
Cost of Capital Weighted Authorized Return On Rate Base	2.63%
Southern California Gas Company [Member] | Capital Structure, Preferred Stock [Member]
Cost Of Capital [Line Items]
Cost of Capital Authorized Weighting	2.40%
Cost of Capital Authorized Rate of Recovery	6.00%
Cost of Capital Weighted Authorized Return On Rate Base	0.14%
Southern California Gas Company [Member] | Capital Structure, Common Equity [Member]
Cost Of Capital [Line Items]
Cost of Capital Authorized Weighting	52.00%
Cost of Capital Authorized Rate of Recovery	10.10%
Cost of Capital Weighted Authorized Return On Rate Base	5.25%

CALIFORNIA UTILITIES' REGULA135

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 2 (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2015	Dec. 31, 2012	Dec. 31, 2014
San Diego Gas and Electric Company [Member]
FERC Electric Transmission Formula Rate Filing [Line Items]
Authorized FERC Return On Equity			10.05%
FERC Return On Equity Requested			11.30%
San Diego Gas and Electric Company [Member] | Year 2012 [Member]
General Rate Case [Line Items]
General Rate Case, Regulatory Asset					$ 162
Incremental Earnings Impact		$ 17		$ 52
Cumulative Earnings Impact	$ 69
San Diego Gas and Electric Company [Member] | Year 2016 [Member]
General Rate Case [Line Items]
General Rate Case, Revenue Requirement, Revised Request			$ 1,811
General Rate Case, Revenue Requirement Increase, Original Request			133
General Rate Case, Revenue Requirement Increase, Revised Request			$ 17
General Rate Case, Revenue Requirement Percentage Increase, Revised Request			1.00%
General Rate Case, Revised Request Decrease Compared To Original			$ (100)
General Rate Case, Adjustment To Decrease Estimated Revenue Requirement			16
General Rate Case, Proposed Rate Base Adjustment			93
General Rate Case, Tax Memorandum Accounts Balance			$ 39
San Diego Gas and Electric Company [Member] | Year 2017 [Member]
General Rate Case [Line Items]
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)			3.50%
San Diego Gas and Electric Company [Member] | Year 2018 [Member]
General Rate Case [Line Items]
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)			3.50%
San Diego Gas and Electric Company [Member] | Year 2019 [Member]
General Rate Case [Line Items]
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)			4.30%
San Diego Gas and Electric Company [Member] | Years 2011 Through 2013 [Member]
Renewable Portfolio Standards [Line Items]
Proportion Annual Energy Requirements From Renewable Energy Sources			20.00%
Limit Total Penalties For Failure To Comply With Renewable Standards			$ 75
San Diego Gas and Electric Company [Member] | Years 2014 Through 2016 [Member]
Renewable Portfolio Standards [Line Items]
Proportion Annual Energy Requirements From Renewable Energy Sources			25.00%
Limit Total Penalties For Failure To Comply With Renewable Standards			$ 75
San Diego Gas and Electric Company [Member] | Years 2017 Through 2020 [Member]
Renewable Portfolio Standards [Line Items]
Proportion Annual Energy Requirements From Renewable Energy Sources			33.00%
Limit Total Penalties For Failure To Comply With Renewable Standards			$ 100
San Diego Gas and Electric Company [Member] | Years 2021 And After [Member]
Renewable Portfolio Standards [Line Items]
Limit Total Penalties For Failure To Comply With Renewable Standards			$ 25
San Diego Gas and Electric Company [Member] | Year 2024 [Member]
Renewable Portfolio Standards [Line Items]
Proportion Annual Energy Requirements From Renewable Energy Sources			40.00%
San Diego Gas and Electric Company [Member] | Year 2027 [Member]
Renewable Portfolio Standards [Line Items]
Proportion Annual Energy Requirements From Renewable Energy Sources			45.00%
San Diego Gas and Electric Company [Member] | Year 2030 [Member]
Renewable Portfolio Standards [Line Items]
Proportion Annual Energy Requirements From Renewable Energy Sources			50.00%
Southern California Gas Company [Member] | Year 2012 [Member]
General Rate Case [Line Items]
General Rate Case, Regulatory Asset					$ 52
Incremental Earnings Impact		$ 12		$ 25
Cumulative Earnings Impact	$ 37
Southern California Gas Company [Member] | Year 2016 [Member]
General Rate Case [Line Items]
General Rate Case, Revenue Requirement, Revised Request			$ 2,219
General Rate Case, Revenue Requirement Increase, Original Request			256
General Rate Case, Revenue Requirement Increase, Revised Request			$ 122
General Rate Case, Revenue Requirement Percentage Increase, Revised Request			6.00%
General Rate Case, Revised Request Decrease Compared To Original			$ (133)
General Rate Case, Proposed Rate Base Adjustment			92
General Rate Case, Tax Memorandum Accounts Balance			$ 74
Southern California Gas Company [Member] | Year 2017 [Member]
General Rate Case [Line Items]
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)			3.50%
Southern California Gas Company [Member] | Year 2018 [Member]
General Rate Case [Line Items]
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)			3.50%
Southern California Gas Company [Member] | Year 2019 [Member]
General Rate Case [Line Items]
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)			4.30%

CALIFORNIA UTILITIES' REGULA136

CALIFORNIA UTILITIES' REGULATORY MATTERS - UTILITY INCENTIVE AWARDS (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
San Diego Gas and Electric Company [Member] | Year 2012 and 2013 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards		$ 7,500
San Diego Gas and Electric Company [Member] | Year 2011 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards			$ 3,900
San Diego Gas and Electric Company [Member] | Year 2013 and 2014 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards	$ 6,500
San Diego Gas and Electric Company [Member] | Year 2006 Through 2008 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards	16,200
Southern California Gas Company [Member] | Year 2012 and 2013 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards		5,900
Southern California Gas Company [Member] | Year 2011 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards			3,100
Southern California Gas Company [Member] | Year 2013 and 2014 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards	4,200
Southern California Gas Company [Member] | Year 2006 Through 2008 [Member]
Energy Efficiency Awards [Line Items]
Approved Energy Efficiency Awards	17,300
Southern California Gas Company [Member] | Year Ending March 31, 2012 [Member]
Utility Incentive Awards [Line Items]
Approved And Recognized Gas Cost Incentive Mechanism Award			$ 5,400
Southern California Gas Company [Member] | Year Ending March 31, 2013 [Member]
Utility Incentive Awards [Line Items]
Approved And Recognized Gas Cost Incentive Mechanism Award		$ 5,800
Southern California Gas Company [Member] | Year Ending March 31, 2014 [Member]
Utility Incentive Awards [Line Items]
Approved And Recognized Gas Cost Incentive Mechanism Award	13,700
Southern California Gas Company [Member] | Year Ending March 31, 2015 [Member]
Utility Incentive Awards [Line Items]
Approved And Recognized Gas Cost Incentive Mechanism Award	$ 7,250

CALIFORNIA UTILITIES' REGULA137

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF UTILITY PROJECTS (Details) $ in Thousands	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 11, 2014USD ($)
Pipeline Safety Phase 1 [Member]
Schedule Of Utility Projects [Line Items]
Revised Estimated Project Cost	$ 2,100,000
Pipeline Safety Phase 1 [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax	500
Revised Estimated Project Cost	500,000
Pipeline Safety Plan Regulatory Account	10,000		$ 100
Recovery Requested, PSEP Costs	100
Pipeline Safety Phase 1 [Member] | Southern California Gas Company [Member]
Schedule Of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax	3,200	$ 5,000
Revised Estimated Project Cost	1,600,000
Pipeline Safety Plan Regulatory Account	162,000		$ 46,000
Recovery Requested, PSEP Costs	26,800
ORA Recommended Disallowance	11,100
ORA Recommended Recovery	15,700
TURN Recommended Disallowance	2,300
TURN Recommended Recovery	24,500
South Orange County Reliability Enhancement [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Upper Range	400,000
Estimated Project Cost, Lower Range	350,000
Cleveland National Forest Transmissions Projects [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Upper Range	450,000
Estimated Project Cost, Lower Range	400,000
South Bay Substation And Relocation [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Upper Range	175,000
Estimated Project Cost, Lower Range	145,000
Southern Gas System Reliability Project [Member] | Utility Subsidiaries [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Upper Range	850,000
Estimated Project Cost, Lower Range	800,000
Sycamore Penasquitos Transmission Project [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Upper Range	150,000
Estimated Project Cost, Lower Range	120,000
Revised Estimated Project Cost, Upper Range	300,000
Revised Estimated Project Cost, Lower Range	250,000
Electric Vehicle Charging Program [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost	103,000
Estimated Capital Investment	59,000
Revised Estimated Project Cost	$ 45,000
Number Of Charging Stations Requested	5,500
Number Of Charging Stations Authorized	3,500
Pipeline Safety And Reliability Project [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost	$ 600,000
Wildfire Cost Recovery [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
WEMA Balance	42,000
Incurred Costs	2,400,000
Requested Recovery	379,000
Insurance Reimbursement	1,100,000
Third Party Settlement Recoveries	824,000
FERC Jurisdictional Rates	$ 80,000
Voluntary Shareholder Contribution, Percentage	10.00%

CALIFORNIA UTILITIES' REGULA138

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF UTILITY PROJECTS 2 (Details) - Sunrise Powerlink Electric Transmission Line [Member] - San Diego Gas and Electric Company [Member] $ in Thousands	Dec. 31, 2015USD ($)
Schedule Of Utility Projects [Line Items]
Final Status Report	$ 1,887,400
2008 CPUC Approval Decision	1,883,000
Difference	4,400
Construction Costs And AFUDC [Member]
Schedule Of Utility Projects [Line Items]
Final Status Report	1,490,900
2008 CPUC Approval Decision	1,594,200
Difference	(103,300)
Undergrounding On Alpine Boulevard [Member]
Schedule Of Utility Projects [Line Items]
Final Status Report	11,700
2008 CPUC Approval Decision	91,000
Difference	(79,300)
Undergrounding Savings Per Quarter Mile	11,000
Mitigation And Monitoring Costs [Member]
Schedule Of Utility Projects [Line Items]
Final Status Report	384,800
2008 CPUC Approval Decision	197,800
Difference	$ 187,000

CALIFORNIA UTILITIES' REGULA139

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 3 (Details) - Southern California Gas Company [Member] - USD ($) $ in Thousands

3 Months Ended

12 Months Ended

Dec. 31, 2015

Sep. 30, 2015

Jun. 30, 2015

Mar. 31, 2015

Dec. 31, 2015

Dec. 31, 2014

[2]

Dec. 31, 2013

[2]

Dec. 31, 2012

[2]

Impact Of 2010 Tax Act [Line Items]

Increase Due To Bonus Depreciation Extension, Net Of Tax

$ 1,100

$ 600

$ 800

$ 1,400

$ 3,900

[1]

$ 3,800

$ 3,700

$ 3,800

Increase Due To Bonus Depreciation Extension, Before Tax

6,600

[1]

$ 6,400

$ 6,300

$ 6,400

Total Increase Due To Bonus Depreciation Extension, Net Of Tax

15,200

Total Increase Due To Bonus Depreciation Extension, Before Tax

$ 25,700

[1]

The approved increase to after-tax earnings for the first and second quarters of 2015 of $1.4 million and $0.8 million, respectively, was recorded in the second quarter of 2015. The approved increase to after-tax earnings for the third and fourth quarters of 2015 of $0.6 million and $1.1 million, respectively, was recorded in the respective quarters.

[2]

The approved increase to after-tax earnings was recorded in the second quarter of 2015.

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LONG-TERM PURCHASE COMMITMENT (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
S D G E Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		$ 67
Contractual Commitments, Payments Due In Two Years		46
Contractual Commitments, Payments Due In Three Years		12
Contractual Commitments, Payments Due In Four Years		17
Contractual Commitments, Payments Due In Five Years		5
Unrecorded Unconditional Purchase Obligation, Due after Five Years		10
Long-term Purchase Commitment, Amount		$ 157
Contractual Commitment Number of Years		30
Proceeds From Long Term Transmission Agreement		$ 85
Natural Gas Contracts [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current	[1]	358
Contractual Commitments, Payments Due In Two Years	[1]	345
Contractual Commitments, Payments Due In Three Years	[1]	302
Contractual Commitments, Payments Due In Four Years	[1]	155
Contractual Commitments, Payments Due In Five Years	[1]	51
Unrecorded Unconditional Purchase Obligation, Due after Five Years	[1]	199
Contractual Commitments, Payments Due, Total	[1]	1,410
Long-term Purchase Commitment, Payments In Period		1,200	$ 1,984	$ 1,680
Natural Gas Contracts [Member] | So Cal Gas Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		127
Contractual Commitments, Payments Due In Two Years		115
Contractual Commitments, Payments Due In Three Years		93
Contractual Commitments, Payments Due In Four Years		49
Contractual Commitments, Payments Due In Five Years		24
Unrecorded Unconditional Purchase Obligation, Due after Five Years		105
Contractual Commitments, Payments Due, Total		513
Long-term Purchase Commitment, Payments In Period		975	1,735	1,464
Natural Gas Transportation Contracts [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		258
Contractual Commitments, Payments Due In Two Years		243
Contractual Commitments, Payments Due In Three Years		217
Contractual Commitments, Payments Due In Four Years		150
Contractual Commitments, Payments Due In Five Years		46
Unrecorded Unconditional Purchase Obligation, Due after Five Years		186
Contractual Commitments, Payments Due, Total		1,100
Natural Gas Transportation Contracts [Member] | So Cal Gas Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		127
Contractual Commitments, Payments Due In Two Years		114
Contractual Commitments, Payments Due In Three Years		92
Contractual Commitments, Payments Due In Four Years		48
Contractual Commitments, Payments Due In Five Years		23
Unrecorded Unconditional Purchase Obligation, Due after Five Years		105
Contractual Commitments, Payments Due, Total		509
Natural Gas Supply Contracts [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current	[1]	100
Contractual Commitments, Payments Due In Two Years	[1]	102
Contractual Commitments, Payments Due In Three Years	[1]	85
Contractual Commitments, Payments Due In Four Years	[1]	5
Contractual Commitments, Payments Due In Five Years	[1]	5
Unrecorded Unconditional Purchase Obligation, Due after Five Years	[1]	13
Contractual Commitments, Payments Due, Total	[1]	310
Natural Gas Supply Contracts [Member] | So Cal Gas Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		0
Contractual Commitments, Payments Due In Two Years		1
Contractual Commitments, Payments Due In Three Years		1
Contractual Commitments, Payments Due In Four Years		1
Contractual Commitments, Payments Due In Five Years		1
Unrecorded Unconditional Purchase Obligation, Due after Five Years		0
Contractual Commitments, Payments Due, Total		4
Purchased Power Contracts [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		741
Contractual Commitments, Payments Due In Two Years		726
Contractual Commitments, Payments Due In Three Years		781
Contractual Commitments, Payments Due In Four Years		776
Contractual Commitments, Payments Due In Five Years		720
Unrecorded Unconditional Purchase Obligation, Due after Five Years		7,169
Contractual Commitments, Payments Due, Total	[2]	10,913
Long-term Purchase Commitment, Payments In Period		1,573	1,574	1,377
Purchased Power Contracts [Member] | S D G E Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		521
Contractual Commitments, Payments Due In Two Years		504
Contractual Commitments, Payments Due In Three Years		502
Contractual Commitments, Payments Due In Four Years		493
Contractual Commitments, Payments Due In Five Years		430
Unrecorded Unconditional Purchase Obligation, Due after Five Years		6,071
Contractual Commitments, Payments Due, Total	[2]	8,521
Long-term Purchase Commitment, Payments In Period	[3]	$ 715	$ 710	$ 570
Sunrise Powerlink Construction [Member] | S D G E Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitment Annual Escalation Percentage		2.00%
Contractual Commitment Number of Years		54
Contractual Commitment Future Annual Payment Amount		$ 3
Contractual Commitment Present Value Future Payments, Regulatory Asset		117
Contractual Commitment Future Payments, Liability		117
Liquefied Natural Gas Contracts [Member] | Sempra Natural Gas Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		330
Contractual Commitments, Payments Due In Two Years		432
Contractual Commitments, Payments Due In Three Years		456
Contractual Commitments, Payments Due In Four Years		487
Contractual Commitments, Payments Due In Five Years		534
Unrecorded Unconditional Purchase Obligation, Due after Five Years		5,524
Contractual Commitments, Payments Due, Total		7,763
Nuclear Plant Maintenance [Member] | San Diego Gas and Electric Company [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount		18
Infrastructure Construction And Improvements [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		1,200
Contractual Commitments, Payments Due In Two Years		53
Contractual Commitments, Payments Due In Three Years		12
Contractual Commitments, Payments Due In Four Years		17
Contractual Commitments, Payments Due In Five Years		5
Unrecorded Unconditional Purchase Obligation, Due after Five Years		10
Long-term Purchase Commitment, Amount		1,300
Infrastructure Construction And Improvements [Member] | S D G E Segment [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Amount		78
Infrastructure Construction And Improvements [Member] | Southern California Gas Company [Member] | So Cal Gas Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		11
Contractual Commitments, Payments Due In Two Years		7
Contractual Commitments, Payments Due, Total		$ 18
Long-term Contracts [Member] | San Diego Gas and Electric Company [Member]
Long-term Purchase Commitment [Line Items]
Purchase Commitment Component Percentage		38.00%
Other Owned Generation [Member] | San Diego Gas and Electric Company [Member]
Long-term Purchase Commitment [Line Items]
Purchase Commitment Component Percentage		56.00%
Spot Market Purchases [Member] | San Diego Gas and Electric Company [Member]
Long-term Purchase Commitment [Line Items]
Purchase Commitment Component Percentage		6.00%
Renewable Energy Contracts Expiring Through 2041 [Member] | San Diego Gas and Electric Company [Member]
Long-term Purchase Commitment [Line Items]
Purchase Commitment Component Percentage		33.00%
Sempra Renewables Construction [Member] | Sempra Renewables Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		$ 754
Contractual Commitments, Payments Due, Total		754
Sempra Rockies Marketing [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		13
Contractual Commitments, Payments Due In Two Years		14
Contractual Commitments, Payments Due In Three Years		34
Contractual Commitments, Payments Due In Four Years		67
Sempra Natural Gas Construction [Member] | Sempra Natural Gas Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		56
Contractual Commitments, Payments Due, Total		56
San Luis Rey Synchronous Condensor And Bay Boulevard Substation [Member] | S D G E Segment [Member]
Long-term Purchase Commitment [Line Items]
Long-term Purchase Commitment, Payments In Period		61
Sonora Pipeline [Member] | Sempra Mexico Segment [Member]
Long-term Purchase Commitment [Line Items]
Contractual Commitments, Payments Due, Current		264
Contractual Commitments, Payments Due, Total		$ 264
[1]	Excludes amounts related to LNG purchase agreements discussed below.
[2]	Excludes purchase agreements accounted for as capital leases and amounts related to Otay Mesa VIE, as it is consolidated by Sempra Energy and SDG&E.
[3]	Excludes DWR-allocated contracts. Under an operating agreement with the DWR that expired at the end of 2013, SDG&E acted as a limited agent on behalf of the DWR in the administration of energy contracts, including natural gas procurement functions under the DWR contracts allocated to SDG&E's customers. The commodity costs associated with these contracts are not included in SDG&E's or Sempra Energy's Consolidated Statements of Operations.

COMMITMENTS AND CONTINGENCIE141

COMMITMENTS AND CONTINGENCIES - CAPITAL LEASES (Details)		12 Months Ended
		Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2012USD ($)
Capital Lease Obligations [Abstract]
Capital lease obligations		$ 387,000,000	$ 310,000,000
HQ Build To Suit Lease [Member]
Capital Lease Obligations [Abstract]
Capital Lease Term (Years)		25
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments		$ 136,000,000
Capital Leases, Future Minimum Payments Due [Abstract]
Capital Leases, Future Minimum Payments Due, Current		10,000,000
Capital Leases, Future Minimum Payments Due in Two Years		10,000,000
Capital Leases, Future Minimum Payments Due in Three Years		10,000,000
Capital Leases, Future Minimum Payments Due in Four Years		10,000,000
Capital Leases, Future Minimum Payments Due in Five Years		11,000,000
Capital Leases, Future Minimum Payments Due Thereafter		256,000,000
Capital Leases, Future Minimum Payments Due, Total		307,000,000
Utility Fleet Leases [Member]
Capital Leases, Income Statement of Lessee [Abstract]
Capital Leases, Income Statement, Amortization Expense		4,000,000	4,000,000	$ 7,000,000
Power Purchase Agreements [Member]
Capital Leases, Future Minimum Payments Due [Abstract]
Capital Leases, Future Minimum Payments Due, Current		39,000,000
Capital Leases, Future Minimum Payments Due in Two Years		77,000,000
Capital Leases, Future Minimum Payments Due in Three Years		104,000,000
Capital Leases, Future Minimum Payments Due in Four Years		104,000,000
Capital Leases, Future Minimum Payments Due in Five Years		104,000,000
Capital Leases, Future Minimum Payments Due Thereafter		1,910,000,000
Capital Leases, Future Minimum Payments Due, Total	[1]	2,338,000,000
Capital Leases, Future Minimum Payments, Executory Costs		(523,000,000)
Capital Leases, Future Minimum Payments, Interest Included in Payments	[2]	(1,072,000,000)
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments, Total	[3]	743,000,000
Capital Leases, Current portion		4,000,000
Capital leases, Noncurrent portion		239,000,000
South American Utilities Fleet And Other Leases [Member]
Capital Lease Obligations [Abstract]
Capital lease obligations		6,000,000
Fleet And Other Capital Leases [Member]
Capital Leases, Future Minimum Payments Due [Abstract]
Capital Leases, Future Minimum Payments Due, Current		4,000,000
Capital Leases, Future Minimum Payments Due in Two Years		2,000,000
Capital Leases, Future Minimum Payments Due in Three Years		1,000,000
Capital Leases, Future Minimum Payments Due Thereafter		8,000,000
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments, Total		8,000,000
San Diego Gas and Electric Company [Member]
Capital Lease Obligations [Abstract]
Capital lease obligations		244,000,000	234,000,000
San Diego Gas and Electric Company [Member] | Utility Fleet Leases [Member]
Capital Lease Obligations [Abstract]
Capital lease obligations		1,000,000
Capital Leases, Income Statement of Lessee [Abstract]
Capital Leases, Income Statement, Amortization Expense		2,000,000	2,000,000	4,000,000
San Diego Gas and Electric Company [Member] | Power Purchase Agreements [Member]
Capital Lease Obligations [Abstract]
Capital lease obligations		$ 243,000,000
Capital Lease Term (Years)		25
Capital Leases, Income Statement of Lessee [Abstract]
Capital Leases, Income Statement, Amortization Expense		$ 4,000,000	3,000,000	2,000,000
Leases, Capital [Abstract]
Number Of Power Purchase Agreements With Peaker Facilities, Capital Leases		4
Number Of Power Purchase Agreements With Peaker Facilities In Commercial Operation In 2015		1
San Diego Gas and Electric Company [Member] | Pending Power Purchase Agreement With Peaker Facilities, Capital Lease [Member]
Capital Lease Obligations [Abstract]
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments		$ 500,000,000
San Diego Gas and Electric Company [Member] | Purchase Power Agreements With 25 Year Term [Member]
Capital Lease Obligations [Abstract]
Capital Lease Term (Years)		25
San Diego Gas and Electric Company [Member] | Purchase Power Agreements With 9 Year Term [Member]
Capital Lease Obligations [Abstract]
Capital Lease Term (Years)		9
Southern California Gas Company [Member]
Capital Lease Obligations [Abstract]
Capital lease obligations		$ 1,000,000	1,000,000
Southern California Gas Company [Member] | Utility Fleet Leases [Member]
Capital Lease Obligations [Abstract]
Capital lease obligations		1,000,000
Capital Leases, Income Statement of Lessee [Abstract]
Capital Leases, Income Statement, Amortization Expense		$ 2,000,000	$ 2,000,000	$ 3,000,000
[1]	This amount will be recorded over the lives of the leases as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs, which are recovered in rates.
[2]	Amount necessary to reduce net minimum lease payments to present value at the inception of the leases.
[3]	Includes $4 million in Current Portion of Long-Term Debt and $239 million in Long-Term Debt on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets at December 31, 2015. Of the present value of net minimum lease payments, $500 million will be recorded as a capital lease obligation when construction of the peaker plant facility is completed and delivery of contracted power commences, which is scheduled to occur in June 2017.

COMMITMENTS AND CONTINGENCIE142

COMMITMENTS AND CONTINGENCIES - OPERATING LEASES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating Leases, Rent Expense [Abstract]
Operating Leases, Rent Expense	$ 78	$ 78	$ 81
Operating Leases, Future Minimum Payments Due [Abstract]
Operating Leases, Future Minimum Payments Due, Current	71
Operating Leases, Future Minimum Payments, Due in Two Years	71
Operating Leases, Future Minimum Payments, Due in Three Years	63
Operating Leases, Future Minimum Payments, Due in Four Years	57
Operating Leases, Future Minimum Payments, Due in Five Years	50
Operating Leases, Future Minimum Payments, Due Thereafter	283
Operating Leases, Future Minimum Payments Due, Total	$ 595
Operating Leases, Annual Rent Escalation [Abstract]
Operating Leases, Annual Rent Escalation, Range, Minimum	2.00%
Operating Leases, Annual Rent Escalation, Range, Maximum	5.00%
Utility Subsidiaries [Member]
Operating Leases, Future Minimum Payments Due [Abstract]
Operating Leases, Aggregate Maximum Lease Limit	$ 150
Operating Leases, Lease Limit Utilized	111
San Diego Gas and Electric Company [Member]
Operating Leases, Rent Expense [Abstract]
Operating Leases, Rent Expense	27	26	23
Operating Leases, Future Minimum Payments Due [Abstract]
Operating Leases, Future Minimum Payments Due, Current	25
Operating Leases, Future Minimum Payments, Due in Two Years	25
Operating Leases, Future Minimum Payments, Due in Three Years	19
Operating Leases, Future Minimum Payments, Due in Four Years	18
Operating Leases, Future Minimum Payments, Due in Five Years	16
Operating Leases, Future Minimum Payments, Due Thereafter	70
Operating Leases, Future Minimum Payments Due, Total	$ 173
Operating Leases, Annual Rent Escalation [Abstract]
Operating Leases, Annual Rent Escalation, Range, Minimum	2.00%
Operating Leases, Annual Rent Escalation, Range, Maximum	5.00%
Southern California Gas Company [Member]
Operating Leases, Rent Expense [Abstract]
Operating Leases, Rent Expense	$ 39	$ 38	$ 31
Operating Leases, Future Minimum Payments Due [Abstract]
Operating Leases, Future Minimum Payments Due, Current	38
Operating Leases, Future Minimum Payments, Due in Two Years	39
Operating Leases, Future Minimum Payments, Due in Three Years	36
Operating Leases, Future Minimum Payments, Due in Four Years	33
Operating Leases, Future Minimum Payments, Due in Five Years	28
Operating Leases, Future Minimum Payments, Due Thereafter	131
Operating Leases, Future Minimum Payments Due, Total	$ 305
Operating Leases, Annual Rent Escalation [Abstract]
Operating Leases, Annual Rent Escalation, Range, Minimum	2.00%
Operating Leases, Annual Rent Escalation, Range, Maximum	5.00%

COMMITMENTS AND CONTINGENCIE143

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Environmental Issues [Line Items]
Environmental Costs Recognized, Capitalized in Period	[1]	$ 64	$ 45	$ 31
San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Environmental Costs Recognized, Capitalized in Period		24	23	13
Southern California Gas Company [Member]
Environmental Issues [Line Items]
Environmental Costs Recognized, Capitalized in Period		$ 39	$ 21	$ 15
[1]	In cases of non-wholly owned affiliates, includes only our share.

COMMITMENTS AND CONTINGENCIE144

COMMITMENTS AND CONTINGENCIES - SITE CONTINGENCY (Details)	12 Months Ended
	Dec. 31, 2015USD ($)
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 45,100,000	[1]
Accrued Environmental Loss Contingencies, Current	24,000,000
Accrued Environmental Loss Contingencies, Noncurrent	21,000,000
Site Contingency, S D G E [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	2,100,000	[1],[2]
Estimated SONGS mitigation costs, recoverable in rates	14,000,000
Accrued Environmental Loss Contingencies, Current	1,000,000
Accrued Environmental Loss Contingencies, Noncurrent	1,000,000
Site Contingency, So Cal Gas [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	25,100,000	[1],[3]
Accrued Environmental Loss Contingencies, Current	6,000,000
Accrued Environmental Loss Contingencies, Noncurrent	19,000,000
Site Contingency, Other Sempra Energy [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	17,900,000	[1]
Manufactured Gas Sites [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	24,900,000
Manufactured Gas Sites [Member] | Site Contingency, S D G E [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 0	[2]
Site Contingency, Sites Completed	3	[4]
Site Contingency, Sites In Process	0
Manufactured Gas Sites [Member] | Site Contingency, So Cal Gas [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 23,100,000	[3]
Site Contingency, Sites Completed	39	[4]
Site Contingency, Sites In Process	3
Manufactured Gas Sites [Member] | Site Contingency, Other Sempra Energy [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 1,800,000
Waste Disposal Sites [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	4,000,000	[5]
Waste Disposal Sites [Member] | Site Contingency, S D G E [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 900,000	[2],[5]
Site Contingency, Sites Completed	2	[4]
Site Contingency, Sites In Process	1
Waste Disposal Sites [Member] | Site Contingency, So Cal Gas [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 2,000,000	[3],[5]
Site Contingency, Sites Completed	5	[4]
Site Contingency, Sites In Process	2
Waste Disposal Sites [Member] | Site Contingency, Other Sempra Energy [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 1,100,000	[5]
Former Fossil Fueled Power Plants [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	700,000
Former Fossil Fueled Power Plants [Member] | Site Contingency, S D G E [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	700,000	[2]
Former Fossil Fueled Power Plants [Member] | Site Contingency, So Cal Gas [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	0	[3]
Former Fossil Fueled Power Plants [Member] | Site Contingency, Other Sempra Energy [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	0
Other Hazardous Waste Sites [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	15,500,000
Other Hazardous Waste Sites [Member] | Site Contingency, S D G E [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	500,000	[2]
Other Hazardous Waste Sites [Member] | Site Contingency, So Cal Gas [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	0	[3]
Other Hazardous Waste Sites [Member] | Site Contingency, Other Sempra Energy [Member]
Site Contingency [Line Items]
Site Contingency, Accrual, Undiscounted Amount	$ 15,000,000
[1]	Sempra Energy, SDG&E and SoCalGas have accrued $45 million, $2 million and $25 million, respectively, for environmental liabilities as of December 31, 2015. Of these amounts, $24 million, $1 million and $6 million were classified as current liabilities, and $21 million, $1 million and $19 million were classified as noncurrent liabilities on Sempra Energy’s, SDG&E’s and SoCalGas’ Consolidated Balance Sheets, respectively.
[2]	Does not include SDG&E’s liability for SONGS marine mitigation.
[3]	Does not include any SoCalGas accrued liabilities for environmental matters for the natural gas leak at the Aliso Canyon facility. We discuss matters related to the leak above under "Legal Proceedings – SoCalGas – Aliso Canyon Natural Gas Storage Facility Gas Leak."
[4]	There may be on-going compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.
[5]	Sites for which we have been identified as a Potentially Responsible Party.

COMMITMENTS AND CONTINGENCIE145

COMMITMENTS AND CONTINGENCIES - LOSS ON CONTINGENCIES (Details) $ in Thousands, € in Millions, £ in Millions	12 Months Ended
	Dec. 31, 2015EUR (€)	Dec. 31, 2015GBP (£)	Dec. 31, 2015USD ($)Bcf	Oct. 23, 2015Bcf	Dec. 31, 2014USD ($)
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value			$ 49,000
Insurance receivable for Aliso Canyon costs			325,000		$ 0	[1]
Reserve for Aliso Canyon costs			274,000		0	[2]
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value			26,000
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value			21,000
Insurance receivable for Aliso Canyon costs			325,000		0	[1]
Reserve for Aliso Canyon costs			274,000		$ 0	[1]
Loss from Catastrophes, 2007 Wildfire [Member] | San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Regulatory Assets Arising From Wildfire Litigation Costs			362,000
Portion of Regulatory Assets Arising From Wildfire Litigation Related To CPUC-Regulated Operations			359,000
Potential After-Tax Earnings Impact			$ 213,000
Number Of Remaining Cases	1	1	1
Number of Appeals Pending	2	2	2
Rim Rock Wind Farm [Member] | San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Estimated Tax Equity Investment			$ 285,000
Loss from Catastrophes, Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Number Of Lawsuits	83	83	83
Number Of Lawsuits Filed In Los Angeles County	81	81	81
Number Of Lawsuits Filed In San Diego County	2	2	2
Liability insurance coverage			$ 1,000,000
Civil Penalties Per Day			250
Net Book Value Of Aliso Canyon Natural Gas Storage Facility			243,000
Construction in Work Progress Of Aliso Canyon Natural Gas Storage Facility			162,000
Recorded Estimated Costs			$ 330,000
Estimated Costs Related To Temporary Relocation, Percentage			70.00%
Estimated Costs Related To Controlling Well And Stopping Leak And Emissions, Percentage			20.00%
Operation And Maintenance Expense, Pretax, Aliso Canyon			$ 4,000
Initial Gas Volume Stored | Bcf				77
Gas Volume Delivered Or Moved | Bcf			57
Minimum Working Gas Volume For Reliability | Bcf			15
Storage Facility Maximum Capacity | Bcf			86
Aliso Canyon Facility As A Percentage of SoCalGas Total Storage Capacity			63.00%
Number Of Days Temporary Relocation Extended			22
So Cal Gas PCB Litigation [Member] | Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Number Of Lawsuits	7	7	7
Number of Lawsuits Settled	6	6	6
Sempra Mexico Property Disputes [Member]
Loss Contingencies [Line Items]
Number Of Lawsuits	2	2	2
Mobile Gas Litigation [Member]
Loss Contingencies [Line Items]
Number Of Plaintiffs	250	250	250
Number Of Lawsuits	14	14	14
Number of Lawsuits Settled	11	11	11
Number of Lawsuits Remaining	3	3	3
HMRC VAT Claim [Member] | Parent Company [Member]
Loss Contingencies [Line Items]
VAT Tax Claim Paid Upon Appeal | £		£ 86
R B S Sempra Commodities [Member]
Loss Contingencies [Line Items]
Damages Sought in VAT Litigation | €	€ 156
Investment in RBS Sempra Commodities LLP			$ 67,000
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.

COMMITMENTS AND CONTINGENCIE146

COMMITMENTS AND CONTINGENCIES - NUCLEAR FUEL DISPOSAL (Details) - San Diego Gas and Electric Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
December 2005 And Prior [Member]
Nuclear Fuel Disposal [Line Items]
Reduction Of Nuclear Power Expenses	$ 10
Reduction of Nuclear Decommissioning Balancing Account	15
Reduction Of Nuclear Plant	3
Nuclear Fuel Disposal Cost Recovery	142
Share Of Damage Award Paid	28
January 2006 Through December 2010 [Member]
Nuclear Fuel Disposal [Line Items]
Nuclear Fuel Disposal Cost Recovery	98
January 2011 Through December 2013 [Member]
Nuclear Fuel Disposal [Line Items]
Nuclear Fuel Disposal Cost Recovery, Increase	$ 84

COMMITMENTS AND CONTINGENCIE147

COMMITMENTS AND CONTINGENCIES - SCHEDULE OF NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Thousands	Dec. 31, 2015USD ($)
Schedule Of Nuclear Insurance [Line Items]
Nuclear Liability Insurance Coverage, Maximum	$ 375,000
Secondary Financial Protection, Maximum	13,200,000
Secondary Financial Protection, Company Contribution, Maximum	50,930
Secondary Financial Protection, Company Contribution, Annual Maximum	7,600
Nuclear Property Damage Insurance, Premium Assessment	9,700
Nuclear Property Damage Insurance, Deductible Per Event	$ 2,500

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 10,231	$ 11,035		$ 10,557
Segment reporting information, Percentage of Total Consolidated Revenues		100.00%	100.00%		100.00%
Segment reporting information, Interest Expense		$ 561	$ 554		$ 559
Segment reporting information, Interest Income		29	22		20
Segment reporting information, Depreciation and Amortization		$ 1,250	$ 1,156		$ 1,113
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		100.00%	100.00%		100.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 341	$ 300		$ 366
Segment reporting information, earnings (losses)		$ 1,349	$ 1,161		$ 1,001
Segment reporting information, Percentage of Consolidated Earnings (Losses)		100.00%	100.00%		100.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 3,156	$ 3,123		$ 2,572
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		100.00%	100.00%		100.00%
Segment reporting information, Assets	[1]	$ 41,150	$ 39,651	[2]	$ 37,165
Segment reporting information, Percentage of Consolidated Assets		100.00%	100.00%		100.00%
S D G E Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 4,219	$ 4,329		$ 4,066
Segment reporting information, Percentage of Total Consolidated Revenues		41.00%	39.00%		39.00%
Segment reporting information, Interest Expense		$ 204	$ 202		$ 197
Segment reporting information, Interest Income		0	0		1
Segment reporting information, Depreciation and Amortization		$ 604	$ 530		$ 494
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		48.00%	46.00%		44.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 284	$ 270		$ 191
Segment reporting information, earnings (losses)	[3]	$ 587	$ 507		$ 404
Segment reporting information, Percentage of Consolidated Earnings (Losses)		43.00%	44.00%		41.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 1,133	$ 1,100		$ 978
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		36.00%	35.00%		38.00%
Segment reporting information, Assets	[1]	$ 16,515	$ 16,260		$ 15,337
Segment reporting information, Percentage of Consolidated Assets		40.00%	41.00%		41.00%
Segment Reporting Information, Intersegment Revenues		$ 9	$ 10		$ 10
So Cal Gas Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 3,489	$ 3,855		$ 3,736
Segment reporting information, Percentage of Total Consolidated Revenues		34.00%	35.00%		35.00%
Segment reporting information, Interest Expense		$ 84	$ 69		$ 69
Segment reporting information, Interest Income		4	0		0
Segment reporting information, Depreciation and Amortization		$ 461	$ 431		$ 383
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		37.00%	37.00%		35.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 138	$ 139		$ 116
Segment reporting information, earnings (losses)	[4]	$ 419	$ 332		$ 364
Segment reporting information, Percentage of Consolidated Earnings (Losses)		31.00%	29.00%		37.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 1,352	$ 1,104		$ 762
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		43.00%	35.00%		30.00%
Segment reporting information, Assets	[1]	$ 12,104	$ 10,446		$ 9,138
Segment reporting information, Percentage of Consolidated Assets		29.00%	26.00%		25.00%
Segment Reporting Information, Intersegment Revenues		$ 75	$ 69		$ 70
All Other Segments [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Interest Expense		263	241		241
Segment reporting information, Interest Income		0	1		0
Segment reporting information, Depreciation and Amortization		$ 10	$ 10		$ 12
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		1.00%	1.00%		1.00%
Segment reporting information, Income Tax Expense (Benefit)		$ (138)	$ (108)		$ (89)
Segment reporting information, earnings (losses)		$ (152)	$ (173)		$ (168)
Segment reporting information, Percentage of Consolidated Earnings (Losses)		(11.00%)	(15.00%)		(17.00%)
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 47	$ 18		$ 2
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		1.00%	1.00%		0.00%
Segment reporting information, Assets	[1]	$ 734	$ 872		$ 817
Segment reporting information, Percentage of Consolidated Assets		2.00%	2.00%		2.00%
Adjustments and Intercompany Eliminations Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ (2)	$ (3)		$ (2)
Segment reporting information, Percentage of Total Consolidated Revenues		0.00%	0.00%		0.00%
Intercompany Eliminations Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Interest Expense		$ (120)	$ (124)		$ (131)
Segment reporting information, Interest Income		(80)	(113)		(105)
Intersegment Revenues Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	[5]	$ (377)	$ (512)		$ (403)
Segment reporting information, Percentage of Total Consolidated Revenues		(3.00%)	(5.00%)		(4.00%)
Intersegment Receivables Segment [Member]
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Assets		$ (2,228)	$ (2,561)		$ (3,314)
Segment reporting information, Percentage of Consolidated Assets		(5.00%)	(6.00%)		(9.00%)
Sempra South American Utilities Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 1,544	$ 1,534		$ 1,495
Segment reporting information, Percentage of Total Consolidated Revenues		15.00%	14.00%		14.00%
Segment reporting information, Interest Expense		$ 32	$ 33		$ 27
Segment reporting information, Interest Income		19	14		14
Segment reporting information, Depreciation and Amortization		$ 50	$ 55		$ 59
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		4.00%	5.00%		5.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 67	$ 58		$ 67
Segment reporting information, earnings (losses)		$ 175	$ 172		$ 153
Segment reporting information, Percentage of Consolidated Earnings (Losses)		13.00%	15.00%		15.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 154	$ 174		$ 200
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		5.00%	6.00%		8.00%
Segment reporting information, Assets	[1]	$ 3,235	$ 3,379		$ 3,531
Segment reporting information, Percentage of Consolidated Assets		8.00%	9.00%		10.00%
Sempra Mexico Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 669	$ 818		$ 675
Segment reporting information, Percentage of Total Consolidated Revenues		7.00%	8.00%		6.00%
Segment reporting information, Interest Expense		$ 23	$ 17		$ 17
Segment reporting information, Interest Income		7	4		2
Segment reporting information, Depreciation and Amortization		$ 70	$ 64		$ 63
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		6.00%	6.00%		6.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 11	$ 5		$ 60
Segment reporting information, earnings (losses)		$ 213	$ 192		$ 122
Segment reporting information, Percentage of Consolidated Earnings (Losses)		16.00%	16.00%		12.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 302	$ 325		$ 371
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		10.00%	10.00%		14.00%
Segment reporting information, Assets	[1]	$ 3,783	$ 3,486		$ 3,243
Segment reporting information, Percentage of Consolidated Assets		9.00%	9.00%		9.00%
Segment Reporting Information, Intersegment Revenues		$ 101	$ 91		$ 91
Sempra Renewables Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 36	$ 35		$ 82
Segment reporting information, Percentage of Total Consolidated Revenues		0.00%	0.00%		1.00%
Segment reporting information, Interest Expense		$ 3	$ 5		$ 23
Segment reporting information, Interest Income		4	1		20
Segment reporting information, Depreciation and Amortization		$ 6	$ 5		$ 21
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		0.00%	0.00%		2.00%
Segment reporting information, Income Tax Expense (Benefit)		$ (49)	$ (44)		$ (19)
Segment reporting information, earnings (losses)		$ 63	$ 81		$ 62
Segment reporting information, Percentage of Consolidated Earnings (Losses)		5.00%	7.00%		6.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 81	$ 190		$ 176
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		2.00%	6.00%		7.00%
Segment reporting information, Assets	[1]	$ 1,441	$ 1,334		$ 1,214
Segment reporting information, Percentage of Consolidated Assets		4.00%	3.00%		3.00%
Sempra Natural Gas Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 653	$ 979		$ 908
Segment reporting information, Percentage of Total Consolidated Revenues		6.00%	9.00%		9.00%
Segment reporting information, Interest Expense		$ 72	$ 111		$ 116
Segment reporting information, Interest Income		75	115		88
Segment reporting information, Depreciation and Amortization		$ 49	$ 61		$ 81
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		4.00%	5.00%		7.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 28	$ (20)		$ 40
Segment reporting information, earnings (losses)		$ 44	$ 50		$ 64
Segment reporting information, Percentage of Consolidated Earnings (Losses)		3.00%	4.00%		6.00%
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment		$ 87	$ 212		$ 83
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		3.00%	7.00%		3.00%
Segment reporting information, Assets	[1]	$ 5,566	$ 6,435		$ 7,199
Segment reporting information, Percentage of Consolidated Assets		13.00%	16.00%		19.00%
Segment Reporting Information, Intersegment Revenues		$ 192	$ 342		$ 232
[1]	December 31, 2014 and 2013 have been adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	For 2013, amount is after preferred dividends and call premium on preferred stock.
[4]	After preferred dividends.
[5]	Revenues for reportable segments include intersegment revenues of $9 million, $75 million, $101 million, and $192 million for 2015, $10 million, $69 million, $91 million and $342 million for 2014, and $10 million, $70 million, $91 million and $232 million for 2013 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.

SEGMENT INFORMATION 2 (Details)

SEGMENT INFORMATION 2 (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Entity-Wide Disclosure On Geographic Areas [Line Items]
Assets, geographical	[1]	$ 30,944	$ 28,750	$ 27,035
Assets. percentage geographical		100.00%	100.00%	100.00%
Segment reporting information, Revenue		$ 10,231	$ 11,035	$ 10,557
Revenues, percentage geographical		100.00%	100.00%	100.00%
Entity-Wide Disclosure On Geographic Areas, United States [Member]
Entity-Wide Disclosure On Geographic Areas [Line Items]
Assets, geographical	[1]	$ 26,132	$ 24,183	$ 22,654
Assets. percentage geographical		84.00%	84.00%	84.00%
Segment reporting information, Revenue	[2]	$ 8,119	$ 8,774	$ 8,478
Revenues, percentage geographical		79.00%	79.00%	80.00%
Entity-Wide Disclosure On Geographic Areas Mexico [Member]
Entity-Wide Disclosure On Geographic Areas [Line Items]
Assets, geographical	[1]	$ 3,160	$ 2,821	$ 2,597
Assets. percentage geographical		10.00%	10.00%	9.00%
Segment reporting information, Revenue	[2]	$ 568	$ 727	$ 584
Revenues, percentage geographical		6.00%	7.00%	6.00%
Entity-Wide Disclosure On Geographic Areas, South America [Member]
Entity-Wide Disclosure On Geographic Areas [Line Items]
Assets, geographical	[1]	$ 1,652	$ 1,746	$ 1,784
Assets. percentage geographical		6.00%	6.00%	7.00%
Segment reporting information, Revenue	[2]	$ 1,544	$ 1,534	$ 1,495
Revenues, percentage geographical		15.00%	14.00%	14.00%
[1]	Includes net property, plant and equipment and investments.
[2]	Amounts are based on where the revenue originated, after intercompany eliminations.

SELECTED QUARTERLY FINANCIAL DA

SELECTED QUARTERLY FINANCIAL DATA (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2014
Significant Items Affecting Quarterly Results [Line Items]
Quarterly Financial Data, Gain on sale of mesquite power (pre-tax)			$ 61
Quarterly Financial Data, Gain on sale of mesquite power (after-tax)			36
Quarterly Financial Data, Louisiana valuation allowance release					$ 25
Quarterly Financial Data, Higher (Lower) Utility Revenue Due to Seasonality	$ 67	$ (158)	(72)	$ 163
Quarterly Financial Data, Higher (Lower) Earnings Due to Seasonality	48	(113)	(48)	113
Southern California Gas Company [Member]
Significant Items Affecting Quarterly Results [Line Items]
Quarterly Financial Data, Higher (Lower) Utility Revenue Due to Seasonality	67	(158)	(72)	163
Quarterly Financial Data, Higher (Lower) Earnings Due to Seasonality	$ 48	$ (113)	$ (48)	$ 113

SELECTED QUARTERLY FINANCIAL151

SELECTED QUARTERLY FINANCIAL DATA 2 (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions		3 Months Ended																12 Months Ended
		Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015		Mar. 31, 2015		Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Selected Quarterly Financial Information [Line Items]
Quarterly Financial Data, Revenues		$ 2,701		$ 2,481		$ 2,367		$ 2,682		$ 2,747		$ 2,815		$ 2,678		$ 2,795
Quarterly Financial Data, Expenses And Other Income		2,269		2,211		1,971		2,076		2,433		2,368		2,302		2,408
Quarterly Financial Data, Net Income		388		282		320		458		321		383		292		266
Quarterly Financial Data, Earnings		$ 369		$ 248		$ 295		$ 437		$ 297		$ 348		$ 269		$ 247		$ 1,349		$ 1,161		$ 1,001
Quarterly Financial Data, Net Income Per Share, Basic	[1]	$ 1.56		$ 1.14		$ 1.29		$ 1.85		$ 1.31		$ 1.56		$ 1.19		$ 1.09
Quarterly Financial Data, Earnings Per Share, Basic		$ 1.48	[1]	$ 1	[1]	$ 1.19	[1]	$ 1.76	[1]	$ 1.21	[1]	$ 1.41	[1]	$ 1.1	[1]	$ 1.01	[1]	$ 5.43		$ 4.72		$ 4.1
Quarterly Financial Data, Weighted Average Number Of Shares Outstanding, Basic		248,700		248,400		248,100		247,700		246,400		246,100		245,700		245,300		248,249	[2]	245,891	[2]	243,863	[2]
Quarterly Financial Data, Net Income Per Share, Diluted	[1]	$ 1.54		$ 1.12		$ 1.27		$ 1.83		$ 1.28		$ 1.53		$ 1.17		$ 1.07
Quarterly Financial Data, Earnings Per Share, Diluted		$ 1.47	[1]	$ 0.99	[1]	$ 1.17	[1]	$ 1.74	[1]	$ 1.18	[1]	$ 1.39	[1]	$ 1.08	[1]	$ 0.99	[1]	$ 5.37		$ 4.63		$ 4.01
Quarterly Financial Data, Weighted Average Number Of Shares Outstanding, Diluted		251,500		251,000		251,500		251,200		251,300		250,800		250,100		249,700		250,923		250,655		249,332
Parent Company [Member]
Selected Quarterly Financial Information [Line Items]
Quarterly Financial Data, Earnings																		$ 1,349		$ 1,161		$ 1,001
Quarterly Financial Data, Earnings Per Share, Basic																		$ 5.43		$ 4.72		$ 4.1
Quarterly Financial Data, Weighted Average Number Of Shares Outstanding, Basic																		248,249		245,891		243,863
Quarterly Financial Data, Earnings Per Share, Diluted																		$ 5.37		$ 4.63		$ 4.01
Quarterly Financial Data, Weighted Average Number Of Shares Outstanding, Diluted																		250,923		250,655		249,332
San Diego Gas and Electric Company [Member]
Selected Quarterly Financial Information [Line Items]
Quarterly Financial Data, Revenues		$ 1,051		$ 1,230		$ 972		$ 966		$ 1,046		$ 1,233		$ 1,063		$ 987
Quarterly Financial Data, Operating Expenses		802		930		745		684		826		957		821		766
Quarterly Financial Data, Operating Income		249		300		227		282		220		276		242		221
Quarterly Financial Data, Net Income		143		182		130		151		128		169		129		101
Quarterly Financial Data, (Earnings) Losses Attributable To Noncontrolling Interests		1		(12)		(4)		(4)		0		(12)		(6)		(2)
Quarterly Financial Data, Earnings																		$ 587		$ 507		$ 411
Quarterly Financial Data, Earnings Attributable To Common Shares		144		170		126		147		128		157		123		99
Southern California Gas Company [Member]
Selected Quarterly Financial Information [Line Items]
Quarterly Financial Data, Revenues		1,041		620		780		1,048		998		855		917		1,085
Quarterly Financial Data, Operating Expenses		834		633		686		728		881		702		795		956
Quarterly Financial Data, Operating Income		207		(13)		94		320		117		153		122		129
Quarterly Financial Data, Net Income		143		(8)		71		214		76		98		81		78
Quarterly Financial Data, Earnings																		$ 420		$ 333		$ 365
Quarterly Financial Data, Dividends On Preferred Stock		0		0		(1)		0		0		0		(1)		0
Quarterly Financial Data, Earnings Attributable To Common Shares		$ 143		$ (8)		$ 70		$ 214		$ 76		$ 98		$ 80		$ 78
[1]	Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.
[2]	Includes fully vested restricted stock units held in our Deferred Compensation Plan of 491 in 2015, 212 in 2014 and none in 2013. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

SUBSEQUENT EVENT (Details)

SUBSEQUENT EVENT (Details) $ in Millions	Dec. 31, 2015USD ($)
Sempra Mexico Segment [Member]
Long Lived Assets Held-for-sale [Line Items]
Book Value Held For Sale	$ 262

SCHEDULE I, CONDENSED FINANC153

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, STATEMENT OF OPERATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended																12 Months Ended
	Dec. 31, 2015		Sep. 30, 2015		Jun. 30, 2015		Mar. 31, 2015		Dec. 31, 2014		Sep. 30, 2014		Jun. 30, 2014		Mar. 31, 2014		Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Condensed Income Statements Captions [Line Items]
Interest income																	$ 29		$ 22		$ 20
Interest expense																	(561)		(554)		(559)
Other income (expense), net																	126		137		140
Income tax (expense) benefit																	(341)		(300)		(366)
Equity earnings, net of income tax																	85		38		24
Net income																	$ 1,448		$ 1,262		$ 1,088
Basic earnings per common share	$ 1.48	[1]	$ 1	[1]	$ 1.19	[1]	$ 1.76	[1]	$ 1.21	[1]	$ 1.41	[1]	$ 1.1	[1]	$ 1.01	[1]	$ 5.43		$ 4.72		$ 4.1
Basic earnings per common share, weighted-average number of shares outstanding (thousands)	248,700		248,400		248,100		247,700		246,400		246,100		245,700		245,300		248,249	[2]	245,891	[2]	243,863	[2]
Diluted earnings per common share	$ 1.47	[1]	$ 0.99	[1]	$ 1.17	[1]	$ 1.74	[1]	$ 1.18	[1]	$ 1.39	[1]	$ 1.08	[1]	$ 0.99	[1]	$ 5.37		$ 4.63		$ 4.01
Diluted earnings per common share, weighted-average number of shares outstanding (thousands)	251,500		251,000		251,500		251,200		251,300		250,800		250,100		249,700		250,923		250,655		249,332
Earnings	$ 369		$ 248		$ 295		$ 437		$ 297		$ 348		$ 269		$ 247		$ 1,349		$ 1,161		$ 1,001
Parent Company [Member]
Condensed Income Statements Captions [Line Items]
Interest income																	0		0		42
Interest expense																	(261)		(235)		(239)
Operating and mainenance																	(66)		(78)		(63)
Other income (expense), net																	7		50		41
Income tax (expense) benefit																	150		133		117
Loss before equity of subsidiaries, net of income taxes																	(170)		(130)		(102)
Equity earnings, net of income tax																	$ 1,519		$ 1,291		$ 1,103
Basic earnings per common share																	$ 5.43		$ 4.72		$ 4.1
Basic earnings per common share, weighted-average number of shares outstanding (thousands)																	248,249		245,891		243,863
Diluted earnings per common share																	$ 5.37		$ 4.63		$ 4.01
Diluted earnings per common share, weighted-average number of shares outstanding (thousands)																	250,923		250,655		249,332
Earnings																	$ 1,349		$ 1,161		$ 1,001
[1]	Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.
[2]	Includes fully vested restricted stock units held in our Deferred Compensation Plan of 491 in 2015, 212 in 2014 and none in 2013. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

SCHEDULE I, CONDENSED FINANC154

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, STATEMENT OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Statement Of Income Captions [Line Items]
Net income	$ 1,448	$ 1,262	$ 1,088
Other Comprehensive Income (Loss), Net of Tax	(334)	(290)	140
Before-Tax Amount [Member]
Condensed Statement Of Income Captions [Line Items]
Net income	1,691	1,462	1,375
Foreign currency translation adjustments	(260)	(193)	111
Other Comprehensive Income (Loss), Derivatives, Net of Tax	(80)	(106)	13
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(3)	(20)	47
Other Comprehensive Income (Loss), Net of Tax	(343)	(319)	171
Comprehensive income	1,348	1,143	1,546
Before-Tax Amount [Member] | Parent Company [Member]
Condensed Statement Of Income Captions [Line Items]
Net income	1,199	1,028	884
Foreign currency translation adjustments	(260)	(193)	111
Other Comprehensive Income (Loss), Derivatives, Net of Tax	(80)	(106)	13
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(3)	(20)	47
Other Comprehensive Income (Loss), Net of Tax	(343)	(319)	171
Comprehensive income	856	709	1,055
Income Tax (Expense) Benefit [Member]
Condensed Statement Of Income Captions [Line Items]
Net income	(341)	(300)	(366)
Foreign currency translation adjustments	0	0	0
Other Comprehensive Income (Loss), Derivatives, Net of Tax	33	42	(4)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1	8	(19)
Other Comprehensive Income (Loss), Net of Tax	34	50	(23)
Comprehensive income	(307)	(250)	(389)
Income Tax (Expense) Benefit [Member] | Parent Company [Member]
Condensed Statement Of Income Captions [Line Items]
Net income	150	133	117
Foreign currency translation adjustments	0	0	0
Other Comprehensive Income (Loss), Derivatives, Net of Tax	33	42	(4)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1	8	(19)
Other Comprehensive Income (Loss), Net of Tax	34	50	(23)
Comprehensive income	184	183	94
Net-Of-Tax Amount [Member]
Condensed Statement Of Income Captions [Line Items]
Net income	1,350	1,162	1,009
Foreign currency translation adjustments	(260)	(193)	111
Other Comprehensive Income (Loss), Derivatives, Net of Tax	(47)	(64)	9
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(2)	(12)	28
Other Comprehensive Income (Loss), Net of Tax	(309)	(269)	148
Comprehensive income	1,041	893	1,157
Net-Of-Tax Amount [Member] | Parent Company [Member]
Condensed Statement Of Income Captions [Line Items]
Net income	1,349	1,161	1,001
Foreign currency translation adjustments	(260)	(193)	111
Other Comprehensive Income (Loss), Derivatives, Net of Tax	(47)	(64)	9
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	(2)	(12)	28
Other Comprehensive Income (Loss), Net of Tax	(309)	(269)	148
Comprehensive income	$ 1,040	$ 892	$ 1,149

SCHEDULE I, CONDENSED FINANC155

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, BALANCE SHEETS (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013	Dec. 31, 2012
ASSETS
Cash and cash equivalents		$ 403	$ 570	[1]	$ 904	$ 475
Due from affiliates, current		6	38	[1]
Deferred income taxes		0	305	[1]
Other current assets		267	293	[1]
Total current assets		2,891	4,184	[1]
Investments in subsidiaries		2,905	2,848	[1]
Due from affiliaties, noncurrent		186	188	[1]
Other assets		761	480	[1]
Total assets	[2]	41,150	39,651	[1]	37,165
LIABILITIES AND EQUITY
Current portion of long-term debt		907	469	[3]
Due to affiliaties, current		14	2	[3]
Other current liabilities		551	649	[3]
Total current liabilities		4,612	5,069	[3]
Long-term debt		13,134	12,086	[3]
Other long-term liabilities		1,176	1,104	[3]
Total shareholders' equity		11,809	11,326	[3]
Total liabilities and equity		41,150	39,651	[3]
Parent Company [Member]
ASSETS
Cash and cash equivalents		4	3	[4]	$ 6	$ 18
Due from affiliates, current		62	101	[4]
Deferred income taxes		0	398	[4]
Other current assets		4	15	[4]
Total current assets		70	517	[4]
Investments in subsidiaries		15,586	14,557	[4]
Due from affiliaties, noncurrent		457	174	[4]
Deferred Tax Assets		2,188	1,544	[4]
Other assets		641	609	[4]
Total assets		18,942	17,401	[4]
LIABILITIES AND EQUITY
Current portion of long-term debt		752	0	[4]
Due to affiliaties, current		332	338	[4]
Income taxes payable		42	93	[4]
Other current liabilities		310	271	[4]
Total current liabilities		1,436	702	[4]
Long-term debt		5,195	4,644	[4]
Due to affiliates		0	230	[4]
Other long-term liabilities		502	499	[4]
Total shareholders' equity		11,809	11,326	[4]
Total liabilities and equity		$ 18,942	$ 17,401	[4]
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	December 31, 2014 and 2013 have been adjusted for the retrospective adoption of ASU 2015-03.
[3]	As adjusted for the retrospective adoption of ASU 2015-03.
[4]	As adjusted for the retrospective adoption of ASU 2015-03.

SCHEDULE I, CONDENSED FINANC156

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, CASH FLOWS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Condensed Cash Flow Statements Captions [Line Items]
Net cash provided by (used in) operating activities	$ 2,905,000,000		$ 2,161,000,000		$ 1,784,000,000
Expenditures for property, plant and equipment	(3,156,000,000)		(3,123,000,000)		(2,572,000,000)
Purchase of trust assets	1,000,000		35,000,000		(12,000,000)
Decrease (increase) in loans to affiliates, net	74,000,000		18,000,000		0
Net cash provided by (used in) investing activities	(2,885,000,000)		(3,342,000,000)		(1,689,000,000)
Common dividends paid	(628,000,000)		(598,000,000)		(606,000,000)
Issuances of common stock	52,000,000		56,000,000		62,000,000
Repurchases of common stock	(74,000,000)		(38,000,000)		(45,000,000)
Payments on long-term debt	(1,854,000,000)		(2,034,000,000)		(1,788,000,000)
Excess Tax Benefit From Share Based Compensation Financing Activities	52,000,000		0		0
Other cash flows from financing activities	(17,000,000)		(37,000,000)		(40,000,000)
Net cash provided by (used in) financing activities	(173,000,000)		854,000,000		338,000,000
Increase (decrease) in cash and cash equivalents	(167,000,000)		(334,000,000)		429,000,000
Cash and cash equivalents, beginning of period	570,000,000	[1]	904,000,000		475,000,000
Cash and cash equivalents, end of period	403,000,000		570,000,000	[1]	904,000,000
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Financing of build-to-suit property	61,000,000		61,000,000		14,000,000
Common Stock Issued Employee Stock Trust	55,000,000		42,000,000		0
Dividends declared but not paid	180,000,000		166,000,000		157,000,000
Parent Company [Member]
Condensed Cash Flow Statements Captions [Line Items]
Net cash provided by (used in) operating activities	(255,000,000)		(260,000,000)		(131,000,000)
Dividends received from subsidiaries	350,000,000		300,000,000		50,000,000
Expenditures for property, plant and equipment	(43,000,000)		(15,000,000)		(1,000,000)
Purchase of trust assets	(5,000,000)		(4,000,000)		(5,000,000)
Proceeds from sales by trust	0		0		10,000,000
Capital contribution to subsidiaries	0		0		(6,000,000)
Decrease (increase) in loans to affiliates, net	(457,000,000)		627,000,000		962,000,000
Net cash provided by (used in) investing activities	(155,000,000)		908,000,000		1,010,000,000
Common dividends paid	(628,000,000)		(598,000,000)		(606,000,000)
Issuances of common stock	52,000,000		56,000,000		62,000,000
Repurchases of common stock	(74,000,000)		(38,000,000)		(45,000,000)
Issuances of long-term debt	1,248,000,000		499,000,000		498,000,000
Payments on long-term debt	0		(800,000,000)		(650,000,000)
Increase (decrease) in loans from affiliates, net	(230,000,000)		234,000,000		(147,000,000)
Excess Tax Benefit From Share Based Compensation Financing Activities	52,000,000		0		0
Other cash flows from financing activities	(9,000,000)		(4,000,000)		(3,000,000)
Net cash provided by (used in) financing activities	411,000,000		(651,000,000)		(891,000,000)
Increase (decrease) in cash and cash equivalents	1,000,000		(3,000,000)		(12,000,000)
Cash and cash equivalents, beginning of period	3,000,000	[2]	6,000,000		18,000,000
Cash and cash equivalents, end of period	4,000,000		3,000,000	[2]	6,000,000
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Financing of build-to-suit property	61,000,000		61,000,000		14,000,000
Common Stock Issued Employee Stock Trust	55,000,000		42,000,000		0
Dividends declared but not paid	$ 174,000,000		$ 163,000,000		$ 154,000,000
[1]	As adjusted for the retrospective adoption of ASU 2015-03.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.

SCHEDULE I, CONDENSED FINANC157

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, FOOTNOTES (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	[1]	$ 897
Long-term Debt, Maturities, Repayments of Principal in Year Two	[1]	854
Long-term Debt, Maturities, Repayments of Principal in Year Three	[1]	1,369
Long-term Debt, Maturities, Repayments of Principal in Year Four	[1]	854
Long-term Debt, Maturities, Repayments of Principal in Year Five	[1]	968
Long-term Debt, Maturities, Repayments of Principal after Year Five	[1]	8,821
Debt Instrument, Unamortized Discount		107	$ 102
Long-term debt		13,134	12,086	[2]
Current portion of long-term debt		(907)	(469)	[2]
Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months		750
Long-term Debt, Maturities, Repayments of Principal in Year Two		600
Long-term Debt, Maturities, Repayments of Principal in Year Three		500
Long-term Debt, Maturities, Repayments of Principal in Year Four		500
Long-term Debt, Maturities, Repayments of Principal in Year Five		900
Long-term Debt, Maturities, Repayments of Principal after Year Five		2,600
Debt Instrument, Unamortized Discount		(10)	(9)	[3]
Long-term debt		5,195	4,644	[4]
Current portion of long-term debt		(752)	0	[4]
Build to suit lease		136	75	[3]
Rabbi trust investment gain (loss)		3	27		$ 39
Unamortized Debt Issuance Costs on Long-Term Debt		(27)	(22)	[3]
Other Long-term Debt, Due June 2018 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 500	500	[3]
Debt Instrument, Interest Rate, Stated Percentage		6.15%
Other Long-term Debt, Due February 2019 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 500	500	[3]
Debt Instrument, Interest Rate, Stated Percentage		9.80%
Other Long-term Debt, Due October 2039 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 750	750	[3]
Debt Instrument, Interest Rate, Stated Percentage		6.00%
Market Value Adjustment For Interest Rate Swap [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Market Value Adjustment For Interest Rate Swap		$ (2)	0	[3]
Other Long Term Debt, Variable Rate Notes Due June 2016 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 750	750	[3]
Debt Instrument, Interest Rate, Stated Percentage		6.50%
Debt Instrument, Interest Rate at Period End		4.77%
Other Long Term Debt Due April 2017 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 600	600	[3]
Debt Instrument, Interest Rate, Stated Percentage		2.30%
Other Long Term Debt, Due October 2022 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 500	500	[3]
Debt Instrument, Interest Rate, Stated Percentage		2.875%
Other Long-term Debt, Due December 2023 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 500	500	[3]
Debt Instrument, Interest Rate, Stated Percentage		4.05%
Other Long-term Debt, Due June 2024 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 500	500	[3]
Debt Instrument, Interest Rate, Stated Percentage		3.55%
Other Long Term Debt Due March 2020 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 500	0	[3]
Debt Instrument, Interest Rate, Stated Percentage		2.40%
Other Long Term Debt Due November 2020 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 400	0	[3]
Debt Instrument, Interest Rate, Stated Percentage		2.85%
Other Long Term Debt Due November 2025 [Member] | Parent Company [Member]
Condensed Financial Information of Parent, Long-term Debt [Line Items]
Long-term Debt, Gross		$ 350	$ 0	[3]
Debt Instrument, Interest Rate, Stated Percentage		3.75%
[1]	Excludes capital lease obligations, build-to-suit lease and market value adjustments for interest rate swaps.
[2]	As adjusted for the retrospective adoption of ASU 2015-03.
[3]	(1) As adjusted for the retrospective adoption of ASU 2015-03.
[4]	As adjusted for the retrospective adoption of ASU 2015-03.