Sempra (SRE) 10-K 27 Feb 14 2013 FY Annual report Financial data

DOCUMENT_AND_ENTITY_INFORMATIO

DOCUMENT AND ENTITY INFORMATION (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Feb. 21, 2014	Jun. 30, 2013
Document and Entity Information [Abstract]	'	'	'
Entity Registrant Name	'Sempra Energy	'	'
Entity Central Index Key	'0001032208	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Document Fiscal Year Focus	'2013	'	'
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 Public Float	'	'	$19,900
Entity Common Shares Outstanding	'	245,089,822	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$904	$475
Restricted cash	24	46
Trade accounts receivable	1,308	1,146
Other accounts and notes receivable, net	214	153
Due from unconsolidated affiliates	4	0
Income taxes receivable	85	56
Deferred income taxes, net current assets	301	148
Inventories	287	408
Regulatory balancing accounts - undercollected	556	395
Regulatory Assets, Current	38	62
Fixed-price contracts and other derivatives, current assets	106	95
Grants Receivable Current	0	258
Asset held for sale, power plant	0	296
Other current assets	170	157
Total current assets	3,997	3,695
Investments And Other Assets [Abstract]	'	'
Restricted cash, noncurrent	25	22
Due from unconsolidated affiliate	14	0
Regulatory assets arising from pension and other postretirement benefit obligations	435	1,151
Regulatory Assets, Noncurrent	2,113	1,591
Nuclear decommissioning trusts	1,034	908
Other investments	1,575	1,516
Goodwill	1,024	1,111
Other intangible assets	426	436
Sundry	1,141	878
Total investments and other assets	7,787	7,613
Property, plant and equipment:	'	'
Property, Plant and Equipment, Gross	34,407	33,528
Less accumulated depreciation and amortization	-8,947	-8,337
Property, plant and equipment, net	25,460	25,191
Total assets	37,244	36,499
Current liabilities:	'	'
Short-term debt	545	546
Accounts payable - trade	1,088	976
Accounts payable - other	127	134
Dividends and interest payable	271	266
Regulatory balancing accounts - overcollected	91	141
Accrued compensation and benefits	376	337
Current portion of long-term debt	1,147	725
Fixed-price contracts and other derivatives, current liabilities	55	77
Customer deposits	154	143
Reserve for wildfire litigation	63	305
Other current liabilities	452	608
Total current liabilities	4,369	4,258
Long-term debt	11,253	11,621
Deferred Credits and Other Liabilities [Abstract]	'	'
Customer advances for construction	155	144
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	667	1,456
Deferred income taxes, net noncurrent liabilities	2,804	2,100
Deferred investment tax credits	42	46
Regulatory liabilities arising from removal obligations	2,623	2,720
Asset retirement obligations	2,084	2,033
Fixed-price contracts and other derivatives, noncurrent liabilities	228	252
Deferred credits and other	1,169	1,107
Total deferred credits and other liabilities	9,772	9,858
Contingently redeemable preferred stock of subsidiary	0	79
Equity:	'	'
Common stock	2,409	2,217
Retained earnings	8,827	8,441
Accumulated other comprehensive income (loss)	-228	-376
Total shareholders' equity	11,008	10,282
Preferred stock of subsidiaries	20	20
Other noncontrolling interests	822	381
Total equity	11,850	10,683
Total liabilities and equity	37,244	36,499
San Diego Gas and Electric Company and Subsidiary [Member]	'	'
Current assets:	'	'
Cash and cash equivalents	27	87
Restricted cash	6	10
Trade accounts receivable	266	252
Other accounts and notes receivable, net	28	21
Due from unconsolidated affiliates	1	39
Income taxes receivable	32	35
Deferred income taxes, net current assets	103	0
Inventories	86	82
Regulatory balancing accounts - undercollected	556	395
Regulatory assets arising from fixed-price contracts and other derivatives - current	0	39
Regulatory Assets, Current	29	10
Fixed-price contracts and other derivatives, current assets	61	41
Other current assets	75	76
Total current assets	1,270	1,087
Investments And Other Assets [Abstract]	'	'
Restricted cash, noncurrent	25	22
Deferred taxes recoverable in rates	788	718
Regulatory assets arising from fixed-price contracts and other derivatives - noncurrent	63	110
Regulatory assets arising from pension and other postretirement benefit obligations	106	303
Regulatory Assets, Noncurrent	991	616
Nuclear decommissioning trusts	1,034	908
Sundry	254	117
Total investments and other assets	3,261	2,794
Property, plant and equipment:	'	'
Property, Plant and Equipment, Gross	14,346	14,124
Less accumulated depreciation and amortization	-3,500	-3,261
Property, plant and equipment, net	10,846	10,863
Total assets	15,377	14,744
Current liabilities:	'	'
Short-term debt	59	0
Accounts payable - trade	420	300
Due to unconsolidated affiliates	39	19
Deferred income taxes, net current liabilities	0	26
Dividends and interest payable	39	36
Accrued compensation and benefits	113	129
Current portion of long-term debt	29	16
Fixed-price contracts and other derivatives, current liabilities	38	56
Customer deposits	71	60
Reserve for wildfire litigation	63	305
Other current liabilities	208	157
Total current liabilities	1,079	1,104
Long-term debt	4,525	4,292
Deferred Credits and Other Liabilities [Abstract]	'	'
Customer advances for construction	34	17
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	132	340
Deferred income taxes, net noncurrent liabilities	2,021	1,636
Deferred investment tax credits	24	25
Regulatory liabilities arising from removal obligations	1,403	1,603
Asset retirement obligations	861	733
Fixed-price contracts and other derivatives, noncurrent liabilities	175	209
Deferred credits and other	404	408
Total deferred credits and other liabilities	5,054	4,971
Contingently redeemable preferred stock of subsidiary	0	79
Equity:	'	'
Common stock	1,338	1,338
Retained earnings	3,299	2,895
Accumulated other comprehensive income (loss)	-9	-11
Total shareholders' equity	4,628	4,222
Other noncontrolling interests	91	76
Total equity	4,719	4,298
Total liabilities and equity	15,377	14,744
Southern California Gas Company [Member]	'	'
Current assets:	'	'
Cash and cash equivalents	27	83
Trade accounts receivable	595	539
Other accounts and notes receivable, net	97	51
Due from unconsolidated affiliates	21	24
Income taxes receivable	25	104
Deferred income taxes, net current assets	0	3
Inventories	69	151
Regulatory Assets, Current	5	4
Other current assets	34	35
Total current assets	873	994
Investments And Other Assets [Abstract]	'	'
Regulatory assets arising from pension and other postretirement benefit obligations	0	141
Regulatory assets arising from pension obligations	326	694
Regulatory Assets, Noncurrent	262	148
Other post retirement benefit assets, net of plan liabilities	95	0
Sundry	124	77
Total investments and other assets	807	1,060
Property, plant and equipment:	'	'
Property, Plant and Equipment, Gross	11,831	11,187
Less accumulated depreciation and amortization	-4,364	-4,170
Property, plant and equipment, net	7,467	7,017
Total assets	9,147	9,071
Current liabilities:	'	'
Short-term debt	42	0
Accounts payable - trade	346	383
Accounts payable - other	79	82
Due to unconsolidated affiliates	16	37
Deferred income taxes, net current liabilities	45	0
Accrued compensation and benefits	141	116
Regulatory balancing accounts, net	91	141
Current portion of long-term debt	252	4
Customer deposits	75	76
Other current liabilities	125	124
Total current liabilities	1,212	963
Long-term debt	1,159	1,409
Deferred Credits and Other Liabilities [Abstract]	'	'
Customer advances for construction	108	111
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	0	141
Pension obligation, net of plan assets	339	714
Deferred income taxes, net noncurrent liabilities	993	881
Deferred investment tax credits	18	20
Regulatory liabilities arising from removal obligations	1,205	1,103
Asset retirement obligations	1,182	1,238
Regulatory liabilities arising from other post retirement benefit assets	95	0
Deferred credits and other	287	256
Total deferred credits and other liabilities	4,227	4,464
Equity:	'	'
Preferred stock	22	22
Common stock	866	866
Retained earnings	1,679	1,365
Accumulated other comprehensive income (loss)	-18	-18
Total equity	2,549	2,235
Total liabilities and equity	$9,147	$9,071

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parentheticals) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Property, plant and equipment related to VIE	$438	$466
Long-term debt related to VIE	325	335
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	244,461,327	242,368,836
San Diego Gas and Electric Company and Subsidiary [Member]	'	'
Property, plant and equipment related to VIE	438	466
Long-term debt related to VIE	$325	$335
Shareholders' equity:	'	'
Preferred stock, shares authorized	25,000,000	'
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

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES	'	'	'
Utilities	$9,309	$8,441	$8,322
Energy-related businesses	1,248	1,206	1,714
Total revenues	10,557	9,647	10,036
Utilities [Abstract]	'	'	'
Cost of natural gas	-1,646	-1,290	-1,866
Cost of electric fuel and purchased power	-1,932	-1,760	-1,397
Energy-related businesses [Abstract]	'	'	'
Cost of natural gas, electric fuel and purchased power	-435	-481	-746
Other cost of sales	-178	-159	-137
Other operation and maintenance	-2,995	-2,956	-2,825
Depreciation and amortization	-1,113	-1,090	-976
Loss from plant closure	-200	0	0
Franchise fees and other taxes	-374	-359	-343
Gains on sale of assets	114	7	0
Equity Earnings (Losses) [Abstract]	'	'	'
Equity (losses) earnings, other	31	-319	9
Remeasurement of equity method investments	0	0	277
Other income (expense), net	140	172	130
Interest income	20	24	26
Interest expense	-559	-493	-465
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	1,430	943	1,723
Income tax (expense) benefit	-366	-59	-394
Equity earnings, net of income tax	24	36	52
Net income	1,088	920	1,381
Losses (earnings) attributable to noncontrolling interests	-79	-55	-42
Call premium on preferred stock of subsidiary	-3	0	0
Preferred dividends of subsidiaries	-5	-6	-8
Earnings	1,001	859	1,331
Basic earnings per common share:	'	'	'
Basic earnings per common share	$4.10	$3.56	$5.55
Basic earnings per common share, weighted-average number of shares outstanding (thousands)	243,863	241,347	239,720
Diluted earnings per common share:	'	'	'
Diluted earnings per common share	$4.01	$3.48	$5.51
Diluted earnings per common share, weighted-average number of shares outstanding (thousands)	249,332	246,693	241,523
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Utility operating revenues	'	'	'
Electric	3,537	3,226	2,830
Natural gas	529	468	543
Total utility operating revenues	4,066	3,694	3,373
Utility operating expenses	'	'	'
Utility cost of natural gas	204	151	226
Utility cost of electric fuel and purchased power	1,019	892	715
Utility operation and maintenance	1,157	1,154	1,072
Utility depreciation and amortization	494	490	422
Utility franchise fees and other taxes	210	198	183
Utility loss from plant closure	200	0	0
Total utility operating expenses	3,284	2,885	2,618
Utility operating income	782	809	755
Equity Earnings (Losses) [Abstract]	'	'	'
Other income (expense), net	40	69	79
Interest income	1	0	0
Interest expense	-197	-173	-142
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	626	705	692
Income tax (expense) benefit	-191	-190	-237
Net income	435	515	455
Losses (earnings) attributable to noncontrolling interests	-24	-26	-19
Earnings	411	489	436
Call premium on preferred stock	-3	0	0
Preferred stock requirements	-4	-5	-5
Earnings attributable to common shares	404	484	431
Southern California Gas Company [Member]	'	'	'
Utility operating revenues	'	'	'
Total utility operating revenues	3,736	3,282	3,816
Utility operating expenses	'	'	'
Utility cost of natural gas	1,362	1,074	1,568
Utility operation and maintenance	1,324	1,304	1,305
Utility depreciation and amortization	383	362	331
Utility franchise fees and other taxes	128	122	126
Total utility operating expenses	3,197	2,862	3,330
Utility operating income	539	420	486
Equity Earnings (Losses) [Abstract]	'	'	'
Other income (expense), net	11	17	13
Interest income	0	0	1
Interest expense	-69	-68	-69
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	481	369	431
Income tax (expense) benefit	-116	-79	-143
Net income	365	290	288
Earnings	365	290	288
Preferred stock requirements	-1	-1	-1
Earnings attributable to common shares	$364	$289	$287

CONSOLIDATED_STATEMENTS_OF_COM

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income	$1,088	$920	$1,381
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Net of Tax, Total	140	117	-189
Preferred dividends of subsidiaries	-5	-6	-8
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net income	435	515	455
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Net of Tax, Total	19	-12	-36
Southern California Gas Company [Member]	'	'	'
Net income	365	290	288
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Net of Tax, Total	'	3	1
Before-Tax Amount [Member]	'	'	'
Net income	1,375	924	1,733
Comprehensive income, net of income tax	'	'	'
Foreign currency translation adjustments	111	119	-79
Reclassification to net income of foreign currency translation adjustment related to remeasurement of equity method investments	'	'	-54
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	'	-2
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	47	-4	-20
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	13	-6	-26
Other Comprehensive Income (Loss), Net of Tax, Total	171	109	-181
Total comprehensive income	1,546	1,033	1,552
Preferred dividends of subsidiaries	-5	-6	-8
Total comprehensive income, after preferred dividends of subsidiaries	1,541	1,027	1,544
Before-Tax Amount [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net income	602	679	673
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	3	-1	'
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	3	-1	0
Total comprehensive income	605	678	673
Before-Tax Amount [Member] | Southern California Gas Company [Member]	'	'	'
Net income	481	369	431
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-2	5	-2
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	1	2	3
Other Comprehensive Income (Loss), Net of Tax, Total	-1	7	1
Total comprehensive income	480	376	432
Income Tax (Expense) Benefit [Member]	'	'	'
Net income	-366	-59	-394
Comprehensive income, net of income tax	'	'	'
Foreign currency translation adjustments	0	0	3
Reclassification to net income of foreign currency translation adjustment related to remeasurement of equity method investments	'	'	0
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	'	1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-19	2	8
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	-4	2	10
Other Comprehensive Income (Loss), Net of Tax, Total	-23	4	22
Total comprehensive income	-389	-55	-372
Preferred dividends of subsidiaries	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	-389	-55	-372
Income Tax (Expense) Benefit [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net income	-191	-190	-237
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-1	0	'
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	-1	0	0
Total comprehensive income	-192	-190	-237
Income Tax (Expense) Benefit [Member] | Southern California Gas Company [Member]	'	'	'
Net income	-116	-79	-143
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1	-3	1
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	-1	-1
Other Comprehensive Income (Loss), Net of Tax, Total	1	-4	0
Total comprehensive income	-115	-83	-143
Net-Of-Tax Amount [Member]	'	'	'
Net income	1,009	865	1,339
Comprehensive income, net of income tax	'	'	'
Foreign currency translation adjustments	111	119	-76
Reclassification to net income of foreign currency translation adjustment related to remeasurement of equity method investments	'	'	-54
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	'	-1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	28	-2	-12
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	9	-4	-16
Other Comprehensive Income (Loss), Net of Tax, Total	148	113	-159
Total comprehensive income	1,157	978	1,180
Preferred dividends of subsidiaries	-5	-6	-8
Total comprehensive income, after preferred dividends of subsidiaries	1,152	972	1,172
Net-Of-Tax Amount [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net income	411	489	436
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	2	-1	'
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	2	-1	'
Total comprehensive income	413	488	436
Net-Of-Tax Amount [Member] | Southern California Gas Company [Member]	'	'	'
Net income	365	290	288
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-1	2	-1
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	1	1	2
Other Comprehensive Income (Loss), Net of Tax, Total	0	3	1
Total comprehensive income	365	293	289
Noncontrolling Interests [Member]	'	'	'
Net income	79	55	42
Comprehensive income, net of income tax	'	'	'
Foreign currency translation adjustments	-27	15	6
Reclassification to net income of foreign currency translation adjustment related to remeasurement of equity method investments	'	'	0
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	'	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0	0	0
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	19	-11	-36
Other Comprehensive Income (Loss), Net of Tax, Total	-8	4	-30
Total comprehensive income	71	59	12
Preferred dividends of subsidiaries	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	71	59	12
Noncontrolling Interests [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net income	24	26	19
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	0	0	'
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	17	-11	-36
Other Comprehensive Income (Loss), Net of Tax, Total	17	-11	-36
Total comprehensive income	41	15	-17
Total Equity [Member]	'	'	'
Net income	1,088	920	1,381
Comprehensive income, net of income tax	'	'	'
Foreign currency translation adjustments	84	134	-70
Reclassification to net income of foreign currency translation adjustment related to remeasurement of equity method investments	'	'	-54
Other Comprehensive Income (Loss), Available-for-sale Securities Adjustment, Net of Tax	'	'	-1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	28	-2	-12
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	28	-15	-52
Other Comprehensive Income (Loss), Net of Tax, Total	140	117	-189
Total comprehensive income	1,228	1,037	1,192
Preferred dividends of subsidiaries	-5	-6	-8
Total comprehensive income, after preferred dividends of subsidiaries	1,223	1,031	1,184
Total Equity [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net income	435	515	455
Comprehensive income, net of income tax	'	'	'
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	2	-1	'
Other Comprehensive Income (Loss), Derivatives Qualifying as Hedges, Net of Tax	17	-11	-36
Other Comprehensive Income (Loss), Net of Tax, Total	19	-12	-36
Total comprehensive income	$454	$503	$419

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	$1,088	$920	$1,381
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation and amortization	1,113	1,090	976
Deferred income taxes and investment tax credits	334	-43	3
Gains on sale of assets	-114	-7	0
Loss from plant closure	200	0	0
Equity earnings	-55	324	-61
Remeasurement of equity method investments	0	0	-277
Fixed-price contracts and other derivatives	-21	-26	2
Other adjustments to reconcile net income to net cash provided by operating activities	13	41	-15
Net change in other working capital components [Abstract]	'	'	'
Net change in accounts and notes receivable	-273	36	-32
Net change in income taxes, net	-38	-29	269
Net change in inventories	116	-78	-84
Net change in other current assets	15	180	295
Net change in regulatory balancing accounts	-198	-291	-150
Net change in regulatory assets and liabilities	1	-6	-2
Net change in accounts payable	-28	3	60
Net change in other current liabilities	-215	-445	-580
Net change in other working capital components	-620	-630	-224
Distributions from RBS Sempra Commodities LLP, operating activities	0	0	53
Changes in other assets	-171	219	34
Changes in other liabilities	17	130	-5
Net cash provided by operating activities	1,784	2,018	1,867
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Expenditures for property, plant and equipment	-2,572	-2,956	-2,844
Expeditures for investments and acquisition of businesses, net of cash acquired	-22	-445	-941
Proceeds from sale of assets	570	74	2
Proceeds from U.S. Treasury grants	238	0	0
Distributions from RBS Sempra Commodities LLP, investing activities	50	0	570
Distributions from other investments	102	207	64
Purchases of nuclear decommissioning and other trust assets	-697	-738	-755
Proceeds from sales by nuclear decommissioning and other trusts	695	733	753
Decrease in restricted cash	329	196	653
Increase in restricted cash	-356	-218	-541
Decrease (increase) in notes receivable from unconsolidated affiliates, net	-14	0	0
Other cash flows from investing activities	-12	-11	-31
Net cash used in investing activities	-1,689	-3,158	-3,070
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Common dividends paid	-606	-550	-440
Preferred dividends paid by subsidiaries	-5	-6	-8
Redemptions of preferred stock of subsidiary	-82	0	-80
Issuances of common stock	62	78	28
Repurchases of common stock	-45	-16	-18
Issuances of debt (maturities greater than 90 days)	2,081	3,097	2,098
Payments on debt (maturities greater than 90 days)	-1,788	-1,112	-482
Proceeds from sale of noncontrolling interest, net of offering costs.	574	0	0
Increase (decrease) in short-term debt, net	256	-47	-498
Distributions to noncontrolling interests	-69	-61	-16
Purchase of noncontrolling interests	0	-7	-43
Other cash flows from financing activities	-40	-21	-7
Net cash provided by (used in) financing activities	338	1,355	534
Effect of exchange rate changes on cash and cash equivalents	-4	8	9
Increase (decrease) in cash and cash equivalents	429	223	-660
Cash and cash equivalents, beginning of period	475	252	912
Cash and cash equivalents, end of period	904	475	252
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION	'	'	'
Interest payments, net of amounts capitalized	544	458	440
Income tax payments, net of refunds	120	130	144
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES	'	'	'
Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization	512	0	0
Accrued capital expenditures	437	357	368
Capital expenditures recoverable by U. S. Treasury grants receivable	3	213	0
Sequestration of U.S. Treasury grants receivable	-23	0	0
Dividends declared but not paid	157	150	120
Cancellation of debt and return of investment	0	0	180
Conversion of debt to equity	0	0	30
Financing of build-to-suit property	14	0	0
Acquisition Of Business [Abstract]	'	'	'
Assets acquired	13	29	2,833
Cash paid, net of cash acquired	-11	-19	-611
Fair of equity method investments immediately prior to the acquisition	0	0	-882
Fair value of noncontrolling interests	0	0	-279
Additional consideration accrued	0	0	-32
Liabilities Assumed	2	10	1,029
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	435	515	455
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Utility depreciation and amortization	494	490	422
Deferred income taxes and investment tax credits	171	285	290
Utility loss from plant closure	200	0	0
Fixed-price contracts and other derivatives	-8	-12	-13
Other adjustments to reconcile net income to net cash provided by operating activities	-37	-63	-68
Net change in other working capital components [Abstract]	'	'	'
Net change in accounts and notes receivable	-40	12	6
Net change in due to/from affiliates, net	38	29	6
Net change in income taxes, net	-50	85	-111
Net change in inventories	-14	0	-11
Net change in other current assets	7	208	309
Net change in regulatory balancing accounts	-140	-322	-87
Net change in accounts payable	50	-42	68
Net change in interest payable	4	5	6
Net change in other current liabilities	-260	-419	-430
Net change in other working capital components	-405	-444	-244
Changes in other assets	-150	201	33
Changes in other liabilities	19	129	7
Net cash provided by operating activities	719	1,101	882
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Expenditures for property, plant and equipment	-978	-1,237	-1,831
Proceeds from sale of assets and investments	11	0	1
Purchases of nuclear decommissioning trust assets	-692	-732	-748
Proceeds from sales by nuclear decommissioning trusts	685	723	741
Decrease in restricted cash	82	92	520
Increase in restricted cash	-81	-81	-447
Net cash used in investing activities	-973	-1,235	-1,764
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Capital contribution	0	0	200
Preferred dividends paid	-5	-5	-5
Redemptions of preferred stock of subsidiary	-82	0	0
Issuances of long-term debt	450	249	598
Payments on long-term debt	-199	-10	-10
Increase (decrease) in short-term debt, net	59	0	0
Contributions to noncontrolling interests	0	0	5
Distributions to noncontrolling interests	-26	-40	0
Other cash flows from financing activities	-3	-2	-4
Net cash provided by (used in) financing activities	194	192	784
Increase (decrease) in cash and cash equivalents	-60	58	-98
Cash and cash equivalents, beginning of period	87	29	127
Cash and cash equivalents, end of period	27	87	29
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION	'	'	'
Interest payments, net of amounts capitalized	187	162	131
Income tax payments, net of refunds	84	-242	59
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES	'	'	'
Nuclear facility plant reclassified to regulatory asset, net of depreciation and amortization	512	0	0
Accrued capital expenditures	182	153	187
Dividends declared but not paid	0	1	1
Southern California Gas Company [Member]	'	'	'
CASH FLOWS FROM OPERATING ACTIVITIES	'	'	'
Net income	365	290	288
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Utility depreciation and amortization	383	362	331
Deferred income taxes and investment tax credits	117	128	130
Other adjustments to reconcile net income to net cash provided by operating activities	-5	-12	-6
Net change in other working capital components [Abstract]	'	'	'
Net change in accounts and notes receivable	-113	37	-57
Net change in due to/from affiliates, net	-57	51	-18
Net change in income taxes, net	51	-83	-12
Net change in inventories	82	-1	-46
Net change in other current assets	3	-6	5
Net change in regulatory balancing accounts	-58	31	-63
Net change in accounts payable	-54	54	-7
Net change in customer deposits	-1	1	2
Net change in other current liabilities	24	-24	-5
Net change in other working capital components	-123	60	-201
Changes in other assets	-52	14	19
Changes in other liabilities	-4	4	-7
Net cash provided by operating activities	681	846	554
CASH FLOWS FROM INVESTING ACTIVITIES	'	'	'
Expenditures for property, plant and equipment	-762	-639	-683
Decrease (increase) in notes receivable from unconsolidated affiliates, net	34	-4	49
Net cash used in investing activities	-728	-643	-634
CASH FLOWS FROM FINANCING ACTIVITIES	'	'	'
Common dividends paid	-50	-250	-50
Preferred dividends paid	-1	-1	-1
Issuances of long-term debt	0	348	0
Payments on long-term debt	0	-250	-250
Increase (decrease) in short-term debt, net	42	0	0
Debt issuance costs	0	-3	0
Net cash provided by (used in) financing activities	-9	-156	-301
Increase (decrease) in cash and cash equivalents	-56	47	-381
Cash and cash equivalents, beginning of period	83	36	417
Cash and cash equivalents, end of period	27	83	36
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION	'	'	'
Interest payments, net of amounts capitalized	65	62	65
Income tax payments, net of refunds	-52	16	25
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES	'	'	'
Accrued capital expenditures	$130	$115	$97

CONSOLIDATED_STATEMENTS_OF_CHA

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (USD $)

Total

San Diego Gas and Electric Company and Subsidiary [Member]

Southern California Gas Company [Member]

Preferred Stock

Common Stock

Common Stock

Common Stock

Retained Earnings

Retained Earnings

Retained Earnings

Deferred Compensation E S O P [Member]

Accumulated Other Comprehensive Income (Loss)

Accumulated Other Comprehensive Income (Loss)

Accumulated Other Comprehensive Income (Loss)

Total Shareholders' Equity

Total Shareholders' Equity

Noncontrolling Interests [Member]

Noncontrolling Interests [Member]

In Millions

Southern California Gas Company [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

Southern California Gas Company [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

Southern California Gas Company [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

Southern California Gas Company [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

Equity, beginning of period at Dec. 31, 2010

$9,201

$3,221

$1,955

$22

$2,036

$1,138

$866

$7,292

$1,980

$1,089

($8)

($330)

($10)

($22)

$8,990

$3,108

$211

$113

Net income

1,381

455

288

'

'

'

'

1,339

436

288

'

'

'

'

1,339

436

42

19

Comprehensive income

-189

-36

1

'

'

'

'

'

'

'

'

-159

'

1

-159

'

-30

-36

Share-based compensation expense

48

'

'

'

48

'

'

'

'

'

'

'

'

'

48

'

'

'

Call premium on preferred stock of subsidiary

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Call premium on preferred stock

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock dividends declared

-461

'

-50

'

'

'

'

-461

'

-50

'

'

'

'

-461

'

'

'

Preferred stock dividends declared

'

-5

-1

'

'

'

'

'

-5

-1

'

'

'

'

'

-5

'

'

Preferred dividends of subsidiaries

-8

'

'

'

'

'

'

-8

'

'

'

'

'

'

-8

'

'

'

Capital contribution

'

200

'

'

'

200

'

'

'

'

'

'

'

'

'

200

'

'

Issuance of common stock

28

'

'

'

28

'

'

'

'

'

'

'

'

'

28

'

'

'

Repurchases of common stock

-18

'

'

'

-18

'

'

'

'

'

'

'

'

'

-18

'

'

'

Common stock released from ESOP

20

'

'

'

14

'

'

'

'

'

6

'

'

'

20

'

'

'

Acquisition of South American entities

279

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

279

'

Equity contributed by noncontrolling interests

36

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

36

'

Distributions to noncontrolling interests

-16

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-16

6

Purchase of noncontrolling interest in subsidiary

-43

'

'

'

-4

'

'

'

'

'

'

'

'

'

-4

'

-39

'

Redemption of preferred stock of subidiary

-80

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-80

'

Equity, end of period at Dec. 31, 2011

10,178

3,841

2,193

22

2,104

1,338

866

8,162

2,411

1,326

-2

-489

-10

-21

9,775

3,739

403

102

Net income

920

515

290

'

'

'

'

865

489

290

'

'

'

'

865

489

55

26

Comprehensive income

117

-12

3

'

'

'

'

'

'

'

'

113

-1

3

113

-1

4

-11

Share-based compensation expense

44

'

'

'

44

'

'

'

'

'

'

'

'

'

44

'

'

'

Call premium on preferred stock of subsidiary

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Call premium on preferred stock

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock dividends declared

-580

'

-250

'

'

'

'

-580

'

-250

'

'

'

'

-580

'

'

'

Preferred stock dividends declared

'

-5

-1

'

'

'

'

'

-5

-1

'

'

'

'

'

-5

'

'

Preferred dividends of subsidiaries

-6

'

'

'

'

'

'

-6

'

'

'

'

'

'

-6

'

'

'

Issuance of common stock

78

'

'

'

78

'

'

'

'

'

'

'

'

'

78

'

'

'

Repurchases of common stock

-16

'

'

'

-16

'

'

'

'

'

'

'

'

'

-16

'

'

'

Common stock released from ESOP

9

'

'

'

7

'

'

'

'

'

2

'

'

'

9

'

'

'

Acquisition of South American entities

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity contributed by noncontrolling interests

8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8

'

Distributions to noncontrolling interests

-62

-41

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-62

-41

Purchase of noncontrolling interest in subsidiary

-7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-7

'

Equity, end of period at Dec. 31, 2012

10,683

4,298

2,235

22

2,217

1,338

866

8,441

2,895

1,365

0

-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

'

'

'

Call premium on preferred stock of subsidiary

-3

'

'

'

'

'

'

-3

'

'

'

'

'

'

-3

'

'

'

Call premium on preferred stock

'

-3

'

'

'

'

'

'

-3

'

'

'

'

'

'

-3

'

'

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

'

'

'

Acquisition of South American entities

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Sale of noncontrolling interests, net of offering costs

574

'

'

'

135

'

'

'

'

'

'

'

'

'

135

'

439

'

Distributions to noncontrolling interests

-69

-26

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-69

-26

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

$0

($228)

($9)

($18)

$11,008

$4,628

$842

$91

SIGNIFICANT_ACCOUNTING_POLICIE

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA	12 Months Ended
	Dec. 31, 2013
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 California 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 Utilities, which do not include the utilities in our Sempra International and Sempra U.S. Gas & Power operating units. Sempra Global is the holding company for most of our subsidiaries that are not subject to California utility regulation. All references in these Notes to “Sempra International,” “Sempra U.S. Gas & Power” and their respective reportable segments are not intended to refer to any legal entity with the same or similar name.
	In the first quarter of 2013, Sempra Energy's subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), completed a private offering in the U.S. and outside of Mexico and a concurrent public offering in Mexico of common stock. The aggregate shares of common stock sold in the offerings represent approximately 18.9 percent of IEnova's outstanding ownership interest. IEnova is reported within the Sempra Mexico reportable segment. We discuss the offerings and IEnova in “Noncontrolling Interests – Sale of Noncontrolling Interests” below.
	Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to exercise significant influence, but not control. We discuss our investments in unconsolidated entities in Notes 3 and 4.
	SDG&E
	SDG&E's Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, 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 minimus accounts of inactive subsidiaries. SoCalGas' common stock is wholly owned by Pacific Enterprises (PE), which is a wholly owned subsidiary of Sempra Energy.
	BASIS OF PRESENTATION
	This 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 two electric distribution utilities in South America. 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 Mexico, S de RL de CV (Ecogas) in northern Mexico, all natural gas distribution utilities. The California Utilities, Sempra Natural Gas' Mobile Gas and Willmut Gas, and Sempra Mexico's Ecogas prepare their financial statements in accordance with the provisions of accounting principles generally accepted in the United States of America (U.S. GAAP) governing regulated operations, as we discuss below under “Regulatory Matters.” We discuss revenue recognition at our utilities in “Revenues–Utilities” below.
	Use of Estimates in the Preparation of the Financial Statements
	We have prepared our Consolidated Financial Statements in conformity with U.S. GAAP. This 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 reasonable, actual amounts ultimately may differ significantly from those estimates.
	Subsequent Events
	We evaluated events and transactions that occurred after December 31, 2013 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. We discuss subsequent events further in Note 18.
	REGULATORY MATTERS
	Effects of Regulation
	The accounting policies of our regulated utility subsidiaries in California, SDG&E and SoCalGas, conform with U.S. GAAP for 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 regulated operations. Under these provisions, a regulated utility records a regulatory asset, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover that asset from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory 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, generally 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 which are passed through to customers in future rates. 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 precedence;
	regulatory 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 rehearings or state court appeals;
	specific approval from a commission; and
	historical experience.
	Our other natural gas distribution utilities, Mobile Gas, Willmut Gas and Ecogas, also apply U.S. GAAP for regulated utilities to their operations.
	We provide information concerning regulatory assets and liabilities below in “Regulatory Balancing Accounts” and “Regulatory Assets 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
			2013		2012		2013		2012		2013		2012
	Current:
	Overcollected		$	-1,077	$	-643	$	-645	$	-340	$	-432	$	-303
	Undercollected			1,542		897		1,201		735		341		162
	Net current receivable (payable)(1)			465		254		556		395		-91		-141
	Non-current:
	Undercollected(2)			213		―		161		―		52		―
	Total net receivable (payable)(1)		$	678	$	254	$	717	$	395	$	-39	$	-141
	-1	At December 31, 2013 and 2012, the net receivable at SDG&E and the net payable at SoCalGas are shown separately on Sempra Energy's Consolidated Balance Sheets.
	-2	Long-term undercollected balance included in Other Regulatory Assets (long-term) on the 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 certain 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 details 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)
		2013		2012
SDG&E
Fixed-price contracts and other derivatives		$	58	$	149
Costs related to SONGS plant closure			303		―
Costs related to wildfire litigation			330		364
Deferred taxes recoverable in rates			788		718
Pension and other postretirement benefit obligations			106		303
Removal obligations(1)			-1,403		-1,603
Unamortized loss on reacquired debt			14		16
Environmental costs			20		16
Legacy meters			62		90
Sunrise Powerlink fire mitigation			115		117
Other			15		23
Total SDG&E			408		193
SoCalGas
Pension and other postretirement benefit obligations			231		835
Employee benefit costs			51		58
Removal obligations(1)			-1,205		-1,103
Deferred taxes recoverable in rates			110		38
Unamortized loss on reacquired debt			14		17
Environmental costs			14		14
Workers’ compensation			26		27
Other			―		-2
Total SoCalGas			-759		-116
Other Sempra Energy
Sempra Natural Gas			-11		3
Sempra Mexico			8		1
Total Other Sempra Energy			-3		4
Total Sempra Energy Consolidated		$	-354	$	81
-1	Related to obligations discussed below in “Asset Retirement Obligations.”
NET REGULATORY ASSETS (LIABILITIES) AS PRESENTED ON THE CONSOLIDATED BALANCE SHEETS AT DECEMBER 31
(Dollars in millions)
		2013							2012
		Sempra							Sempra
		Energy							Energy
		Consolidated		SDG&E		SoCalGas			Consolidated		SDG&E		SoCalGas
Current regulatory assets		$	38	$	29	$	5		$	62	$	49	$	4
Noncurrent regulatory assets(1)			2,335		1,787		536			2,742		1,747		983
Current regulatory liabilities(2)			-7		-5		―			-2		―		―
Noncurrent regulatory liabilities(3)			-2,720		-1,403		-1,300			-2,721		-1,603		-1,103
Total		$	-354	$	408	$	-759		$	81	$	193	$	-116
-1	Excludes long-term undercollected balancing accounts of $213 million at Sempra Energy, $161 million at SDG&E and $52 million at SoCalGas recorded in Other Regulatory Assets (long-term).
-2	Included in Other Current Liabilities.
-3	At December 31, 2013 and 2012, $97 million and $1 million, respectively, at Sempra Energy Consolidated is included in Deferred Credits and Other.
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 related to the San Onofre Nuclear Generating Station (SONGS) plant closure represent management's estimate of what SDG&E will be allowed to recover in rates in the future associated with SDG&E's investment in SONGS as of the plant closure date, the cost of operations since Units 2 and 3 were taken offline, and the cost of purchased replacement power, 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 “Excess Wildfire Claims Cost Recovery at the CPUC” and Note 15 under “SDG&E—2007 Wildfire Litigation.”
Deferred taxes recoverable in rates are based on current regulatory ratemaking and income tax laws. SDG&E and SoCalGas expect to recover net regulatory assets related to deferred income taxes over the lives of the assets that give rise to the accumulated deferred income tax liabilities. These net assets are included in ratebase.
Regulatory assets/liabilities related to pension and other postretirement 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 original amortization periods of the losses on reacquired debt. These periods range from 5 months to 14 years for SDG&E and from 8 years to 12 years for SoCalGas.
Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of 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 replaced under the Smart Meter Program is their undepreciated value. SDG&E is recovering this asset over a 4-year period in ratebase.
The 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 50-year period.
FAIR VALUE MEASUREMENTS
We apply recurring fair value measurements to certain assets and liabilities, primarily nuclear decommissioning and benefit plan trust assets and other miscellaneous derivatives. “Fair value” is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).
A fair value measurement reflects the assumptions market participants would use 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 issuer's credit standing when measuring its liabilities at fair value.
We establish a fair 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 identical 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 assets 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 consist of listed equities, 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 reporting 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
time 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 derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include the Nuclear Decommissioning Trusts' investments at SDG&E 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 that 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
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 $49 million and $68 million at December 31, 2013 and 2012, respectively. Of this, $24 million and $46 million were classified as current and $25 million and $22 million were classified as noncurrent at December 31, 2013 and 2012, respectively.
Sempra Renewables had restricted cash of $6 million and $35 million classified as current at December 31, 2013 and 2012, respectively. The 2013 balance primarily represents funds held in accordance with long-term debt agreements at Copper Mountain Solar 1. The 2012 balance represents funds held in accordance with long-term debt agreements at Copper Mountain Solar 1 and Mesquite Solar 1. We discuss the debt agreements further in Note 5 and in “Restricted Net Assets” below.
At December 31, 2013, Sempra Mexico had restricted cash of $12 million classified as current to pay for rights of way, license fees, permits, topographic surveys and other costs pursuant to trust agreements related to a pipeline project.
SDG&E had $31 million and $32 million of restricted cash at December 31, 2013 and 2012, respectively, which represents funds held by a trustee for Otay Mesa VIE (see “Variable Interest Entities—Otay Mesa VIE” below) to pay certain operating costs. Of this, $6 million and $10 million were classified as current and $25 million and $22 million were classified as noncurrent at December 31, 2013 and 2012, respectively.
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 the changes in these allowances in the table below:
COLLECTION ALLOWANCES
(Dollars in millions)
	Years ended December 31,
	2013		2012		2011
Sempra Energy Consolidated
Allowances for collection of receivables at January 1	$	31	$	29	$	29
Provisions for uncollectible accounts		16		21		20
Write-offs of uncollectible accounts		-18		-19		-20
Allowances for collection of receivables at December 31	$	29	$	31	$	29
SDG&E
Allowances for collection of receivables at January 1	$	6	$	6	$	5
Provisions for uncollectible accounts		4		5		8
Write-offs of uncollectible accounts		-5		-5		-7
Allowances for collection of receivables at December 31	$	5	$	6	$	6
SoCalGas
Allowances for collection of receivables at January 1	$	14	$	12	$	14
Provisions for uncollectible accounts		7		12		8
Write-offs of uncollectible accounts		-9		-10		-10
Allowances for collection of receivables at December 31	$	12	$	14	$	12
We evaluate accounts receivable collectibility 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 historical and industry trends.
We write off accounts receivable in the period in which we deem the receivable 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 market.
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 market. 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
		2013		2012			2013	2012		2013		2012		2013		2012
SDG&E		$	3	$	3	$	―	$	―	$	83	$	79	$	86	$	82
SoCalGas			42		128		―		―		27		23		69		151
Sempra South American Utilities			―		―		―		―		40		34		40		34
Sempra Mexico			―		―		3		8		9		8		12		16
Sempra Renewables			―		―		―		―		2		3		2		3
Sempra Natural Gas			68		109		5		8		5		5		78		122
Sempra Energy Consolidated		$	113	$	240	$	8	$	16	$	166	$	152	$	287	$	408
U.S. TREASURY GRANTS RECEIVABLE
At December 31, 2012, we had recognized receivables for U.S. Treasury grants based on eligible costs at our Mesquite Solar 1 and Copper Mountain Solar 2 generating facilities when the projects, or portions of projects, were placed into service. 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, cash grant payments to eligible taxpayers for renewable energy projects were reduced, and we recorded a reduction to our grants receivable of $23 million and a reversal of income tax benefit of $5 million during the first quarter of 2013. In June 2013, we received $74 million in cash related to the Copper Mountain Solar 2 grant. We received $164 million in cash for the remaining grant receivable for Mesquite Solar 1 in August 2013.
INCOME TAXES
Income tax expense includes current and deferred income taxes from operations during the year. We record deferred income taxes for temporary differences between the book and the tax bases 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, Mobile Gas and Willmut Gas recognize
regulatory assets to offset deferred tax liabilities if it is probable that the amounts will be recovered from customers; and
regulatory liabilities to offset deferred tax assets if it is probable that the amounts will be returned to customers.
Other than local country withholding tax on current Peruvian earnings, we 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 their cumulative undistributed earnings are indefinitely 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 technical 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 results of operations, financial position and cash flows.
We provide additional information about income taxes in Note 6.
GREENHOUSE GAS ALLOWANCES
The California Utilities, Sempra Mexico and Sempra Natural Gas supply power into the California Independent System Operator (ISO) grid and are, therefore, required by California Assembly Bill 32 to acquire greenhouse gas allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during generation. We account for greenhouse gas allowances as inventory, measured 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 Current Liabilities and Deferred Credits 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 Utilities expect that all costs and revenues associated with the greenhouse gas program will be recorded through Regulatory Balancing Accounts on the Consolidated Balance Sheets.
RENEWABLE ENERGY CERTIFICATES
Renewable energy 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 are the mechanism used to verify renewable portfolio standards compliance. The cost of RECs is recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Consolidated Statements of Operations.
PROPERTY, PLANT AND EQUIPMENT
Property, plant and equipment primarily represents the buildings, equipment and other facilities used by the California Utilities to provide natural gas and electric utility services, and by Sempra International and Sempra U.S. Gas & Power, including construction work in progress at these operating units. Property, plant and equipment also includes lease improvements and other equipment at Parent, as well as property acquired under a build-to-suit lease included in construction work in progress.
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 our utility plant and selected non-utility regulated projects in Mexico include an allowance for funds used during construction (AFUDC). We discuss AFUDC below. The cost of non-utility plant includes capitalized interest.
Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant minus 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
		and Equipment at					Depreciation rates for
		December 31,					years ended December 31,
		2013		2012			2013		2012		2011
SDG&E:
Natural gas operations		$	1,454	$	1,406		2.35	%	3.2	%	3.15	%
Electric distribution			5,492		5,217		3.36		4.15		4.13
Electric transmission(1)			3,932		3,714		2.58		2.63		2.74
Electric generation(2)			1,768		2,242		3.76		4.68		4.92
Other electric(3)			759		679		7.58		7.92		8.26
Construction work in progress(1)			941		866		NA		NA		NA
Total SDG&E			14,346		14,124
SoCalGas:
Natural gas operations(4)			11,394		10,756		3.7		3.74		3.62
Other non-utility			118		129		1.56		1.36		1.62
Construction work in progress			319		302		NA		NA		NA
Total SoCalGas			11,831		11,187
							Estimated			Weighted Average
Other operating units and parent(5):							Useful Lives			Useful Life
Land and land rights			276		298		20 to 50 years(6)			47
Machinery and equipment:
Utility electric distribution operations			1,440		1,459		10 to 46 years			40
Generating plants			993		1,568		3 to 35 years			31
LNG terminals			2,094		2,061		3 to 50 years			46
Pipelines and storage			1,638		1,634		3 to 50 years			42
Other			212		241		1 to 47 years			13
Construction work in progress			1,283		692		NA			NA
Other			294		264		2 to 80 years			29
			8,230		8,217
Total Sempra Energy Consolidated		$	34,407	$	33,528
-1	At December 31, 2013, includes $350 million in electric transmission assets and $5 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 $183 million at both December 31, 2013 and 2012, primarily related to variable interest entities of which SDG&E is not the primary beneficiary.
-3	Includes capital lease assets of $23 million at both December 31, 2013 and 2012.
-4	Includes capital lease assets of $33 million and $32 million at December 31, 2013 and 2012, respectively.
-5	December 31, 2013 balances include $155 million, $180 million and $22 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively. December 31, 2012 balances include $144 million, $171 million and $18 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 straight-line method over the asset's estimated original composite useful life, the CPUC-prescribed period or the remaining term of the site leases, whichever is shortest.
The accumulated depreciation and decommissioning amounts on our Consolidated Balance Sheets are as follows:
ACCUMULATED DEPRECIATION AND DECOMMISSIONING AMOUNTS
(Dollars in millions)
		December 31,
		2013		2012
SDG&E:
Accumulated depreciation and decommissioning of utility plant in service:
Electric(1)		$	2,861	$	2,660
Natural gas			639		601
Total SDG&E			3,500		3,261
SoCalGas:
Accumulated depreciation of natural gas utility plant in service(2)			4,279		4,067
Accumulated depreciation – other non-utility			85		103
Total SoCalGas			4,364		4,170
Other operating units and parent:
Accumulated depreciation – other(3)			938		806
Accumulated depreciation of utility electric distribution operations			145		100
			1,083		906
Total Sempra Energy Consolidated		$	8,947	$	8,337
-1	Includes accumulated depreciation for assets under capital lease of $26 million and $21 million at December 31, 2013 and 2012, respectively. Includes $199 million 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 $31 million and $28 million at December 31, 2013 and 2012, respectively.
-3	December 31, 2013 balances include $38 million, $25 million and $2 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively. December 31, 2012 balances include $34 million, $21 million and $1 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively.
The California 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 of the assets.
Pipeline projects currently under construction by Sempra Mexico that are both regulated by the Comisión Reguladora de Energía (or CRE, the Energy Regulatory Commission) and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC related to equity. Beginning in the fourth quarter of 2013, Sempra Mexico began recording AFUDC equity for its Sonora Pipeline project.
Sempra International and Sempra U.S. Gas & Power businesses capitalize interest costs incurred to finance capital projects. The California Utilities also capitalize certain interest costs.
CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Years ended December 31,
	2013		2012		2011
Sempra Energy Consolidated:
AFUDC related to debt	$	22	$	38	$	40
AFUDC related to equity		75		96		99
Other capitalized financing costs		22		52		26
Total Sempra Energy Consolidated	$	119	$	186	$	165
SDG&E:
AFUDC related to debt	$	16	$	30	$	33
AFUDC related to equity		39		71		80
Total SDG&E	$	55	$	101	$	113
SoCalGas:
AFUDC related to debt	$	6	$	8	$	7
AFUDC related to equity		17		25		19
Other capitalized financing costs		1		1		―
Total SoCalGas	$	24	$	34	$	26
ASSETS HELD FOR SALE
We classify assets as held for sale when management approves and commits to a formal plan to actively market an asset for sale and we expect the sale to close within the next twelve months. Upon classifying an asset as held for sale, we record the asset at the lower of its carrying value or its estimated fair value reduced for selling costs, and we stop recording depreciation expense on the asset.
At December 31, 2013, there are no assets classified as held for sale. We discuss assets held for sale further in Note 18.
In December 2012, management approved a formal plan and executed an agreement to sell one 625-megawatt (MW) block of Sempra Natural Gas' Mesquite Power natural gas-fired power plant in Arizona to Salt River Project Agricultural Improvement and Power District. In February 2013, the asset was sold for $371 million in cash.
At December 31, 2012, the carrying amount of the major classes of assets and related liability held for sale associated with the plant included the following:
(Dollars in millions)		2012
Property, plant, and equipment, net		$	292
Inventories			4
Total assets held for sale			296
Liability held for sale - asset retirement obligation(1)			-5
Total		$	291
-1	Included in Other Current Liabilities on the Consolidated Balance Sheet.
For the year ended December 31, 2012, there was no impairment of the assets held for sale as the estimated fair value less costs to sell exceeded the carrying amount.
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 is tested 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, including goodwill, exceeds its fair value, and the book value 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 qualitative 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, quantitative 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
country risk
entity risk
Goodwill included on the Sempra Energy Consolidated Balance Sheets is as follows:
GOODWILL
(Dollars in millions)
			Sempra
		South American			Sempra		Sempra
			Utilities		Mexico		Natural Gas		Total
Balance at December 31, 2011		$	949	$	25	$	62	$	1,036
Acquisition of subsidiary			―		―		10		10
Foreign currency translation(1)			65		―		―		65
Balance at December 31, 2012			1,014		25		72		1,111
Foreign currency translation(1)			-87		―		―		-87
Balance at December 31, 2013		$	927	$	25	$	72	$	1,024
-1	We record the offset of this fluctuation to other comprehensive income.
Sempra Natural Gas recorded goodwill of $10 million in connection with the acquisition of Willmut Gas Company in May 2012.
We provide additional information concerning goodwill related to our equity method investments and the impairment of investments in unconsolidated subsidiaries in Note 4.
Other Intangible Assets
Sempra Natural Gas recorded $460 million of intangible assets in connection with the acquisition of EnergySouth, Inc. in 2008. These intangible assets 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) and were recorded at estimated fair value as of the date of the acquisition using discounted cash flows analysis. Our assumptions in determining fair value included estimated future cash flows, the estimated useful life of the intangible assets and appropriate discount rates. We are amortizing these intangible assets over their estimated useful lives as shown in the table below.
Other Intangible Assets included on the Sempra Energy Consolidated Balance Sheets are as follows:
OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period	December 31,
	(years)	2013		2012
Storage rights	46	$	138	$	138
Development rights	50		322		322
Other	15 years to indefinite		19		19
			479		479
Less accumulated amortization:
Storage rights			-16		-13
Development rights			-34		-27
Other			-3		-3
			-53		-43
		$	426	$	436
Amortization expense for such intangible assets was $10 million in each of 2013, 2012 and 2011. We estimate the amortization expense for the next five years to be $10 million per year.
LONG-LIVED ASSETS
We 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 unconsolidated 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 price 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 current 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
Impairment of long-lived assets occurs when the estimated future undiscounted cash flows are less than the carrying amount of the assets. If that comparison indicates that the assets' carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the assets. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
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 the VIE.
SDG&E
Tolling Agreements
SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements).  SDG&E's obligation to absorb natural gas costs may be a significant variable interest.  In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based upon our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility's useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which we consider the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If we determine that SDG&E is the primary beneficiary, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE, as we discuss below.
Otay Mesa VIE
SDG&E has an agreement to purchase power generated at the Otay Mesa Energy Center (OMEC), a 605-MW generating facility. In addition to tolling, the agreement provides SDG&E with the option to purchase the power plant at the end of the contract term in 2019, or upon earlier termination of the purchased-power agreement, at a predetermined price subject to adjustments based on performance of the facility. If SDG&E does not exercise its option, under certain circumstances, it may be required to purchase the power plant at a predetermined price, which we refer to as the put option.
The facility owner, Otay Mesa Energy Center LLC (OMEC LLC), is a VIE (Otay Mesa VIE), of which SDG&E is the primary beneficiary. SDG&E has no OMEC LLC voting rights and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. SDG&E and Sempra Energy have consolidated Otay Mesa VIE since the second quarter of 2007. Otay Mesa VIE's equity of $91 million at December 31, 2013 and $76 million at December 31, 2012 is included on the Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.
OMEC LLC has a loan outstanding of $335 million at December 31, 2013, the proceeds of which were used for the construction of OMEC. The loan is with third party lenders and is secured by OMEC's property, plant and equipment. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC. The loan fully matures in April 2019 and bears interest at rates varying with market rates. In addition, OMEC LLC has entered into interest rate swap agreements to moderate its exposure to interest rate changes. We provide additional information concerning the interest rate swaps in Note 9.
Other Variable Interest Entities
SDG&E's power procurement is subject to reliability requirements that may require SDG&E to enter into various power purchase arrangements which include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and thereby Sempra Energy, is the primary beneficiary. SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE mentioned above, result in SDG&E being the primary beneficiary at December 31, 2013. In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs, including certain construction costs, tax credits, and other components of cash flow expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects are not expected to significantly affect the financial position, results of operations, or liquidity of SDG&E. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates.
Sempra Energy's other operating units also enter into arrangements which could include variable interests. We evaluate these arrangements and applicable entities based upon the qualitative and quantitative analyses described above. Certain of these entities are service companies that are VIEs. As the primary beneficiary of these service companies, we consolidate them. In all other cases, we have determined that these contracts are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation of VIEs.
The Consolidated Financial Statements of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The financial statements of other consolidated VIEs are not material to the financial statements of Sempra Energy. The captions on the tables below correspond to SDG&E's Consolidated Balance Sheets and Consolidated Statements of Operations.
AMOUNTS ASSOCIATED WITH OTAY MESA VIE
(Dollars in millions)
						December 31,
						2013		2012
Cash and cash equivalents						$	17	$	8
Restricted cash							6		10
Inventories							2		2
Other							1		1
Total current assets							26		21
Restricted cash							25		22
Sundry							4		5
Property, plant and equipment, net							438		466
Total assets						$	493	$	514
Current portion of long-term debt						$	10	$	10
Fixed-price contracts and other derivatives							16		17
Other							19		8
Total current liabilities							45		35
Long-term debt							325		335
Fixed-price contracts and other derivatives							39		64
Deferred credits and other							-7		4
Other noncontrolling interest							91		76
Total liabilities and equity						$	493	$	514
				Years ended December 31,
				2013		2012		2011
Operating expenses
Cost of electric fuel and purchased power				$	-91	$	-83	$	-72
Operation and maintenance					24		19		19
Depreciation and amortization					28		26		22
Total operating expenses					-39		-38		-31
Operating income					39		38		31
Other expense, net					―		-1		-1
Interest expense					-15		-11		-11
Income before income taxes/Net income					24		26		19
Earnings attributable to noncontrolling interest					-24		-26		-19
Earnings				$	―	$	―	$	―
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 estimated retirement cost over the life of the related asset by depreciating the present value of the obligation (measured at the time of the asset's acquisition) and accreting the discount until the liability is settled. Rate-regulated entities 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. We have recorded a regulatory liability to show that the California Utilities have collected funds from customers more quickly and for larger amounts than we would accrete the retirement liability and depreciate the asset in accordance with U.S. GAAP.
We have recorded asset retirement obligations related to various assets, including:
SDG&E and SoCalGas
fuel and storage tanks
natural gas distribution systems
hazardous waste storage facilities
asbestos-containing construction materials
SDG&E
decommissioning of nuclear power facilities
electric distribution and transmission systems
site restoration of a former power plant
power generation plant (natural gas)
SoCalGas
natural gas transmission pipelines
underground natural gas storage facilities and wells
Sempra Mexico
power generation plant (natural gas)
natural gas distribution and transportation systems
LNG terminal
Sempra Renewables
certain power generation plants (solar)
Sempra Natural Gas
power generation plant (natural gas)
natural gas distribution and transportation systems
underground natural gas storage facilities
The changes in asset retirement obligations are as follows:
CHANGES IN ASSET RETIREMENT OBLIGATIONS
(Dollars in millions)
		Sempra Energy
		Consolidated					SDG&E					SoCalGas
		2013		2012			2013		2012			2013		2012
Balance as of January 1(1)		$	2,056	$	1,925		$	741	$	698		$	1,253	$	1,175
Accretion expense			97		92			45		42			49		48
Liabilities incurred			4		21			―		―			―		―
Reclassification(2)			―		-5			―		―			―		―
Payments			-49		-2			-48		―			―		-1
Revisions, GRC-related(3)			-135		―			-30		―			-105		―
Revisions, other(4)			179		25			205		1			2		31
Balance as of December 31(1)		$	2,152	$	2,056		$	913	$	741		$	1,199	$	1,253
-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 Sheets, as we discuss in "Assets Held for Sale" above.
-3	The decreases in asset retirement obligations in 2013 at SDG&E and SoCalGas are due to revised estimates related to the 2012 General Rate Case (GRC) that received final approval in May 2013. At SDG&E, these revisions included increases in asset service lives ranging from 2 percent to 7 percent, and lower estimated cost of removal. At SoCalGas, the decrease includes increases in asset service lives ranging from 4 percent to 6 percent, partially offset by a higher estimated cost of removal.
-4	The increase in asset retirement obligations in 2013 at SDG&E is due to revised estimates recorded in the third quarter of 2013 related to the early decommissioning of SONGS Units 2 and 3 (see Note 13).
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:
information 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 contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
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.
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 Income show the changes in the components of other comprehensive income (OCI), including the amounts attributable to noncontrolling interests. The following tables present the changes in Accumulated Other Comprehensive Income (Loss) (AOCI) by component, and amounts reclassified out of AOCI to net income, excluding amounts attributable to noncontrolling interests:
CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
		Year ended December 31, 2013
				Pension and Other
				Postretirement Benefits
		Foreign								Total
		Currency		Unamortized		Unamortized				Accumulated Other
		Translation		Net Actuarial		Prior Service		Financial		Comprehensive
		Adjustments		Gain (Loss)		Credit (Cost)		Instruments		Income (Loss)
Sempra Energy Consolidated:
Balance as of December 31, 2012		$	-240	$	-102	$	1	$	-35	$	-376
Other comprehensive (loss) income before
reclassifications			-159		―		―		2		-157
Amounts reclassified from accumulated other
comprehensive income			270	-2	29		-1		7		305
Net other comprehensive income (loss)			111		29		-1		9		148
Balance as of December 31, 2013		$	-129	$	-73	$	―	$	-26	$	-228
SDG&E:
Balance as of December 31, 2012		$	―	$	-12	$	1	$	―	$	-11
Amounts reclassified from accumulated other
comprehensive income			―		2		―		―		2
Net other comprehensive income			―		2		―		―		2
Balance as of December 31, 2013		$	―	$	-10	$	1	$	―	$	-9
SoCalGas:
Balance as of December 31, 2012		$	―	$	-4	$	1	$	-15	$	-18
Amounts reclassified from accumulated other
comprehensive (loss) income			―		-1		―		1		―
Net other comprehensive (loss) income			―		-1		―		1		―
Balance as of December 31, 2013		$	―	$	-5	$	1	$	-14	$	-18
-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.
RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Year ended December 31, 2013
			Amount reclassified
Details about accumulated			from accumulated other				Affected line item
other comprehensive income (loss) components			comprehensive income (loss)				on Consolidated Statement of Operations
Sempra Energy Consolidated:
Foreign currency translation adjustments				$	270		Equity Earnings, Net of Income Tax(1)
Financial instruments:
Interest rate and foreign exchange instruments				$	11		Interest Expense
Interest rate instruments					10		Equity Losses, Before Income Tax
Commodity contracts not subject to							Cost of Natural Gas, Electric Fuel and Purchased
	rate recovery				-1		Power
Total before income tax					20
					-4		Income Tax Expense
Net of income tax					16
					-9		Earnings Attributable to Noncontrolling Interests
				$	7
Pension and other postretirement benefits:
Net actuarial gain				$	38		-2
Amortization of actuarial loss					10		-2
Prior service cost					-1		-2
					-19		Income Tax Expense
Net of income tax				$	28
Total reclassifications for the period, net of tax				$	305
SDG&E:
Financial instruments:
Interest rate instruments				$	9		Interest Expense
					-9		Earnings Attributable to Noncontrolling Interest
				$	―
Pension and other postretirement benefits:
Net actuarial gain				$	2		-2
Amortization of actuarial loss					1		-2
					-1		Income Tax Expense
Net of income tax				$	2
Total reclassifications for the period, net of tax				$	2
SoCalGas:
Financial instruments:
Interest rate instruments				$	1		Interest Expense
Pension and other postretirement benefits:
Net actuarial loss				$	-3		-2
Amortization of actuarial loss					1		-2
					1		Income Tax Expense
Net of income tax				$	-1
Total reclassifications for the period, net of tax				$	―
-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, 2011 - 2013" in Note 7).
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. As a result, noncontrolling interests are reported as a separate component of equity on the Consolidated Balance Sheets. Earnings or loss attributable to the noncontrolling interests is separately identified on the Consolidated Statements of Operations, and net income or loss and comprehensive income or loss attributable to the noncontrolling interests is separately identified on the Consolidated Statements of Comprehensive Income and Consolidated Statements of Changes in Equity.
Sale of Noncontrolling Interests
On March 21, 2013, Sempra Energy's IEnova subsidiary priced a private offering in the U.S. and outside of Mexico and a concurrent initial public offering in Mexico of new shares of Class II, Single Series common stock at $2.75 per share in U.S. dollars or 34.00 Mexican pesos. The initial purchasers in the private offering and the underwriters in the Mexican public offering were granted a 30-day option to purchase additional common shares at the initial offering price, less the underwriting discount, to cover overallotments. These options were exercised before the settlement date of the offerings, which was March 27, 2013. After the initial offerings and the exercise of the overallotment options, the aggregate shares of common stock sold in the offerings totaled 218,110,500, representing approximately 18.9 percent of IEnova's outstanding ownership interest.
The net proceeds of the offerings, including the additional option shares, were approximately $574 million in U.S. dollars or 7.1 billion Mexican pesos. IEnova is using the net proceeds of the offerings primarily for general corporate purposes, and for the funding of its current investments and ongoing expansion plans. All U.S. dollar equivalents presented here were based on an exchange rate of 12.3841 Mexican pesos to 1.00 U.S. dollar as of March 21, 2013, the pricing date for the offerings. Net proceeds are after reduction for underwriting discounts and commissions and offering expenses. Following completion of the initial offerings and overallotment options, we beneficially owned 81.1 percent of IEnova and its subsidiaries. Consistent with applicable accounting guidance, changes in noncontrolling interests that do not result in a change of control are accounted for as equity transactions. When there are changes in noncontrolling interests of a subsidiary that do not result in a change of control, any difference between carrying value and fair value related to the change in ownership is recorded as an adjustment to shareholders' equity. As a result of the offerings and overallotment options, we recorded an increase in Sempra Energy's shareholders' equity of $135 million in the second quarter of 2013 for the sale of IEnova shares to noncontrolling interests.
IEnova is a separate legal entity, formerly known as Sempra México, S.A. de C.V., comprised primarily of Sempra Energy's operations in Mexico. IEnova is included within our Sempra Mexico reportable segment, but is not the same in its entirety as the reportable segment. In addition to the IEnova operating companies, the Sempra Mexico segment includes, among other things, certain holding companies and risk management activity. Also, IEnova's financial results are reported in Mexico under International Financial Reporting Standards (IFRS), as required by the Mexican Stock Exchange (La Bolsa Mexicana de Valores, S.A.B. de C.V., BMV) where the shares are traded under the symbol IENOVA.
The private offering was exempt from registration under the U.S. Securities Act of 1933, as amended (the Securities Act), and shares in the private offering were offered and sold only to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside of the United States, in accordance with Regulation S under the Securities Act. The shares were not registered under the Securities Act or any state securities laws, and may not be offered or sold in the United States absent registration or an applicable exemption from the registration requirements of the Securities Act and applicable securities laws.
Preferred Stock
The preferred stock at SoCalGas is presented at Sempra Energy as a noncontrolling interest at December 31, 2013 and 2012. The preferred stock of SDG&E at December 31, 2012 was contingently redeemable preferred stock and was fully redeemed in October 2013, as we discuss in Note 11. At Sempra Energy, the preferred stock dividends of SDG&E and SoCalGas are charges against income related to noncontrolling interests. We provide additional information concerning preferred stock in Note 11.
At December 31, 2013 and 2012, we reported the following noncontrolling ownership interests held by others (not including preferred shareholders) recorded in Other Noncontrolling Interests in Total Equity on Sempra Energy's Consolidated Balance Sheets:
OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
				December 31,
		Percent Ownership Held by Others		2013		2012
SDG&E:
Otay Mesa VIE		100	%	$	91	$	76
Sempra South American Utilities:
Chilquinta Energía subsidiaries(1)		24.4 - 43.4			27		29
Luz del Sur		20.2			222		236
Tecsur		9.8			3		4
Sempra Mexico:
IEnova, S.A.B. de C.V.		18.9			442		―
Sempra Natural Gas:
Bay Gas Storage Company, Ltd.		9.1			22		20
Liberty Gas Storage, LLC		25			14		15
Southern Gas Transmission Company		49			1		1
Total Sempra Energy				$	822	$	381
-1	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.
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. They record these revenues following the accrual method and recognize them upon delivery and performance. They also record revenue from CPUC-approved incentive awards, some of which require approval by the CPUC prior to being recognized. We provide additional discussion on utility incentive mechanisms in Note 14.
Under an operating agreement with the California Department of Water Resources (DWR) that expired at the end of 2013, SDG&E has 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 legal and financial responsibilities associated with these activities resided with the DWR. Accordingly, the commodity costs associated with long-term contracts allocated to SDG&E from the DWR (and the revenues to recover those costs) are not included in SDG&E's or Sempra Energy's Consolidated Statements of Operations. We provide discussion on electric industry regulation related to the DWR in Note 14.
On a monthly basis, SoCalGas accrues natural gas storage contract revenues, which consist of storage reservation and variable charges based on negotiated agreements with terms of up to 15 years.
Our natural gas utilities outside of California (Mobile Gas, Willmut Gas and Ecogas) apply U.S. GAAP for regulated utilities consistent with the California Utilities.
Our utilities in South America, which were consolidated as part of our Sempra South American Utilities segment beginning April 6, 2011 as we discuss in Note 3, are Chilquinta Energía S.A. (Chilquinta Energía) and Luz del Sur S.A.A. (Luz del Sur), and their subsidiaries. Chilquinta Energía is an electric distribution utility serving customers in the cities of Valparaiso and Viña del Mar in central Chile. Luz del Sur is an electric distribution utility in the southern zone of metropolitan Lima, Peru. The companies serve primarily regulated customers, and their revenues are based on tariffs that are set by the National Energy Commission (Comisión Nacional de Energía, or CNE) in Chile and the Energy and Mining Investment Supervisory Body (Organismo Supervisor de la Inversión en Energía y Minería, 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 distribution company defined by Chilean law in the case of Chilquinta Energía, 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 (Valor Nuevo de Reemplazo, or VNR) of depreciable assets, charges 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), recovery 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 cover 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 regulatory accounting.
For Chilquinta Energía, rates for four-year periods related to distribution and sub-transmission are reviewed separately on an alternating basis every two years. In late 2011, Chilquinta Energía initiated the process to establish its distribution rates for the period from November 2012 to October 2016. This process was completed in November 2012, with rates published in April 2013, and tariff adjustments going into effect retroactively from November 2012.
In April 2013, the CNE completed the process to establish Chilquinta Energía's sub-transmission rates for the period January 2011 to December 2014. The CNE has not yet published the sub-transmission rates for this period, although we expect publication in the first half of 2014. Once the rates are published, the tariff adjustments will go into effect retroactively from January 2011.
The next reviews are scheduled to be completed, with tariff adjustments also going into effect, in January 2015 for sub-transmission, and again for distribution in November 2016.
The components of tariffs above for Luz del Sur are reviewed and adjusted every four years. The final distribution rate-setting resolution for the 2013-2017 period was published in October 2013 and went into effect on November 1, 2013.
The table below shows the total utilities revenues in Sempra Energy's Consolidated Statements of Operations for each of the last three years. The revenues include amounts for services rendered but unbilled (approximately one-half month's deliveries) at the end of each year.
TOTAL UTILITIES REVENUES AT SEMPRA ENERGY CONSOLIDATED(1)
(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
Electric revenues		$	4,911	$	4,568	$	3,833
Natural gas revenues			4,398		3,873		4,489
Total		$	9,309	$	8,441	$	8,322
-1	Excludes intercompany revenues.
As we discuss in Note 14, the natural gas supply for SDG&E's and SoCalGas' core natural gas customers is purchased by SoCalGas as a combined procurement portfolio managed by SoCalGas. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service, therefore amounts related to SDG&E are not included in SoCalGas' Consolidated Statements of Operations.
We provide additional information concerning utility revenue recognition in “Regulatory Matters” above.
Energy-Related Businesses
Sempra South American Utilities
Sempra South American Utilities generates revenues from providing electric construction services, and recognizes these revenues when services are provided in accordance with contractual agreements.
Sempra Mexico
Sempra Mexico's Termoeléctrica de Mexicali generates revenues from selling electricity and/or capacity to the California ISO and to governmental, public utility and wholesale power marketing entities. Sempra Mexico recognizes these revenues as the electricity is delivered and capacity is provided. Sempra Mexico's pipeline operations recognize revenues from the sale and transportation of natural gas as deliveries are made and from fixed capacity 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 service 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.
Sempra 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.
Sempra Natural Gas
Sempra Natural Gas generates revenues from selling electricity and/or capacity from its Mesquite Power facility to the California ISO and to governmental, public utility and wholesale power marketing entities. Sempra Natural Gas recognizes these revenues as the electricity is delivered and capacity is provided. In 2011, Sempra Natural Gas' electricity sales to the DWR accounted for a significant portion of its revenues. This contract ended September 30, 2011. Related to its LNG terminal and marketing operations, Sempra Natural Gas recognizes revenues from the sale of LNG and natural gas as deliveries are made to counterparties, as well as revenues from reservation and usage fees. Sempra Natural Gas also records revenues from contractual counterparty obligations for non-delivery of cargoes. 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 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.
OTHER COST OF SALES
Other Cost of Sales primarily includes
pipeline capacity marketing costs, and pipeline transportation and natural gas marketing costs incurred at Sempra Natural Gas;
electric construction services costs at Sempra South American Utilities; and
energy management service fees at Sempra Mexico.
The costs at Sempra South American Utilities are related to the energy-services companies in South America that we discuss in Note 3.
OPERATION AND MAINTENANCE EXPENSES
Operation and Maintenance includes operating and maintenance costs, and general and administrative costs, which consist primarily of personnel costs, purchased materials and services, litigation expense and rent.
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 resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings (unless the operation is being discontinued), but are reflected in Comprehensive Income and in Accumulated Other Comprehensive Income (Loss), a component of shareholders' equity.
To reflect the fluctuations in the values of functional currencies of our South American investments, which were accounted for under the equity method prior to April 6, 2011, the following adjustments were made to the carrying value of these investments (dollars in millions):
			Upward (downward) adjustment to investments
Investment		Currency	2011(1)
Chilquinta Energía		Chilean Peso	$	-10
Luz del Sur		Peruvian Nuevo Sol		―
-1	As discussed in Note 3, the cumulative foreign currency translation adjustment balances totaling $54 million in Accumulated Other Comprehensive Income (Loss) as of April 6, 2011 were reclassified to net income as a result of the gain on the remeasurement of our equity method investments in Chilquinta Energía and Luz del Sur during the second quarter of 2011.
Smaller adjustments have been made to other operations where the U.S. dollar is not the functional currency. We provide additional information concerning these investments in Note 4.
Currency transaction gains and losses in a currency other than the entity's functional currency are included in the calculation of Other Income, Net, at Sempra Energy as follows:
	Years ended December 31,
(Dollars in millions)	2013		2012		2011
Currency transaction gain (loss)	$	-3	$	9	$	11
Cash flows of the consolidated foreign subsidiaries are translated into U.S. dollars using average exchange rates for the period. We report the effect of exchange rate changes on cash balances held in foreign currencies in “Effect of Exchange Rate Changes on Cash and Cash Equivalents” on our Consolidated Statements of Cash Flows.
TRANSACTIONS WITH AFFILIATES
Loans to and Receivables from Unconsolidated Affiliates – Sempra Energy Consolidated
Sempra South American Utilities has a U.S. dollar-denominated loan to Eletrans S.A., an affiliate of Chilquinta Energía that we discuss in Note 4. At December 31, 2013, the loan has a $14 million principal balance outstanding plus a negligible amount of accumulated interest at a fixed interest rate of 4 percent.
At December 31, 2013, Sempra Energy had $4 million in accounts receivable from various Sempra Renewables joint venture investments.
Service Agreements
Sempra Energy, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Amounts due to/from affiliates are as follows:
AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
(Dollars in millions)
		December 31,
		2013		2012
SDG&E
Current:
Due from SoCalGas		$	―	$	37
Due from various affiliates			1		2
		$	1	$	39
Due to Sempra Energy		$	25	$	19
Due to various affiliates			14		―
		$	39	$	19
Income taxes due from Sempra Energy(1)		$	70	$	12
SoCalGas
Current:
Due from Sempra Energy		$	―	$	24
Due from various affiliates			21		―
		$	21	$	24
Due to SDG&E		$	―	$	37
Due to Sempra Energy			16		―
		$	16	$	37
Income taxes due from Sempra Energy(1)		$	18	$	99
-1	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 the companies’ having always filed a separate return.
Revenues from unconsolidated affiliates at SDG&E and SoCalGas are as follows:
REVENUES FROM UNCONSOLIDATED AFFILIATES AT SDG&E AND SOCALGAS
(Dollars in millions)
	Years ended December 31,
	2013		2012		2011
SDG&E	$	12	$	9	$	7
SoCalGas		70		46		53
Transactions with Rockies Express Pipelines LLC
Sempra Rockies Marketing, a subsidiary of Sempra Natural Gas, has an agreement with Rockies Express Pipelines LLC (Rockies Express) for capacity on the Rockies Express Pipeline (REX) through November 2019. Sempra Rockies Marketing recorded cost of sales of $78 million in each of 2013, 2012 and 2011 related to this agreement. We discuss this agreement further in Note 15.
Transactions with RBS Sempra Commodities
In 2008, our commodities-marketing businesses, previously wholly owned subsidiaries of Sempra Energy, were sold into RBS Sempra Commodities LLP (RBS Sempra Commodities), a partnership jointly owned by Sempra Energy and The Royal Bank of Scotland (RBS). Several of our segments have engaged in transactions with RBS Sempra Commodities. As a result of the divestiture of substantially all of RBS Sempra Commodities' businesses, as we discuss in Note 4, transactions between our segments and RBS Sempra Commodities were assigned over time to the buyers of the joint venture businesses. The assignments of the related contracts were substantially completed by May 1, 2011. Amounts in our Consolidated Financial Statements related to these transactions for the year ended December 31, 2011 are as follows:
AMOUNTS RECORDED FOR TRANSACTIONS WITH RBS SEMPRA COMMODITIES(1)
(Dollars in millions)
					Cost of
			Revenues		Natural Gas
Sempra Mexico		$	37	$	74
Sempra Natural Gas			7		3
-1	With the exception of Sempra Mexico, whose contract with RBS Sempra Commodities expired in July 2011, amounts only include activities prior to May 1, 2011, the date by which substantially all the contracts with RBS Sempra Commodities were assigned to buyers of the joint venture businesses.
RESTRICTED NET ASSETS
Sempra Energy Consolidated
As we discuss below, the California Utilities have restrictions on the amount of funds that can be transferred to Sempra Energy by dividend, advance or loan as a result of conditions imposed by various regulators. Additionally, certain other Sempra Energy subsidiaries are subject to various financial and other covenants and other restrictions contained in debt and credit agreements (described in Note 5) and in other agreements that limit the amount of funds that can be transferred to Sempra Energy. At December 31, 2013, Sempra Energy was in compliance with all covenants related to its debt agreements.
At December 31, 2013, the amount of restricted net assets of wholly owned subsidiaries of Sempra Energy, including the California Utilities discussed below, that may not be distributed to Sempra Energy in the form of a loan or dividend is $6.2 billion. Although the restrictions cap the amount of funding that the various operating subsidiaries can provide to Sempra Energy, we do not believe these restrictions will have a significant impact on our ability to access cash to pay dividends.
As we discuss in Note 4, $129 million of Sempra Energy's consolidated retained earnings balance represents undistributed earnings of equity method investments at December 31, 2013.
California Utilities
The CPUC's regulation of the California Utilities' capital structures limits the amounts available for dividends and loans to Sempra Energy. At December 31, 2013, Sempra Energy could have received combined loans and dividends of approximately $425 million from SDG&E and approximately $1.0 billion from SoCalGas.
The payment and amount of future dividends for SDG&E and SoCalGas are at the discretion of their board of directors. The following restrictions limit the amount of retained earnings that may be paid as common dividends or loaned to Sempra Energy from either utility:
The CPUC requires that SDG&E's and SoCalGas' common equity ratios be no lower than one percentage point below the CPUC-authorized percentage of each entity's authorized capital structure. The authorized percentage at December 31, 2013 is 52 percent at both SDG&E and SoCalGas.
The FERC requires SDG&E to maintain a common equity ratio of 30 percent or above.
The California Utilities have a combined revolving credit line that requires each utility to maintain a ratio of consolidated indebtedness to consolidated capitalization (as defined in the agreement) of no more than 65 percent, as we discuss in Note 5.
Based upon these restrictions, at December 31, 2013, SDG&E's restricted net assets were $4.2 billion and SoCalGas' restricted net assets were $1.5 billion, which could not be transferred to Sempra Energy.
Sempra International
Significant restrictions of Sempra International subsidiaries include
Peru and Mexico require domestic corporations to maintain minimum legal reserves as a percentage of capital stock, resulting in restricted net assets of $35 million at Luz del Sur and $79 million at Sempra Energy's consolidated Mexican subsidiaries at December 31, 2013.
Sempra U.S. Gas & Power
Significant restrictions of Sempra U.S. Gas & Power subsidiaries include
Wholly owned Copper Mountain Solar 1 has a long-term debt agreement that requires the establishment and funding of project accounts to which the proceeds of loans, project revenues and other amounts are deposited and applied in accordance with the debt agreement. This long-term debt agreement also limits Copper Mountain Solar 1's ability to incur liens, incur additional indebtedness, make acquisitions and undertake certain actions, while also requiring maintenance of certain debt ratios. Under these restrictions, net assets totaling $11 million are restricted at December 31, 2013.
50-percent owned and unconsolidated joint ventures at Sempra Renewables have debt agreements which require each joint venture to maintain reserve accounts in order to pay the projects' debt service and operation and maintenance requirements. We discuss Sempra Energy guarantees associated with these requirements in Note 5. As a result of these requirements, there were total restricted assets at December 31, 2013 at our joint ventures of approximately:
$34 million at Cedar Creek 2 Wind Farm (Cedar Creek 2)
$14 million at Copper Mountain Solar 2
$47 million at Flat Ridge 2 Wind Farm (Flat Ridge 2)
$37 million at Fowler Ridge 2 Wind Farm (Fowler Ridge 2)
$19 million at Mehoopany Wind Farm (Mehoopany Wind)
$48 million at Mesquite Solar 1.
Wholly owned Mobile Gas has long-term debt instruments containing restrictions relating to the payment of dividends and other distributions with respect to capital stock. Under these restrictions, net assets of approximately $116 million are restricted at December 31, 2013.
91-percent owned Bay Gas has long-term debt instruments containing restrictions relating to the payment of dividends and other distributions if Bay Gas does not maintain a specified debt service coverage ratio. Bay Gas had no restricted net assets at December 31, 2013.
OTHER INCOME, NET
Other Income, Net on the Consolidated Statements of Operations consists of the following:
OTHER INCOME, NET
(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
Sempra Energy Consolidated:
Allowance for equity funds used during construction		$	75	$	96	$	99
Investment gains(1)			39		41		22
Gains (losses) on interest rate and foreign exchange instruments, net(2)			17		10		-14
Regulatory interest, net(3)			5		1		2
Sundry, net			4		24		21
	Total	$	140	$	172	$	130
SDG&E:
Allowance for equity funds used during construction		$	39	$	71	$	80
Regulatory interest, net(3)			4		2		2
Losses on interest rate instruments(4)			―		―		-1
Sundry, net			-3		-4		-2
	Total	$	40	$	69	$	79
SoCalGas:
Allowance for equity funds used during construction		$	17	$	25	$	19
Regulatory interest, net(3)			1		-1		―
Sundry, net			-7		-7		-6
	Total	$	11	$	17	$	13
-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	Sempra Energy Consolidated includes Otay Mesa VIE and additional instruments.
-3	Interest on regulatory balancing accounts.
-4	Related to Otay Mesa VIE.

NEW_ACCOUNTING_STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2013
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) 2011-11, “Disclosures about Offsetting Assets and Liabilities” (ASU 2011-11) and ASU 2013-01, “Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities” (ASU 2013-01): In order to allow for balance sheet comparison between U.S. GAAP and IFRS, ASU 2011-11 requires enhanced disclosures related to financial assets and liabilities eligible for offsetting in the statement of financial position. An entity must disclose both gross and net information about financial instruments and transactions subject to a master netting arrangement and eligible for offset, including cash collateral received and posted.
	ASU 2013-01 clarifies that the scope of ASU 2011-11 applies to derivatives, including bifurcated embedded derivatives, repurchase agreements and reverse repurchase agreements, and securities borrowing and securities lending transactions.
	We adopted ASU 2011-11 and ASU 2013-01 on January 1, 2013 as required, and it did not affect our financial condition, results of operations or cash flows.
	ASU 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income” (ASU 2013-02): ASU 2013-02 requires an entity to present, either on the face of the statement of operations or in the notes to financial statements, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. For other amounts that are not required under U.S. GAAP to be reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures required under U.S. GAAP that provide additional detail about those amounts.
	We adopted ASU 2013-02 on January 1, 2013 as required and it did not affect our financial condition, results of operations or cash flows.
	ASU 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists” (ASU 2013-11): ASU 2013-11 provides explicit guidance on the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. ASU 2013-11 requires an entity to present an unrecognized tax benefit, or a portion of an unrecognized tax benefit, as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward. If a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction to settle any additional income taxes that would result from the disallowance of a tax position or the tax law of the applicable jurisdiction does not require the entity to use, and the entity does not intend to use, the deferred tax asset for such purposes, an entity is required to present the unrecognized tax benefit in the financial statements as a liability instead of combined with deferred tax assets.
	We will adopt ASU 2013-11 on January 1, 2014 as required and do not expect it to significantly affect our financial condition, results of operations or cash flows.

ACQUISTION_AND_DIVESTITURE_ACT

ACQUISTION AND DIVESTITURE ACTIVITY	12 Months Ended
	Dec. 31, 2013
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.
	SEMPRA SOUTH AMERICAN UTILITIES
	Chilquinta Energía and Luz del Sur
	On April 6, 2011, Sempra South American Utilities acquired from AEI its interests in Chilquinta Energía in Chile and Luz del Sur in Peru, and their subsidiaries. Prior to the acquisition, Sempra South American Utilities and AEI each owned 50 percent of Chilquinta Energía and approximately 38 percent of Luz del Sur. Upon completion of the acquisition, Sempra South American Utilities owned 100 percent of Chilquinta Energía and approximately 76 percent of Luz del Sur, with the remaining shares of Luz del Sur held by institutional investors and the general public. As part of the transaction, Sempra South American Utilities also acquired AEI's interests in two energy-services companies, Tecnored S.A. and Tecsur S.A. The adjusted purchase price of $888 million resulted from valuing the net assets in Chile, Peru and other holding companies at $495 million, $385 million and $8 million, respectively. We paid $611 million in cash ($888 million less $245 million of cash acquired and $32 million of consideration withheld for a liability related to the purchase).
	As part of our acquisition of AEI's interest in Luz del Sur, we were required to launch a tender offer to the minority shareholders of Luz del Sur to purchase their shares (up to a maximum 14.73 percent interest in Luz del Sur). In September 2011, we purchased 18,918,954 additional Luz del Sur shares for $43 million in settlement of the mandatory public tender offer, bringing Sempra South American Utilities' ownership to 79.82 percent.
	Chilquinta Energía owned 85 percent of Luzlinares S.A. (Luzlinares) through October 31, 2012. On November 26, 2012, Chilquinta Energía purchased the remaining 15-percent ownership interest in Luzlinares for $7 million in cash.
	We allocated the original purchase price for Chilquinta Energía and Luz del Sur on a preliminary basis in the second quarter of 2011. In the third and fourth quarters of 2011, we adjusted the preliminary allocation for additional assets and liabilities identified, including an $11 million premium related to long-term debt at Chilquinta Energía. The retrospective application of these adjustments to prior quarters was de minimus. There were no further adjustments through April 2012, the end of the measurement period. The following table summarizes the consideration paid in the acquisition and the recognized amounts of the assets acquired and liabilities assumed, as well as the fair value at the acquisition date of the noncontrolling interests:
	PURCHASE PRICE ALLOCATION
	(Dollars in millions)
				At April 6, 2011
									Other
					Chilean		Peruvian		holding
					entities		entities		companies		Total
	Fair value of businesses acquired:
		Cash consideration (fair value of total
		consideration)		$	495	$	385	$	8	$	888
		Fair value of equity method
		investments immediately prior to
		the acquisition			495		385		2		882
		Fair value of noncontrolling interests			37		242		―		279
	Total fair value of businesses acquired				1,027		1,012		10		2,049
	Recognized amounts of identifiable assets
		acquired and liabilities assumed:
			Cash		219		22		4		245
			Property, plant and equipment		555		931		―		1,486
			Long-term debt		-305		-179		―		-484
			Other net assets (liabilities) acquired		44		-223		6		-173
	Total identifiable net assets				513		551		10		1,074
	Goodwill			$	514	$	461	$	―	$	975
	Our results for the year ended December 31, 2011 include a $277 million gain (both pretax and after-tax) related to the remeasurement of equity method investments, included as Remeasurement of Equity Method Investments on our Consolidated Statement of Operations. We calculated the gain as the difference between the acquisition-date fair value ($882 million) and the book value ($605 million) of our equity interests in Chilquinta Energía and Luz del Sur immediately prior to the acquisition date. This book value of our equity interests included currency translation adjustment balances in Accumulated Other Comprehensive Income (Loss). The valuation techniques we used to allocate the purchase price to the businesses included discounted cash flow analysis and the market multiple approach (enterprise value to earnings before interest, taxes, depreciation and amortization (EBITDA)). Our assumptions for these measures included estimated future cash flows, appropriate discount rates, market trading multiples and market transaction multiples. Discount rates used reflected consideration of risk free rates, as well as country and company risk. Methodologies used to determine fair values of material assets as of the date of the acquisition included
	the replacement cost approach for property, plant and equipment; and
	goodwill associated primarily with the value of residual future cash flows that we believe these businesses will generate, to be tested annually for impairment. For income tax purposes, none of the goodwill recorded is deductible in Chile, Peru or the United States.
	For substantially all other assets and liabilities, our analysis of fair value factors indicated that book value approximated fair value. We valued noncontrolling interests based on the fair value of tangible assets and an allocation of goodwill based on relative enterprise value.
	Our Consolidated Statement of Operations includes 100 percent of the acquired companies' revenues, net income and earnings from the date of acquisition, including $1.1 billion, $160 million and $135 million, respectively, from the date of acquisition for the year ended December 31, 2011. These amounts do not include the remeasurement gain.
	Following are pro forma revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2010, which primarily reflect the incremental increase to revenues and earnings from our increased ownership and consolidation of the entities acquired. Although some short-term debt borrowings may have resulted from the actual acquisition in 2011, we have not assumed any additional interest expense in the pro forma impact on earnings below, as the amounts would be immaterial due to the low interest rates available to us on commercial paper. The pro forma amounts do not include the impact of the increased ownership in Luz del Sur resulting from the tender offer completed in September 2011 discussed above.
			Year ended
	(Dollars in millions)		31-Dec-11
	Revenues		$	10,379
	Earnings(1)			1,079
	-1	Excludes the $277 million gain related to the remeasurement of equity method investments.
	The companies use their local currency, the Chilean Peso or the Peruvian Nuevo Sol, as their functional currency, and we account for them as discussed above in Note 1 under “Foreign Currency Translation.”
	We provide additional information about Sempra South American Utilities' investments in Chilquinta Energía and Luz del Sur in Note 4.
	SEMPRA RENEWABLES
	In July 2013, Sempra Renewables formed a joint venture with Consolidated Edison Development (ConEdison Development), a nonrelated party, by selling a 50-percent interest in its 150-MW Copper Mountain Solar 2 solar power facility for $72 million in cash. Sempra Renewables recognized a pretax gain on the sale of $4 million ($2 million after-tax), included in Gain on Sale of Assets on our Consolidated Statement of Operations. Our remaining 50-percent interest in Copper Mountain Solar 2 is now accounted for under the equity method.
	In September 2013, Sempra Renewables formed another joint venture with ConEdison Development by selling a 50-percent interest in its 150-MW Mesquite Solar 1 solar power facility for $103 million in cash. Sempra Renewables recognized a pretax gain on the sale of $36 million ($22 million after-tax), included in Gain on Sale of Assets on our Consolidated Statement of Operations. Our remaining 50-percent interest in Mesquite Solar 1 is now accounted for under the equity method.
	Our equity method investments in Copper Mountain Solar 2 and Mesquite Solar 1 were measured at their historical cost and, therefore, no portion of the gains was attributable to a remeasurement of the retained investments to fair value. The following table summarizes the deconsolidation:
	(Dollars in millions)		Copper Mountain Solar 2		Mesquite Solar 1
	Proceeds from sale, net of transaction costs(1)		$	69	$	100
	Property, plant and equipment, net			-266		-461
	Other assets			-30		-72
	Long-term debt, including current portion			146		297
	Other liabilities			19		31
	Gain on sale of assets			-4		-36
	Equity method investments upon deconsolidation		$	-66	$	-141
	-1	Transaction costs were $3 million at each of Copper Mountain Solar 2 and Mesquite Solar 1.
	In September 2013, Sempra Renewables acquired the rights to develop the 75-MW Broken Bow 2 Wind project in Custer County, Nebraska. Sempra Renewables will develop the project, which is expected to be operational in late 2014.
	SEMPRA NATURAL GAS
	Mesquite Power Sale
	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 to the Salt River Project Agricultural Improvement and Power District (SRP). The asset was classified as held for sale at December 31, 2012 and we recognized a pretax gain on sale of $74 million ($44 million after-tax) in 2013, included in Gain on Sale of Assets on our Consolidated Statement of Operations. In connection with the sale, we entered into a 20-year operations and maintenance agreement with SRP on February 28, 2013, whereby SRP assumed plant operations and maintenance of the facility, including our remaining 625-MW block. We provide additional information concerning the operations and maintenance agreement in Note 15 under “Other Commitments – Sempra Natural Gas” and additional information regarding our plan to sell the remaining block of the plant in Note 18.
	Willmut Gas Company
	In May 2012, Sempra Natural Gas acquired 100 percent of the outstanding common stock of Willmut Gas, a regulated natural gas distribution utility serving approximately 19,000 customers in Hattiesburg, Mississippi. Willmut Gas was purchased for $19 million in cash and the assumption of $10 million of liabilities. Included in the acquisition was $17 million in net property, plant and equipment. As a result of the acquisition, we recorded $10 million of goodwill.
	The results of operations for Willmut Gas are included in our Consolidated Statement of Operations from the date of acquisition, including revenues of $10 million and negligible earnings for the year ended December 31, 2012. Pro forma impacts on revenues and earnings for Sempra Energy had the acquisition occurred on January 1, 2011 were additional revenues of $7 million and negligible earnings in 2012 and additional revenues of $21 million and negligible earnings for 2011.

INVESTMENTS_IN_UNCONSOLIDATED_

INVESTMENTS IN UNCONSOLIDATED ENTITIES	12 Months Ended
	Dec. 31, 2013
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 an ownership interest of 20 percent to 50 percent. In these cases, our pro rata shares of the entities' net assets are included in Investments on the Consolidated Balance Sheets. These investments are adjusted for our share of each investee's earnings or losses, dividends, and other comprehensive income or loss.
	The carrying value of unconsolidated entities is evaluated for impairment under the U.S. GAAP provisions for equity method investments.
	We summarize our investment balances and earnings below:
	EQUITY METHOD AND OTHER INVESTMENTS ON THE CONSOLIDATED BALANCE SHEETS
	(Dollars in millions)
			December 31,
			2013		2012
	Sempra South American Utilities:
	Eletrans(1)		$	-3	$	―
	Sempra Mexico:
	Gasoductos de Chihuahua			379		340
	Sempra Renewables:
	Auwahi Wind Farm			53		72
	Cedar Creek 2 Wind Farm			92		93
	Copper Mountain Solar 2			67		―
	Flat Ridge 2 Wind Farm			292		291
	Fowler Ridge 2 Wind Farm			51		47
	Mehoopany Wind Farm			85		89
	Mesquite Solar 1			67		―
	Sempra Natural Gas:
	Rockies Express Pipeline LLC			329		361
	Parent and other:
	RBS Sempra Commodities LLP			73		126
	Other			―		8
	Total equity method investments			1,485		1,427
	Other(2)			90		89
	Total		$	1,575	$	1,516
	-1	Includes losses on forward exchange contracts as we discuss below.
	-2	Other includes Sempra South American Utilities' $10 million and $11 million in real estate investments at December 31, 2013 and 2012, respectively, and Sempra Natural Gas' $77 million and $74 million investment in industrial development bonds at Mississippi Hub at December 31, 2013 and 2012, respectively.
	Our share of the undistributed earnings of equity method investments was $129 million and $107 million at December 31, 2013 and 2012, respectively. The December 31, 2013 and 2012 balances do not include remaining distributions of $73 million and $126 million, respectively, associated with our investment in RBS Sempra Commodities and expected to be received from the partnership as it is dissolved, as we discuss below.
	Equity method goodwill of $65 million at both December 31, 2013 and 2012 related to our unconsolidated subsidiary located in Mexico is included in Investments on the Sempra Energy Consolidated Balance Sheets and its functional currency is U.S. dollars. We discuss our equity method investments below.
	SEMPRA SOUTH AMERICAN UTILITIES
	As discussed in Note 3, on April 6, 2011, Sempra South American Utilities acquired from AEI its interests in Chilquinta Energía in Chile and Luz del Sur in Peru, and their subsidiaries. Prior to the acquisition, Sempra South American Utilities and AEI each owned 50 percent of Chilquinta Energía and approximately 38 percent of Luz del Sur. We consolidated Chilquinta Energía and Luz del Sur effective April 6, 2011 and no longer record them as equity method investments.
	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 our Argentine 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 investments to estimated fair value. 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 investments 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 peso, 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. (collectively, 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. We recorded $4 million of equity losses for 2013 related to these forward contracts in Equity Earnings, Net of Income Tax on the Consolidated Statement of Operations.
	SEMPRA MEXICO
	Sempra Mexico owns a 50-percent interest in Gasoductos de Chihuahua, a joint venture with Petróleos Mexicanos (or PEMEX, the Mexican state-owned oil company). The joint venture operates several natural gas pipelines and propane systems in Mexico and is constructing a 70-mile natural gas pipeline, the Los Ramones I project, from the northern portion of the state of Tamaulipas bordering the U.S. to Los Ramones in the Mexican state of Nuevo León. Sempra Mexico acquired its investment in Gasoductos de Chihuahua as part of the purchase of Mexican pipeline and natural gas infrastructure assets in 2010.
	SEMPRA RENEWABLES
	Sempra Renewables accounts for its investments in all of the following projects using the equity method.
	During 2013, Sempra Renewables formed joint ventures with ConEdison Development, a nonrelated party, by selling 50-percent interests in both its Copper Mountain Solar 2 and Mesquite Solar 1 facilities. In 2013, Sempra Renewables received a $28 million return of capital from Mesquite Solar 1. We discuss these joint ventures further in Notes 3 and 5.
	During 2013, 2012 and 2011, Sempra Renewables invested $4 million, $291 million and $146 million, respectively, in a joint venture with BP Wind Energy, a wholly owned subsidiary of BP p.l.c., to develop the 470-MW Flat Ridge 2 Wind Farm project near Wichita, Kansas, which became operational in December 2012. In December 2012, Sempra Renewables received a $148 million return of investment from Flat Ridge 2 as a result of the joint venture entering into a loan to finance the project.
	During 2013, 2012 and 2011, Sempra Renewables invested $1 million, $20 million and $88 million, respectively, in a joint venture with BP Wind Energy to develop the 141-MW Mehoopany Wind Farm project near Wyoming County, Pennsylvania, which became operational in December 2012. In 2013 and 2012, Sempra Renewables received a $13 million and $17 million return of capital, respectively, from loan proceeds from financing at Mehoopany Wind.
	During 2013, 2012 and 2011, Sempra Renewables invested $1 million, $62 million and $11 million, respectively, in a joint venture with BP Wind Energy to develop the 21-MW Auwahi Wind Farm in the southeastern region of Maui, a project that was previously wholly owned by Sempra Renewables. The project became operational in December 2012. In 2013, Sempra Renewables received a $19 million return of capital from Auwahi Wind, $15 million of which relates to U.S. Treasury grant proceeds received at the joint venture.
	Additionally, in 2013 Sempra Renewables received a $6 million return of capital from Cedar Creek 2 Wind Farm.
	We discuss guarantees related to Flat Ridge 2 and Mehoopany Wind in Note 5.
	SEMPRA NATURAL GAS
	Sempra Natural Gas owns a 25-percent interest 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. In November 2012, Kinder Morgan Energy Partners L.P. (KMP) sold its 50-percent interest in Rockies Express, as part of a larger asset group, to Tallgrass Energy Partners, L.P. (Tallgrass). Phillips 66 owns the remaining 25-percent interest. Our total investment in Rockies Express is accounted for as an equity method investment.
	The general partner of KMP is Kinder Morgan, Inc. (KMI). As a condition of KMI receiving antitrust approval from the Federal Trade Commission (FTC) for its acquisition of El Paso Corporation, KMI agreed to divest certain assets in its natural gas pipeline group. Included in the asset group, as noted above, was KMP's interest in Rockies Express. KMP recorded remeasurement losses during 2012 associated with these operations (classified as discontinued operations by KMP). In 2012, we recorded impairments of our partnership investment in Rockies Express of $300 million ($179 million after-tax) and $100 million ($60 million after-tax) in the second and third quarters, respectively, which are included in Equity Earnings (Losses), Before Income Tax on the Consolidated Statement of Operations. Our remaining carrying value in Rockies Express at December 31, 2013 is $329 million. We recorded the write-downs in 2012 as a result of our estimate of fair value for our investment at the reporting date and our conclusion that the impairments were other-than-temporary, as required by U.S. GAAP. We discuss the fair value measurement of our investment in Rockies Express in Note 10.
	For income tax purposes, upon KMP's sale of its 50-percent interest in Rockies Express, the partnership was considered terminated under federal tax law and a new partnership immediately formed which triggered a restart of depreciation method on the partnership's remaining tax basis of its tangible assets. As required by the LLC agreement, KMP made a cash make-whole payment to Sempra Natural Gas of $41 million in November 2012, which was recorded as equity income from Rockies Express.
	RBS SEMPRA COMMODITIES
	RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra Energy and 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 July, November, and December of 2010 and February of 2011. We account for our investment in RBS Sempra Commodities under the equity method, and report our share of partnership earnings and other associated costs in Parent and Other.
	We recorded $3 million in pretax equity losses and no equity earnings or losses for the years ended December 31, 2013 and 2012, respectively. Pretax equity losses from RBS Sempra Commodities were $24 million for the year ended December 31, 2011. The partnership income that is distributable to us on an annual basis is computed on the partnership's basis of accounting, IFRS, as adopted by the European Union. For the years ended December 31, 2013 and 2012, there was no distributable income or loss on an IFRS basis. For the year ended December 31, 2011, our share of distributable loss, on an IFRS basis, was $30 million. Included in our pretax equity losses in 2011 is an impairment charge of $16 million ($10 million after-tax). The impairment charge is included in Equity Earnings (Losses), Before Income Tax on the Consolidated Statement of Operations. We discuss the fair value measurement of our investment in the partnership in Note 10.
	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 addresses 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 and $623 million in 2011. The 2011 distributions included sales proceeds and our portion of 2010 distributable income totaling $651 million, less amounts to settle certain liabilities that we owed to RBS of $28 million. We received no cash distributions in 2012. The investment balance of $73 million at December 31, 2013 reflects remaining distributions expected to be received from the partnership in accordance with the Letter Agreement. The timing and amount of distributions may be impacted by the matters we discuss related to RBS Sempra Commodities in Note 15 under “Other 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 Letter 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.

DEBT_AND_CREDIT_FACILITIES

DEBT AND CREDIT FACILITIES	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Debt and Credit Facilities	'
	NOTE 5. DEBT AND CREDIT FACILITIES
	COMMITTED LINES OF CREDIT
	At December 31, 2013, Sempra Energy Consolidated had an aggregate of $4.1 billion in committed lines of credit to provide liquidity and to support commercial paper and variable-rate demand notes, the major components of which we detail below. Available unused credit on these lines at December 31, 2013 was $3.4 billion.
	Sempra Energy
	Sempra Energy has a $1.067 billion, five-year syndicated revolving credit agreement expiring in March 2017. Citibank, N.A. serves as administrative agent for the syndicate of 24 lenders. No single lender has greater than a 7-percent share.
	Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy's credit ratings. The facility requires Sempra Energy to maintain 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, 2013 and 2012, Sempra Energy was in compliance with this and all other financial covenants under the credit facility. The facility also provides for issuance of up to $635 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 December 31, 2013, Sempra Energy had $12 million of letters of credit outstanding supported by the facility.
	Sempra Global
	Sempra Global has a $2.189 billion, five-year syndicated revolving credit agreement expiring in March 2017. Citibank, N.A. serves as administrative agent for the syndicate of 25 lenders. No single lender has greater than a 7-percent share.
	Sempra Energy guarantees Sempra Global's obligations under the credit facility. Borrowings bear interest at benchmark rates plus a margin that varies with market index rates and Sempra Energy's credit ratings. The facility requires Sempra Energy to maintain 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, 2013 and 2012, Sempra Energy was in compliance with this and all other financial covenants under the credit facility.
	At December 31, 2013, Sempra Global had $590 million of commercial paper outstanding supported by the facility. At December 31, 2013 and 2012, respectively, $200 million and $300 million of commercial paper outstanding was classified as long-term debt based on management's intent and ability to maintain this level of borrowing on a long-term basis either supported by this credit facility or by issuing long-term debt. This classification has no impact on cash flows.
	California Utilities
	SDG&E and SoCalGas have a combined $877 million, five-year syndicated revolving credit agreement expiring in March 2017. JPMorgan Chase Bank, N.A. serves as administrative agent for the syndicate of 24 lenders. No single lender has greater than a 7-percent share. The agreement permits each utility to individually borrow up to $658 million, subject to a combined limit of $877 million for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credit commitment of $200 million for both utilities. Effective January 29, 2014, the combined letter of credit commitment increased to $300 million. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit.
	Borrowings under the facility bear interest at benchmark rates plus a margin that varies with market index rates and the borrowing utility's credit ratings. The agreement requires each utility to maintain 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, 2013 and 2012, 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, 2013, SDG&E and SoCalGas had $59 million and $42 million of commercial paper outstanding supported by the facility, respectively. Available unused credit on the line at December 31, 2013 was $599 million and $616 million at SDG&E and SoCalGas, respectively, subject to the combined limit on the facility of $877 million.
	GUARANTEES
	Sempra Renewables
	Sempra Renewables and BP Wind Energy each currently hold 50-percent interests in Flat Ridge 2. The project obtained construction financing in December 2012, and proceeds from the loans were used to return $148 million of each owner's joint venture investment in 2012. In March 2013, the construction financing was converted into permanent financing consisting of a term loan and a fixed-rate note. The term loan of $242 million expires in June 2023 and the fixed rate note of $110 million expires in June 2035. The financing agreement requires Sempra Renewables and BP Wind Energy, severally for each partner's 50-percent interest, to return cash to the project in the event that the project does not meet certain cash flow criteria or in the event that the project's debt service, operation and maintenance and firm transmission and production tax credits reserve accounts are not maintained at specific thresholds. Sempra Renewables recorded a liability of $3 million in 2013 for the fair value of its obligations associated with the cash flow requirements, which constitutes a guarantee. The liability is being amortized over its expected life. The outstanding loans are not guaranteed by the partners.
	Sempra Renewables and BP Wind Energy each currently hold 50-percent interests in Mehoopany Wind. The project obtained construction financing in June 2012, and proceeds from the loans were used to return $13 million and $17 million of each owner's joint venture investment in 2013 and 2012, respectively. In May 2013, the construction financing was converted into permanent financing consisting of a term loan. The term loan of $162 million expires in May 2031. The financing agreement requires Sempra Renewables and BP Wind Energy, severally for each partner's 50-percent interest, to return cash to the project in the event that the project does not meet certain cash flow criteria or in the event that the project's debt service, operation and maintenance and production tax credits reserve accounts are not maintained at specific thresholds. Additionally, in conjunction with the term loan conversion, Sempra Renewables and BP Wind Energy have provided guarantees to the lenders in lieu of Mehoopany Wind funding a reserve account requirement. Sempra Renewables recorded liabilities of $11 million in 2013 for the fair value of its obligations associated with the cash flow and reserve account requirements, which constitute guarantees. The liabilities are being amortized over their expected lives. The outstanding loans are not guaranteed by the partners.
	RBS Sempra Commodities
	As we discuss in Note 4, in 2010 and early 2011, Sempra Energy, RBS and RBS Sempra Commodities sold substantially all of the businesses and assets within the partnership in four separate transactions. In connection with each of these transactions, the buyers were, subject to certain qualifications, obligated to replace any guarantees that we had issued in connection with the applicable businesses sold with guarantees of their own. By February 26, 2014, all such guarantees had been replaced or open positions closed. We discuss additional matters related to our investment in RBS Sempra Commodities in Note 15.
	WEIGHTED AVERAGE INTEREST RATES
	The weighted average interest rates on the total short-term debt outstanding at Sempra Energy were 0.64 percent and 0.72 percent at December 31, 2013 and 2012, respectively. The weighted average interest rate on the total short-term debt outstanding at both SDG&E and SoCalGas was 0.13 percent at December 31, 2013. The weighted average interest rates at December 31, 2013 and 2012 include interest rates for commercial paper borrowings classified as long-term, as we discuss above.
	LONG-TERM DEBT
	The following tables show the detail and maturities of long-term debt outstanding:
	LONG-TERM DEBT
	(Dollars in millions)
			December 31,
			2013		2012
	SDG&E
	First mortgage bonds:
		6.8% June 1, 2015	$	―	$	14
		5.3% November 15, 2015		250		250
		1.65% July 1, 2018(1)		161		161
		5.85% June 1, 2021(1)		―		60
		3% August 15, 2021		350		350
		3.6% September 1, 2023		450		―
		6% June 1, 2026		250		250
		5% to 5.25% December 1, 2027(1)		150		150
		5.875% January and February 2034(1)		176		176
		5.35% May 15, 2035		250		250
		6.125% September 15, 2037		250		250
		4% May 1, 2039(1)		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
				3,912		3,536
	Other long-term debt (unsecured unless otherwise noted):
		5.9% Notes June 1, 2014		15		130
		5.3% Notes July 1, 2021(1)		39		39
		5.5% Notes December 1, 2021(1)		60		60
		4.9% Notes March 1, 2023(1)		25		25
		5.2925% OMEC LLC loan
		payable 2013 through April 2019 (secured by plant assets)		335		345
	Capital lease obligations:
		Purchased-power agreements		176		178
		Other		3		7
				653		784
				4,565		4,320
	Current portion of long-term debt			-29		-16
Unamortized discount on long-term debt			-11		-12
Total SDG&E			4,525		4,292
SoCalGas
First mortgage bonds:
	5.5% March 15, 2014		250		250
	5.45% April 15, 2018		250		250
	5.75% November 15, 2035		250		250
	5.125% November 15, 2040		300		300
	3.75% September 15, 2042		350		350
			1,400		1,400
Other long-term debt (unsecured):
	4.75% Notes May 14, 2016(1)		8		8
	5.67% Notes January 18, 2028		5		5
Capital lease obligations			2		4
			15		17
			1,415		1,417
Current portion of long-term debt			-252		-4
Unamortized discount on long-term debt			-4		-4
Total SoCalGas			1,159		1,409
LONG-TERM DEBT (CONTINUED)
(Dollars in millions)
		December 31,
		2013		2012
Sempra Energy
Other long-term debt (unsecured):
	6% Notes February 1, 2013		―		400
	8.9% Notes November 15, 2013, including $200 at variable rates after fixed-to-floating
	rate swaps effective January 2011		―		250
	2% Notes March 15, 2014		500		500
	Notes at variable rates (1.01% at December 31, 2013) March 15, 2014		300		300
	6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating
	rate swaps effective January 2011 (4.46% at December 31, 2013)		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
	2.875% Notes October 1, 2022		500		500
	4.05% Notes December 1, 2023		500		―
	6% Notes October 15, 2039		750		750
Market value adjustments for interest rate swaps, net (expire November 2013 and June 2016)			12		19
Build-to-suit lease(2)			14		―
Sempra Global
Other long-term debt (unsecured):
	Commercial paper borrowings at variable rates, classified as long-term debt
	(0.35% weighted average at December 31, 2013)		200		300
Sempra South American Utilities
Other long-term debt (unsecured):
Chilquinta Energía
	2.75% Series A Bonds October 30, 2014(1)		―		86
	4.25% Series B Bonds October 30, 2030(1)		209		224
Luz del Sur
	Bank loans 5.5% to 6.75% payable 2016 through December 2018		70		31
	Notes at 4.75% to 7.09% payable 2014 through October 2022		292		284
Sempra Mexico
Other long-term debt (unsecured):
	Notes February 8, 2018 at variable rates at 2.66% after floating-to-fixed rate cross-currency
	swaps effective February 2013		100		―
	6.3% Notes February 2, 2023 (4.12% after cross-currency swap)		298		―
Sempra Renewables
Other long-term debt (secured):
	Loan at variable rates payable 2014 through December 2028, including $78 at 4.54%
	after floating-to-fixed rate swaps effective June 2012 (2.75% at December 31, 2013)(1)		104		111
	Loans at 2.24% to 2.26% payable 2014 through January 2031		―		286
Sempra Natural Gas
First mortgage bonds (Mobile Gas):
	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(1)		18		17
	9% Notes May 13, 2013		―		1
	8.45% Notes payable 2014 through December 2017, secured		21		25
	3.1% Notes December 30, 2018, secured(1)		5		―
	4.5% Notes July 1, 2024, secured(1)		77		74
	Industrial development bonds at variable rates (0.05% at December 31, 2013)
	August 1, 2037, secured(1)		55		55
			6,437		6,625
Current portion of long-term debt			-866		-705
Unamortized discount on long-term debt			-9		-8
Unamortized premium on long-term debt			7		8
Total other Sempra Energy			5,569		5,920
Total Sempra Energy Consolidated		$	11,253	$	11,621
-1	Callable long-term debt not subject to make-whole provisions.
-2	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
2014		$	24	$	250	$	866	$	1,140
2015			260		―		52		312
2016			10		8		828		846
2017			10		―		662		672
2018			171		250		652		1,073
Thereafter			3,910		905		3,349		8,164
Total		$	4,385	$	1,413	$	6,409	$	12,207
-1	Excludes capital lease obligations, build-to-suit lease and market value adjustments for interest rate swaps.
Various long-term obligations totaling $6.2 billion at Sempra Energy at December 31, 2013 are unsecured. This includes unsecured long-term obligations totaling $138 million at SDG&E and $13 million at SoCalGas.
CALLABLE LONG-TERM DEBT
At the option of Sempra Energy, SDG&E and SoCalGas, certain debt 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	$	686	$	8	$	468	$	1,162
Subject to make-whole provisions		3,350		1,400		4,683		9,433
In addition, the OMEC LLC project financing loan discussed in Note 1, with $335 million of borrowings at December 31, 2013, 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 upon compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-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 permit the issuance, subject to CPUC authorization, of an additional $3.8 billion of first mortgage bonds at SDG&E and $1.06 billion at SoCalGas at December 31, 2013.
In September 2013, SDG&E publicly offered and sold $450 million of 3.60-percent first mortgage bonds maturing in 2023. SDG&E used a portion of the proceeds from this offering to redeem all $60 million of its outstanding 5.85-percent Pollution Control Revenue Bonds (PCRB) due in 2021 and $115 million of its outstanding 5.90-percent PCRBs due in 2014.
In December 2013, SDG&E redeemed all $14 million of its outstanding 6.8-percent first mortgage bonds due in 2015.
INDUSTRIAL DEVELOPMENT BONDS
Sempra Natural Gas
To secure an approved exemption from sales and use tax, Sempra Natural Gas has incurred through December 31, 2013, $257 million ($3 million in 2013, $53 million in 2012, $84 million in 2011, $42 million in 2010 and $75 million in 2009) out of a maximum available $265 million of long-term debt related to the construction and equipping of its Mississippi Hub natural gas storage facility. After a redemption of $180 million in December 2011, the debt balance remaining at December 31, 2013, is $77 million. The debt is payable to the Mississippi Business Finance Corporation (MBFC), and we recorded bonds receivable from the MBFC for the same amount. Both the financing obligation and the bonds receivable have interest rates of 4.5 percent and are due on July 1, 2024.
OTHER LONG-TERM DEBT
Sempra Energy
In November 2013, Sempra Energy publicly offered and sold $500 million of 4.05-percent notes maturing in 2023.
Sempra South American Utilities
Chilquinta Energía has outstanding Chilean public bonds denominated in Chilean Unidades de Fomento. The Chilean Unidad de Fomento is a unit of account used in Chile that is adjusted for inflation, and its value is quoted in Chilean Pesos. In May 2013, Chilquinta Energía retired $86 million of outstanding Series A Chilean public bonds maturing in 2014 with a stated interest rate of 2.75 percent.
Luz del Sur has outstanding corporate bonds and bank loans which are denominated in the local currency. During 2013, Luz del Sur publicly offered and sold $30 million of corporate bonds at 5.81 percent maturing in 2017 and $30 million of corporate bonds at 7.03 percent maturing in 2021. Additionally, Luz del Sur drew bank loans in 2013 as follows:
2013 BANK LOAN DRAWS – LUZ DEL SUR
(Dollars in millions)
		Amount at
Month Issued		Issuance		Interest Rate		Maturity Date
June		$	11	5.50%		25-Jun-16
July			5	6.00%		11-Jul-16
July			14	5.85%		24-Jul-16
December			22	6.41%		20-Dec-18
Sempra Mexico
On February 14, 2013, IEnova publicly offered and sold in Mexico $306 million (U.S. dollar equivalent) of 6.3-percent notes maturing in 2023 with a U.S. dollar equivalent rate of 4.12 percent after entering into a cross-currency swap for U.S. dollars at the time of issuance. IEnova also publicly offered and sold in Mexico $102 million (U.S. dollar equivalent) of variable rate notes, maturing in 2018, which after a floating-to-fixed cross-currency swap for U.S. dollars at the time of issuance, carry a U.S. dollar equivalent rate of 2.66 percent. The notes and related interest are denominated in Mexican pesos, and the interest rate for the variable rate notes is based on the 28-day Interbank Equilibrium Interest Rate plus 30 basis points. IEnova used $357 million of the proceeds of the notes for the repayment of intercompany debt, including accrued interest, primarily to other Sempra Energy consolidated foreign entities.
Sempra Renewables
In May 2013, Copper Mountain Solar 2 entered into a loan agreement with a syndicate of banks to borrow up to $286 million and took a draw of $146 million in May 2013, the proceeds of which were distributed to Sempra Renewables to reimburse it for the first phase of construction costs of the project. The loan, which is secured by the project, is payable semi-annually and fully matures in May 2023. To partially moderate its exposure to interest rate changes, Copper Mountain Solar 2 entered into floating-to-fixed interest rate swaps for 75 percent of the loan amount, resulting in an effective fixed rate of 5.33 percent. The remaining 25 percent bears interest at rates varying with market rates. In connection with the loan agreement, Copper Mountain Solar 2 may also utilize up to $60 million under a letter of credit facility, which may be used to meet project collateral requirements and debt service reserve requirements.
In September 2011, Sempra Renewables entered into a loan agreement with the U.S. Department of Energy (DOE) to borrow up to $337 million, which includes $7 million of accrued interest. Sempra Renewables took draws of $13 million in June 2013 at 3.03 percent, $253 million in November 2012 at 2.26 percent and $33 million in December 2012 at 2.24 percent, the proceeds of which were applied to construction costs of the Mesquite Solar 1 project. The loan is payable semi-annually and fully matures in January 2031.
In the third quarter of 2013, Sempra Renewables sold 50-percent interests in Copper Mountain Solar 2 and Mesquite Solar 1 to ConEdison Development. Sempra Renewables' interests are now accounted for under the equity method and its long-term debt of $146 million at Copper Mountain Solar 2 and $297 million at Mesquite Solar 1 was deconsolidated upon the sales. We provide further discussion of the sales in Note 3.
Sempra Natural Gas
In December 2013, Willmut Gas obtained a $5 million term loan carrying an interest rate of 3.1 percent and maturing December 30, 2018. This loan is secured by Willmut Gas' property, plant and equipment.
INTEREST RATE SWAPS
We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 9.

INCOME_TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Income Taxes	'
	NOTE 6. INCOME TAXES
	Reconciliation of net U.S. statutory federal income tax rates to the effective income tax rates is as follows:
	RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES
			Years ended December 31,
			2013		2012		2011
	Sempra Energy Consolidated
	U.S. federal statutory income tax rate		35	%	35	%	35	%
	Utility depreciation		4		6		3
	Income tax restructuring related to IEnova stock offerings		4		―		―
	State income taxes, net of federal income tax benefit		1		-1		2
	Utility repairs expenditures		-5		-8		-1
	Tax credits		-3		-7		-1
	Non-U.S. earnings taxed at lower statutory income tax rates		-3		-4		-8
	Self-developed software expenditures		-3		-5		-3
	Adjustments to prior years’ income tax items		-3		-1		―
	Allowance for equity funds used during construction		-1		-4		-2
	Variable interest entities		-1		-1		―
	Life insurance contracts		―		-7		―
	Mexican foreign exchange and inflation effects		―		1		-1
	Other, net		1		2		-1
	Effective income tax rate		26	%	6	%	23	%
	SDG&E
	U.S. federal statutory income tax rate		35	%	35	%	35	%
	Depreciation		5		4		4
	State income taxes, net of federal income tax benefit		3		4		5
	Utility repairs expenditures		-4		-4		-1
	Self-developed software expenditures		-3		-3		-3
	Allowance for equity funds used during construction		-2		-4		-4
	Variable interest entity		-1		-1		-1
	Adjustments to prior years’ income tax items		-1		-3		―
	Other, net		-1		-1		-1
	Effective income tax rate		31	%	27	%	34	%
	SoCalGas
	U.S. federal statutory income tax rate		35	%	35	%	35	%
	Depreciation		6		7		6
	State income taxes, net of federal income tax benefit		4		3		4
	Utility repairs expenditures		-9		-12		―
	Self-developed software expenditures		-6		-9		-7
	Adjustments to prior years’ income tax items		-5		―		―
	Allowance for equity funds used during construction		-1		-2		-2
	Other, net		―		-1		-3
	Effective income tax rate		24	%	21	%	33	%
	In 2013, 2012 and 2011, 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. In 2011, the earnings in Chile and Peru include the impact of the $277 million remeasurement gain related to our acquisition of controlling interests in Chilquinta Energía and Luz del Sur, which was non-taxable. We discuss this gain further in Note 3.
	In 2013, our effective income tax rate was also affected by $63 million of income tax expense recorded in the first quarter of 2013 resulting from a corporate reorganization in connection with the IEnova stock offerings. We discuss the stock offerings further in Note 1.
	Utility repairs expenditures significantly affecting the effective income tax rates for Sempra Energy Consolidated, SDG&E and SoCalGas in 2013 and 2012 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 providing a safe harbor for deducting certain repairs expenditures from taxable income when incurred for tax years beginning on or after January 1, 2011. A $22 million benefit for SDG&E related to the 2011 U.S. federal income tax return filed in the third quarter of 2012 is included in Adjustments to Prior Years' Income Tax Items in the table above. 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.
	Life insurance contracts significantly affected the effective tax rate for Sempra Energy Consolidated in 2012 primarily due to our decision in the second quarter of 2012 to hold life insurance contracts kept in support of certain benefit plans to term. Previously, we took the position that we might cash in or sell these contracts before maturity, which required that we record deferred income taxes on unrealized gains on investments held within the insurance contracts.
	In September 2013, the IRS and U.S. Department of the Treasury released final tangible property regulations on the capitalization and expensing rules applicable to expenditures for the acquisition and production of tangible property. A company must conform its tax accounting methods and elect any safe harbors under the final regulations no later than January 1, 2014, however, if a change in the company's tax accounting methods is required to conform to the final regulations, the company must adjust its deferred tax balances in the current period for any tax adjustments required to bring all prior periods into compliance with the final regulations. We evaluated our deferred tax balances based on the guidance contained in the final tangible property regulations and determined that we are following the guidance in all material respects. Any adjustments to deferred taxes resulting from changes to comply with the final tangible property regulations would have a de minimus impact on the financial statements. Accordingly, we have not made any adjustment to our deferred tax balances at December 31, 2013 based on the issuance of the final tangible property regulations.
	The 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 regulatory 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 results in impacting the current effective 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 following items are subject to flow-through treatment:
	repairs expenditures 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
	self-developed software expenditures
	depreciation on a certain portion of utility plant assets
	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 and 2011, 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 energy assets, referred to as the day-one basis difference. The financial statement basis 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 50 percent for grants and not at all for ITC.
	Cash grants are generally expected to be collectible in cash shortly after a project is constructed. 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) carryforward can result in delaying this conversion.
	The geographic components of Income Before Income Taxes and Equity Earnings of Certain Unconsolidated Subsidiaries at Sempra Energy are as follows:
		Years ended December 31,
	(Dollars in millions)	2013		2012		2011
	U.S.	$	941	$	442	$	1,011
	Non-U.S.		489		501		712
	Total	$	1,430	$	943	$	1,723
The components of income tax expense are as follows:
INCOME TAX EXPENSE (BENEFIT)
(Dollars in millions)
	Years ended December 31,
	2013		2012		2011
Sempra Energy Consolidated
Current:
U.S. Federal	$	-70	$	-36	$	76
U.S. State		-5		-6		-3
Non-U.S.		107		144		149
Total		32		102		222
Deferred:
U.S. Federal		275		-63		176
U.S. State		15		3		43
Non-U.S.		48		20		-45
Total		338		-40		174
Deferred investment tax credits		-4		-3		-2
Total income tax expense	$	366	$	59	$	394
SDG&E
Current:
U.S. Federal	$	9	$	-109	$	-59
U.S. State		11		14		6
Total		20		-95		-53
Deferred:
U.S. Federal		149		255		253
U.S. State		24		30		36
Total		173		285		289
Deferred investment tax credits		-2		―		1
Total income tax expense	$	191	$	190	$	237
SoCalGas
Current:
U.S. Federal	$	4	$	-73	$	-6
U.S. State		-5		24		19
Total		-1		-49		13
Deferred:
U.S. Federal		103		136		128
U.S. State		16		-6		5
Total		119		130		133
Deferred investment tax credits		-2		-2		-3
Total income tax expense	$	116	$	79	$	143
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,
	2013		2012
Deferred income tax liabilities:
Differences in financial and tax bases of depreciable and amortizable assets	$	3,951	$	3,710
Regulatory balancing accounts		663		770
Unrealized revenue		15		3
Loss on reacquired debt		8		9
Property taxes		50		46
Difference in financial and tax bases of partnership interests		256		118
Other deferred income tax liabilities		72		55
Total deferred income tax liabilities		5,015		4,711
Deferred income tax assets:
Tax credits		105		67
Equity losses		16		16
Net operating losses		2,023		1,898
Compensation-related items		128		156
Postretirement benefits		264		587
Other deferred income tax assets		14		90
State income taxes		30		58
Bad debt allowance		8		8
Litigation and other accruals not yet deductible		20		7
Deferred income tax assets before valuation allowances		2,608		2,887
Less: valuation allowances		96		128
Total deferred income tax assets		2,512		2,759
Net deferred income tax liability	$	2,503	$	1,952
Our policy is to show deferred income taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information.
DEFERRED INCOME TAXES FOR SDG&E AND SOCALGAS
(Dollars in millions)
	SDG&E				SoCalGas
	December 31,				December 31,
	2013		2012		2013		2012
Deferred income tax liabilities:
Differences in financial and tax bases of
utility plant and other assets	$	2,040	$	1,947	$	1,045	$	938
Regulatory balancing accounts		411		344		265		439
Loss on reacquired debt		3		4		6		7
Property taxes		36		32		16		15
Other		25		22		―		―
Total deferred income tax liabilities		2,515		2,349		1,332		1,399
Deferred income tax assets:
Net operating losses		440		446		65		34
Postretirement benefits		57		137		126		370
Tax credits		15		16		12		14
Compensation-related items		13		14		38		48
State income taxes		22		31		10		18
Litigation and other accruals not yet deductible		45		38		27		21
Hedging transaction		1		1		5		7
Other		4		4		11		9
Total deferred income tax assets		597		687		294		521
Net deferred income tax liability	$	1,918	$	1,662	$	1,038	$	878
Our policy is to show deferred income taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information.
The net deferred income tax liabilities are recorded on the Consolidated Balance Sheets at December 31 as follows:
NET DEFERRED INCOME TAX LIABILITY
(Dollars in millions)
	Sempra Energy
	Consolidated				SDG&E				SoCalGas
	2013		2012		2013		2012		2013		2012
Current (asset) liability	$	-301	$	-148	$	-103	$	26	$	45	$	-3
Noncurrent liability		2,804		2,100		2,021		1,636		993		881
Total	$	2,503	$	1,952	$	1,918	$	1,662	$	1,038	$	878
At December 31, 2013, Sempra Energy has recorded a valuation allowance against a portion of its total deferred income tax assets, as shown above in the “Deferred Income Taxes for 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 valuation 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 below, that we currently do not believe will be realized on a more-likely-than-not basis. At both Sempra Energy and SDG&E, deferred income taxes for variable interest entities are shown on a net basis. Therefore, valuation allowances of $60 million at December 31, 2013 and $108 million at December 31, 2012 related to variable interest entities are not reflected in the table above. Of Sempra Energy's total valuation allowance of $96 million at December 31, 2013, $12 million is related to non-U.S. NOLs and $84 million to U.S. state NOLs. Of Sempra Energy's total valuation allowance of $128 million at December 31, 2012, $20 million is related to non U.S. NOLs, $100 million to U.S. state NOLs and $8 million to other future U.S. state temporary differences. The total valuation allowance decreased in 2013 primarily due to a reduction in the U.S. state temporary differences and release of Mexico valuation allowance. We believe that it is more-likely-than-not that the remainder of the total deferred income tax asset is realizable.
At December 31, 2013, Sempra Energy's non-U.S. subsidiaries had $61 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 holding companies in Mexico, the Netherlands and Spain. The carryforward periods for our non-U.S. unused NOLs expire between 2014 and 2023. As of December 31, 2013, our Mexican subsidiaries have NOLs of $182 million, of which $165 million have been utilized on a consolidated level. As part of the Mexican tax reform enacted in 2014, the $165 million of NOLs utilized in consolidation is subject to recapture between 2014 and 2018. These NOLs expire between 2016 and 2023. Sempra Energy's U.S. subsidiaries had $2.9 billion of unused U.S. state NOLs, primarily in Alabama, California, Connecticut, District of Columbia, Indiana, Kansas, Louisiana, Minnesota, New Jersey, New York, Oklahoma and Pennsylvania. These U.S. state NOLs expire between 2014 and 2032. We have not recorded deferred income tax benefits on a portion of Sempra Energy's total non-U.S. and U.S. state NOLs because we currently believe they will not be realized on a more-likely-than-not basis, as discussed above. Sempra Natural Gas is currently progressing with plans for a development project to utilize its Cameron LNG receipt terminal for the liquefaction of natural gas and export of LNG. Depending on achieving certain milestones related to the project, we expect to release approximately $20 million to $25 million of Louisiana valuation allowance against the deferred tax asset. The timing of the release of the valuation allowance and the amount can vary depending upon ultimate contractual agreements and forecasted economics. Sempra Energy's consolidated U.S. subsidiaries had $5.1 billion of unused U.S. federal consolidated NOLs that will begin to expire in 2031. Included in this amount is $0.2 billion of excess tax deductions related to employee stock expense for which a benefit will be recorded to additional paid in capital when realized. We have recorded deferred income tax benefits on these NOLs, in total, because we currently believe they will be realized on a more-likely-than-not basis.
At December 31, 2013, SDG&E had $1.2 billion of unused U.S. federal NOLs (the remaining 2011 NOL of $24 million expires in 2031 and the 2012 NOL of $1.2 billion expires in 2032). We have recorded deferred income tax benefits on these NOLs, in total, because we currently believe they will be realized on a more-likely-than-not basis. At December 31, 2013, SoCalGas had $172 million of unused U.S. federal NOL which expires in 2032. We have recorded a deferred income tax benefit on this NOL, in total, because we currently believe it will be realized on a more-likely-than-not basis.
At December 31, 2013, Sempra Energy had not recognized a U.S. deferred income tax liability related to a $3.3 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 basis difference consists of $3.3 billion of cumulative undistributed earnings that we expect to reinvest indefinitely outside of the U.S., which includes the $0.3 billion gain related to the remeasurement of equity method investments in Chilquinta Energía and Luz del Sur that we discuss in Note 3. 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 practical to determine the hypothetical unrecognized amount of U.S. deferred income taxes that might be payable if the cumulative undistributed earnings were eventually distributed or the investments were sold. U.S. deferred income taxes would be recorded on $3.3 billion of the basis difference related to cumulative undistributed earnings if we no longer intend to indefinitely reinvest all, or a part, of the cumulative undistributed earnings.
Following is a summary of unrecognized income tax benefits:
SUMMARY OF UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
	Years ended December 31,
	2013		2012		2011
Sempra Energy Consolidated:
Total	$	90	$	82	$	72
Of the total, amounts related to tax positions that,
if recognized in future years, would
decrease the effective tax rate	$	-86	$	-81	$	-72
increase the effective tax rate		19		16		7
SDG&E:
Total	$	17	$	12	$	7
Of the total, amounts related to tax positions that,
if recognized in future years, would
decrease the effective tax rate	$	-14	$	-12	$	-7
increase the effective tax rate		11		12		7
SoCalGas:
Total	$	13	$	5	$	―
Of the total, amounts related to tax positions that,
if recognized in future years, would
decrease the effective tax rate	$	-13	$	-5	$	―
increase the effective tax rate		8		4		―
Following is a reconciliation of the changes in unrecognized income tax benefits for the years ended December 31:
RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS
(Dollars in millions)
	2013		2012		2011
Sempra Energy Consolidated:
Balance as of January 1	$	82	$	72	$	97
Increase in prior period tax positions		26		2		7
Decrease in prior period tax positions		-24		-1		-26
Increase in current period tax positions		7		10		3
Settlements with taxing authorities		-1		-1		-9
Balance as of December 31	$	90	$	82	$	72
SDG&E:
Balance as of January 1	$	12	$	7	$	5
Increase in prior period tax positions		7		1		―
Decrease in prior period tax positions		-4		―		―
Increase in current period tax positions		2		4		2
Balance as of December 31	$	17	$	12	$	7
SoCalGas:
Balance as of January 1	$	5	$	―	$	8
Increase in prior period tax positions		4		―		2
Increase in current period tax positions		5		5		―
Settlements with taxing authorities		-1		―		-10
Balance as of December 31	$	13	$	5	$	―
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,
	2013		2012		2011
Sempra Energy Consolidated:
Expiration of statutes of limitations on tax assessments	$	-7	$	-7	$	-7
Potential resolution of audit issues with various
U.S. federal, state and local and non-U.S. taxing authorities		-63		-10		―
	$	-70	$	-17	$	-7
SDG&E:
Potential resolution of audit issues with various
U.S. federal, state and local and non-U.S. taxing authorities	$	-14	$	-5	$	―
SoCalGas:
Potential resolution of audit issues with various
U.S. federal, state and local and non-U.S. taxing authorities	$	-11	$	-4	$	―
Amounts accrued for interest and penalties associated with unrecognized income tax benefits are included in income tax expense on the Consolidated Statements of Operations. The amounts accrued at December 31 on the Consolidated Balance Sheets for interest and penalties associated with unrecognized income tax benefits are stated alongside 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,
	2013		2012		2011			2013		2012
Sempra Energy Consolidated:
Interest expense (income)	$	1	$	―	$	-3		$	4	$	3
Penalties		―		―		-1			3		3
SDG&E:
Interest expense	$	―	$	―	$	―		$	1	$	1
SoCalGas:
Interest (income) expense	$	-1	$	―	$	-1		$	―	$	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 to income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 2008. We are subject to examination by major state tax jurisdictions for tax years after 2005. Certain major non-U.S. income tax returns from 2007 through the present are open to examination.
In addition, we have filed state refund claims for tax years back to 1998, and PE has filed state refund claims for tax years back to 1993. The pre-2006 tax years are closed to new issues; therefore, no additional tax may be assessed by the taxing authorities for these 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 years after 2008 and by major state tax jurisdictions for years after 2005.

EMPLOYEE_BENEFIT_PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2013
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 changes in the funded status of pension and other postretirement benefit plans in the year in which the changes occur. Generally, those changes 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 defined benefit plans, including separate plans for SDG&E and SoCalGas, which collectively cover substantially all domestic and certain foreign employees, and members of the Sempra Energy board of directors who were participants in a predecessor plan on or before June 1, 1998. The plans generally provide defined benefits based on years of service and either final average or career salary.
	Chilquinta Energía, which was acquired by Sempra Energy in 2011, has an unfunded contributory defined benefit plan covering all employees hired before October 1, 1981 and an unfunded noncontributory termination indemnity obligation covering all employees. The plans generally provide defined benefits to retirees based on date of hire, years of service and final average salary.
	Sempra Energy also has other postretirement benefit plans (PBOP), including separate plans for SDG&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 contributory. 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 health care plan and an energy subsidy plan that provides for reduced energy rates. The health care plan includes benefits for retirees' spouses and dependents.
	Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. These assumptions include
	discount rates
	expected return on plan assets
	health care cost trend rates
	mortality rates
	rate of compensation 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 prior to the beginning of each year and update them as appropriate. We consider current 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, which totaled $506 million and $510 million at December 31, 2013 and 2012, respectively.
	Pension and Other Postretirement Benefit Plans
	Benefit Plan Amendments Affecting 2013
	Effective July 1, 2014, an enhanced pension benefit will be provided to certain employees of SoCalGas who transfer from a represented to a nonrepresented position after June 30, 1998. This increased the pension benefit obligation by $27 million at each of Sempra Energy Consolidated and SoCalGas.
	Effective April 1, 2014, we will provide a one-time, ad hoc cost of living adjustment of 13.2 percent for SoCalGas and PE retirees who retired prior to July 1, 1996 and their beneficiaries that are receiving qualified pension benefits in the form of an annuity. This election increased the pension benefit obligation by $40 million at Sempra Energy Consolidated and $39 million at SoCalGas.
	Effective January 1, 2013, the face value of the fully paid life insurance benefit for employees that participate in our Executive Retirement Life Insurance Program and retire after December 31, 2012 was increased from one times pay to one-and-a-half times pay. In addition, the tax gross-ups paid to the retiring employee based on the value of the final premium were eliminated. These changes resulted in a decrease of the other postretirement benefit obligation of $4 million at Sempra Energy Consolidated.
	Effective January 1, 2014, the benefits provided by one of the dental plans available to all employees that participate in the plans, except the represented employees at SoCalGas, were enhanced to increase the annual total maximum and lifetime orthodontic maximum covered costs. In addition, the costs of diagnostic and preventive services were excluded from the total covered annual maximum costs. These plan design changes increased the recorded liability for other postretirement benefits by $1 million at each of Sempra Energy Consolidated and SoCalGas.
	The plan amendments above were adopted in 2013, and therefore reflected in the 2013 pension and other postretirement benefit obligations.
	Benefit Plan Amendments Affecting 2012
	Effective January 1, 2012, the pension plan death benefit for represented employees at SoCalGas was enhanced to the full value of the benefit that the participant would have received had the employee terminated employment and taken a distribution of their benefit. Effective October 1, 2012, the death benefit for represented employees at SDG&E was similarly enhanced. This increased the benefit obligation by approximately $8 million for Sempra Energy Consolidated, $1 million for SDG&E and $7 million for SoCalGas.
	Effective January 1, 2012, SoCalGas' represented employees with less than 15 years of service now receive a defined dollar benefit to cover postretirement medical benefits. This amendment was the result of the ratification on March 1, 2012 of the SoCalGas union collective bargaining agreement (CBA) covering wages, hours, working conditions and medical and other benefit plans effective January 1, 2012 through September 30, 2015. The amendment resulted in a remeasurement of the SoCalGas other postretirement benefit liability as of February 29, 2012. The effect of this plan change as of December 31, 2012 was a decrease in the recorded liability for other postretirement benefits of $53 million at each of Sempra Energy Consolidated and SoCalGas.
	Effective January 1, 2012, certain postretirement plans were amended to effectively reverse the 2011 amendment that increased employer contributions to maintain the grandfathered retiree plan status under the Patient Protection and Affordable Care Act (PPACA), described below, as it was no longer required due to a restructuring of benefits provided under the plans. The 2012 amendment resulted in a decrease in the recorded liability for other postretirement benefits of approximately $3 million for Sempra Energy Consolidated, $2 million for SDG&E and $1 million for SoCalGas.
	Special Termination Benefits Affecting 2013
	All nonrepresented employees of SDG&E and SoCalGas who were age 62 and had 5 years of service and all other nonrepresented employees who were age 55 and had 10 years of service that retired under the Voluntary Retirement Enhancement Program (VREP) offered in 2013 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 termination benefits. This resulted in a one-time charge that increased the recorded liability for other postretirement benefits by approximately $5 million for Sempra Energy Consolidated, $2 million for SDG&E and $2 million for SoCalGas.
	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 2013 and 2012, and a statement of the funded status at December 31, 2013 and 2012:
	PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
	(Dollars in millions)
			Pension Benefits					Other Postretirement Benefits
	Sempra Energy Consolidated		2013		2012			2013		2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION:
	Net obligation at January 1		$	3,804	$	3,406		$	1,115	$	1,160
	Service cost			109		90			28		25
	Interest cost			148		162			44		52
	Contributions from plan participants			―		―			16		15
	Actuarial (gain) loss			-371		374			-177		-25
	Benefit payments			-293		-217			-55		-56
	Plan amendments			67		8			-3		-56
	Special termination benefits			―		―			5		―
	Settlements			-5		-19			―		―
	Net obligation at December 31			3,459		3,804			973		1,115
	CHANGE IN PLAN ASSETS:
	Fair value of plan assets at January 1			2,558		2,332			873		778
	Actual return on plan assets			396		339			151		97
	Employer contributions			133		123			27		39
	Contributions from plan participants			―		―			16		15
	Benefit payments			-293		-217			-55		-56
	Settlements			-5		-19			―		―
	Fair value of plan assets at December 31			2,789		2,558			1,012		873
	Funded status at December 31		$	-670	$	-1,246		$	39	$	-242
	Net recorded (liability) asset at December 31		$	-670	$	-1,246		$	39	$	-242
PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension Benefits					Other Postretirement Benefits
SDG&E	2013		2012			2013		2012
CHANGE IN PROJECTED BENEFIT OBLIGATION:
Net obligation at January 1	$	1,067	$	981		$	185	$	182
Service cost		32		28			8		7
Interest cost		41		45			8		9
Contributions from plan participants		―		―			6		6
Actuarial (gain) loss		-66		87			-19		-5
Benefit payments		-89		-75			-12		-12
Plan amendments		―		1			―		-2
Special termination benefits		―		―			2		―
Settlements		-4		―			―		―
Transfer of liability to other plans		-42		―			-7		―
Net obligation at December 31		939		1,067			171		185
CHANGE IN PLAN ASSETS:
Fair value of plan assets at January 1		781		712			126		106
Actual return on plan assets		117		99			18		13
Employer contributions		51		45			14		13
Contributions from plan participants		―		―			6		6
Benefit payments		-89		-75			-12		-12
Settlements		-4		―			―		―
Transfer of assets to other plans		-37		―			-6		―
Fair value of plan assets at December 31		819		781			146		126
Funded status at December 31	$	-120	$	-286		$	-25	$	-59
Net recorded liability at December 31	$	-120	$	-286		$	-25	$	-59
PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
		Pension Benefits					Other Postretirement Benefits
SoCalGas		2013		2012			2013		2012
CHANGE IN PROJECTED BENEFIT OBLIGATION:
Net obligation at January 1		$	2,299	$	2,017		$	873	$	921
Service cost			67		53			17		16
Interest cost			90		99			34		41
Contributions from plan participants			―		―			10		9
Actuarial (gain) loss			-285		245			-151		-19
Benefit payments			-169		-120			-40		-41
Plan amendments			66		7			1		-54
Special termination benefits			―		―			2		―
Settlements			―		-2			―		―
Transfer of liability from other plans			42		―			7		―
Net obligation at December 31			2,110		2,299			753		873
CHANGE IN PLAN ASSETS:
Fair value of plan assets at January 1			1,581		1,443			732		658
Actual return on plan assets			250		213			131		83
Employer contributions			59		47			9		23
Contributions from plan participants			―		―			10		9
Benefit payments			-169		-120			-40		-41
Settlements			―		-2			―		―
Transfer of assets from other plans			37		―			6		―
Fair value of plan assets at December 31			1,758		1,581			848		732
Funded status at December 31		$	-352	$	-718		$	95	$	-141
Net recorded (liability) asset at December 31		$	-352	$	-718		$	95	$	-141
The actuarial gains for pension plans in 2013 were primarily due to an increase in the weighted average discount rate and the rate used to convert monthly annuity-type benefits to a lump sum benefit payment.
The actuarial gains for other postretirement plans in 2013 resulted from several factors, including an increase in the discount rate, updated census data and actual claims costs at SoCalGas, updates in actual premiums and retiree contributions for 2013, expected decrease in 2014 claims costs based on 2014 renewal premium rates, and a decrease in the healthcare cost trending rate. The actuarial gains were partially offset by the impact of updated census data and actual claims costs at all companies except SoCalGas, changes in retirement and termination rates, and an expected increase in non-spouse dependents for all employees of SoCalGas not covered by the defined dollar benefit.
The actuarial losses for pension plans in 2012 were primarily due to a decrease in the weighted average discount rate and the rate used to convert monthly annuity-type benefits to a lump sum benefit payment.
The actuarial gains for other postretirement plans in 2012 resulted from several factors, including updated census data and actual claims costs, premiums and retiree contributions for 2012, expected gains on 2013 claims costs based on 2013 renewal premium rates, changes in retirement rate assumptions and the move to an Employer Group Waiver Plan (EGWP) for all represented employees of SoCalGas effective February 29, 2012. An EGWP is an alternative means of providing the existing pharmacy benefit, discussed below. The actuarial gains were partially offset by the impact of a lower discount rate for the obligation remeasurement on February 29, 2012 discussed above and a lower discount rate at the December 31, 2012 measurement date.
Net Assets and Liabilities
The assets and liabilities of the pension and other postretirement benefit plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Sempra Energy Consolidated (except for SDG&E) and SoCalGas use the asset smoothing method for their pension and other postretirement plans. This method develops an asset value that recognizes realized and unrealized investment gains and losses over 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 the 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, SDG&E and 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 active 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 and 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 authorized by the CPUC. The annual contributions to the pension plans are limited to a minimum required funding amount as determined by the Internal Revenue Service. The annual contributions to the other postretirement plans are equal to the lesser of the maximum tax deductible amount 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 the 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 regulated entities.
The net liability is included in the following captions on the Consolidated Balance Sheets at December 31:
	Pension Benefits					Other Postretirement Benefits
(Dollars in millions)	2013		2012			2013		2012
Sempra Energy Consolidated
Noncurrent assets	$	―	$	―		$	95	$	―
Current liabilities		-59		-31			―		-1
Noncurrent liabilities		-611		-1,215			-56		-241
Net recorded liability	$	-670	$	-1,246		$	39	$	-242
SDG&E
Current liabilities	$	-13	$	-5		$	―	$	―
Noncurrent liabilities		-107		-281			-25		-59
Net recorded liability	$	-120	$	-286		$	-25	$	-59
SoCalGas
Noncurrent assets	$	―	$	―		$	95	$	―
Current liabilities		-13		-4			―		―
Noncurrent liabilities		-339		-714			―		-141
Net recorded liability	$	-352	$	-718		$	95	$	-141
Amounts recorded in Accumulated Other Comprehensive Income (Loss) as of December 31, 2013 and 2012, 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
	2013		2012			2013		2012
Sempra Energy Consolidated
Net actuarial loss	$	-73	$	-96		$	―	$	-6
Prior service credit		―		1			―		―
Total	$	-73	$	-95		$	―	$	-6
SDG&E
Net actuarial loss	$	-10	$	-12
Prior service credit		1		1
Total	$	-9	$	-11
SoCalGas
Net actuarial loss	$	-5	$	-4
Prior service credit		1		1
Total	$	-4	$	-3
The accumulated benefit obligation for defined benefit pension plans at December 31, 2013 and 2012 was as follows:
	Sempra Energy Consolidated					SDG&E					SoCalGas
(Dollars in millions)	2013		2012			2013		2012			2013		2012
Accumulated benefit obligation	$	3,254	$	3,530		$	923	$	1,041		$	1,944	$	2,080
Sempra Energy has unfunded and funded pension plans. SDG&E and SoCalGas each have an unfunded and a funded pension plan. The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets as of December 31:
(Dollars in millions)	2013		2012
Sempra Energy Consolidated
Projected benefit obligation	$	3,212	$	3,544
Accumulated benefit obligation		3,027		3,295
Fair value of plan assets		2,789		2,558
SDG&E
Projected benefit obligation	$	899	$	1,025
Accumulated benefit obligation		886		1,003
Fair value of plan assets		819		781
SoCalGas
Projected benefit obligation	$	2,085	$	2,275
Accumulated benefit obligation		1,920		2,057
Fair value of plan assets		1,758		1,581
Net Periodic Benefit Cost, 2011-2013
The following three tables provide the components of net periodic benefit cost and amounts recognized in other comprehensive income for the years ended December 31:
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
	Pension Benefits							Other Postretirement Benefits
Sempra Energy Consolidated	2013		2012		2011			2013		2012		2011
Net Periodic Benefit Cost
Service cost	$	109	$	90	$	83		$	28	$	25	$	31
Interest cost		148		162		168			44		52		65
Expected return on assets		-162		-155		-144			-58		-53		-48
Amortization of:
Prior service cost (credit)		4		3		4			-4		-4		―
Actuarial loss		54		47		34			7		12		17
Settlement charge		2		8		13			―		―		―
Special termination benefits		―		―		―			5		―		―
Regulatory adjustment		-20		-29		43			6		7		7
Total net periodic benefit cost		135		126		201			28		39		72
Other Changes in Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income
Net (gain) loss		-30		19		23			-8		-6		7
Prior service cost		1		―		―			―		―		―
Amortization of actuarial loss		-9		-9		-10			-1		―		―
Total recognized in other comprehensive income		-38		10		13			-9		-6		7
Total recognized in net periodic benefit cost and other comprehensive income	$	97	$	136	$	214		$	19	$	33	$	79
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
	Pension Benefits							Other Postretirement Benefits
SDG&E	2013		2012		2011			2013		2012		2011
Net Periodic Benefit Cost
Service cost	$	32	$	28	$	28		$	8	$	7	$	7
Interest cost		41		45		49			8		9		10
Expected return on assets		-52		-47		-46			-8		-8		-8
Amortization of:
Prior service cost		2		2		1			4		4		4
Actuarial loss		14		14		9			―		―		―
Settlement charge		1		1		1			―		―		―
Special termination benefits		―		―		―			2		―		―
Regulatory adjustment		14		6		31			―		1		2
Total net periodic benefit cost		52		49		73			14		13		15
Other Changes in Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income
Net (gain) loss		-2		2		1			―		―		―
Amortization of actuarial loss		-1		-1		-1			―		―		―
Total recognized in other comprehensive income		-3		1		―			―		―		―
Total recognized in net periodic benefit cost and other comprehensive income	$	49	$	50	$	73		$	14	$	13	$	15
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
(Dollars in millions)
	Pension Benefits							Other Postretirement Benefits
SoCalGas	2013		2012		2011			2013		2012		2011
Net Periodic Benefit Cost
Service cost	$	67	$	53	$	46		$	17	$	16	$	22
Interest cost		90		99		99			34		41		53
Expected return on assets		-98		-96		-85			-48		-44		-40
Amortization of:
Prior service cost (credit)		2		2		2			-8		-7		-4
Actuarial loss		31		23		17			6		11		17
Settlement charge		―		1		1			―		―		―
Special termination benefits		―		―		―			2		―		―
Regulatory adjustment		-34		-36		12			6		5		5
Total net periodic benefit cost		58		46		92			9		22		53
Other Changes in Plan Assets and Benefit Obligations
Recognized in Other Comprehensive Income
Net loss (gain)		3		-4		2			―		―		―
Amortization of actuarial loss		-1		-1		-1			―		―		―
Total recognized in other comprehensive income		2		-5		1			―		―		―
Total recognized in net periodic benefit cost and other comprehensive income	$	60	$	41	$	93		$	9	$	22	$	53
The estimated net loss for the pension plans that will be amortized from Accumulated Other Comprehensive Income (Loss) into net periodic benefit cost in 2014 is $10 million for Sempra Energy Consolidated, $1 million for SDG&E and $1 million for SoCalGas. Negligible amounts of prior service credit for the pension plans will be similarly amortized in 2014.
Patient Protection and Affordable Care Act of 2010
The Patient Protection and Affordable Care Act of 2010 was enacted in March 2010. We have incorporated the impact on costs of the provisions of this legislation into our determination of projected benefit obligations and accumulated benefit obligations for all of Sempra Energy's affected plans.
Medicare Prescription Drug, Improvement and Modernization Act of 2003
The Medicare Prescription Drug, Improvement and Modernization Act of 2003 establishes a prescription drug benefit under Medicare (Medicare Part D) and a tax-exempt federal subsidy to sponsors of retiree health-care benefit plans that provide a benefit that actuarially is at least equivalent to Medicare Part D. As a result of the ratification of the SoCalGas CBA on March 1, 2012, described above, there was a change in medical plans offered for post-age 65 medical benefits. SoCalGas now administers the Medicare Part D benefit through an EGWP. The EGWP allows a plan sponsor to contract with a Medicare Part D sponsor to receive the benefit of the subsidy through reduced premiums. We have determined that benefits provided to certain participants actuarially will be at least equivalent to Medicare Part D. Due to this election of an EGWP for SoCalGas' represented employees effective February 29, 2012, and the same election for all other employees on January 1, 2012, as of these dates, we are no longer entitled to a tax-exempt subsidy that reduces our accumulated postretirement benefit obligation under our plans and reduces our net periodic cost in future years.
Assumptions for Pension and Other Postretirement Benefit Plans
Benefit Obligation and Net Periodic Benefit Cost
Except for the 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 expected 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 least $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 also 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 events 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 Chilquinta Energía based on 10-year Chilean government bond yields and the expected local long-term rate of inflation. This method for developing the discount rate is 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.
The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows:
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31
		Pension Benefits					Other Postretirement Benefits
		2013		2012			2013		2012
Sempra Energy Consolidated
Discount rate		4.84	%	4.04	%		4.95	%	4.09	%
Rate of compensation increase		3.50-10.00		3.50-9.50			3.50-10.00		3.50-9.50
SDG&E
Discount rate		4.69	%	3.94	%		5	%	4.1	%
Rate of compensation increase		3.50-10.00		3.50-9.50			3.50-10.00		3.50-9.50
SoCalGas
Discount rate		4.94	%	4.1	%		4.95	%	4.1	%
Rate of compensation increase		3.50-10.00		3.50-9.50			3.50-10.00		3.50-9.50
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST FOR YEARS ENDED DECEMBER 31
		Pension Benefits							Other Postretirement Benefits
		2013		2012		2011			2013		2012		2011
Sempra Energy Consolidated
Discount rate		4.04	%	4.40-5.05	%	4.40-5.14	%		4.09	%	4.10-5.15	%	4.10-5.15	%
Expected return on plan assets		7		7		7			6.96		6.96		6.25
Rate of compensation increase		3.50-9.50		3.50-8.50		3.50-8.50			3.50-9.50		3.50-9.50		3.50-9.50
SDG&E
Discount rate		3.94	%	4.70-4.80	%	4.70-4.80	%		4.1	%	5.05	%	5.05	%
Expected return on plan assets		7		7		7			6.81		6.81		6.69
Rate of compensation increase		3.50-9.50		3.50-8.50		3.50-8.50			N/A		N/A		N/A
SoCalGas
Discount rate		4.1	%	4.70-5.05	%	4.70-5.05	%		4.1	%	5.15	%	5.15	%
Expected return on plan assets		7		7		7			7		7		7
Rate of compensation increase		3.50-9.50		3.50-8.50		3.50-8.50			3.50-9.50		3.50-9.50		3.50-9.50
Health Care Cost Trend Rates
Assumed health care cost trend rates have a significant effect on the amounts that we report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans
		2013		2012
ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31:
Health care cost trend rate		-1		-2
Rate to which the cost trend rate is assumed to decline (the ultimate trend)		-3		-4
Year that the rate reaches the ultimate trend		-5		2020
-1	8.25% for pre-65 retirees and 5.50% for retirees aged 65 years and older. For Mobile Gas, the health care cost trend rate is assumed to be 7.50%.
-2	10.00% for pre-65 retirees and 8.25% for retirees aged 65 years and older. For Mobile Gas, the health care cost trend rate is assumed to be 8.00%.
-3	5.00% for pre-65 retirees and 4.50% for retirees aged 65 years and older. For Mobile Gas, the rate to which the cost trend rate is assumed to decline is 5.00%.
-4	5.00% for pre-65 retirees and 4.75% for retirees aged 65 years and older. For Mobile Gas, the rate to which the cost trend rate is assumed to decline is 5.00%.
-5	2019 for Mobile Gas plan and 2020 for all other plans.
A one-percent change in assumed health care cost trend rates would have the following effects:
	Sempra Energy
	Consolidated					SDG&E					SoCalGas
	1%		1%			1%		1%			1%		1%
(Dollars in millions)	Increase		Decrease			Increase		Decrease			Increase		Decrease
Effect on total of service and interest
cost components of net periodic
postretirement health care benefit cost	$	8	$	-6		$	1	$	-1		$	6	$	-5
Effect on the health care component of the
accumulated other postretirement
benefit obligations		100		-62			8		-6			90		-54
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' asset allocations are
38 percent domestic equity
26 percent international equity
5 percent high yield credit
12 percent intermediate credit
14 percent long credit
5 percent real assets
The asset allocation of the plans is reviewed by our Plan Funding Committee 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. When asset class exposure reaches a minimum or maximum level, we generally rebalance the portfolio back to target allocations, unless the Committees determine otherwise.
Rate of Return Assumption
The expected return on assets in our pension plans 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, except for the assets in the SDG&E other postretirement benefit plan. 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. The forecasts are developed using a build-up method that considers real risk-free interest rates, inflation rates and asset class specific risk premiums. We expect a return of between 7 percent and 10 percent on equity securities and between 3 percent and 6 percent for fixed-income securities.
The expected return on assets in the SDG&E other postretirement benefit plan is based on the weighted-average of the expected return on plan assets held in the Voluntary Employee Beneficiary Association (VEBA) trust designated for non-collectively bargained benefits and the expected return on plan assets held in the pension master trust and the collectively bargained VEBA. The expected return on assets for the non-collectively bargained VEBA trust is based on the weighted-average of the expected return on equity securities, as described above, and a 4 percent expected return on fixed income securities, which are all invested in tax-exempt municipal bonds.
Concentration of Risk
Plan assets are fully 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 and other 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 has been formulated to best suit the long-term nature of the obligations.
Fair Value of Pension and Other Postretirement Benefit Plan Assets
We classify the investments in Sempra Energy's pension master trust and the 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 market 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 measurement.
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 on 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.
Registered Investment Companies — Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices for equity and certain fixed income securities or are 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 for the remaining fixed income securities.
Common/Collective Trusts — Investments in common/collective trust funds are valued based on the redemption price of units owned, which is based on the current fair value of the funds' underlying assets.
Private Equity Funds — Investments in private equity funds do not trade in active markets. Fair value is determined by the fund managers, based upon their review of the underlying investments as well as their utilization of discounted cash flows and other valuation models.
Real Estate — Real estate investments are valued on the basis of a discounted cash flows approach, which includes the future rental receipts, expenses, and residual values for the highest and best use of the real estate from a market participant view as rental property.
The methods described are intended to produce a fair value calculation that is indicative of net realizable value or reflective of future fair values. However, while management believes the valuation methods are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date.
We provide more discussion of fair value measurements in Notes 1 and 10. The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and other postretirement benefit plan trusts measured at fair value on a recurring basis.
The fair values of our pension plan assets by asset category are as follows:
FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		At fair value as of December 31, 2013
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	576	$	269	$	6	$	851
SoCalGas (see table below)			1,157		540		13		1,710
Other Sempra Energy
Equity securities:
Domestic(1)			79		―		―		79
Foreign			52		―		―		52
Registered investment companies			11		―		―		11
Fixed income securities:
U.S. Treasury securities			1		―		―		1
Domestic municipal bonds			―		3		―		3
Foreign government bonds			―		7		―		7
Domestic corporate bonds(2)			―		38		―		38
Foreign corporate bonds			―		13		―		13
Common/collective trusts(3)			―		5		―		5
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total other Sempra Energy(5)			143		66		2		211
Total Sempra Energy Consolidated(6)		$	1,876	$	875	$	21	$	2,772
		At fair value as of December 31, 2012
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	530	$	241	$	6	$	777
SoCalGas (see table below)			1,074		485		13		1,572
Other Sempra Energy
Equity securities:
Domestic(1)			77		―		―		77
Foreign			54		―		―		54
Registered investment companies			2		―		―		2
Fixed income securities:
Domestic municipal bonds			―		3		―		3
Foreign government bonds			―		5		―		5
Domestic corporate bonds(2)			―		37		―		37
Foreign corporate bonds			―		13		―		13
Common/collective trusts(3)			―		2		―		2
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total other Sempra Energy(5)			133		60		2		195
Total Sempra Energy Consolidated(6)		$	1,737	$	786	$	21	$	2,544
-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.
-5	Excludes cash and cash equivalents of $1 million at each of December 31, 2013 and 2012.
-6	Excludes cash and cash equivalents of $17 million and $14 million at December 31, 2013 and 2012, respectively.
FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
		At fair value as of December 31, 2013
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	317	$	―	$	―	$	317
Foreign			211		―		―		211
Foreign preferred			2		―		―		2
Registered investment companies			44		―		―		44
Fixed income securities:
U.S. Treasury securities			2		―		―		2
Domestic municipal bonds			―		11		―		11
Foreign government bonds			―		25		―		25
Domestic corporate bonds(2)			―		152		―		152
Domestic partnership bonds(2)			―		1		―		1
Foreign corporate bonds			―		55		―		55
Common/collective trusts(3)			―		25		―		25
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		6		6
Total investment assets(5)		$	576	$	269	$	6	$	851
		At fair value as of December 31, 2012
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	307	$	―	$	―	$	307
Foreign			215		―		―		215
Foreign preferred			2		―		―		2
Registered investment companies			6		―		―		6
Fixed income securities:
Domestic municipal bonds			―		12		―		12
Foreign government bonds			―		22		―		22
Domestic corporate bonds(2)			―		147		―		147
Foreign corporate bonds			―		52		―		52
Common/collective trusts(3)			―		8		―		8
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		6		6
Total investment assets(6)		$	530	$	241	$	6	$	777
-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.
-5	Excludes cash and cash equivalents of $5 million and transfers payable to other plans of $37 million.
-6	Excludes cash and cash equivalents of $4 million.
FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
		At fair value as of December 31, 2013
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	637	$	―	$	―	$	637
Foreign			423		―		―		423
Foreign preferred			4		―		―		4
Registered investment companies			89		―		―		89
Fixed income securities:
U.S. Treasury securities			4		―		―		4
Domestic municipal bonds			―		21		―		21
Foreign government bonds			―		51		―		51
Domestic corporate bonds(2)			―		306		―		306
Domestic partnership bonds(2)			―		2		―		2
Foreign corporate bonds			―		110		―		110
Common/collective trusts(3)			―		50		―		50
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		13		13
Total investment assets(5)		$	1,157	$	540	$	13	$	1,710
		At fair value as of December 31, 2012
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	622	$	―	$	―	$	622
Foreign			436		―		―		436
Foreign preferred			4		―		―		4
Registered investment companies			12		―		―		12
Fixed income securities:
Domestic municipal bonds			―		24		―		24
Foreign government bonds			―		44		―		44
Domestic corporate bonds(2)			―		297		―		297
Foreign corporate bonds			―		105		―		105
Common/collective trusts(3)			―		15		―		15
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		13		13
Total investment assets(6)		$	1,074	$	485	$	13	$	1,572
-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.
-5	Excludes cash and cash equivalents of $11 million and transfers receivable from other plans of $37 million.
-6	Excludes cash and cash equivalents of $9 million.
The fair values by asset category of the postretirement benefit plan assets held in the pension master trust and in the additional trusts for SoCalGas' postretirement benefit plans and SDG&E's postretirement benefit plan (PBOP plan trusts) are as follows:
FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		At fair value as of December 31, 2013
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	105	$	45	$	1	$	151
SoCalGas (see table below)			256		581		2		839
Other Sempra Energy
Equity securities:
Domestic(1)			4		―		―		4
Foreign			4		―		―		4
Registered investment companies			4		―		―		4
Fixed income securities:
Domestic corporate bonds(2)			―		3		―		3
Foreign government bonds			―		1		―		1
Foreign corporate bonds			―		1		―		1
Registered investment companies			―		1		―		1
Total other Sempra Energy			12		6		―		18
Total Sempra Energy Consolidated(3)		$	373	$	632	$	3	$	1,008
		At fair value as of December 31, 2012
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	87	$	38	$	1	$	126
SoCalGas (see table below)			213		514		2		729
Other Sempra Energy
Equity securities:
Domestic(1)			5		―		―		5
Foreign			1		―		―		1
Foreign preferred			1		―		―		1
Registered investment companies			3		1		―		4
Fixed income securities:
Domestic corporate bonds(2)			―		2		―		2
Foreign government bonds			―		1		―		1
Foreign corporate bonds			―		1		―		1
Total other Sempra Energy			10		5		―		15
Total Sempra Energy Consolidated(4)		$	310	$	557	$	3	$	870
-1	Investments in common stock of domestic corporations.
-2	Bonds of U.S. issuers from diverse industries, primarily investment-grade.
-3	Excludes cash and cash equivalents of $4 million, $3 million and $1 million of which is held in SoCalGas and SDG&E PBOP plan trusts, respectively.
-4	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts.
FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
		At fair value as of December 31, 2013
OTHER POSTRETIREMENT BENEFIT PLAN - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	37	$	―	$	―	$	37
Foreign			25		―		―		25
Registered investment companies			43		―		―		43
Fixed income securities:
Domestic municipal bonds(2)			―		3		―		3
Domestic corporate bonds(3)			―		18		―		18
Foreign government bonds			―		3		―		3
Foreign corporate bonds			―		6		―		6
Common/collective trusts(4)			―		3		―		3
Registered investment companies			―		12		―		12
Other types of investments:
Private equity funds(5) (stated at net asset value)			―		―		1		1
Total investment assets(6)		$	105	$	45	$	1	$	151
		At fair value as of December 31, 2012
OTHER POSTRETIREMENT BENEFIT PLAN - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	32	$	―	$	―	$	32
Foreign			23		―		―		23
Registered investment companies			32		―		―		32
Fixed income securities:
Domestic municipal bonds(2)			―		3		―		3
Domestic corporate bonds(3)			―		15		―		15
Foreign government bonds			―		2		―		2
Foreign corporate bonds			―		5		―		5
Common/collective trusts(4)			―		1		―		1
Registered investment companies			―		12		―		12
Other types of investments:
Private equity funds(5) (stated at net asset value)			―		―		1		1
Total investment assets		$	87	$	38	$	1	$	126
-1	Investments in common stock of domestic corporations.
-2	Bonds of California municipalities held in SDG&E PBOP plan trusts.
-3	Bonds of U.S. issuers from diverse industries, primarily investment-grade.
-4	Investment in common/collective trusts held in PBOP plan VEBA trusts.
-5	Investments in venture capital and real estate funds.
-6	Excludes cash and cash equivalents of $1 million, all of which is held in SDG&E PBOP plan trusts, and transfers payable to other plans of $6 million.
FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
		At fair value as of December 31, 2013
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	128	$	―	$	―	$	128
Foreign			83		―		―		83
Foreign preferred			1		―		―		1
Registered investment companies			43		―		―		43
Broad market funds			―		220		―		220
Fixed income securities:
U.S. Treasury securities			1		―		―		1
Domestic municipal bonds			―		4		―		4
Domestic corporate bonds(2)			―		60		―		60
Foreign government bonds			―		10		―		10
Foreign corporate bonds			―		22		―		22
Common/collective trusts(3)			―		262		―		262
Registered investment companies			―		3		―		3
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total investment assets(5)		$	256	$	581	$	2	$	839
		At fair value as of December 31, 2012
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	118	$	―	$	―	$	118
Foreign			84		―		―		84
Registered investment companies			11		―		―		11
Broad market funds			―		316		―		316
Fixed income securities:
Domestic municipal bonds			―		5		―		5
Domestic corporate bonds(2)			―		57		―		57
Foreign government bonds			―		8		―		8
Foreign corporate bonds			―		20		―		20
Common/collective trusts(3)			―		107		―		107
Registered investment companies			―		1		―		1
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total investment assets(6)		$	213	$	514	$	2	$	729
-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.
-4	Investments in venture capital and real estate funds.
-5	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts, and transfers receivable from other plans of $6 million.
-6	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts.
The investments of the pension master trust allocated to the pension and postretirement benefit plans classified as Level 3 are private equity funds and represent a percentage of each plan's total allocated assets as follows at December 31:
	Private Equity Funds
	2013					2012
(Dollars in millions)	SDG&E	SoCalGas	All Other	Sempra Energy Consolidated		SDG&E	SoCalGas	All Other	Sempra Energy Consolidated
PENSION PLANS
Total Level 3 investment assets	$6	$13	$2	$21		$6	$13	$2	$21
Percentage of total investment assets	1%	1%	1%	1%		1%	1%	1%	1%
OTHER POSTRETIREMENT BENEFIT PLANS
Total Level 3 investment assets	$1	$2	$-	$3		$1	$2	$-	$3
Percentage of total investment assets	1%	-%	-%	-%		1%	-%	-%	-%
The following table provides a reconciliation of changes in the fair value of investments classified as Level 3:
LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Private Equity Funds
		SDG&E		SoCalGas		All Other		Sempra Energy Consolidated
PENSION PLANS
Balance as of January 1, 2012	$	7	$	15	$	2	$	24
Unrealized gains		2		4		―		6
Sales		-3		-6		―		-9
Balance as of December 31, 2012		6		13		2		21
Realized gains		1		2		―		3
Unrealized losses		-1		-1		―		-2
Sales		―		-1		―		-1
Balance as of December 31, 2013	$	6	$	13	$	2	$	21
OTHER POSTRETIREMENT BENEFIT PLANS
Balance as of January 1, 2012	$	1	$	3	$	―	$	4
Sales		―		-1		―		-1
Balance as of December 31, 2012 and 2013	$	1	$	2	$	―	$	3
Derivative Financial Instruments
In accordance with the Sempra Energy pension investment guidelines, derivative financial instruments are used by the pension master trust's equity and fixed income portfolio investment managers. Equity index future contracts are typically used to equitize cash. Foreign currency exchange transactions are used primarily to purchase foreign currency denominated shares or to hedge underlying exposure to foreign currency. Fixed income futures and options may be used as substitutes for certain types of fixed income securities.
Future Payments
We expect to contribute the following amounts to our pension and other postretirement benefit plans in 2014:
	Sempra Energy
(Dollars in millions)	Consolidated		SDG&E		SoCalGas
Pension plans	$	199	$	72	$	85
Other postretirement benefit plans		12		9		―
The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets.
	Sempra Energy Consolidated					SDG&E					SoCalGas
			Other					Other					Other
	Pension		Postretirement			Pension		Postretirement			Pension		Postretirement
(Dollars in millions)	Benefits		Benefits			Benefits		Benefits			Benefits		Benefits
2014	$	390	$	47		$	109	$	8		$	234	$	36
2015		335		52			95		9			202		40
2016		329		55			89		10			199		43
2017		317		60			88		11			194		46
2018		308		64			85		12			188		49
2019-2023		1,305		346			381		65			772		261
PROFIT SHARING PLANS
Under Chilean law, Chilquinta Energía is required to pay all employees either (1) 30 percent of Chilquinta Energía's taxable income after deducting a 10 percent return on equity, allocated in proportion to the annual salary of each employee or (2) 25 percent of each employee's annual salary, with a maximum mandatory profit sharing of 4.75 months of Chile's legal minimum salary. Chilquinta Energía has elected the second option but calculates the profit sharing amounts with actual employee salaries instead of the legal minimum salary, resulting in a higher cost. The amounts are paid out each pay period. Chilquinta Energía recorded annual profit sharing expense of $4 million for 2013, $6 million for 2012 and $5 million for 2011 related to this plan.
Under Peruvian law, Luz del Sur is required to pay their employees 5 percent of Luz del Sur's taxable income, paid once a year and allocated as follows: 50 percent based on each employee's annual hours worked and 50 percent based on each employee's annual salary. Luz del Sur recorded annual profit sharing expense of $9 million for 2013, $10 million for 2012 and $9 million for 2011 related to this plan.
SAVINGS PLANS
Sempra Energy offers trusteed savings plans to all domestic employees. Participation in the plans is immediate for salary deferrals for all employees except for the represented employees at SoCalGas, who are eligible upon completion of one year of service. Subject to plan provisions, employees may contribute from one percent to 50 percent of their regular earnings, subject to annual IRS limits, when they begin employment. After one year of the employee's completed service, Sempra Energy makes matching contributions. Employer contribution amounts and methodology vary by plan, but generally the contributions are equal to 50 percent of the first 6 percent of eligible base salary contributed by employees and, if certain company goals are met, an additional amount related to incentive compensation payments.
Beginning September 1, 2012 for the Sempra Energy, SDG&E and Mobile Gas savings plans and October 1, 2012 for the SoCalGas savings plan, employer contributions are invested based upon each employee's investment elections in effect at the time of contribution. Prior to that, employer contributions were initially invested in Sempra Energy common stock, but the employee could transfer the contribution to other investments. Contributions are invested in Sempra Energy common stock, mutual funds and/or institutional trusts. Prior to the termination of the ESOP discussed below, employer contributions for substantially all plans were partially funded by the ESOP.
Contributions to the savings plans were as follows:
(Dollars in millions)	2013		2012		2011
Sempra Energy Consolidated	$	35	$	34	$	32
SDG&E		14		16		14
SoCalGas		17		15		14
The market value of Sempra Energy common stock held by the savings plans was $1.3 billion and $1.1 billion at December 31, 2013 and 2012, respectively.
Employee Stock Ownership Plan (ESOP)
Sempra Energy terminated the ESOP effective June 30, 2012, as all ESOP debt was paid and all shares were released from the ESOP Trust as of that date. Prior to the plan's termination all contributions to the ESOP Trust (Trust) were made by Sempra Energy; there were no contributions made by the participants. The Trust was used to fund part of the retirement savings plan described above. As Sempra Energy made contributions, the ESOP debt service was paid and shares were released in proportion to the total expected debt service. We charged compensation expense and credited equity for the market value of the released shares. Dividends on unallocated shares were used to pay debt service and were applied against the liability. The shares held by the Trust were unallocated and consisted of 0.2 million shares of Sempra Energy common stock with a fair value of $8 million at December 31, 2011.
ESOP debt was paid down by a total of $34 million in 2012 and 2011 when 504,440 shares of Sempra Energy common stock were released from the Trust in order to fund employer contributions to the Sempra Energy savings plan trust. Interest on the ESOP debt was a negligible amount in each of 2012 and 2011. Dividends used for debt service consisted of a negligible amount in 2012 and $1 million in 2011.

SHAREBASED_COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2013
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
	incentive stock options
	restricted stock
	restricted stock units
	stock appreciation rights
	performance awards
	stock payments
	dividend equivalents
	Eligible California Utilities employees participate in Sempra Energy's share-based compensation plans as a component of their compensation package.
	In May 2013, shareholders approved the Sempra Energy 2013 Long-Term Incentive Plan (the 2013 Plan). Upon approval, the remaining authorized shares from the Sempra Energy 2008 Long Term Incentive Plan and the 2008 Long 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, 2013, 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 exercise may be accelerated upon a change in control, in accordance with severance pay agreements or upon eligibility for retirement. Options are subject to forfeiture or earlier expiration when an employee terminates employment.
	Performance-Based Restricted Stock Units: These restricted stock unit awards vest in Sempra Energy common stock at the end of four-year performance periods based on Sempra Energy's total return to shareholders relative to that of market indices. If Sempra Energy's total return to shareholders exceeds the target levels established under the 2008 Long Term Incentive Plan for awards granted beginning in 2008 and under the 2013 Long-Term Incentive Plan beginning in May 2013, up to an additional 50 percent of the number of granted restricted stock units may be issued. If Sempra Energy's total return to shareholders is below the target levels, shares are subject to partial vesting on a pro rata basis. Restricted stock units may also be solely service-based; these 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. 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 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, 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.
	Restricted Stock: Prior to 2009, substantially all restricted stock awards were performance-based and vested at the end of four-year performance periods based on Sempra Energy's total return to shareholders relative to that of market indices. Since 2009, restricted stock awards have been 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 stock 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 Incentive 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 based on the fair market value of the awards, based on IEnova's common stock value, upon vesting. In 2013, IEnova issued 1,014,899 restricted stock units from this plan, all of which remain outstanding at December 31, 2013.
	SHARE-BASED AWARDS AND COMPENSATION EXPENSE
	We 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 basis over the requisite service period of the award, which is generally 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. Substantially 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, 2013, 7,210,346 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,
		2013		2012		2011
	Share-based compensation expense, before income taxes	$	38	$	40	$	44
	Income tax benefit		-15		-16		-18
	Share-based compensation expense, net of income taxes	$	23	$	24	$	26
	Net share-based compensation expense, per common share
	Basic	$	0.09	$	0.1	$	0.11
	Diluted	$	0.09	$	0.1	$	0.11
	Sempra Energy Consolidated's capitalized compensation cost was $4 million in each of 2013, 2012 and 2011.
	We classify the tax benefits resulting from tax deductions in excess of the tax benefit related to compensation cost recognized for stock option exercises as financing cash flows.
	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' corporate staff costs. Expenses and capitalized compensation costs recorded by SDG&E and SoCalGas were as follows:
	SHARE-BASED COMPENSATION EXPENSE ― SDG&E AND SOCALGAS
	(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
	SDG&E:
	Compensation expense	$	8	$	8	$	8
	Capitalized compensation cost		3		3		3
	SoCalGas:
	Compensation expense	$	8	$	7	$	9
	Capitalized compensation cost		1		1		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-termination 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 2013, 2012 or 2011.
	The following table shows a summary of non-qualified stock options as of December 31, 2013 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 December 31, 2012		2,701,118	$	51.86
	Exercised		-1,237,348	$	50.32
	Forfeited/canceled		-4,625	$	48.4
	Outstanding at December 31, 2013		1,459,145	$	53.18		4	$	53
	Vested or expected to vest, at December 31, 2013		1,459,145	$	53.18		4	$	53
	Exercisable at December 31, 2013		1,300,745	$	52.86		3.8	$	48
	The aggregate intrinsic value at December 31, 2013 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
$41 million in 2013
$45 million in 2012
$23 million in 2011
The total fair value of shares vested in the last three years was
$2 million in 2013
$4 million in 2012
$7 million in 2011
Total compensation cost related to nonvested stock options not yet recognized as of December 31, 2013 was negligible.
We received cash from option exercises during 2013 totaling $62 million. There were no realized tax benefits for the share-based payment award deductions in 2013 over and above the $15 million income tax benefit shown above.
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 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 2013, 2012 and 2011 for Sempra Energy:
	2013		2012		2011
Risk-free rate of return	0.60%		0.60%		1.50%
Annual dividend yield	3.30%		3.40%		3.00%
Stock price volatility	19%		27%		27%
Restricted Stock Awards
We provide below a summary of Sempra Energy's restricted stock awards as of December 31, 2013 and the activity during the year.
RESTRICTED STOCK AWARDS
			Weighted-
			Average
			Grant-Date
	Shares		Fair Value
Nonvested at December 31, 2012		24,689	$	56.59
Granted		4,617	$	75.82
Vested		-11,837	$	55.49
Nonvested at December 31, 2013		17,469	$	62.43
Vested or expected to vest, at December 31, 2013		17,469	$	62.43
Total compensation cost of $1 million related to nonvested restricted stock awards not yet recognized as of December 31, 2013 is expected to be recognized over a weighted average period of 1.5 years. The weighted-average per-share fair value for restricted stock awards granted was $57.81 in 2012 and $52.96 in 2011.
The total fair value of shares vested in the last three years was
$1 million in 2013
$1 million in 2012
$28 million in 2011
Restricted Stock Units
We provide below a summary of Sempra Energy's restricted stock units as of December 31, 2013 and the activity during the year.
RESTRICTED STOCK UNITS
		Performance-Based				Service-Based
		Restricted Stock Units				Restricted Stock Units
			Weighted-				Weighted-
			Average				Average
			Grant-Date				Grant-Date
		Units	Fair Value			Units	Fair Value
Nonvested at December 31, 2012		3,400,033	$	42.72		135,241	$	55.42
Granted		657,168	$	57.55		107,718	$	72.71
Vested		-864,100	$	36.04		-24,751	$	61.97
Forfeited		-28,540	$	50.55		-2,610	$	56.23
Nonvested at December 31, 2013(1)		3,164,561	$	47.55		215,598	$	63.3
Vested or expected to vest, at December 31, 2013		3,107,020	$	47.45		203,655	$	63.12
-1	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, up to an additional 50 percent of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.
The total fair value of shares vested in 2013 was $33 million.
The $29 million of total compensation cost related to nonvested restricted stock units not yet recognized as of December 31, 2013 is expected to be recognized over a weighted-average period of 2.4 years. The weighted-average per-share fair values for restricted stock units granted were $50.17 in 2012 and $42.35 in 2011.

DERIVATIVE_FINANCIAL_INSTRUMEN

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2013
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 and benchmark interest rate risk. We may also manage foreign exchange rate exposures using derivatives. 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 in 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 revenues, expenses, assets or liabilities that are not presented below.
	We record all 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) undesignated. 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 (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 Statements of Cash Flows.
	In certain cases, we apply the normal purchase or sale exception to derivative accounting 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.
	HEDGE ACCOUNTING
	We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting 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 offsetting the risk that a given future 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 rate 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 locations 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.
	The California Utilities use natural gas energy derivatives, on their customers' behalf, with the objective of managing price risk and basis risks, and lowering natural gas costs. These derivatives include fixed price natural gas positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas 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 Consolidated 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 are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, 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 natural 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 of 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, 2013 and 2012 as follows:
				December 31,
	Segment and Commodity			2013	2012
	California Utilities:
	SDG&E:
		Natural gas		43 million MMBtu	25 million MMBtu	-1
		Congestion revenue rights		33 million MWh	30 million MWh	-2
	SoCalGas - natural gas			2 million MMBtu	―
	Energy-Related Businesses:
	Sempra Natural Gas:
	Electric power			1 million MWh	1 million MWh
	Natural gas			15 million MMBtu	36 million MMBtu
	Sempra Mexico - natural gas			―	1 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 physical locations of our assets and other contractual obligations, 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 utilize 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 in 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. 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 natural gas derivatives. Accordingly, interest rate derivatives are generally accounted for as hedges at the California Utilities, as well as at the rest of Sempra Energy's subsidiaries. Separately, Otay Mesa VIE has entered into interest rate swap agreements to moderate its exposure to interest rate changes. This activity was designated as a cash flow hedge as of April 1, 2011.
	At December 31, 2013 and 2012, the net notional amounts of our interest rate derivatives, excluding the cross-currency swaps discussed below, were:
			31-Dec-13			31-Dec-12
	(Dollars in millions)		Notional Debt		Maturities	Notional Debt		Maturities
	Sempra Energy Consolidated
		Cash flow hedges(1)	$	413	2014-2028	$	439	2013-2028
		Fair value hedges		300	2016		500	2013-2016
	SDG&E
		Cash flow hedge(1)		335	2019		345	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. From time to time, we may utilize short-term foreign 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 may also utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries. On February 14, 2013, Sempra Mexico entered into cross-currency swap agreements, which were designated as cash flow hedges. We discuss the notional amount of the swaps in Note 5.
	In addition, Sempra South American Utilities may utilize foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. We 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 management believes a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Consolidated Balance Sheets at December 31, 2013 and 2012, 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)
			31-Dec-13
										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)		$	14	$	12	$	-18	$	-75
	Derivatives not designated as hedging instruments:
	Interest rate and foreign exchange instruments			8		22		-7		-17
	Commodity contracts not subject to rate recovery			47		7		-51		-5
Associated offsetting commodity contracts			-43		-5		43		5
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			35		72		-10		-8
Associated offsetting commodity contracts			-3		-2		3		2
Net amounts presented on the balance sheet			58		106		-39		-98
Additional cash collateral for commodity contracts
not subject to rate recovery			17		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			31		―		―		―
Total		$	106	$	106	$	-39	$	-98
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	-16	$	-39
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery			34		72		-9		-8
Associated offsetting commodity contracts			-3		-2		3		2
Net amounts presented on the balance sheet			31		70		-22		-45
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			29		―		―		―
Total		$	61	$	70	$	-22	$	-45
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery		$	1	$	―	$	-1	$	―
Net amounts presented on the balance sheet			1		―		-1		―
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			2		―		―		―
Total		$	5	$	―	$	-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.
DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		31-Dec-12
									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 instruments(3)		$	7	$	12	$	-19	$	-64
Commodity contracts not subject to rate recovery			1		―		―		―
Derivatives not designated as hedging instruments:
Interest rate instruments			8		40		-8		-35
Commodity contracts not subject to rate recovery			117		15		-116		-27
Associated offsetting commodity contracts			-102		-12		102		12
Associated offsetting cash collateral			―		―		4		7
Commodity contracts subject to rate recovery			30		35		-35		-1
Associated offsetting commodity contracts			-4		―		4		―
Associated offsetting cash collateral			―		―		22		1
Net amounts presented on the balance sheet			57		90		-46		-107
Additional cash collateral for commodity contracts
not subject to rate recovery			22		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			13		―		―		―
Total		$	92	$	90	$	-46	$	-107
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	-17	$	-64
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery			28		35		-33		-1
Associated offsetting commodity contracts			-3		―		3		―
Associated offsetting cash collateral			―		―		22		1
Net amounts presented on the balance sheet			25		35		-25		-64
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			12		―		―		―
Total		$	38	$	35	$	-25	$	-64
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery		$	2	$	―	$	-2	$	―
Associated offsetting commodity contracts			-1		―		1		―
Net amounts presented on the balance sheet			1		―		-1		―
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			1		―		―		―
Total		$	4	$	―	$	-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.
The effects of derivative instruments designated as hedges on the Consolidated Statements of Operations and on Other Comprehensive Income (OCI) and Accumulated Other Comprehensive Income (AOCI) for the years ended December 31 were:
FAIR VALUE HEDGE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
			Gain (loss) on derivatives recognized in earnings
			Years ended December 31,
		Location	2013		2012		2011
Sempra Energy Consolidated:
	Interest rate instruments	Interest Expense	$	8	$	6	$	9
	Interest rate instruments	Other Income, Net		-7		3		13
	Total(1)		$	1	$	9	$	22
SoCalGas:
	Interest rate instrument	Interest Expense	$	―	$	―	$	1
	Interest rate instrument	Other Income, Net		―		―		-3
	Total(1)		$	―	$	―	$	-2
-1	There has been no hedge ineffectiveness on these swaps. Changes in the fair values of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt.
CASH FLOW HEDGE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
		Pretax gain (loss) recognized in OCI							Gain (loss) reclassified from AOCI into earnings
		(effective portion)							(effective portion)
		Years ended December 31,							Years ended December 31,
			2013		2012		2011	Location		2013		2012		2011
Sempra Energy Consolidated:
	Interest rate and foreign
	exchange instruments(1)	$	1	$	-22	$	-42	Interest Expense	$	-11	$	-9	$	-8
								Equity Earnings (Losses),
	Interest rate instruments		15		-10		-32	Before Income Tax		-10		-6		-5
	Commodity contracts not							Cost of Natural Gas, Electric
	subject to rate recovery		-4		-1		―	Fuel and Purchased Power		1		―		―
	Total	$	12	$	-33	$	-74		$	-20	$	-15	$	-13
SDG&E:
	Interest rate instruments(1)	$	8	$	-16	$	-40	Interest Expense	$	-9	$	-5	$	-5
SoCalGas:
	Interest rate instrument	$	―	$	―	$	―	Interest Expense	$	-1	$	-2	$	-3
-1	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. There was a negligible amount of ineffectiveness related to these swaps.
For Sempra Energy Consolidated we expect that losses of $23 million, which are net of income tax benefit, that are currently recorded in AOCI (including $12 million in noncontrolling interests) 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 derivative contracts that are currently outstanding mature. The Sempra Energy Consolidated amount includes $11 million at SDG&E in noncontrolling interest related to Otay Mesa VIE.
SoCalGas expects that losses of $1 million, 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 months 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, 2013 is approximately 15 years and 5 years for Sempra Energy and SDG&E, respectively. The maximum term of hedged interest rate variability related to debt at Sempra Renewables' equity method investees is 22 years.
We recorded $1 million of hedge ineffectiveness in 2013, $2 million of hedge ineffectiveness in 2012 and negligible hedge ineffectiveness in 2011.
The effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations for the years ended December 31 were:
UNDESIGNATED DERIVATIVE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
			Gain (loss) on derivatives recognized in earnings
			Years ended December 31,
		Location	2013		2012		2011
Sempra Energy Consolidated:
	Interest rate and foreign
	exchange instruments(1)	Other Income, Net	$	17	$	10	$	-14
	Foreign exchange instruments	Equity Earnings, Net of Income Tax		-4		―		―
	Commodity contracts not subject	Revenues: Energy-Related
	to rate recovery	Businesses		-1		7		30
	Commodity contracts not subject	Cost of Natural Gas, Electric
	to rate recovery	Fuel and Purchased Power		―		―		1
	Commodity contracts not subject
	to rate recovery	Other Operation and Maintenance		1		1		1
	Commodity contracts subject	Cost of Electric Fuel
	to rate recovery	and Purchased Power		53		69		-14
	Commodity contracts subject
	to rate recovery	Cost of Natural Gas		―		-2		-2
	Total		$	66	$	85	$	2
SDG&E:
	Interest rate instruments(1)	Other Income, Net	$	―	$	―	$	-1
	Commodity contracts subject	Cost of Electric Fuel
	to rate recovery	and Purchased Power		53		69		-14
	Total		$	53	$	69	$	-15
SoCalGas:
	Commodity contracts not subject
	to rate recovery	Operation and Maintenance	$	1	$	1	$	1
	Commodity contracts subject
	to rate recovery	Cost of Natural Gas		―		-2		-2
	Total		$	1	$	-1	$	-1
-1	Amount for 2011 is related to Otay Mesa VIE. Sempra Energy Consolidated also includes additional instruments.
CONTINGENT FEATURES
For Sempra Energy and SDG&E, certain of our derivative instruments contain credit limits which vary depending upon 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 derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization.
For Sempra Energy, the total fair value of this group of derivative instruments in a net liability position at December 31, 2013 and 2012 is $3 million and $8 million, respectively. At December 31, 2013, if the credit ratings of Sempra Energy were reduced below investment grade, $3 million of additional assets could be required to be posted as collateral for these derivative contracts.
For SDG&E, the total fair value of this group of derivative instruments in a net liability position at December 31, 2013 and 2012 is $3 million and $6 million, respectively. At December 31, 2013, if the credit ratings of SDG&E were reduced below investment grade, $3 million of additional assets could be required to be posted as collateral for these derivative contracts.
For Sempra Energy, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain 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, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Fair Value Measurements	'
	NOTE 10. FAIR 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 as of December 31, 2013 and 2012. 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 valuation 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 “Financial 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 deposits, 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, 2013 and 2012 in the tables below include the following:
	Nuclear decommissioning trusts reflect 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 independent 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). Other debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2).
	We enter into commodity contracts and interest rate derivatives primarily as a means to manage price exposures. We may also manage foreign exchange rate exposures using derivatives. 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 corroborated, 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 models 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). All Level 3 recurring items are related to CRRs at SDG&E, as we discuss below under “Level 3 Information.” We record commodity derivative contracts that are subject to rate recovery as commodity costs that are offset by regulatory account balances and are recovered in rates.
	Investments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1).
	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 presented, nor any changes in valuation techniques used in recurring fair value measurements.
	RECURRING FAIR VALUE MEASURES ― SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
			At fair value as of December 31, 2013
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts
	Equity securities		$	614	$	―	$	―	$	―	$	614
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			59		58		―		―		117
	Municipal bonds			―		111		―		―		111
	Other securities			―		153		―		―		153
	Total debt securities			59		322		―		―		381
	Total nuclear decommissioning trusts(2)			673		322		―		―		995
	Interest rate instruments			―		56		―		―		56
	Commodity contracts subject to rate recovery			2		1		99		31		133
	Commodity contracts not subject to rate recovery			1		5		―		17		23
	Total		$	676	$	384	$	99	$	48	$	1,207
	Liabilities:
	Interest rate and foreign exchange instruments		$	―	$	117	$	―	$	―	$	117
	Commodity contracts subject to rate recovery			―		13		―		―		13
	Commodity contracts not subject to rate recovery			4		8		―		-5		7
	Total		$	4	$	138	$	―	$	-5	$	137
			At fair value as of December 31, 2012
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts
	Equity securities		$	539	$	―	$	―	$	―	$	539
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			87		69		―		―		156
	Municipal bonds			―		63		―		―		63
	Other securities			―		130		―		―		130
	Total debt securities			87		262		―		―		349
	Total nuclear decommissioning trusts(2)			626		262		―		―		888
	Interest rate instruments			―		68		―		―		68
	Commodity contracts subject to rate recovery			―		―		61		13		74
	Commodity contracts not subject to rate recovery			13		8		―		22		43
	Investments			1		―		―		―		1
	Total		$	640	$	338	$	61	$	35	$	1,074
	Liabilities:
	Interest rate instruments		$	―	$	126	$	―	$	―	$	126
	Commodity contracts subject to rate recovery			23		9		―		-23		9
	Commodity contracts not subject to rate recovery			6		23		―		-11		18
	Total		$	29	$	158	$	―	$	-34	$	153
	-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)
			At fair value as of December 31, 2013
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts
Equity securities		$	614	$	―	$	―	$	―	$	614
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			59		58		―		―		117
Municipal bonds			―		111		―		―		111
Other securities			―		153		―		―		153
Total debt securities			59		322		―		―		381
Total nuclear decommissioning trusts(2)			673		322		―		―		995
Commodity contracts subject to rate recovery			1		1		99		29		130
Commodity contracts not subject to rate recovery			―		―		―		1		1
Total		$	674	$	323	$	99	$	30	$	1,126
Liabilities:
Interest rate instruments		$	―	$	55	$	―	$	―	$	55
Commodity contracts subject to rate recovery			―		12		―		―		12
Total		$	―	$	67	$	―	$	―	$	67
		At fair value as of December 31, 2012
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts
Equity securities		$	539	$	―	$	―	$	―	$	539
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			87		69		―		―		156
Municipal bonds			―		63		―		―		63
Other securities			―		130		―		―		130
Total debt securities			87		262		―		―		349
Total nuclear decommissioning trusts(2)			626		262		―		―		888
Commodity contracts subject to rate recovery			―		―		61		12		73
Commodity contracts not subject to rate recovery			―		―		―		1		1
Total		$	626	$	262	$	61	$	13	$	962
Liabilities:
Interest rate instruments		$	―	$	81	$	―	$	―	$	81
Commodity contracts subject to rate recovery			23		8		―		-23		8
Total		$	23	$	89	$	―	$	-23	$	89
-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)
		At fair value as of December 31, 2013
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	1	$	―	$	―	$	2	$	3
Commodity contracts not subject to rate recovery			―		―		―		2		2
Total		$	1	$	―	$	―	$	4	$	5
Liabilities:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	―	$	1
Total		$	―	$	1	$	―	$	―	$	1
		At fair value as of December 31, 2012
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	―	$	―	$	―	$	1	$	1
Commodity contracts not subject to rate recovery			1		―		―		2		3
Total		$	1	$	―	$	―	$	3	$	4
Liabilities:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	―	$	1
Total		$	―	$	1	$	―	$	―	$	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 CRRs 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,
	2013		2012		2011
Balance as of January 1	$	61	$	23	$	2
Realized and unrealized gains		11		31		32
Allocated transmission instruments		51		58		7
Settlements		-24		-51		-18
Balance as of December 31	$	99	$	61	$	23
Change in unrealized gains or losses relating to
instruments still held at December 31	$	11	$	17	$	17
SDG&E's Energy and Fuel Procurement department, in conjunction with SDG&E's finance group, is responsible for determining the appropriate fair value methodologies used to value and classify CRRs on an ongoing basis. Inputs used to determine the fair value of CRRs are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to CRRs 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 prices published by the California Independent System Operator (ISO), an objective source. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. At December 31, 2013, the auction prices ranged from $(6) per MWh to $12 per MWh at a given location, and the fair value of these instruments is derived from auction price differences between two locations. At December 31, 2012, the auction prices ranged from $(11) per MWh to $12 per MWh. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two 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. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, 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 management believes 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 at December 31, 2013 and 2012:
	December 31,
(Dollars in millions)	2013		2012
Sempra Energy Consolidated	$	48	$	35
SDG&E		30		13
SoCalGas		4		3
Fair Value of Financial Instruments
The fair values of certain of our financial instruments (cash, temporary investments, accounts and notes receivable, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments at December 31:
FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
		31-Dec-13
		Carrying			Fair Value
		Amount			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Total long-term debt(1)		$	12,022		$	―	$	11,925	$	751	$	12,676
Preferred stock of subsidiary			20			―		20		―		20
SDG&E:
Total long-term debt(2)		$	4,386		$	―	$	4,226	$	335	$	4,561
SoCalGas:
Total long-term debt(3)		$	1,413		$	―	$	1,469	$	―	$	1,469
Preferred stock			22			―		22		―		22
		31-Dec-12
		Carrying			Fair Value
		Amount			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Investments in affordable housing partnerships(4)		$	12		$	―	$	―	$	36	$	36
Total long-term debt(1)			11,873			―		12,287		956		13,243
Preferred stock of subsidiaries			99			―		107		―		107
SDG&E:
Total long-term debt(2)		$	4,135		$	―	$	4,243	$	345	$	4,588
Contingently redeemable preferred stock(5)			79			―		85		―		85
SoCalGas:
Total long-term debt(3)		$	1,413		$	―	$	1,599	$	―	$	1,599
Preferred stock			22			―		24		―		24
-1	Before reductions for unamortized discount (net of premium) of $17 million and $16 million at December 31, 2013 and 2012, respectively, and excluding build-to-suit and capital leases of $195 million and capital leases of $189 million at December 31, 2013 and 2012, respectively, and commercial paper classified as long-term debt of $200 million and $300 million at December 31, 2013 and 2012, respectively. We discuss our long-term debt in Note 5.
-2	Before reductions for unamortized discount of $11 million and $12 million at December 31, 2013 and 2012, respectively, and excluding capital leases of $179 million and $185 million at December 31, 2013, respectively.
-3	Before reductions for unamortized discount of $4 million at both December 31, 2013 and 2012 and excluding capital leases of $2 million and $4 million at December 31, 2013 and 2012, respectively.
-4	Investments in affordable housing partnerships at Parent and Other. At December 31, 2013, the carrying amount and fair value of these investments were negligible.
-5	On October 15, 2013, SDG&E redeemed all outstanding shares of its contingently redeemable preferred stock for $82 million. We discuss the redemption in Note 11.
We base the fair value of certain 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 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 calculate the fair value of our investments in affordable housing partnerships using an income approach based on the present value of estimated future cash flows discounted at rates available for similar investments (Level 3).
Non-Recurring Fair Value Measures – Sempra Energy Consolidated
We discuss non-recurring fair value measures and the associated accounting impact on our investments in Rockies Express and RBS Sempra Commodities in Note 4.
Rockies Express
In 2012, we recorded a $400 million pretax impairment of our investment in Rockies Express. In the second quarter of 2012, the noncash impairment charge of $300 million ($179 million after-tax) primarily resulted from the continuing decline in basis differential associated with shale gas production zones coming on line, assumptions related to the re-contracting of the long-term transportation agreements, and the refinancing of the existing project level debt, discussed further below. The fair value measurement was significantly impacted by unobservable inputs (Level 3) as defined by the accounting guidance for fair value measurements, which we discuss in Note 1 under “Fair Value Measurements.” We considered a market participant's view of the total value for Rockies Express, based on an estimation of the future cash distributions it would be able to generate, adjusted for our 25-percent ownership interest. To estimate future cash distributions, we considered factors impacting Rockies Express' ability to pay future distributions including:
the extent to which future cash flows are hedged by capacity sales contracts and their duration (generally through 2019), as well as the creditworthiness of the various counterparties;
Rockies Express' future financing needs, including the ability to secure borrowings at reasonable rates as well as potentially using operating cash to retire principal;
prospects for generating attractive revenues and cash flows beyond 2019, including natural gas' future basis differentials (driven by the location and extent of future supply and demand) and alternative strategies potentially available to utilize the assets; and
discount rates commensurate with the risks inherent in the cash flows.
In the third quarter of 2012, KMI reached an agreement with Tallgrass, which closed in the fourth quarter of 2012, to sell its asset group as mandated by the FTC, which group included its interest in Rockies Express. Events in the third quarter of 2012 related to this agreement also provided us with additional market participant data. We therefore updated our analysis of the fair value of our investment in Rockies Express as of September 30, 2012 to reflect these additional inputs and recorded an additional impairment charge of $100 million ($60 million after-tax). This fair value measurement in the third quarter was based primarily on the Level 2 input. We believe this is useful and reliable information, but we considered that it may be impacted by the FTC's requirement for KMI to sell its interest in Rockies Express. To reflect this uncertainty, our updated analysis included the less subjective Level 2 market participant input as the primary indicator of fair value, with less weight ascribed to value based on estimated discounted cash flows as discussed above and in the table below. The updates to the cash flow analysis used in determining fair value in the second quarter reflected discussions with Tallgrass as to the strategic direction they are planning to take with their equity partners for Rockies Express, as well as additional discussions with other market participants. Tallgrass became the operator of Rockies Express in November 2012.
We believe our analysis forms a reasonable estimate of the fair value of Rockies Express. This estimate includes the material input described above, which was generally observable during the period most relevant to our analysis. Regarding the unobservable inputs, significant uncertainties exist with regard to REX's ability to secure attractive revenues beyond 2019. Accordingly, our analysis suggests that the fair value of our investment in Rockies Express could be materially different from the value we have estimated at this time. For example, if REX is able to sustain the level of revenues currently generated beyond 2019, the value of our investment in Rockies Express would be materially enhanced and the indicated value of our investment in Rockies Express could be significantly higher. Conversely, if REX is unable to sell its transport capacity at sufficient rates or in sufficient volumes beyond 2019, the fair value of our investment in Rockies Express could be materially lower than our carrying amount. Separately, future events involving REX equity could occur and may also provide additional information regarding the fair value of our investment in REX.
Sempra Natural Gas developed the models and scenarios used to measure the fair value of our investment in REX. This modeling used inputs from external sources as described above and in the table below, as well as internally available data, such as operating and maintenance budgets used for financial planning purposes. External experts that forecast the future price of natural gas at various physical locations were also engaged to help validate certain scenarios and modeling assumptions. The fair value measurements were reviewed in detail by Sempra Natural Gas' financial management, as well as Sempra Energy's financial management team.
RBS Sempra Commodities
Parent and Other recorded an impairment charge of $16 million in 2011 to reduce the carrying value of our investment in RBS Sempra Commodities, which we discuss in Note 4. This impairment resulted from an adjustment to the carrying value of our investment in the partnership at the reporting date. We recorded the $16 million charge ($10 million after-tax) to reduce our investment in the partnership to reflect the estimates of our expected future cash distributions from the partnership at that time, which had been impacted by additional amounts incurred to conclude the sales of the partnership's businesses. In 2011, the fair value of our investment in RBS Sempra Commodities was significantly impacted by unobservable inputs (i.e. Level 3 inputs) as defined by the accounting guidance for fair value measurements and described in the table below. The inputs included estimated future cash distributions expected from the partnership, excluding the impact of costs anticipated for transactions that had not closed at the time of fair value measurement.
The following table summarizes significant inputs impacting non-recurring fair value measures related to our investments in REX and RBS Sempra Commodities:
NON-RECURRING FAIR VALUE MEASURES ― SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
					% of
		Estimated		Fair	Fair Value
		Fair		Value	Measure-		Range of
		Value	Valuation Technique	Hierarchy	ment	Inputs Used to Develop Measurement	Inputs
Investment in
Rockies Express		$369(1)	Market approach	Level 2	67%	Equity sale offer price	100%
			Probability weighted	Level 3	33%	Combined transportation rate assumption(2)	6% - 78%
			discounted cash flow			Counterparty credit risk on existing contracts	Low
						Operation and maintenance escalation rate	0% - 1%
						Forecasted interest rate on debt to be refinanced	5% - 10%
						Discount rate	8% - 10%
Investment in
RBS Sempra
Commodities		$126(3)	Discounted cash flow	Level 3	100%	Future cash distributions	90% - 110%
-1	At measurement date of September 30, 2012. At December 31, 2013, our investment in Rockies Express had a carrying value of $329 million, reflecting subsequent equity method activity to record distributions and earnings.
-2	Transportation rate beyond existing contract terms as a percentage of current mean REX rates.
-3	At measurement date of September 30, 2011. At December 31, 2013, our investment in RBS Sempra Commodities had a carrying value of $73 million, reflecting subsequent equity method activity to record distributions and losses.

PREFERRED_STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Preferred Stock	'
	NOTE 11. PREFERRED STOCK
	The table below shows the details of preferred stock for SDG&E and SoCalGas. All series of Pacific Enterprises (PE) preferred stock were redeemed during 2011 and all series of SDG&E preferred stock were redeemed during 2013 as we discuss below.
	PREFERRED STOCK
				Final Call/
				Redemption	December 31,
				Price	2013		2012
					(in millions)
	Contingently redeemable:
		SDG&E:
		$20 par value, authorized 1,375,000 shares(1):
		5% Series, 375,000 shares outstanding	$	24	$	―	$	8
		4.5% Series, 300,000 shares outstanding	$	21.2		―		6
		4.4% Series, 325,000 shares outstanding	$	21		―		7
		4.6% Series, 373,770 shares outstanding	$	20.25		―		7
		Without par value(1):
		$1.70 Series, 1,400,000 shares outstanding	$	25		―		35
		$1.82 Series, 640,000 shares outstanding	$	26		―		16
		SDG&E - Total contingently redeemable preferred stock				―		79
		Sempra Energy - Total contingently redeemable preferred
		stock of subsidiary			$	―	$	79
	SoCalGas:
	$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 PE					-2		-2
						20		20
		Sempra Energy - Total preferred stock of subsidiary			$	20	$	20
	-1	Represents shares outstanding at December 31, 2012, which were fully redeemed in October 2013.
	Following are the attributes of each company's preferred stock. No amounts currently outstanding are subject to mandatory redemption.
	SDG&E
	On October 15, 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 redeemed shares are no longer outstanding and represent only the right to receive the applicable redemption prices (including accrued and accumulated dividends through October 15, 2013), without interest, upon surrender of the share certificates.
	SDG&E is currently authorized to issue up to 25 million shares of an additional class of preference shares designated as “Series Preference Stock.” The stock's rights, preferences and privileges would be established by the board of directors at the time of issuance.
	SOCALGAS
	None of SoCalGas' outstanding preferred stock is callable.
	All outstanding series have one vote per share, cumulative preferences as to dividends and liquidation preferences of $25 per share 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 preferences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock. Other rights and privileges of the stock would be established by the board of directors at the time of issuance.
	PACIFIC ENTERPRISES
	On June 30, 2011, PE redeemed all five series of its outstanding preferred stock for $81 million. Each series was redeemed for cash at redemption prices ranging from $100 to $101.50 per share, plus accrued dividends up to the redemption date of an aggregate of $1 million. The redeemed shares are no longer outstanding and represent only the right to receive the applicable redemption price, to the extent that shares have not yet been presented for payment.
	PE currently is authorized to issue 10 million shares of series preferred stock and 5 million shares of Class A series preferred stock, both without par value and with cumulative preferences as to dividends and liquidation value. No shares of preferred stock or Class A series preferred stock are outstanding. Class A series preferred stock, when issued, would rank junior to all other series of preferred stock with respect to dividends and liquidation value. Other rights and privileges of each series of the preferred stock and Class A series preferred 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, 2013
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. Basic earnings per common share (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,
		2013		2012		2011
	Numerator:
	Earnings/Income attributable to common shareholders	$	1,001	$	859	$	1,331
	Denominator:
	Weighted-average common shares outstanding for basic EPS		243,863		241,347		239,720
	Dilutive effect of stock options, restricted stock awards and
	restricted stock units		5,469		5,346		1,803
	Weighted-average common shares outstanding for diluted EPS		249,332		246,693		241,523
	Earnings per share:
	Basic	$	4.1	$	3.56	$	5.55
	Diluted	$	4.01	$	3.48	$	5.51
	Dividends declared per share of common stock	$	2.52	$	2.4	$	1.92
	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 compensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation 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). We had no such antidilutive stock options outstanding during 2013 and 40,000 and 2,083,275 outstanding during 2012 and 2011, respectively.
	During 2013 and 2012, we had no stock options outstanding that were antidilutive because of the unearned compensation and windfall tax benefits recognized included in the assumed proceeds under the treasury stock method. We had 900 such antidilutive stock options outstanding during 2011.
	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 benefits recognized 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 antidilutive RSAs and no antidilutive RSUs from the application of unearned compensation in the treasury stock method in 2013. There were 1,934 such antidilutive RSAs and 7,673 such antidilutive RSUs in 2012 and no such antidilutive restricted stock awards or units in 2011.
	Each performance-based RSU represents the right to receive between zero and 1.5 shares of Sempra Energy common stock based on Sempra Energy's four-year cumulative total shareholder return compared to the Standard & Poor's (S&P) 500 Utilities Index, as follows:
	Four-Year Cumulative Total Shareholder Return Ranking versus S&P 500 Utilities Index(1)		Number of Sempra Energy Common Shares Received for Each Performance-Based Restricted Stock Unit(2)
	75th Percentile or Above		1.5
	50th Percentile		1
	35th Percentile or Below		―
	-1	If Sempra Energy ranks at or above the 50th percentile compared to the S&P 500 Index, participants will receive a minimum of 1.0 share for each RSU.
	-2	Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate.
	RSAs and those RSUs that are solely service-based have a maximum potential of 100 percent vesting and have the same dividend equivalent rights as performance-based RSUs. We include our performance-based RSUs in potential dilutive shares at zero to 150 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 both Sempra Energy stock and the comparative index, dilutive performance-based RSU shares may vary widely from period-to-period. We include our RSAs, which are solely service-based, and those RSUs that are solely service-based in potential dilutive shares at 100 percent.
	RSUs and RSAs may be excluded from potential dilutive shares by the application of unearned compensation in the treasury stock method, as we discuss above, or because performance goals are currently not met. The maximum excluded RSUs and RSAs, assuming performance goals were met at maximum levels, were 641,751; 1,134,456 and 4,109,717 for the years ended December 31, 2013, 2012 and 2011, 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.
	There were no shares of common stock held by the ESOP at December 31, 2013 or 2012, and 153,625 at December 31, 2011. These shares were unallocated and therefore excluded from the computation of EPS.
	Excluding shares held by the ESOP, common stock activity consisted of the following:
	COMMON STOCK ACTIVITY
			Years ended December 31,
				2013		2012		2011
	Common shares outstanding, January 1			242,368,836		239,934,681		240,447,416
	Stock options exercised			1,237,348		1,876,303		958,126
	Restricted stock issuances			21,121		2,580		11,876
	Restricted stock units vesting(1)			1,491,170		683,416		2,625
	Shares released from ESOP			―		153,625		350,815
	Shares repurchased(2)			-657,148		-281,769		-1,836,177
	Common shares outstanding, December 31			244,461,327		242,368,836		239,934,681
	-1	Includes dividend equivalents.
	-2	In addition to formal common stock repurchase programs which we discuss below, we also, from time to time, purchase shares of our common stock from restricted stock plan participants who elect to sell a sufficient number of vesting restricted shares to meet minimum statutory tax withholding requirements.
	Our board of directors has the discretion to determine the payment and amount of future dividends.
	COMMON STOCK REPURCHASE PROGRAMS
	On September 11, 2007, our board of directors authorized the repurchase of additional shares of our common stock provided that the amounts expended for such purposes did not exceed the greater of $2 billion or amounts expended to purchase no more than 40 million shares. Purchases may include open-market and negotiated transactions, structured purchase arrangements, and tender offers.
	In April 2008, we entered into a share repurchase program under which we expended $1 billion to repurchase 18,416,241 shares of our common stock in 2008 at a weighted average price of $54.30 per share.
	In September 2010, we entered into a share repurchase program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The program was completed in March 2011 with a total of 9,574,435 shares repurchased at an average price of $52.22 per share. Our outstanding shares used to calculate earnings per share were reduced by the number of shares repurchased when they were delivered to us, and the $500 million purchase price was recorded as a reduction in shareholders' equity upon its prepayment. We received 8,078,000 shares during 2010 and 1,496,435 shares in 2011.
	These share repurchase programs are unrelated to share-based compensation as described in Note 8.

NUCLEAR_PLANT

NUCLEAR PLANT	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Nuclear Plant	'
	SDG&E has a 20-percent ownership interest in SONGS, a 2,150-MW nuclear generating facility near San Clemente, California. SONGS is operated by Southern California Edison Company (Edison), the majority owner, and is subject to the jurisdiction of the Nuclear Regulatory Commission (NRC) and the CPUC.
	On June 6, 2013, Edison notified SDG&E that it had reached a decision to permanently retire SONGS Units 2 and 3 and seek approval from the NRC to start the decommissioning activities for the entire facility. Edison advised SDG&E that its management had made the unilateral decision to retire the Units once Edison concluded that the considerable uncertainty about when, or if, the NRC would allow a restart of Unit 2 could not be resolved. Given this uncertainty, Edison decided to retire both Units and seek the authority from the NRC to commence the decommissioning of SONGS.
	Background
	The steam generators were replaced in Units 2 and 3, and the Units returned to service in 2010 and 2011, respectively. Both Units have been shut down since 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 generators, as well. In March 2012, in response to the shutdown of SONGS, the NRC issued a Confirmatory Action Letter (CAL) which, among other things, outlined the requirements Edison would be required to meet before the NRC would approve a restart of either of the Units.
	In October 2012, Edison submitted a restart plan to the NRC proposing to operate Unit 2 at a reduced power level for a period of five months, at which time the Unit would be brought down for further inspection. Edison did not file a restart plan for Unit 3, pending further inspection and analysis of what the required repairs or modifications would need to be to return the Unit back to service in a safe manner. The NRC had been reviewing the restart plan for Unit 2 proposed by Edison since that time, and in May 2013, the Atomic Safety and Licensing Board (ASLB), an adjudicatory arm of the NRC, concluded that the CAL process constituted a de facto license amendment proceeding that was subject to a public hearing. This conclusion by the ASLB resulted in further uncertainty regarding when a final decision might be made on restarting Unit 2.
	In response to the prolonged outage, the CPUC issued an 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 OII consolidated most SONGS issues in various related proceedings into a single proceeding. The OII, among other things, ruled that all revenues associated with the investment in, and operation of, SONGS since January 1, 2012 are subject to refund to customers, pending the outcome of all phases of the proceeding. The OII proceeding will also determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outage, including purchased replacement power costs that are typically recovered through the Energy Resource Recovery Account (ERRA) balancing account subject only to a reasonableness review by the CPUC.
	The first phase of the OII addresses the reasonableness of the costs incurred in 2012. In November 2013, the CPUC issued a Proposed Decision (PD) on the first phase of the OII, which included the following impacts:
	The PD identified $182.8 million as SDG&E's share of the costs incurred by Edison, including overheads and capital, in 2012. Of this amount, the PD deemed $19.3 million to have been unreasonably incurred and recommended that this amount be refunded in rates effective January 1, 2014.
	In addition, the PD identified $27 million as SDG&E's share of the $122 million in costs incurred by Edison in 2012 associated with the steam generator inspection and repair, which costs will be reviewed in Phase 3, but not removed from rates yet. These costs are to be separately accounted for and interest accrued at the one-year U.S. Treasury rate should the CPUC decide in Phase 3 that they should also be refunded.
	In addition, the PD defines the methodology to calculate replacement power costs, and the SONGS owners must re-calculate their replacement power costs according to the adopted methodology. Those costs are subject to refund (to the extent they are in rates) pending the outcome of Phase 3. The PD is subject to final approval by the CPUC and may be amended or changed.
	The second phase of the OII addresses the appropriate rate recovery treatment of the investment in SONGS assets. Hearings on this second phase were held in October 2013, and a CPUC decision on this phase of the OII is scheduled for the first half of 2014.
	The third phase of the OII will address the reasonableness of the steam generator replacement project costs. We expect this phase to begin in the second half of 2014.
	Since the unscheduled outage started, SDG&E has procured power to meet its customers' needs to replace the power that would have been supplied to SDG&E from SONGS, had SONGS been in operation. The estimated cost of the purchased replacement power, determined consistent with the methodology used in the CPUC's OII into the SONGS outage, incurred from January 2012 through June 6, 2013, the date Edison notified SDG&E of the early closure of SONGS, was approximately $165 million. Of this total, $98 million was incurred in 2012 and has been approved for collection in rates pursuant to prior ERRA proceedings. The remaining $67 million, discussed below, represents replacement power costs incurred in 2013 through June 6 that have not yet been approved for recovery in rates. Although $98 million has been authorized for recovery through ERRA, the OII will determine whether any of this amount will be required to be refunded to customers.
	In addition to the estimated cost of the purchased replacement power mentioned above, SDG&E's share of SONGS' operating costs, including depreciation, and the return on its investment in SONGS from January 1, 2012 through June 30, 2013, was approximately $300 million.
	Given the decision by Edison to close SONGS, SDG&E management assessed the appropriate accounting for an early-retired plant. In conducting this assessment, management took into consideration, among other things, the interrelationship of any recovery of SDG&E's investment in SONGS, the cost of operations, the cost of purchased replacement power and the probability of having to refund to customers a portion or all of the revenue subject to refund. Management's assessment took into account that the CPUC is considering all of these elements on a combined basis in the OII. After considering the regulatory precedent regarding rate recovery of investments in and costs incurred related to early-retired plants, management considered a number of possible regulatory outcomes from the OII proceeding, none of which management considered certain, and given SDG&E's non-operator and minority interest position and the regulatory precedent on such matters, management believes that it is probable that SDG&E will recover in rates the amount recorded in the SONGS regulatory asset, as described below. We determined the amount deemed probable of recovery based on our assessment of the likelihood of the potential regulatory outcomes identified, resulting in SDG&E recording a $200 million pretax loss in the second quarter of 2013.
	As a result of Edison's decision to permanently retire SONGS Units 2 and 3, and as a result of our assessment described above, SDG&E established a new regulatory asset included in Other Regulatory Assets on the Consolidated Balance Sheet. As of December 31, 2013, the balance in this new regulatory asset was $303 million and was comprised of the following:
	the net book value of SDG&E's investment in SONGS plant and nuclear fuel of $516 million, which prior to the date of the plant retirement, had been reported as Property, Plant and Equipment on the Consolidated Balance Sheet;
	SDG&E's SONGS-related materials and supplies of $10 million, which prior to the date of the plant retirement, had been reported as Inventory on the Consolidated Balance Sheet;
	SDG&E's 2013 cost of replacement power that is in excess of the amount previously authorized for recovery in ERRA of $67 million which, prior to the date of the plant retirement, would have been reported as Regulatory Balancing Accounts, Net in Current Assets on the Consolidated Balance Sheet;
	miscellaneous costs incurred or expected to be incurred by SDG&E associated with the early closure of the plant of $35 million; net of
	a $200 million reserve for disallowance of rate recovery reported as Loss from Plant Closure on the Consolidated Statement of Operations; and
	$125 million for amounts billed to customers for operating costs and the recovery of and return on investment in SONGS since the plant closure in early June 2013 that are subject to refund.
	The amount that SDG&E will eventually recover will require a regulatory decision from the CPUC that could result in recovery of an amount that is materially different than management's estimate. In addition to recoveries through the regulatory process, SDG&E intends to pursue various avenues for recovery from other potentially responsible parties and insurance carriers. However, these anticipated recoveries, if any, cannot be included in our current estimates. SDG&E will continue to assess the probability of recovery in rates of this new regulatory asset, as well as: 1) the cost of the purchased replacement power of $98 million approved in prior ERRA proceedings for collection in rates, and 2) the operations and maintenance expenses incurred by SDG&E since the start of the forced outages, which amounted to approximately $184 million through December 31, 2013. Should SDG&E conclude that recovery in rates is less than the amount anticipated or no longer probable, SDG&E will record an additional charge against earnings at the time such a conclusion is reached.
	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 generators. 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 party responsible for performing the verification and checking of the design of the steam generators.
	Simultaneously, 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 onsite 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.
	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 NRC regulations, as well as regulations of the Environmental Protection Agency (EPA), the U.S. Department of the Navy (the land owner), the CPUC and other regulatory bodies. The NRC regulations categorize the decommissioning activities into three phases: initial activities, major decommissioning and storage activities, and license termination. Initial activities include providing notice of permanent cessation of operations (accomplished on June 12, 2013) and notice of permanent removal of fuel from the reactor vessels (provided by Edison to the NRC 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, an irradiated fuel management plan and a site-specific decommissioning cost estimate. Edison currently estimates that it will provide the other initial activity phase plans and cost estimates to the NRC by the end of 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. At December 31, 2013, the fair value of SDG&E's NDT assets was $1 billion. Except for the use of funds for the planning of decommissioning activities, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs. In February 2014, SDG&E filed a request with the CPUC for such authorization. Until CPUC approval is received, SDG&E will use working capital to pay for any SONGS decommissioning costs incurred, and such expenditures will be reimbursed from the NDT upon that approval. The timing of SDG&E's access to the NDT assets may also depend on a finding by the NRC regarding the characterization of the commingled funds. SDG&E expects the NRC to make such a finding in 2014.
	SDG&E and Edison have a joint application pending with the CPUC requesting continued rate recovery of the estimated cost for decommissioning of SONGS. SDG&E is currently authorized to recover $8 million annually to fund additional investments in the NDT to pay for the cost of decommissioning SONGS. In its pending application with the CPUC, SDG&E is requesting to recover $16 million on an annual basis to fund additional investments in the NDT. We expect a decision on this application in the first half of 2014.
	NOTE 13. SAN ONOFRE NUCLEAR GENERATING STATION (SONGS)
	SDG&E has a 20-percent ownership interest in SONGS, a 2,150-MW nuclear generating facility near San Clemente, California. SONGS is operated by Southern California Edison Company (Edison), the majority owner, and is subject to the jurisdiction of the Nuclear Regulatory Commission (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 expenditures.
	SDG&E's share of operating expenses is included in Sempra Energy's and SDG&E's Consolidated Statements of Operations.
	SONGS Outage and Retirement
	On June 6, 2013, Edison notified SDG&E that it had reached a decision to permanently retire SONGS Units 2 and 3 and seek approval from the NRC to start the decommissioning activities for the entire facility. Edison advised SDG&E that its management had made the unilateral decision to retire the Units once Edison concluded that the considerable uncertainty about when, or if, the NRC would allow a restart of Unit 2 could not be resolved. Given this uncertainty, Edison decided to retire both Units and seek the authority from the NRC to commence the decommissioning of SONGS.
	Background
	The steam generators were replaced in Units 2 and 3, and the Units returned to service in 2010 and 2011, respectively. Both Units have been shut down since 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 generators, as well. In March 2012, in response to the shutdown of SONGS, the NRC issued a Confirmatory Action Letter (CAL) which, among other things, outlined the requirements Edison would be required to meet before the NRC would approve a restart of either of the Units.
	In October 2012, Edison submitted a restart plan to the NRC proposing to operate Unit 2 at a reduced power level for a period of five months, at which time the Unit would be brought down for further inspection. Edison did not file a restart plan for Unit 3, pending further inspection and analysis of what the required repairs or modifications would need to be to return the Unit back to service in a safe manner. The NRC had been reviewing the restart plan for Unit 2 proposed by Edison since that time, and in May 2013, the Atomic Safety and Licensing Board (ASLB), an adjudicatory arm of the NRC, concluded that the CAL process constituted a de facto license amendment proceeding that was subject to a public hearing. This conclusion by the ASLB resulted in further uncertainty regarding when a final decision might be made on restarting Unit 2.
	The 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. We discuss these proceedings in Note 15.
	CPUC SONGS Order Instituting Investigation (OII)
	In response to the prolonged outage, the CPUC issued an 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 OII consolidated most SONGS issues in various related proceedings into a single proceeding. The OII, among other things, ruled that all revenues associated with the investment in, and operation of, SONGS since January 1, 2012 are subject to refund to customers, pending the outcome of all phases of the proceeding. The OII proceeding will also determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outage, including purchased replacement power costs that are typically recovered through the Energy Resource Recovery Account (ERRA) balancing account subject only to a reasonableness review by the CPUC.
	The first phase of the OII addresses the reasonableness of the costs incurred in 2012. In November 2013, the CPUC issued a Proposed Decision (PD) on the first phase of the OII, which included the following impacts:
	The PD identified $182.8 million as SDG&E's share of the costs incurred by Edison, including overheads and capital, in 2012. Of this amount, the PD deemed $19.3 million to have been unreasonably incurred and recommended that this amount be refunded in rates effective January 1, 2014.
	In addition, the PD identified $27 million as SDG&E's share of the $122 million in costs incurred by Edison in 2012 associated with the steam generator inspection and repair, which costs will be reviewed in Phase 3, but not removed from rates yet. These costs are to be separately accounted for and interest accrued at the one-year U.S. Treasury rate should the CPUC decide in Phase 3 that they should also be refunded.
	In addition, the PD defines the methodology to calculate replacement power costs, and the SONGS owners must re-calculate their replacement power costs according to the adopted methodology. Those costs are subject to refund (to the extent they are in rates) pending the outcome of Phase 3. The PD is subject to final approval by the CPUC and may be amended or changed.
	The second phase of the OII addresses the appropriate rate recovery treatment of the investment in SONGS assets. Hearings on this second phase were held in October 2013, and a CPUC decision on this phase of the OII is scheduled for the first half of 2014.
	The third phase of the OII will address the reasonableness of the steam generator replacement project costs. We expect this phase to begin in the second half of 2014.
	Since the unscheduled outage started, SDG&E has procured power to meet its customers' needs to replace the power that would have been supplied to SDG&E from SONGS, had SONGS been in operation. The estimated cost of the purchased replacement power, determined consistent with the methodology used in the CPUC's OII into the SONGS outage, incurred from January 2012 through June 6, 2013, the date Edison notified SDG&E of the early closure of SONGS, was approximately $165 million. Of this total, $98 million was incurred in 2012 and has been approved for collection in rates pursuant to prior ERRA proceedings. The remaining $67 million, discussed below, represents replacement power costs incurred in 2013 through June 6 that have not yet been approved for recovery in rates. Although $98 million has been authorized for recovery through ERRA, the OII will determine whether any of this amount will be required to be refunded to customers.
	In addition to the estimated cost of the purchased replacement power mentioned above, SDG&E's share of SONGS' operating costs, including depreciation, and the return on its investment in SONGS from January 1, 2012 through June 30, 2013, was approximately $300 million.
	Accounting for the Early Retirement of SONGS
	Given the decision by Edison to close SONGS, SDG&E management assessed the appropriate accounting for an early-retired plant. In conducting this assessment, management took into consideration, among other things, the interrelationship of any recovery of SDG&E's investment in SONGS, the cost of operations, the cost of purchased replacement power and the probability of having to refund to customers a portion or all of the revenue subject to refund. Management's assessment took into account that the CPUC is considering all of these elements on a combined basis in the OII. After considering the regulatory precedent regarding rate recovery of investments in and costs incurred related to early-retired plants, management considered a number of possible regulatory outcomes from the OII proceeding, none of which management considered certain, and given SDG&E's non-operator and minority interest position and the regulatory precedent on such matters, management believes that it is probable that SDG&E will recover in rates the amount recorded in the SONGS regulatory asset, as described below. We determined the amount deemed probable of recovery based on our assessment of the likelihood of the potential regulatory outcomes identified, resulting in SDG&E recording a $200 million pretax loss in the second quarter of 2013.
	As a result of Edison's decision to permanently retire SONGS Units 2 and 3, and as a result of our assessment described above, SDG&E established a new regulatory asset included in Other Regulatory Assets on the Consolidated Balance Sheet. As of December 31, 2013, the balance in this new regulatory asset was $303 million and was comprised of the following:
	the net book value of SDG&E's investment in SONGS plant and nuclear fuel of $516 million, which prior to the date of the plant retirement, had been reported as Property, Plant and Equipment on the Consolidated Balance Sheet;
	SDG&E's SONGS-related materials and supplies of $10 million, which prior to the date of the plant retirement, had been reported as Inventory on the Consolidated Balance Sheet;
	SDG&E's 2013 cost of replacement power that is in excess of the amount previously authorized for recovery in ERRA of $67 million which, prior to the date of the plant retirement, would have been reported as Regulatory Balancing Accounts, Net in Current Assets on the Consolidated Balance Sheet;
	miscellaneous costs incurred or expected to be incurred by SDG&E associated with the early closure of the plant of $35 million; net of
	a $200 million reserve for disallowance of rate recovery reported as Loss from Plant Closure on the Consolidated Statement of Operations; and
	$125 million for amounts billed to customers for operating costs and the recovery of and return on investment in SONGS since the plant closure in early June 2013 that are subject to refund.
	The amount that SDG&E will eventually recover will require a regulatory decision from the CPUC that could result in recovery of an amount that is materially different than management's estimate. In addition to recoveries through the regulatory process, SDG&E intends to pursue various avenues for recovery from other potentially responsible parties and insurance carriers. However, these anticipated recoveries, if any, cannot be included in our current estimates. SDG&E will continue to assess the probability of recovery in rates of this new regulatory asset, as well as: 1) the cost of the purchased replacement power of $98 million approved in prior ERRA proceedings for collection in rates, and 2) the operations and maintenance expenses incurred by SDG&E since the start of the forced outages, which amounted to approximately $184 million through December 31, 2013. Should SDG&E conclude that recovery in rates is less than the amount anticipated or no longer probable, SDG&E will record an additional charge against earnings at the time such a conclusion is reached.
	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 generators. 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 party responsible for performing the verification and checking of the design of the steam generators.
	Simultaneously, 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 onsite 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 NRC regulations, as well as regulations of the Environmental Protection Agency (EPA), the U.S. Department of the Navy (the land owner), the CPUC and other regulatory bodies. The NRC regulations categorize the decommissioning activities into three phases: initial activities, major decommissioning and storage activities, and license termination. Initial activities include providing notice of permanent cessation of operations (accomplished on June 12, 2013) and notice of permanent removal of fuel from the reactor vessels (provided by Edison to the NRC 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, an irradiated fuel management plan and a site-specific decommissioning cost estimate. Edison currently estimates that it will provide the other initial activity phase plans and cost estimates to the NRC by the end of 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. At December 31, 2013, the fair value of SDG&E's NDT assets was $1 billion. Except for the use of funds for the planning of decommissioning activities, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs. In February 2014, SDG&E filed a request with the CPUC for such authorization. Until CPUC approval is received, SDG&E will use working capital to pay for any SONGS decommissioning costs incurred, and such expenditures will be reimbursed from the NDT upon that approval. The timing of SDG&E's access to the NDT assets may also depend on a finding by the NRC regarding the characterization of the commingled funds. SDG&E expects the NRC to make such a finding in 2014.
SDG&E and Edison have a joint application pending with the CPUC requesting continued rate recovery of the estimated cost for decommissioning of SONGS. SDG&E is currently authorized to recover $8 million annually to fund additional investments in the NDT to pay for the cost of decommissioning SONGS. In its pending application with the CPUC, SDG&E is requesting to recover $16 million on an annual basis to fund additional investments in the NDT. We expect a decision on this application in the first half of 2014.
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 held in the trust funds. We provide additional fair value disclosures for the trusts in Note 10.
NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
				Gross		Gross		Estimated
				Unrealized		Unrealized		Fair
		Cost		Gains		Losses		Value
At December 31, 2013:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies(1)		$	116	$	3	$	-2	$	117
Municipal bonds(2)			110		2		-1		111
Other securities(3)			155		3		-5		153
Total debt securities			381		8		-8		381
Equity securities			207		409		-2		614
Cash and cash equivalents			39		―		―		39
Total		$	627	$	417	$	-10	$	1,034
At December 31, 2012:
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies		$	147	$	9	$	―	$	156
Municipal bonds			57		6		―		63
Other securities			121		10		-1		130
Total debt securities			325		25		-1		349
Equity securities			249		292		-2		539
Cash and cash equivalents			20		―		―		20
Total		$	594	$	317	$	-3	$	908
-1	Maturity dates are 2014-2056.
-2	Maturity dates are 2014-2062.
-3	Maturity dates are 2014-2111.
The following table shows the proceeds from sales of securities in the trusts and gross realized gains and losses on those sales.
SALES OF SECURITIES
(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
Proceeds from sales(1)		$	685	$	723	$	715
Gross realized gains			26		21		75
Gross realized losses			-18		-13		-52
-1	Excludes securities that are held to maturity.
Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on the Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
Customer 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 future customer contributions.
Asset Retirement Obligation and Spent Nuclear Fuel
SDG&E's asset retirement obligation related to decommissioning costs for the SONGS units was $756 million at December 31, 2013. That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. Edison generally updates decommissioning cost studies every three years. The most recent cost study was approved by the CPUC in July 2012. The obligation at December 31, 2013 is based on this cost study, adjusted to reflect the acceleration of the start of decommissioning Units 2 and 3. SDG&E's share of decommissioning costs under the approved study is approximately $768 million in 2008 dollars and $912 million escalated to 2013 dollars. Rate recovery of decommissioning costs is allowed until the time that the costs are fully recovered.
Unit 1 was permanently shut down in 1992, and physical decommissioning 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 installation (ISFSI) licensed by the NRC. The decommissioning of Unit 1 remaining structures (subsurface and intake/discharge) will take place as Units 2 and 3 are decommissioned. The ISFSI will be decommissioned after a permanent storage facility becomes available and the 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 until the DOE accepts it for final disposal. Spent nuclear fuel for Units 2 and 3 has been stored in the SONGS spent fuel pools for each reactor and in the ISFSI.
We provide additional information about SONGS in Note 15.

CALIFORNIA_UTILITIES_REGULATOR

CALIFORNIA UTILITIES' REGULATORY MATTERS	12 Months Ended
	Dec. 31, 2013
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 prospectively set rates sufficient 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. In December 2010, the California Utilities filed their 2012 General Rate Case (2012 GRC) applications to establish their authorized 2012 revenue requirements and the ratemaking mechanisms by which those requirements would change on an annual basis over the subsequent three-year (2013-2015) period.
	In May 2013, the CPUC approved a final decision (Final GRC Decision) in the California Utilities' 2012 GRC. The Final GRC Decision establishes a 2012 revenue requirement of $1.733 billion for SDG&E and $1.959 billion for SoCalGas. This represents an increase of $119 million (7.4 percent) and $115 million (6.2 percent) over SDG&E's and SoCalGas' authorized 2011 revenue requirements, respectively. The Final GRC Decision is effective retroactive to January 1, 2012, and SDG&E and SoCalGas recorded the cumulative earnings effect of the retroactive application of the Final GRC Decision of $69 million and $37 million, respectively, in the second quarter of 2013. For SDG&E and SoCalGas, respectively, these amounts include 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.
	The amount of revenue associated with the retroactive period is expected to be 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, 2013, SDG&E reported on its Consolidated Balance Sheet $324 million as a regulatory asset, with $161 million classified as noncurrent, representing the retroactive revenue from the Final GRC Decision to be recovered by SDG&E in rates during the period December 2013 through December 2015. At December 31, 2013, SoCalGas reported on its Consolidated Balance Sheet a regulatory asset of $104 million, with $52 million as noncurrent, representing the retroactive revenue from the Final GRC Decision to be recovered in rates through December 2015.
	The Final GRC Decision also establishes a four-year GRC period (through 2015) with a revenue attrition mechanism for the escalation of the adopted revenue requirements for years 2013, 2014 and 2015 based on fixed annual factors of 2.65 percent, 2.75 percent and 2.75 percent, respectively.
	For SDG&E, the Final GRC Decision also provides the revenue requirement for cost recovery of wildfire insurance premiums beginning January 1, 2012.
	CPUC Cost of Capital
	A 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 electric and natural gas distribution, natural gas transmission and electric generation assets. In addition, a cost of capital proceeding also addresses the automatic ROR adjustment mechanism 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.
	SDG&E and SoCalGas filed separate applications with the CPUC in April 2012 to update their cost of capital effective January 1, 2013. The CPUC issued a ruling in June 2012 bifurcating the proceeding. Phase 1 addressed each utility's cost of capital for 2013, with a final decision issued in December 2012, which granted SDG&E and SoCalGas an authorized ROR of 7.79 percent and 8.02 percent, respectively, as presented in the table below. The CPUC-authorized ROR in effect prior to the effective date of this decision was 8.40 percent for SDG&E and 8.68 percent for SoCalGas. Phase 2 addressed the cost of capital adjustment mechanisms for SDG&E, SoCalGas, Edison and Pacific Gas and Electric Company (PG&E).
	The CPUC's final decision for Phase 1 is outlined in the table below:
	COST OF CAPITAL FINAL DECISION SUMMARY
	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, SoCalGas, PG&E, Edison and the Office of Ratepayer Advocates (ORA) (formerly the Division of Ratepayer Advocates or DRA) sponsored a joint stipulation in Phase 2 of the proceeding. In March 2013, the CPUC's final decision adopted the joint stipulation, as proposed. SDG&E retains its current cost of capital adjustment mechanism, and SoCalGas has implemented this same adjustment mechanism, discussed below. Both utilities are forgoing their proposed off-ramp provision, which was intended as a safeguard to protect against extreme changes in interest rates and allow the CPUC latitude to suspend the annual mechanism if prudent.
	The cost of capital adjustment mechanism benchmark is based on the 12-month average monthly A-rated utility bond yield as published by Moody's (CCM Benchmark) for the 12-month period October through September of each fiscal year. If the 12-month average falls outside of a specified range, then the utility's authorized ROE would be adjusted, upward or downward, by one-half of the difference between the 12-month average and the mid-point of the specified range. In addition, the utility's authorized recovery rate for the cost of debt and preferred stock would also be adjusted to their respective actual weighted average cost. Therefore, for intervening years between scheduled cost of capital updates, the utility's authorized ROR would adjust, upward or downward, as a result of all three adjustments with the new rate going into effect on January 1 following the year in which the benchmark range was exceeded. For both SDG&E and SoCalGas, the CCM Benchmark rate is set at 4.24 percent, resulting in the specified range of a low of 3.24 percent to a high of 5.24 percent. The 12-month average rate would have to fall outside of this range for the adjustments to occur. For the four-month period ended January 31, 2014, the monthly average CCM Benchmark was 4.73 percent.
	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 August 2011. The proposed safety measures, investments and estimated costs are not included in the California Utilities' 2012 GRC requests discussed above, but the associated cost recovery and return of and on invested capital will be determined as part of the Triennial Cost Allocation Proceeding (TCAP), as we discuss below. The comprehensive plan covers all of the utilities' approximately 4,000 miles of transmission lines (3,750 miles for SoCalGas and 250 miles for SDG&E) and would be implemented in two phases:
	Phase 1 focuses on populated areas of SoCalGas' and SDG&E's service territories and would be implemented over a 10-year period, from 2012 to 2022.
	Phase 2 covers unpopulated areas of SoCalGas' and SDG&E's service territories and will be filed with the CPUC at a later date.
	The total cost estimate for Phase 1, over the 10-year period of 2012 to 2022, is $3.1 billion ($2.5 billion for SoCalGas and $600 million for SDG&E). In their August 2011 filing, the utilities requested the CPUC to authorize funding for the recovery of costs through 2015 of approximately $1.5 billion for SoCalGas, of which $1.2 billion would be capital investment, and $240 million for SDG&E, of which $230 million would be capital investment. After 2015, the utilities proposed to include the costs of the PSEP in their next General Rate Case (for their authorized revenue requirements in 2016). The utilities also proposed that the cost of the program be recovered through a surcharge, rather than by incorporating it into rates. The surcharge would increase over time, as more project work is completed. Since the date of the initial filing, the California Utilities have provided the CPUC's Safety and Enforcement Division (formerly the Consumer Protection and Safety Division) updated information that reflects the current scope of work, including the recovery of additional records resulting in a reduction to the number of pipeline miles without records. The California Utilities anticipate that the PD in this proceeding will require SDG&E and SoCalGas to update the costs included in their previous filings, based on the latest scope of work.
	In December 2011, the assigned Commissioner to the rulemaking proceeding for the pipeline safety regulations ruled that SDG&E's and SoCalGas' TCAP would be the most logical proceeding to conduct the reasonableness and ratemaking review of the companies' PSEP.
	In January 2012, the CPUC Consumer Protection and Safety Division (CPSD) issued a Technical Report on the California Utilities' PSEP.  The report, along with testimony and evidentiary hearings, will be used to evaluate the PSEP in the regulatory process.  Generally, the report found that the PSEP approach to pipeline replacement and pressure testing and other proposed enhancements is reasonable.
	In February 2012, the assigned Commissioner in the TCAP issued a ruling setting a schedule for the review of the SDG&E and SoCalGas PSEP with evidentiary hearings held in August 2012. SDG&E and SoCalGas now expect the Administrative Law Judge to issue a proposed decision in Phase 1A of this proceeding in 2014.
	In April 2012, the CPUC issued an interim decision in the rulemaking proceeding formally transferring the PSEP to the TCAP and authorizing SDG&E and SoCalGas to establish regulatory accounts to record the incremental costs of initiating the PSEP prior to a final decision on the PSEP. The TCAP proceeding will address the recovery of the costs recorded in the regulatory account.
	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 utilities 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 management 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 established. In December 2012, the CPUC issued a final decision accepting the utility safety plans filed pursuant to SB 705.
	Southern Gas System Reliability Project
	In December 2013, SoCalGas and SDG&E filed a joint application with the CPUC seeking authority to recover the full cost of the Southern Gas System Reliability Project. Also known as the North-South Gas Transmission Pipeline Project, the project will enhance reliability on the southern portions of the utilities' integrated gas transmission system (Southern System). We estimate the cost of the project to be between $600 million to $650 million. As proposed, the project consists of three components: 1) constructing a 36-inch gas transmission pipeline between the SoCalGas Adelanto and Moreno gas compressor stations, a distance of approximately 60 miles; 2) upgrading the Adelanto compressor station; and 3) constructing a 36-inch pipeline from the Moreno compressor station to a pressure limiting station in Whitewater, a distance of approximately 31 miles. SDG&E and SoCalGas have requested a CPUC decision in the first quarter of 2015. The project is scheduled to be in service by the end of 2019.
	Utility Incentive Mechanisms
	The CPUC applies performance-based measures and incentive mechanisms to all California investor-owned utilities, 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 associated 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 earnings 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 more likely than not that the CPUC would assess a penalty.
	We provide a summary of the incentive awards recognized below.
	UTILITY INCENTIVE AWARDS RECORDED IN EARNINGS 2011-2013(1)
	(Dollars in millions)
			Years ended December 31,
			2013			2012		2011
	Sempra Energy Consolidated
	Energy efficiency		$	7		$	6	$	16
	Unbundled natural gas storage and hub services			1			3		4
	Natural gas procurement			5			6		6
	Operational incentives			―			5		3
	Total awards		$	13		$	20	$	29
	SDG&E
	Energy efficiency		$	4		$	3	$	14
	Operational incentives			―			2		1
	Total awards		$	4		$	5	$	15
	SoCalGas
	Energy efficiency		$	3		$	3	$	2
	Unbundled natural gas storage and hub services			1			3		4
	Natural gas procurement			5			6		6
	Operational incentives			―			3		2
Total awards		$	9		$	15	$	14
-1	Awards are included in earnings upon CPUC approval of the award.
Energy Efficiency
The CPUC established incentive mechanisms that are based on the effectiveness of energy efficiency programs. In December 2011, the CPUC awarded $13.7 million to SDG&E and $2.0 million to SoCalGas for their 2009 program year results. In December 2012, the CPUC issued a final decision adopting a mechanism for the 2010–2012 program cycle and approving shareholder awards of $3.3 million for SDG&E and $2.7 million for SoCalGas for their energy efficiency program performance in 2010 under the mechanism. The decision established an annual process for the utilities to obtain awards for their performance in 2011 and 2012.
In December 2013, the CPUC awarded $3.1 million to SoCalGas and $3.9 million to SDG&E for their 2011 program year results. Both SoCalGas and SDG&E plan to file incentive award claims for the 2012 program year in the third quarter of 2014. We currently expect the award amounts to approximate the amounts claimed for the 2011 program year, awarded in 2013.
In September 2013, the CPUC approved a new Efficiency Savings and Performance Incentive mechanism that would apply for the 2013–2014 program period. The mechanism will be applied on an annual basis and remain in effect for future program cycles unless modified by the CPUC. We currently expect the annual amounts of the energy efficiency awards for both SoCalGas and SDG&E under this new mechanism to approximate the amounts claimed for the 2011 program year, awarded in 2013.
Unbundled Natural Gas Storage and System Operator Hub Services
The CPUC has established a revenue sharing mechanism, effective through 2014, which provides for the sharing between ratepayers and SoCalGas (shareholders) of the net revenues generated by SoCalGas' unbundled natural gas storage and system operator hub services. SoCalGas is seeking to extend the mechanism through 2015. Annual net revenues (revenues less allocated service costs) under the mechanism are shared on a graduated basis, as follows:
the first $15 million of net revenue to be shared 90 percent ratepayers/10 percent shareholders;
the next $15 million of net revenue to be shared 75 percent ratepayers/25 percent shareholders;
all additional net revenues to be shared evenly between ratepayers and shareholders; and
the maximum total annual shareholder-allocated portion of the net revenues cannot exceed $20 million.
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' gas cost incentive mechanism (GCIM) is applied on the combined portfolio basis.
In July 2013, the CPUC approved SoCalGas' application requesting a GCIM award of $5.4 million for the 12-month period ending March 31, 2012, which SoCalGas recorded in the third quarter of 2013. In June 2013, SoCalGas applied to the CPUC for approval of a GCIM award of $5.8 million for natural gas procured for its core customers during the 12-month period ending March 31, 2013. SoCalGas expects a CPUC decision on this application in the first half of 2014.
In the first quarter of 2012, SoCalGas recorded its approved GCIM award of $6.2 million for natural gas procured for its core customers during the 12-month period ending March 31, 2011.
In September 2011, SoCalGas recorded its approved GCIM award of $6 million for natural gas procured for its core customers during the 12-month period ending March 31, 2010.
Operational Incentives
The CPUC may establish operational incentives and associated performance benchmarks as part of a general rate case or cost of service proceeding. Through the end of 2011, the California Utilities had operational incentives that applied to their performance in the area of employee safety. In the California Utilities' 2012 GRC final decision described above, SDG&E was directed to establish a performance measure and incentive for electric reliability. In September 2013, SDG&E filed its proposed mechanism, which is currently pending action by the CPUC. If adopted, the electric reliability mechanism would apply to calendar years 2014 and 2015. The CPUC did not establish any operational incentives for SoCalGas in the 2012 GRC final decision.
SDG&E MATTERS
SONGS
We discuss regulatory and other matters related to SONGS in Note 13.
Power Procurement and Resource Planning
Background—Electric Industry Regulation
California's legislative response to the 2000 – 2001 energy crisis resulted in the 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 procurement customers of each of the California investor-owned utilities (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 last 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 California 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 comply 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 substantial 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' ability to obtain project financing and permitting; and
successful development and implementation of the renewable energy technologies.
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 a CPUC-imposed penalty of 5 cents per kilowatt hour of renewable energy under-delivery, which could materially affect its business, cash flows, financial condition, results of operations and/or prospects.
Subject to approval of its final report by the CPUC, SDG&E believes that it has met the requirements for the first compliance period, January 1, 2011 to December 31, 2013, of procuring an average of 20 percent of its annual electric requirements from renewable energy sources and that it will comply with the 33% RPS Program requirements.
Cleveland National Forest Transmission Projects
SDG&E filed an application with the CPUC in October 2012 for a permit to construct various transmission replacement projects in and around the Cleveland National Forest (CNF). The proposed projects will replace and fire-harden five transmission lines at an estimated cost of between $400 million and $450 million. As directed by the CPUC, SDG&E filed an amended application in June 2013 to provide notice of certain alternatives proposed by the U.S. Forest Service (USFS) in connection with SDG&E's request for a Master Special Use Permit (MSUP). USFS approval of the MSUP will establish land rights and conditions for SDG&E's continued operation and maintenance of facilities located within the CNF. CPUC approval is not required for the MSUP, even though construction of the projects is subject to review by both the USFS and CPUC. A joint environmental report will be developed by the CPUC and USFS. SDG&E currently expects a CPUC decision approving the transmission projects in the first half of 2015 and then expects the various phases of this project to be placed in service starting in 2016 and continuing through the end of the project in 2019.
South Orange County Reliability Enhancement
SDG&E filed an application with the CPUC in May 2012 for a Certificate of Public Convenience and Necessity to construct the South Orange County Reliability Enhancement project. The purpose of the project is to enhance the capacity and reliability of SDG&E's electric service to the south Orange County area. The proposed project primarily includes replacing and upgrading approximately eight miles of transmission lines and rebuilding and upgrading a substation at an existing site. SDG&E expects a final CPUC decision approving the estimated $450 million to $500 million project in 2015. SDG&E obtained approval for the project from the ISO in May 2011. As the project is planned in phases, management currently expects the entire project to be in service in 2019.
South Bay Substation
SDG&E filed an application in 2010 with the CPUC for a permit to construct a new substation to replace the aging and obsolete South Bay substation and accommodate the retirement of the South Bay Power Plant. The existing substation will be demolished when the new substation has been constructed, energized and all transmission lines have been transferred. In October 2013, the CPUC approved SDG&E's permit to construct the South Bay Substation Relocation Project at SDG&E's proposed site, which will be located south of the existing site. The project, estimated at $145 million to $175 million, will replace the existing 138/69-kilovolt (kV) substation with the new 230/69/12-kV Bay Boulevard Substation. SDG&E is in the process of obtaining the additional permits required to begin construction, including the coastal development permit from the California Coastal Commission. SDG&E currently expects the project to be in service in 2017.
East County Substation
In June 2012, the CPUC approved SDG&E's application for authorization to proceed with the East County Substation project, estimated to cost between $425 million and $450 million. The Bureau of Land Management (BLM) issued its record of decision in August 2012. SDG&E began construction in the second quarter of 2013 and expects the substation to be placed in service in the second half of 2014.
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 the period beginning September 1, 2013. The 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 investments 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 orders accepting the filing, subject to refund, and established settlement and hearing procedures, with rates being effective as of 2013.
On January 31, 2014, SDG&E filed an uncontested multi-party settlement at the FERC regarding the TO4 filing. The settlement, subject to the FERC's approval, will be in effect through December 31, 2018, is subject to a one-time right of termination by any party, and establishes a 10.05 percent ROE. SDG&E also has the right to seek 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. SDG&E expects that the FERC will act on this settlement by the end of the third quarter of 2014.
Excess Wildfire Claims Cost Recovery at the CPUC
SDG&E and SoCalGas filed an application, along with other related filings, with the CPUC in August 2009 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 authorized 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.
SDG&E intends to pursue recovery of such costs in a future application. SDG&E will continue to assess the potential for recovery of these costs in rates. 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 related to CPUC-regulated operations was no longer probable or was less than currently estimated at December 31, 2013, the resulting after-tax charge against earnings would have been up to $186 million. In addition, in periods following any such conclusion, SDG&E's earnings will be adversely impacted by increases in the estimated cost to litigate or settle pending wildfire claims. We discuss how we assess the probability of recovery of our regulatory assets in Note 1.
We provide additional information about 2007 wildfire litigation costs and their recovery in Note 15.
SOCALGAS MATTERS
Aliso Canyon Natural Gas Storage Compressor Replacement
In September 2009, SoCalGas filed an application with the CPUC requesting approval to replace certain obsolete natural gas turbine compressors used in the operations of SoCalGas' Aliso Canyon natural gas storage reservoir with a new electric compressor station. In April 2012, the CPUC issued a draft environmental impact report (EIR) for the project concluding that no significant or unavoidable adverse environmental impacts have been identified from the construction or operation of the proposed project. In November 2013, the CPUC issued a final decision that adopts the EIR and approves the estimated $200 million project.
Advanced Metering Infrastructure
In November 2011, the DRA and The Utility Reform Network (TURN) filed a joint petition requesting that the CPUC reconsider its prior approval of SoCalGas' advanced metering infrastructure (AMI) project and stay AMI deployment while the CPUC considers the request. The CPUC, which is not obligated to respond to such requests, has taken no action in response to the DRA/TURN petition, and SoCalGas is continuing its deployment of AMI pursuant to the April 2010 CPUC decision approving the project.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Commitments and Contingencies	'
	SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. This insurance provides $375 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides for up to $13.2 billion of secondary financial protection (SFP). If a nuclear liability loss occurring at any U.S. licensed/commercial reactor exceeds the $375 million insurance limit, all nuclear reactor owners could be required to contribute to the SFP. SDG&E's contribution would be up to $50.93 million. This amount is subject to an annual maximum of $7.6 million, unless a default occurs by any other SONGS owner. If the SFP is insufficient to cover the liability loss, SDG&E could be subject to an additional assessment.
	The SONGS owners, including SDG&E, also have $2.75 billion of nuclear property, decontamination, and debris removal insurance, subject to a $2.5 million deductible for “each and every loss.” This insurance coverage is provided through Nuclear Electric Insurance Limited (NEIL), a mutual insurance company. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $9.7 million of retrospective premiums based on overall member claims. Edison, on behalf of itself and the minority owners of SONGS (including SDG&E), has placed NEIL on notice of claims under both the property damage and outage insurance policies as a result of SONGS' Units 2 and 3 being shut down since early 2012.
	The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act). The industry aggregate loss limit for property claims arising from non-certified acts of terrorism is $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.
	NOTE 15. COMMITMENTS AND CONTINGENCIES
	LEGAL PROCEEDINGS
	We accrue losses for legal proceedings when it is probable that a loss has been incurred and the amounts 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 materially 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, 2013, Sempra Energy's accrued liabilities for material legal proceedings, on a consolidated basis, were $154 million. At December 31, 2013, accrued liabilities for material legal proceedings for SDG&E and SoCalGas were $146 million and $0.1 million, respectively. At December 31, 2013, liabilities of $104 million at Sempra Energy and SDG&E were related to wildfire litigation discussed below.
	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.” Cal Fire reported that the Rice fire burned approximately 9,500 acres and damaged 206 homes and two commercial properties, and the Witch and Guejito fires merged and eventually burned approximately 198,000 acres, resulting in two fatalities, approximately 40 firefighters injured and an estimated 1,141 homes destroyed.
	A September 2008 staff report issued by the CPUC's CPSD reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice fires and the lashing wire involved in the Guejito fire were not properly designed, constructed and maintained. In April 2010, proceedings initiated by the CPUC to determine if any of its rules were violated were settled with SDG&E's payment of $14.75 million.
	Numerous parties have sued SDG&E and Sempra Energy in San Diego County Superior Court seeking recovery of unspecified amounts of damages, including punitive damages, from the three fires. These include owners and insurers of properties that were destroyed or damaged in the fires and government entities seeking recovery of firefighting, emergency response, and environmental costs. They assert 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 regard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines.
	In October 2010, the Court of Appeal affirmed the trial court's ruling that these claims must be pursued in individual lawsuits, rather than as class actions on behalf of all persons who incurred wildfire damages. In February 2011, the California Supreme Court denied a petition for review of the affirmance. At the February 2014 status conference, the Court set a February 2015 trial date for a trial to be comprised of 5 cases involving plaintiffs who claim damages resulting from the Witch fires.
	SDG&E filed cross-complaints against Cox seeking indemnification for any liability that SDG&E might incur in connection with the Guejito fire, two SDG&E contractors seeking indemnification in connection with the Witch fire, and one SDG&E contractor seeking indemnification in connection with the Rice fire. SDG&E settled its claims against Cox and the three contractors for a total of approximately $824 million. Among other things, the settlement agreements provide that SDG&E will defend and indemnify Cox and the three contractors against all compensatory damage claims and related costs arising out of the wildfires.
	SDG&E has settled all of the approximately 19,000 claims brought by homeowner insurers for damage to insured property relating to the three fires. Under the settlement agreements, SDG&E has paid or will pay 57.5 percent of the approximately $1.6 billion paid or reserved for payment by the insurers to their policyholders and received an assignment of the insurers' claims against other parties potentially responsible for the fires.
	The wildfire litigation also includes claims of non-insurer plaintiffs for damage to uninsured and underinsured structures, business interruption, evacuation expenses, agricultural damage, emotional harm, personal injuries and other losses. SDG&E has settled the claims of approximately 6,100 of these plaintiffs, including all of the government entities. There are now approximately 40 cases left to be resolved and substantially all of those remaining individual and business plaintiffs have submitted settlement demands and damage estimates totaling approximately $380 million. SDG&E does not expect a significant number of additional plaintiffs to file lawsuits given the applicable statutes of limitation, but does expect to receive additional settlement demands and damage estimates from existing plaintiffs as settlement negotiations continue. SDG&E has established reserves for the wildfire litigation as we discuss below.
	SDG&E's settled claims and defense costs have exceeded its $1.1 billion of liability insurance coverage for the covered period and the $824 million recovered from third parties. It expects that its wildfire reserves and amounts paid to resolve wildfire claims will continue to increase as it obtains additional information.
	As we discuss in Note 14, SDG&E has concluded that it is probable that it will be permitted to recover in rates a substantial portion of its reasonably incurred costs of resolving wildfire claims in excess of its liability insurance coverage and the amounts recovered from third parties. Accordingly, although such recovery will require future regulatory approval, at December 31, 2013, Sempra Energy and SDG&E have recorded assets of $330 million in Other Regulatory Assets on their Consolidated Balance Sheets, including $315 million related to CPUC-regulated operations, which represents the amount substantially equal to the aggregate amount it has paid or reserved for payment for the resolution of wildfire claims and related costs in excess of its liability insurance coverage and amounts recovered from third parties. SDG&E will increase the regulatory assets if the estimate of amounts to settle remaining claims increases.
	SDG&E will continue to assess the probability of recovery of these excess wildfire costs in rates. 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 related to CPUC-regulated operations was no longer probable or was less than currently estimated at December 31, 2013, the resulting after-tax charge against earnings would have been up to $186 million. In addition, in periods following any such conclusion, SDG&E's earnings will be adversely impacted by increases in the estimated cost to litigate or settle pending wildfire claims. 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 regulatory assets in Note 1.
	SDG&E's cash flow may be materially adversely affected due to the timing differences between the resolution of claims and the recoveries in rates, which may extend over a number of years. Also, recovery from customers will require future regulatory actions, and a failure to obtain substantial or full recovery, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy's and SDG&E's businesses, financial condition, cash flows, results of operations and prospects.
	SDG&E will continue to gather information to evaluate and assess the remaining wildfire claims and the likelihood, amount and timing of related recoveries in rates and will make appropriate adjustments to wildfire reserves and the related regulatory assets as additional information becomes available.
	Since 2010, as liabilities for wildfire litigation have become reasonably estimable in the form of settlement demands, damage estimates and other damage information, SDG&E has recorded related reserves as a liability. The impact of this liability at December 31, 2013 is offset by the recognition of regulatory assets, as discussed above, for reserves in excess of the insurance coverage and recoveries from third parties. The impact of the reserves on SDG&E's and Sempra Energy's after-tax earnings was an increase (decrease) of $0.3 million, $(6) million and $(13) million for the years ended December 31, 2013, 2012 and 2011, respectively. At December 31, 2013, wildfire litigation reserves were $104 million ($63 million in current and $41 million in long-term). Additionally, through December 31, 2013, SDG&E has expended $344 million (cumulative, excluding amounts covered by insurance and amounts recovered from third parties) to pay for the settlement of wildfire claims and related costs.
	Sunrise Powerlink Electric Transmission Line
	The Sunrise Powerlink is a 117-mile, 500-kV electric transmission line between the Imperial Valley and the San Diego region that was energized and placed in service in June 2012. The Sunrise Powerlink project was approved by the CPUC in December 2008, the BLM in January 2009, and the USFS in July 2010. Numerous administrative appeals and legal challenges have been resolved in favor of the project. One legal challenge remains pending.
	In February 2011, opponents of the Sunrise Powerlink 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 have appealed.
	A claim for additional compensation has been submitted by one of SDG&E's contractors on the Sunrise Powerlink project. The contractor was awarded the transmission line overhead and underground construction contract on a fixed-fee basis of $456 million after agreed-upon amendments. The contractor has asserted that it is owed additional compensation above the fixed-fee portion of the contract. In May 2013, the contractor filed claims totaling $180.3 million, including one in San Diego County for the sum of $99.2 million and the other in Imperial County for the sum of $81.1 million, seeking foreclosure of previously filed Mechanics Liens. In October 2013, the contractor served a Demand for Arbitration pursuant to contractual provisions. SDG&E has answered the demand and filed a counter claim against the contractor. The arbitration panel has set a March 2015 arbitration hearing date.
	September 2011 Power Outage
	In September 2011, a power outage lasting approximately 12 hours affected millions of people from Mexico to southern Orange County, California. Within several days of the outage, several SDG&E customers filed a class action lawsuit in Federal District Court in San Diego against Arizona Public Service Company, Pinnacle West Capital Corporation, and SDG&E alleging that the companies failed to prevent the outage. The lawsuit seeks recovery of unspecified amounts of damages, including punitive damages. In July 2012, the court granted SDG&E's motion to dismiss the punitive damages request and dismissed Arizona Public Service Company and Pinnacle West Capital Corporation from the lawsuit. In September 2013, the court granted SDG&E's motion for summary judgment and dismissed the lawsuit. In October 2013, the plaintiffs appealed the court's dismissal of their action.
	FERC and North American Electric Reliability Corporation (NERC) Staff conducted a joint inquiry to determine the cause of the power failure and issued a report in May 2012 regarding their findings. Following that report, Staff from FERC's Office of Enforcement (FERC Enforcement Staff) investigated potential violations of FERC's Reliability Standards associated with the outage. In January 2014, FERC Enforcement Staff issued a Staff Notice of Alleged Violations, in which FERC Enforcement Staff alleged violations of various Reliability Standards by several entities. FERC Enforcement Staff did not allege or find any violations by SDG&E.
	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, 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.
	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 representations 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 arising 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 answered and filed a counter-claim against Edison.
	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. SDG&E's contractual obligations to invest in the Rim Rock wind farm and to purchase renewable energy credits from the wind farm under the power purchase agreement are both subject to the satisfaction of certain conditions which, if not achieved, would allow SDG&E to terminate the power purchase agreement and to 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. The project developer filed a separate complaint against SDG&E in Montana state court.
	SoCalGas
	SoCalGas, along with Monsanto Co., Solutia, Inc., Pharmacia Corp., and Pfizer, Inc., are defendants in seven Los Angeles County Superior Court lawsuits filed beginning in 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 other 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 negligence and products liability. SoCalGas has settled three of the seven lawsuits for an amount that is not significant and has been recorded.
	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. 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 asserted 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 then new Ensenada Mayor attempted 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 terminal permits or operations were affected as a result of these proceedings or events and the terminal has continued to operate normally. Sempra Mexico expects additional Mexican court proceedings and governmental actions regarding the claimant's assertions as to whether the terminal's permits should be modified or revoked in any manner.
	The claimant filed complaints in the federal Agrarian Court challenging the refusal of the Secretaría Reforma Agraria (now the Secretaría de Desarrollo Agrario, Territorial y Urbano, or SEDATU) in 2006 to issue a title to him for the disputed property. In November 2013, the Agrarian Court ordered that SEDATU issue the requested title and cause it to be registered. Both SEDATU and Sempra Mexico have challenged the rulings. Sempra Mexico expects additional proceedings regarding the claims, although such proceedings are not related to the permit challenges referenced above. The property claimant also filed a lawsuit in July 2010 against Sempra Energy in Federal District Court in San Diego seeking compensatory and punitive damages as well as the earnings from the Energía Costa Azul LNG terminal based on his allegations that he was wrongfully evicted from the adjacent property and that he has been harmed by other allegedly improper actions.
	Additionally, several administrative challenges are pending in Mexico before the Mexican environmental protection agency (SEMARNAT) and/or the Federal Tax and Administrative Courts seeking revocation of the environmental impact authorization (EIA) issued to Energía Costa Azul in 2003. These cases generally allege that the conditions and mitigation measures in the EIA are inadequate and challenge findings that the activities of the terminal are consistent with regional development guidelines. The Mexican Supreme Court decided to exercise jurisdiction over one such case, and on February 7, 2014, announced that it would decline to grant the relief sought by the plaintiff. Sempra Mexico expects the Court to issue a written resolution in the first quarter of 2014 providing further details regarding its ruling. A similar administrative challenge seeking to revoke the port concession for our marine operations at our Energía Costa Azul LNG terminal, which was filed with and rejected by the Mexican Communications and Transportation Ministry, remains on appeal in Mexican federal court as well.
	There are two real property cases pending against Energía Costa Azul in which the plaintiffs seek to annul the recorded property titles for parcels on which the Energía Costa Azul LNG terminal is situated and to obtain possession of different parcels that allegedly sit in the same place; one of these cases was dismissed in September 2013 at the direction of the state appellate court. A third complaint was served in April 2013 seeking to invalidate the contract by which Energía Costa Azul, S. de R.L. de C.V. purchased another of the terminal parcels, on the grounds the purchase price was unfair. Sempra Mexico expects further proceedings on each of these matters, except for the real property case that was dismissed.
	Property Title Dispute (Dismissed)
	In July 2012, a Mexicali state court issued a ruling declaring the purchase contract by which Termoeléctrica de Mexicali acquired the property on which the facility is located to be invalid, on the grounds that the proceeding in which the seller acquired title was invalid. In June 2013, an appellate court overturned the lower court ruling, and the case was subsequently dismissed.
	Competitor Claims (Dismissed)
	In October 2012, a competitor for one of the two contracts awarded by the Mexican Federal Electricity Commission (Comisión Federal de Electricidad, or CFE) for the construction and operation of a natural gas pipeline in Sonora filed an amparo in the Mexican federal district court in Mexico City, challenging the tender process and the award to us. The competitor, a subsidiary of Fermaca, Sásabe Pipeline, S. de R.L. de C.V., filed suit against 11 different governmental authorities, including the CFE, the President of Mexico, and the Mexican Energy Ministry. Sásabe Pipeline, which was the second-place bidder, alleges CFE discriminated against it in the bidding process, including by failing to accept its comments on the bid guidelines. In February 2013, we were notified that Guaymas Pipeline S. de R. L. de C.V., another subsidiary of Fermaca, filed another, similar amparo challenging the process by which the second of the two contracts was awarded, although it did not submit a bid for the project. Both cases were dismissed in April 2013.
	Sempra Natural Gas
	Liberty Gas Storage, LLC (Liberty) received a demand for arbitration from Williams Midstream Natural Gas Liquids, Inc. (Williams) in February 2011 related to a sublease agreement. Williams alleges that Liberty was negligent in its attempt to convert certain salt caverns to natural gas storage and seeks damages of $56.7 million. Liberty filed a counterclaim alleging breach of contract in the inducement and seeks damages of more than $215 million.
	Other Litigation
	As described in Note 4, we hold a noncontrolling interest in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. In March 2012, RBS received a letter from the United Kingdom's Revenue and Customs Department (HMRC) regarding a value-added-tax (VAT) matter related to RBS Sempra Energy Europe (RBS SEE), a former indirect subsidiary of RBS Sempra Commodities that was sold to JP Morgan. The letter states that HMRC is conducting a number of investigations into VAT tax refund claims made by various businesses related to the purchase and sale of carbon credit allowances. The letter also states that HMRC believes it has grounds to deny RBS the ability to reduce its VAT liability by VAT paid during 2009 because it knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. In September 2012, HMRC issued an assessment of £86 million for the VAT paid in connection with these transactions and identified several options for responding, including requesting a review by HMRC and appealing to an independent tribunal. HMRC indicated that the assessment was issued on a protective basis as discussion about the issues is continuing.
	In August 2007, the U.S. Court of Appeals for the Ninth Circuit issued a decision reversing and remanding certain FERC orders declining to provide refunds regarding short-term bilateral sales up to one month in the Pacific Northwest for the January 2000 to June 2001 time period. In December 2010, the FERC approved a comprehensive settlement previously reached by Sempra Energy and RBS Sempra Commodities with the State of California. The settlement resolves all issues with regard to sales between the California Department of Water Resources and Sempra Commodities in the Pacific Northwest, but potential claims may exist regarding sales in the Pacific Northwest between Sempra Commodities and other parties. The FERC is in the process of addressing these potential claims on remand. Pursuant to the agreements related to the formation of RBS Sempra Commodities, we have indemnified RBS should the liability from the final resolution of these matters be greater than the reserves related to Sempra Commodities. Pursuant to our agreement with the Noble Group Ltd., one of the buyers of RBS Sempra Commodities' businesses, we have also indemnified Noble Americas Gas & Power Corp. and its affiliates for all losses incurred by such parties resulting from these proceedings as related to Sempra Commodities.
	We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, product liability, property damage and other claims. California juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases.
	CONTRACTUAL COMMITMENTS
	Natural Gas Contracts
	Natural Gas
	SoCalGas has the responsibility for procuring natural gas for both SDG&E's and SoCalGas' core customers in a combined portfolio. SoCalGas buys natural gas under short-term and long-term contracts for this portfolio. Purchases are from various producing regions in the southwestern U.S., U.S. Rockies, and Canada and are primarily based on published monthly bid-week indices.
	SoCalGas transports natural gas primarily under long-term firm interstate pipeline capacity agreements that provide for annual reservation charges, which are recovered in rates. SoCalGas has commitments with interstate pipeline companies for firm pipeline capacity under contracts that expire at various dates through 2028.
	Sempra Natural Gas' and Sempra Mexico's businesses have various natural gas purchase agreements to fuel natural gas-fired power plants and capacity agreements for natural gas storage and transportation.
	Sempra Rockies Marketing, a subsidiary of Sempra Natural Gas, has an agreement for capacity on the Rockies Express Pipeline through November 2019, as we discuss in Note 4. Historically, the capacity costs have been more than offset by revenues from releases of the capacity. However, certain capacity release commitments concluded during 2013 and new contracting activity related to that capacity may not be sufficient to offset all of our capacity commitments. Including capacity released to others, Sempra Rockies Marketing's obligation to Rockies Express Pipeline LLC for future capacity payments are expected to be $14 million each year in 2014 through 2017, $33 million in 2018 and $50 million in 2019.
	At December 31, 2013, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts were
	Sempra Energy Consolidated
			Storage and
(Dollars in millions)		Transportation		Natural Gas(1)		Total(1)
2014		$	242	$	162	$	404
2015			239		4		243
2016			226		4		230
2017			220		4		224
2018			202		4		206
Thereafter			361		16		377
Total minimum payments		$	1,490	$	194	$	1,684
-1	Excludes amounts related to LNG purchase agreements as discussed below.
SoCalGas
(Dollars in millions)	Transportation		Natural Gas		Total
2014	$	126	$	57	$	183
2015		120		1		121
2016		111		1		112
2017		107		1		108
2018		89		1		90
Thereafter		157		―		157
Total minimum payments	$	710	$	61	$	771
Total payments under natural gas contracts and natural gas storage and transportation contracts as well as payments to meet additional portfolio needs at SoCalGas were:
	Years ended December 31,
(Dollars in millions)	2013		2012		2011
Sempra Energy Consolidated	$	1,680	$	1,345	$	1,991
SoCalGas		1,464		1,222		1,810
LNG
Sempra Natural Gas has various purchase agreements with major international companies for the supply of LNG to the Energía Costa Azul and Cameron terminals. The agreements range from short-term to multi-year periods and are priced using a predetermined formula based on natural gas market indices.
Although these contracts specify a number of cargoes to be delivered, under their terms, customers may divert certain cargoes, which would reduce amounts paid under the contracts by Sempra Natural Gas. As of December 31, 2013, if all cargoes under the contracts were to be delivered, future payments under these contracts would be
$670 million in 2014
$662 million in 2015
$654 million in 2016
$658 million in 2017
$678 million in 2018
$8.3 billion in 2019 – 2029
The amounts above are based on forward prices of the index applicable to each contract from 2014 to 2023 and an estimated one percent escalation per year beyond 2023. The LNG commitment amounts above are based on Sempra Natural Gas' commitment to accept the maximum possible delivery of cargoes under the agreements. Actual LNG purchases in 2013, 2012 and 2011 have been significantly lower than the maximum amount possible due to customers electing to divert most cargoes as allowed by the agreements.
Purchased-Power Contracts
For 2014, SDG&E expects to meet its customer power requirements from the following resource types:
Long-term contracts: 31 percent (of which 25.4 percent is provided by renewable energy contracts expiring on various dates through 2039)
SDG&E-owned generation (including Palomar Energy Center, Miramar Energy Center, Desert Star Energy Center and Cuyamaca Peak Energy Plant) and tolling contracts (including OMEC): 55 percent
Spot market purchases: 14 percent
Chilquinta Energía and Luz del Sur also have purchased-power contracts, expiring on various dates extending through 2027, which cover most of the consumption needs of the companies' customers. These commitments are included under Sempra Energy Consolidated in the table below.
At December 31, 2013, the estimated future minimum payments under long-term purchased-power contracts were:
		Sempra
		Energy
(Dollars in millions)		Consolidated		SDG&E
2014		$	1,328	$	471
2015			1,473		543
2016			1,487		524
2017			1,494		517
2018			1,483		488
Thereafter			11,826		6,349
Total minimum payments(1)		$	19,091	$	8,892
-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.
Payments on these contracts represent capacity charges and minimum energy purchases. SDG&E is required to pay additional amounts for actual purchases of energy that exceed the minimum energy commitments. Excluding DWR-allocated contracts, total payments under purchased-power contracts were:
	Years ended December 31,
(Dollars in millions)	2013		2012		2011
Sempra Energy Consolidated	$	1,377	$	1,205	$	918
SDG&E		570		381		346
Operating Leases
Sempra Energy Consolidated, SDG&E and SoCalGas have operating leases on real and personal property expiring at various dates from 2014 through 2054. Certain leases on office facilities contain escalation clauses requiring annual increases in rent ranging from two percent to six percent at Sempra Energy Consolidated, four percent to six percent at SDG&E, and two percent to five percent at SoCalGas. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year, and most leases contain extension options that we could exercise.
The California Utilities have an operating lease agreement for future acquisitions of fleet vehicles with RBS Asset Finance, Inc. with an aggregate maximum lease limit of $125 million, $113 million of which has been utilized as of December 31, 2013.
Rent expense for all operating leases totaled
	Years ended December 31,
(Dollars in millions)	2013		2012		2011
Sempra Energy Consolidated	$	81	$	74	$	77
SDG&E		23		20		18
SoCalGas		31		26		35
At December 31, 2013, the minimum rental commitments payable in future years under all noncancelable operating leases were as follows:
	Sempra
	Energy
(Dollars in millions)	Consolidated		SDG&E		SoCalGas
2014	$	85	$	23	$	32
2015		83		22		32
2016		71		22		25
2017		74		20		30
2018		69		17		28
Thereafter		576		91		174
Total future rental commitments	$	958	$	195	$	321
Capital Leases
Utility Fleet Vehicles
The California Utilities entered into agreements with U.S. Bancorp Equipment Finance in 2009 and with RBS Asset Finance, Inc. in 2010 to refinance existing fleet vehicles. These are capital leases, and as of December 31, 2013, the related capital lease obligations were $5 million at Sempra Energy Consolidated, including $3 million at SDG&E and $2 million at SoCalGas. As of December 31, 2012, the related capital lease obligations were $11 million at Sempra Energy Consolidated, including $7 million at SDG&E and $4 million at SoCalGas.
At December 31, 2013, the future minimum lease payments and present value of the net minimum lease payments under these capital leases are as follows:
		Sempra
		Energy
(Dollars in millions)		Consolidated		SDG&E		SoCalGas
2014		$	4	$	2	$	2
2015			1		1		―
Total minimum lease payments		$	5	$	3	$	2
Present value of net minimum lease payments(1)		$	5	$	3	$	2
-1	Excludes negligible amounts of interest.
The 2013 annual amortization charge for the utility fleet vehicles was $7 million at Sempra Energy Consolidated, including $4 million at SDG&E and $3 million at SoCalGas. The 2012 annual amortization charge for the utility fleet vehicles was $13 million at Sempra Energy Consolidated, including $7 million at SDG&E and $6 million at SoCalGas. The 2011 annual amortization charge for the utility fleet vehicles was $15 million at Sempra Energy Consolidated, including $7 million at SDG&E and $8 million at SoCalGas.
Headquarters Build-to-Suit Lease
In August 2013, Sempra Energy entered into a 25-year, build-to-suit lease for its future San Diego, California, headquarters. We expect to occupy the building in the second half of 2015. At December 31, 2013, future payments on the lease are as follows:
(Dollars in millions)
2014	$	―
2015		4
2016		10
2017		10
2018		10
Thereafter		277
Total future payments	$	311
Power Purchase Agreements
SDG&E has two power purchase agreements with peaker plant facilities that went into commercial operation in June 2010 and are accounted for as capital leases. The entities that own the peaker plant facilities are VIEs of which SDG&E is not the primary beneficiary. As of December 31, 2013, capital lease obligations for these leases, each with a 25-year term, were valued at $176 million. SDG&E does not have any additional implicit or explicit financial responsibility related to these VIEs.
At December 31, 2013, the future minimum lease payments and present value of the net minimum lease payments under these capital leases for both Sempra Energy Consolidated and SDG&E were as follows:
(Dollars in millions)
	2014	$	24
	2015		24
	2016		24
	2017		24
	2018		24
	Thereafter		394
	Total minimum lease payments(1)		514
	Less: estimated executory costs		-84
	Less: interest(2)		-254
	Present value of net minimum lease payments(3)	$	176
-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.
-2	Amount necessary to reduce net minimum lease payments to present value at the inception of the leases.
-3	Includes $3 million in Current Portion of Long-Term Debt and $173 million in Long-Term Debt on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets at December 31, 2013.
The annual amortization charge for the power purchase agreements was $2 million in 2013, 2012, and 2011.
Construction and Development Projects
Sempra Energy Consolidated has various capital projects in progress in the United States, Mexico and South America. Sempra Energy's total commitments under these projects are $2 billion, requiring future payments of $1.3 billion in 2014, $393 million in 2015, $116 million in 2016, $112 million in 2017, $24 million in 2018 and $47 million thereafter. The following is a summary by segment of contractual commitments and contingencies related to the construction projects.
SDG&E
At December 31, 2013, SDG&E has commitments to make future payments of $332 million for construction projects that include
$87 million for the engineering, material procurement and construction costs associated with the East County Substation project;
$132 million related to nuclear fuel fabrication and other construction projects at SONGS; and
$113 million for infrastructure improvements for natural gas and electric transmission and distribution operations.
SDG&E expects future payments under these contractual commitments to be $177 million in 2014, $32 million in 2015, $28 million in 2016, $27 million in 2017, $23 million in 2018 and $45 million thereafter.
SoCalGas
At December 31, 2013, SoCalGas has commitments to make future payments of $442 million for construction and infrastructure improvements for natural gas transmission and distribution operations and pipeline integrity. The future payments under these contractual commitments are expected to be $190 million in 2014 and $84 million each year in 2015 through 2017.
Sempra South American Utilities
At December 31, 2013, Sempra South American Utilities has commitments to make future payments of $27 million for construction projects that include $15 million for the construction of the Santa Teresa hydroelectric power plant at Luz del Sur. The future payments under these contractual commitments are all expected to be in 2014.
Sempra Mexico
At December 31, 2013, Sempra Mexico has commitments to make future payments of $631 million for contracts related to the construction of an approximately 500-mile natural gas transport pipeline network and the Energía Sierra Juárez wind project. The future payments under these contractual commitments are expected to be $391 million in 2014, $236 million in 2015, $3 million in 2016, negligible amounts in 2017 and 2018 and $1 million thereafter.
Sempra Renewables
At December 31, 2013, Sempra Renewables has commitments to make future payments of $569 million for the construction of the Copper Mountain Solar 3 and Broken Bow 2 facilities. The future payments under these contractual commitments are expected to be $524 million in 2014, $41 million in 2015, $1 million each year in 2016 through 2018 and $1 million thereafter.
Sempra Natural Gas
At December 31, 2013, Sempra Natural Gas has commitments to make future payments of $8 million primarily for natural gas storage projects. The future payments under these contractual commitments are all expected to be in 2014.
GUARANTEES
At December 31, 2013, Sempra Renewables has provided guarantees to its solar and wind farm joint ventures aggregating a maximum of $165 million with an associated aggregated carrying value of $2 million, primarily related to purchased-power agreements and engineering, procurement and construction contracts. In addition, Sempra Renewables has provided guarantees aggregating a maximum of $328 million with an associated aggregated carrying value of $17 million at December 31, 2013 to certain wind farm joint ventures for debt service and operation of the wind farms, which we discuss in Note 5.
As of December 31, 2013, SDG&E and SoCalGas did not have any outstanding guarantees.
OTHER COMMITMENTS
SDG&E
In connection with the completion of the Sunrise Powerlink project, the CPUC required that SDG&E establish a fire mitigation fund to minimize the risk of fire as well as reduce the potential wildfire impact on residences and structures near the Sunrise Powerlink. The future payments for these contractual commitments are expected to be approximately $3 million per year, subject to escalation of 2 percent per year, for 58 years. At December 31, 2013, the present value of these future payments of $115 million has been recorded as a regulatory asset as the amounts represent a cost that will be recovered from customers in the future, and the related liability was $115 million.
In July 2012, SDG&E received $85 million from Citizens Sunrise Transmission, LLC (Citizens), a subsidiary of Citizens Energy Corporation. For this payment, under the terms of the agreement with Citizens, SDG&E will provide Citizens with access to a segment of the Sunrise Powerlink transmission line known as the Border-East transmission line equal to 50 percent of the transfer capacity of this portion of the line for a period of 30 years. After the 30-year contract term, the transfer capability will revert to SDG&E. SDG&E will amortize deferred revenues from the use of the transfer capability over the 30-year term, and depreciation for 50 percent of the Border-East transmission line segment will be accelerated from an estimated 58-year life to 30 years.
We discuss reserves at Sempra Energy and SDG&E for wildfire litigation above in “Legal Proceedings – SDG&E – 2007 Wildfire Litigation.”
Sempra Natural Gas
In February 2013, Sempra Natural Gas entered into a long-term operations and maintenance agreement for its remaining block of the Mesquite Power natural gas-fired power plant, which expires in 2033. The total cost associated with this agreement is estimated to be approximately $35 million. The future payments for this contractual commitment are expected to be $2 million each year in 2014 through 2018 and $25 million thereafter. We provide additional information about Mesquite Power in Notes 3 and 18.
Additional consideration for a 2006 comprehensive legal settlement with the State of California to resolve the Continental Forge litigation included an agreement that, for a period of 18 years beginning in 2011, Sempra Natural Gas would sell to the California Utilities, subject to annual CPUC approval, up to 500 million cubic feet (MMcf) per day of regasified LNG from Sempra Mexico's Energía Costa Azul facility that is not delivered or sold in Mexico at the California border index minus $0.02 per MMBtu. There are no specified minimums required, and to date, we have not been required to deliver any natural gas pursuant to this agreement.
ENVIRONMENTAL ISSUES
Our operations are subject to federal, state and local environmental laws. We also are subject to regulations related to hazardous wastes, air and water quality, land use, solid waste disposal and the protection of wildlife. These laws and regulations require that we investigate and correct the effects of the release or disposal of materials at sites associated with our past and our present operations. These sites include those at which we have been identified as a Potentially Responsible Party (PRP) under the federal Superfund laws and similar state laws.
In addition, we are required to obtain numerous governmental permits, licenses and other approvals to construct facilities and operate our businesses. The related costs of environmental monitoring, pollution control equipment, cleanup costs, and emissions fees are significant. Increasing national and international concerns regarding global warming and mercury, carbon dioxide, nitrogen oxide and sulfur dioxide emissions could result in requirements for additional pollution control equipment or significant emissions fees or taxes that could adversely affect Sempra Natural Gas and Sempra Mexico. The California Utilities' costs to operate their facilities in compliance with these laws and regulations generally have been recovered in customer rates.
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. The following table shows (in millions) our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations:
		Years ended December 31,
		2013		2012		2011
Sempra Energy Consolidated(1)		$	31	$	92	$	144
SDG&E			13		77		130
SoCalGas			15		12		13
-1	In cases of non-wholly owned affiliates, includes only our share.
Fluctuations at SDG&E and Sempra Energy Consolidated from 2011 to 2012 and 2012 to 2013 were primarily due to mitigation activities on the Sunrise Powerlink project, which was placed into service in June 2012. We have not identified any significant environmental issues outside the United States.
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.
The environmental issues currently facing us or resolved during the last three years include (1) investigation and remediation of the California Utilities' manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by the California Utilities at sites for which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS. The requirements for enhanced fish protection and restoration of 150 acres of coastal wetlands for the SONGS mitigation are in process and include a 150-acre artificial reef that was dedicated in 2008 and continues in process to meet California Coastal Commission acceptance requirements. The table below shows the status at December 31, 2013, of the California Utilities' manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP:
		# Sites		# Sites
		Completed(1)		In Process
SDG&E
Manufactured-gas sites			3		―
Third-party waste-disposal sites			2		3
SoCalGas
Manufactured-gas sites			39		3
Third-party waste-disposal sites			5		1
-1	There may be on-going compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.
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 engineering evaluations. We review our accruals periodically and, as investigations and cleanup proceed, we make adjustments as necessary. The following table shows (in millions) our accrued liabilities for environmental matters at December 31, 2013:
				Waste		Former Fossil-		Other
		Manufactured-		Disposal		Fueled Power		Hazardous
		Gas Sites		Sites (PRP)(1)		Plants		Waste Sites		Total
SDG&E(2)(3)		$	―	$	―	$	5.2	$	0.4	$	5.6
SoCalGas(3)			14.7		0.2		―		0.2		15.1
Other			2.2		1.2		―		0.8		4.2
Total Sempra Energy		$	16.9	$	1.4	$	5.2	$	1.4	$	24.9
-1	Sites for which we have been identified as a Potentially Responsible Party.
-2	Does not include SDG&E’s liability for SONGS marine mitigation.
-3	This includes $5.5 million at SDG&E and $15.1 million at SoCalGas related to hazardous waste sites subject to the Hazardous Waste Collaborative mechanism approved by the CPUC in 1994. This mechanism permits California’s IOUs, including the California Utilities, to recover in rates 90 percent of hazardous waste cleanup costs and related third-party litigation costs, and 70 percent of the related insurance-litigation expenses for certain sites. In addition, the California Utilities have the opportunity to retain a percentage of any recoveries from insurance carriers and other third parties to offset the cleanup and associated litigation costs not recovered in rates.
We expect to pay the majority of these accruals over the next three years. In connection with the issuance of operating permits, SDG&E and the other owners of SONGS previously reached an agreement with the California Coastal Commission to mitigate the damage to the marine environment caused by the cooling-water discharge from SONGS during its operation. SONGS' early retirement, described in Note 13, does not reduce SDG&E's mitigation obligation. At December 31, 2013, SDG&E's share of the estimated mitigation costs remaining to be spent through 2050 is $14 million, which is recoverable in rates.
We discuss renewable energy requirements in Note 14 and greenhouse gas regulation in Note 1.
NUCLEAR INSURANCE
SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. This insurance provides $375 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides for up to $13.2 billion of secondary financial protection (SFP). If a nuclear liability loss occurring at any U.S. licensed/commercial reactor exceeds the $375 million insurance limit, all nuclear reactor owners could be required to contribute to the SFP. SDG&E's contribution would be up to $50.93 million. This amount is subject to an annual maximum of $7.6 million, unless a default occurs by any other SONGS owner. If the SFP is insufficient to cover the liability loss, SDG&E could be subject to an additional assessment.
The SONGS owners, including SDG&E, also have $2.75 billion of nuclear property, decontamination, and debris removal insurance, subject to a $2.5 million deductible for “each and every loss.” This insurance coverage is provided through Nuclear Electric Insurance Limited (NEIL), a mutual insurance company. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $9.7 million of retrospective premiums based on overall member claims. Edison, on behalf of itself and the minority owners of SONGS (including SDG&E), has placed NEIL on notice of claims under both the property damage and outage insurance policies as a result of SONGS' Units 2 and 3 being shut down since early 2012.
The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act). The industry aggregate loss limit for property claims arising from non-certified acts of terrorism is $3.24 billion. This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.
We provide additional information about SONGS in Note 13.
DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL
The Nuclear Waste Policy Act of 1982 made the DOE responsible for the disposal of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. This cost will be recovered through SONGS revenue unless SDG&E is able to recover the increased cost from the federal government.
In June 2010, the United States Court of Federal Claims issued a decision granting Edison and the SONGS co-owners damages of approximately $142 million to recover costs incurred through December 31, 2005 for the DOE's failure to meet its obligation to begin accepting spent nuclear fuel from SONGS. Edison received payment from the federal government in the amount of the damage award in November 2011. In January 2012, Edison refunded SDG&E $28 million for its respective share of the damage award paid. SDG&E recorded a $10 million reduction of nuclear power expenses, a $15 million reduction of its nuclear decommissioning balancing account and a $3 million reduction in nuclear plant. Edison, as operating agent, filed a lawsuit against the DOE in the Court of Federal Claims in December 2011 seeking damages for the period from January 1, 2006 to December 31, 2010 for the DOE's failure to meet its obligation to begin accepting spent nuclear fuel. Additional legal action would be necessary to recover damages incurred after December 31, 2010.
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 all 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 customers 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, Sempra 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 consider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects.

SEGMENT_INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2013
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 operates electric transmission and distribution utilities in Chile and Peru. In June 2013, we sold our interests in two Argentine utilities, which we discuss further in Note 4 above.
	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 wind), 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, California, Colorado, Hawaii, Indiana, Kansas, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States.
	Sempra Natural Gas develops, owns and operates, or holds interests in, a natural gas-fired electric generation asset, 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 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 directly 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.
	Sempra Natural Gas' sales to the DWR, under a 10-year contract that expired September 30, 2011, comprised 6 percent of our revenues in 2011.
	The following tables show 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 consist primarily of parent organizations and the former commodities-marketing businesses of RBS Sempra Commodities, as we discuss in Note 4.
	SEGMENT INFORMATION
	(Dollars in millions)
		Years ended December 31,
		2013				2012				2011
	REVENUES
	SDG&E	$	4,066	39	%	$	3,694	38	%	$	3,373	34	%
	SoCalGas		3,736	35			3,282	34			3,816	38
	Sempra South American Utilities		1,495	14			1,441	15			1,080	11
	Sempra Mexico		675	6			605	6			736	7
	Sempra Renewables		82	1			68	1			22	―
	Sempra Natural Gas		908	9			931	10			1,632	16
	Adjustments and eliminations		-2	―			-2	―			-2	―
	Intersegment revenues(1)		-403	-4			-372	-4			-621	-6
	Total	$	10,557	100	%	$	9,647	100	%	$	10,036	100	%
	INTEREST EXPENSE
	SDG&E	$	197			$	173			$	142
	SoCalGas		69				68				69
	Sempra South American Utilities		27				32				34
	Sempra Mexico		17				8				19
	Sempra Renewables		23				22				13
	Sempra Natural Gas		116				98				80
	All other		241				251				233
	Intercompany eliminations		-131				-159				-125
	Total	$	559			$	493			$	465
	INTEREST INCOME
	SDG&E	$	1			$	―			$	―
	SoCalGas		―				―				1
	Sempra South American Utilities		14				15				22
	Sempra Mexico		2				2				1
	Sempra Renewables		20				6				―
	Sempra Natural Gas		88				55				34
	All other		―				4				―
	Intercompany eliminations		-105				-58				-32
	Total	$	20			$	24			$	26
	DEPRECIATION AND AMORTIZATION
	SDG&E	$	494	44	%	$	490	45	%	$	422	43	%
	SoCalGas		383	35			362	33			331	34
	Sempra South American Utilities		59	5			56	5			40	4
	Sempra Mexico		63	6			62	6			63	6
	Sempra Renewables		21	2			16	1			6	1
	Sempra Natural Gas		81	7			93	9			103	11
	All other		12	1			11	1			11	1
	Total	$	1,113	100	%	$	1,090	100	%	$	976	100	%
	INCOME TAX EXPENSE (BENEFIT)
	SDG&E	$	191			$	190			$	237
	SoCalGas		116				79				143
	Sempra South American Utilities		67				78				42
	Sempra Mexico		60				73				37
	Sempra Renewables		-19				-63				-28
	Sempra Natural Gas		40				-157				72
All other		-89				-141				-109
Total	$	366			$	59			$	394
SEGMENT INFORMATION (Continued)
(Dollars in millions)
		At December 31 or for the years ended December 31,
		2013				2012				2011
EARNINGS (LOSSES)
SDG&E(2)		$	404	41	%	$	484	56	%	$	431	32	%
SoCalGas(3)			364	37			289	34			287	22
Sempra South American Utilities			153	15			164	19			425	32
Sempra Mexico			122	12			157	18			192	14
Sempra Renewables			62	6			61	7			7	1
Sempra Natural Gas			64	6			-241	-28			115	9
All other			-168	-17			-55	-6			-126	-10
Total		$	1,001	100	%	$	859	100	%	$	1,331	100	%
ASSETS
SDG&E		$	15,377	41	%	$	14,744	40	%	$	13,555	41	%
SoCalGas			9,147	25			9,071	25			8,475	25
Sempra South American Utilities			3,531	10			3,310	9			2,981	9
Sempra Mexico			3,246	9			2,591	7			2,502	8
Sempra Renewables			1,219	3			2,439	7			1,210	4
Sempra Natural Gas			7,200	19			5,145	14			5,738	17
All other			838	2			818	2			442	1
Intersegment receivables			-3,314	-9			-1,619	-4			-1,654	-5
Total		$	37,244	100	%	$	36,499	100	%	$	33,249	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	978	38	%	$	1,237	42	%	$	1,831	64	%
SoCalGas			762	30			639	22			683	24
Sempra South American Utilities			200	8			183	6			110	4
Sempra Mexico			371	14			45	2			16	―
Sempra Renewables			176	7			717	24			248	9
Sempra Natural Gas			83	3			131	4			157	6
All other			2	―			4	―			4	―
Intercompany eliminations(4)			―	―			―	―			-205	-7
Total		$	2,572	100	%	$	2,956	100	%	$	2,844	100	%
GEOGRAPHIC INFORMATION
Long-lived assets(5):
United States		$	22,654	84	%	$	22,698	85	%	$	21,405	85	%
Mexico			2,597	9			2,219	8			2,189	9
South America			1,784	7			1,790	7			1,542	6
Total		$	27,035	100	%	$	26,707	100	%	$	25,136	100	%
Revenues:
United States		$	8,478	80	%	$	7,711	80	%	$	8,521	85	%
South America			1,495	14			1,441	15			1,080	11
Mexico			584	6			495	5			435	4
Total		$	10,557	100	%	$	9,647	100	%	$	10,036	100	%
-1	Revenues for reportable segments include intersegment revenues of:
	$10 million, $70 million, $91 million and $232 million for 2013, $8 million, $46 million, $108 million and $210 million for 2012, and $6 million, $53 million, $300 million and $262 million for 2011 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
-2	After preferred dividends and 2013 call premium on preferred stock.
-3	After preferred dividends.
-4	Amount represents elimination of intercompany sale of El Dorado power plant (renamed Desert Star Energy Center) in 2011, by Sempra Natural Gas to SDG&E.
-5	Includes net property, plant and equipment and investments.

QUARTERLY_FINANCIAL_DATA

QUARTERLY FINANCIAL DATA	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Quarterly Financial Data	'
	NOTE 17. QUARTERLY FINANCIAL DATA (UNAUDITED)
	SEMPRA ENERGY
	(In millions, except per share amounts)
			Quarters ended
			31-Mar		30-Jun		30-Sep		31-Dec
	2013
	Revenues		$	2,650	$	2,651	$	2,551	$	2,705
	Expenses and other income		$	2,298	$	2,353	$	2,119	$	2,357
	Net income		$	178	$	267	$	323	$	320
	Earnings attributable to Sempra Energy		$	178	$	245	$	296	$	282
	Basic per-share amounts(1):
	Net income		$	0.73	$	1.1	$	1.32	$	1.31
	Earnings attributable to Sempra Energy		$	0.73	$	1	$	1.21	$	1.15
	Weighted average common shares outstanding			243.3		243.6		244.1		244.4
	Diluted per-share amounts(1):
	Net income		$	0.72	$	1.07	$	1.29	$	1.28
	Earnings attributable to Sempra Energy		$	0.72	$	0.98	$	1.19	$	1.13
	Weighted average common shares outstanding			247.5		248.5		249.3		249.9
	2012
	Revenues		$	2,383	$	2,089	$	2,507	$	2,668
	Expenses and other income		$	2,026	$	2,141	$	2,178	$	2,359
	Net income		$	251	$	74	$	290	$	305
	Earnings attributable to Sempra Energy		$	236	$	62	$	268	$	293
	Basic per-share amounts(1):
	Net income		$	1.04	$	0.31	$	1.2	$	1.26
	Earnings attributable to Sempra Energy		$	0.98	$	0.26	$	1.11	$	1.21
	Weighted average common shares outstanding			240.6		241.1		241.7		242
	Diluted per-share amounts(1):
	Net income		$	1.02	$	0.3	$	1.18	$	1.23
	Earnings attributable to Sempra Energy		$	0.97	$	0.25	$	1.09	$	1.18
	Weighted average common shares outstanding			243.8		246.3		245.8		247.6
	-1	Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.
	Revenues and Expenses and Other Income for each of the quarters in 2013 compared to 2012 were higher partly due to higher natural gas prices at SoCalGas.
	Revenues and Expenses and Other Income for the third quarter of 2013 were lower compared to the first, second and fourth quarters of 2013 due to a decrease in cost of natural gas.
	In the first and second quarters of 2013 compared to the same periods in 2012, increased Revenues included $68 million and $67 million, respectively, of higher authorized revenues from electric transmission at SDG&E. Also in the first and second quarters of 2013 compared to the same periods in 2012, Revenues and Expenses and Other Income included $46 million and $112 million, respectively, from higher cost of electric fuel and purchased power at SDG&E.
	In the first quarter of 2013, Expenses and Other Income were favorably impacted by $74 million and Net Income and Earnings Attributable to Sempra Energy were favorably impacted by $44 million due to the sale of one 625-MW block of the 1,250-MW Mesquite Power natural gas-fired power plant, as we discuss in Note 3.
	In the first quarter of 2013, Net Income and Earnings Attributable to Sempra Energy included $63 million income tax expense resulting from a corporate reorganization in connection with the IEnova stock offerings.
	In the second quarter of 2013, Revenues included $131 million and Net Income and Earnings Attributable to Sempra Energy included $106 million favorable impacts from the retroactive application of the 2012 GRC for the period from January 2012 to March 2013 at the California Utilities.
	In the second quarter of 2013, Expenses and Other Income were negatively impacted by $200 million and Net Income and Earnings Attributable to Sempra Energy were negatively impacted by $119 million due to the early retirement of SONGS, as we discuss in Note 13.
	In the second quarter of 2012, Expenses and Other Income were negatively impacted by $300 million and Net Income and Earnings Attributable to Sempra Energy were negatively impacted by $179 million from an impairment charge to write down our investment in Rockies Express, as we discuss in Note 4. In the third quarter of 2012, Expenses and Other Income were negatively impacted by $100 million and Net Income and Earnings Attributable to Sempra Energy were negatively impacted by $60 million from an impairment to further write down our investment in Rockies Express.
	In the second quarter of 2012, Net Income and Earnings Attributable to Sempra Energy were impacted by a $54 million income tax benefit primarily associated with the decision to hold life insurance contracts that are kept in support of certain benefit plans to term.
	We discuss quarterly fluctuations related to SDG&E and SoCalGas below.
	SDG&E
	(Dollars in millions)
		Quarters ended
		31-Mar		30-Jun		30-Sep		31-Dec
	2013
	Operating revenues	$	939	$	1,064	$	1,063	$	1,000
	Operating expenses		771		939		800		774
	Operating income	$	168	$	125	$	263	$	226
	Net income	$	81	$	73	$	139	$	142
	Losses (earnings) attributable to noncontrolling interest		11		-7		-5		-23
	Earnings		92		66		134		119
	Call premium on preferred stock		―		―		-3		―
	Dividends on preferred stock		-1		-1		-2		―
	Earnings attributable to common shares	$	91	$	65	$	129	$	119
	2012
	Operating revenues	$	834	$	780	$	1,092	$	988
	Operating expenses		656		611		822		796
	Operating income	$	178	$	169	$	270	$	192
	Net income	$	112	$	101	$	188	$	114
	Earnings attributable to noncontrolling interest		-6		-5		-12		-3
	Earnings		106		96		176		111
Dividends on preferred stock		-1		-1		-2		-1
Earnings attributable to common shares	$	105	$	95	$	174	$	110
Net Income and Earnings were negatively impacted by higher operating expenses due to the delay in the CPUC decision on the 2012 GRC until the second quarter of 2013.
In the first and second quarters of 2013 compared to the same periods in 2012, Operating Revenues for SDG&E included $68 million and $67 million, respectively, of higher authorized revenues from electric transmission, primarily related to placing the Sunrise Powerlink transmission line in service in June 2012.
In the first and second quarters of 2013 compared to the same periods in 2012, Operating Revenues and Operating Expenses for SDG&E included $46 million and $112 million, respectively, from higher cost of electric fuel and purchased power due to
$19 million and $94 million, respectively, from the incremental cost of renewable energy and increased cost of other purchased power primarily due to higher prices; and
$27 million and $18 million, respectively, of increases in the cost of power purchased to replace power scheduled to be generated and delivered to SDG&E from SONGS.
SDG&E's Operating Revenues in the second quarter of 2013 included $90 million and Net Income and Earnings included $69 million favorable impacts from the retroactive application of the 2012 GRC for the period from January 2012 to March 2013.
In the second quarter of 2013, Operating Expenses were negatively impacted by $200 million and Net Income and Earnings were negatively impacted by $119 million due to the early retirement of SONGS, as we discuss in Note 13.
In the third quarter of 2012, SDG&E's Net Income and Earnings were impacted by $33 million from a change in the income tax treatment of certain repairs expenditures that are capitalized for financial statement purposes ($22 million for the full year 2011 and $11 million for the first six months of 2012).
SOCALGAS
(Dollars in millions)
	Quarters ended
	31-Mar		30-Jun		30-Sep		31-Dec
2013
Operating revenues	$	983	$	904	$	807	$	1,042
Operating expenses		900		725		652		920
Operating income	$	83	$	179	$	155	$	122
Net income	$	46	$	119	$	102	$	98
Dividends on preferred stock		―		-1		―		―
Earnings attributable to common shares	$	46	$	118	$	102	$	98
2012
Operating revenues	$	880	$	720	$	728	$	954
Operating expenses		761		625		609		867
Operating income	$	119	$	95	$	119	$	87
Net income	$	66	$	54	$	71	$	99
Dividends on preferred stock		―		-1		―		―
Earnings attributable to common shares	$	66	$	53	$	71	$	99
Net Income and Earnings were negatively impacted by higher operating expenses due to the delay in the CPUC decision on the 2012 GRC until the second quarter of 2013.
SoCalGas' Operating Revenues and Operating Expenses for each of the quarters in 2013 compared to 2012 were higher primarily due to higher natural gas prices.
In the second quarter of 2013, Operating Revenues included $41 million and Net Income and Earnings included $37 million favorable impacts from the retroactive application of the 2012 GRC for the period from January 2012 to March 2013.
In the fourth quarter of 2013 compared to 2012, SoCalGas' Net Income and Earnings were impacted by $26 million lower income tax benefit due to a change in 2012 in the income tax treatment of certain repairs expenditures that are capitalized for financial statement purposes. This was offset by the favorable impacts in 2013 of $19 million due to higher CPUC base operating margin as a result of the 2012 GRC decision and $12 million primarily due to higher favorable resolution of prior years' tax issues.

SUBSEQUENT_EVENT

SUBSEQUENT EVENT	12 Months Ended
	Dec. 31, 2013
Notes to Consolidated Financial Statements [Abstract]	'
Subsequent Events	'
	NOTE 18. SUBSEQUENT EVENT
	MESQUITE POWER PLANT
	In January 2014, management approved a plan to market and sell the remaining 625-MW block of Sempra Natural Gas' Mesquite Power natural gas-fired power plant in Arizona. As a result, in January 2014, we ceased depreciation on the plant and classified the book value of $287 million as an asset held for sale.

SCHEDULE_I_CONDENSED_FINANCIAL

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
	Dec. 31, 2013
Condensed Financial Information Of Parent (Tables) [Abstract]	'
Condensed Financial Information of Parent	'
	SEMPRA ENERGY
	CONDENSED STATEMENTS OF OPERATIONS
	(Dollars in millions, except per share amounts)
		Years ended December 31,
		2013		2012		2011
	Interest income	$	42	$	83	$	109
	Interest expense		-239		-247		-242
	Operation and maintenance		-63		-68		-64
	Other income, net		41		66		42
	Income tax benefits		117		145		82
	Loss before equity in earnings of subsidiaries		-102		-21		-73
	Equity in earnings of subsidiaries, net of income taxes		1,103		880		1,404
	Net income/earnings	$	1,001	$	859	$	1,331
	Basic earnings per common share	$	4.1	$	3.56	$	5.55
	Weighted-average number of shares outstanding (thousands)		243,863		241,347		239,720
	Diluted earnings per common share	$	4.01	$	3.48	$	5.51
	Weighted-average number of shares outstanding (thousands)		249,332		246,693		241,523
	See Notes to Condensed Financial Information of Parent.
	SEMPRA ENERGY
	CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
	(Dollars in millions)
			Years ended December 31, 2013, 2012 and 2011
			Pretax		Income Tax		Net-of-tax
			Amount		(Expense) Benefit		Amount
	2013:00:00
	Net income		$	884	$	117	$	1,001
	Other comprehensive income:
	Foreign currency translation adjustments			111		―		111
	Pension and other postretirement benefits			47		-19		28
	Financial instruments			13		-4		9
	Total other comprehensive income			171		-23		148
	Comprehensive income		$	1,055	$	94	$	1,149
	2012:00:00
	Net income		$	714	$	145	$	859
	Other comprehensive income (loss):
	Foreign currency translation adjustments			119		―		119
	Pension and other postretirement benefits			-4		2		-2
	Financial instruments			-6		2		-4
	Total other comprehensive income			109		4		113
	Comprehensive income		$	823	$	149	$	972
	2011:00:00
	Net income		$	1,249	$	82	$	1,331
	Other comprehensive loss:
	Foreign currency translation adjustments			-79		3		-76
	Reclassification to net income of foreign
	currency translation adjustment related
	to remeasurement of equity method
	investments			-54		―		-54
	Available-for-sale securities			-2		1		-1
	Pension and other postretirement benefits			-20		8		-12
	Financial instruments			-26		10		-16
	Total other comprehensive loss			-181		22		-159
	Comprehensive income		$	1,068	$	104	$	1,172
	See Notes to Condensed Financial Information of Parent.
	SEMPRA ENERGY
	CONDENSED BALANCE SHEETS
	(Dollars in millions)
			December 31,		December 31,
			2013		2012
	Assets:
	Cash and cash equivalents		$	6	$	18
	Due from affiliates			132		125
	Deferred income taxes			170		109
Other current assets			16		16
Total current assets			324		268
Investments in subsidiaries			13,866		12,545
Due from affiliates			802		1,759
Deferred income taxes			1,466		1,541
Other assets			555		576
Total assets		$	17,013	$	16,689
Liabilities and shareholders’ equity:
Current portion of long-term debt		$	800	$	652
Due to affiliates			273		539
Income taxes payable			64		26
Other current liabilities			276		260
Total current liabilities			1,413		1,477
Long-term debt			4,117		4,409
Other long-term liabilities			475		521
Shareholders’ equity			11,008		10,282
Total liabilities and shareholders’ equity		$	17,013	$	16,689
See Notes to Condensed Financial Information of Parent.
SEMPRA ENERGY
CONDENSED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Years ended December 31,
	2013		2012		2011
Net cash used in operating activities	$	-131	$	-809	$	-287
Dividends received from subsidiary		50		250		50
Expenditures for property, plant and equipment		-1		-1		-2
Purchase of trust assets		-5		-6		-7
Proceeds from sales by trust		10		10		12
Capital contribution to subsidiaries		-6		―		-200
Decrease (increase) in loans to affiliates, net		962		-33		82
Cash provided by (used in) investing activities		1,010		220		-65
Common stock dividends paid		-606		-550		-440
Issuances of common stock		62		78		28
Repurchases of common stock		-45		-16		-18
Issuances of long-term debt		498		1,100		799
Payments on long-term debt		-650		-8		-24
Decrease in loans from affiliates, net		-147		―		-136
Other		-3		-8		-3
Cash (used in) provided by financing activities		-891		596		206
(Decrease) increase in cash and cash equivalents		-12		7		-146
Cash and cash equivalents, January 1		18		11		157
Cash and cash equivalents, December 31	$	6	$	18	$	11
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, Net, on the Condensed Statements of Operations includes $39 million, $41 million and $22 million of gains on dedicated assets in support of our executive retirement and deferred compensation plans in 2013, 2012 and 2011, respectively.
Because of its nature as a holding company, Sempra Energy classifies dividends received from subsidiaries as an investing cash flow.
Note 2. Long-Term Debt
	December 31,		December 31,
(Dollars in millions)	2013		2012
6% Notes February 1, 2013	$	―	$	400
8.9% Notes November 15, 2013, including $200 at variable rates after
fixed-to-floating rate swaps effective January 2011		―		250
2% Notes March 15, 2014		500		500
Notes at variable rates (1.01% at December 31, 2013) March 15, 2014		300		300
6.5% Notes June 1, 2016, including $300 at variable rates after
fixed-to-floating rate swaps effective January 2011 (4.46% at December 31, 2013)		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
2.875% Notes October 1, 2022		500		500
4.05% Notes December 1, 2023		500		―
6% Notes October 15, 2039		750		750
Market value adjustments for interest rate swaps, net
(expire November 2013 and June 2016)		12		19
Build-to-suit lease		14		―
		4,926		5,069
Current portion of long-term debt		-800		-652
Unamortized discount on long-term debt		-9		-8
Total long-term debt	$	4,117	$	4,409
Maturities of long-term debt are $800 million in 2014, $750 million in 2016, $600 million in 2017, $500 million in 2018 and $2.3 billion thereafter.
Additional 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 3. Commitments and Contingencies
For contingencies and guarantees related to Sempra Energy, refer to Notes 5 and 15 of the Notes to Consolidated Financial Statements in the Annual Report.

SIGNIFICANT_ACCOUNTING_POLICIE1

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Policies)	12 Months Ended
	Dec. 31, 2013
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 evaluate accounts receivable collectibility 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 historical and industry trends.
	We write off accounts receivable in the period in which we deem the receivable to be uncollectible.  We record recoveries of accounts receivable previously written off when it is known that they will be received.
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 estimated retirement cost over the life of the related asset by depreciating the present value of the obligation (measured at the time of the asset's acquisition) and accreting the discount until the liability is settled. Rate-regulated entities 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. We have recorded a regulatory liability to show that the California Utilities have collected funds from customers more quickly and for larger amounts than we would accrete the retirement liability and depreciate the asset in accordance with U.S. GAAP.
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.
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:
	information 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 contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
Consolidation Policy [Abstract]	'
Principles of Consolidation	'
	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 California 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 Utilities, which do not include the utilities in our Sempra International and Sempra U.S. Gas & Power operating units. Sempra Global is the holding company for most of our subsidiaries that are not subject to California utility regulation. All references in these Notes to “Sempra International,” “Sempra U.S. Gas & Power” and their respective reportable segments are not intended to refer to any legal entity with the same or similar name.
	In the first quarter of 2013, Sempra Energy's subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), completed a private offering in the U.S. and outside of Mexico and a concurrent public offering in Mexico of common stock. The aggregate shares of common stock sold in the offerings represent approximately 18.9 percent of IEnova's outstanding ownership interest. IEnova is reported within the Sempra Mexico reportable segment. We discuss the offerings and IEnova in “Noncontrolling Interests – Sale of Noncontrolling Interests” below.
	Sempra Energy uses the equity method to account for investments in affiliated companies over which we have the ability to exercise significant influence, but not control. We discuss our investments in unconsolidated entities in Notes 3 and 4.
	SDG&E
	SDG&E's Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, 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 minimus accounts of inactive subsidiaries. SoCalGas' common stock is wholly owned by Pacific Enterprises (PE), which is a wholly owned subsidiary of Sempra Energy.
	BASIS OF PRESENTATION
	This 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 two electric distribution utilities in South America. 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 Mexico, S de RL de CV (Ecogas) in northern Mexico, all natural gas distribution utilities. The California Utilities, Sempra Natural Gas' Mobile Gas and Willmut Gas, and Sempra Mexico's Ecogas prepare their financial statements in accordance with the provisions of accounting principles generally accepted in the United States of America (U.S. GAAP) governing regulated operations, as we discuss below under “Regulatory Matters.” We discuss revenue recognition at our utilities in “Revenues–Utilities” below.
	Use of Estimates in the Preparation of the Financial Statements
	We have prepared our Consolidated Financial Statements in conformity with U.S. GAAP. This 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 reasonable, actual amounts ultimately may differ significantly from those estimates.
	Subsequent Events
	We evaluated events and transactions that occurred after December 31, 2013 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. We discuss subsequent events further in Note 18.
	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 the VIE.
	SDG&E
	Tolling Agreements
	SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements).  SDG&E's obligation to absorb natural gas costs may be a significant variable interest.  In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based upon our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility's useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which we consider the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If we determine that SDG&E is the primary beneficiary, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE, as we discuss below.
	Other Variable Interest Entities
	SDG&E's power procurement is subject to reliability requirements that may require SDG&E to enter into various power purchase arrangements which include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and thereby Sempra Energy, is the primary beneficiary. SDG&E has determined that no contracts, other than the one relating to Otay Mesa VIE mentioned above, result in SDG&E being the primary beneficiary at December 31, 2013. In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs, including certain construction costs, tax credits, and other components of cash flow expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects are not expected to significantly affect the financial position, results of operations, or liquidity of SDG&E. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates.
	Sempra Energy's other operating units also enter into arrangements which could include variable interests. We evaluate these arrangements and applicable entities based upon the qualitative and quantitative analyses described above. Certain of these entities are service companies that are VIEs. As the primary beneficiary of these service companies, we consolidate them. In all other cases, we have determined that these contracts are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation of VIEs.
Cost Of Sales Policy [Abstract]	'
Other Cost of Sales, Policy	'
	OTHER COST OF SALES
	Other Cost of Sales primarily includes
	pipeline capacity marketing costs, and pipeline transportation and natural gas marketing costs incurred at Sempra Natural Gas;
	electric construction services costs at Sempra South American Utilities; and
	energy management service fees at Sempra Mexico
Emission Credits Policy [Abstract]	'
Emission Credits or Allowances Policy	'
	GREENHOUSE GAS ALLOWANCES
	The California Utilities, Sempra Mexico and Sempra Natural Gas supply power into the California Independent System Operator (ISO) grid and are, therefore, required by California Assembly Bill 32 to acquire greenhouse gas allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during generation. We account for greenhouse gas allowances as inventory, measured 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 Current Liabilities and Deferred Credits 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 Utilities expect that all costs and revenues associated with the greenhouse gas program will be recorded through Regulatory Balancing Accounts on the Consolidated Balance Sheets.
	RENEWABLE ENERGY CERTIFICATES
	Renewable energy 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 are the mechanism used to verify renewable portfolio standards compliance. The cost of RECs is recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Consolidated Statements of Operations.
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 other miscellaneous derivatives. “Fair value” is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price).
	A fair value measurement reflects the assumptions market participants would use 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 issuer's credit standing when measuring its liabilities at fair value.
	We establish a fair 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 identical 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 assets 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 consist of listed equities, 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 reporting 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
	time 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 derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include the Nuclear Decommissioning Trusts' investments at SDG&E 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 that 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.
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 resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings (unless the operation is being discontinued), but are reflected in Comprehensive Income and in Accumulated Other Comprehensive Income (Loss), a component of shareholders' equity.
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 is tested 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, including goodwill, exceeds its fair value, and the book value 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 qualitative 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, quantitative 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
	country risk
	entity risk
	Other Intangible Assets
	Sempra Natural Gas recorded $460 million of intangible assets in connection with the acquisition of EnergySouth, Inc. in 2008. These intangible assets 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) and were recorded at estimated fair value as of the date of the acquisition using discounted cash flows analysis. Our assumptions in determining fair value included estimated future cash flows, the estimated useful life of the intangible assets and appropriate discount rates. We are amortizing these intangible assets 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	'
	ASSETS HELD FOR SALE
	We classify assets as held for sale when management approves and commits to a formal plan to actively market an asset for sale and we expect the sale to close within the next twelve months. Upon classifying an asset as held for sale, we record the asset at the lower of its carrying value or its estimated fair value reduced for selling costs, and we stop recording depreciation expense on the asset.
	LONG-LIVED ASSETS
	We 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 unconsolidated 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 price 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 current 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
	Impairment of long-lived assets occurs when the estimated future undiscounted cash flows are less than the carrying amount of the assets. If that comparison indicates that the assets' carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the assets. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
Income Tax Policy [Abstract]	'
Income Taxes, Policy	'
	INCOME TAXES
	Income tax expense includes current and deferred income taxes from operations during the year. We record deferred income taxes for temporary differences between the book and the tax bases 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, Mobile Gas and Willmut Gas recognize
	regulatory assets to offset deferred tax liabilities if it is probable that the amounts will be recovered from customers; and
	regulatory liabilities to offset deferred tax assets if it is probable that the amounts will be returned to customers.
	Other than local country withholding tax on current Peruvian earnings, we 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 their cumulative undistributed earnings are indefinitely 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 technical 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 results of operations, financial position and cash flows.
	The 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 regulatory 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 results in impacting the current effective 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 following items are subject to flow-through treatment:
	repairs expenditures 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
	self-developed software expenditures
	depreciation on a certain portion of utility plant assets
	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 and 2011, 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 energy assets, referred to as the day-one basis difference. The financial statement basis 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 50 percent for grants and not at all for ITC.
	Cash grants are generally expected to be collectible in cash shortly after a project is constructed. 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) carryforward can result in delaying this conversion.
	The geographic components of Income Before Income Taxes and Equity Earnings of Certain Unconsolidated Subsidiaries at Sempra Energy are as follows:
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 market.
	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 market. Sempra Mexico and Sempra Natural Gas value liquefied natural gas (LNG) inventory by the first-in first-out method.
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 legal proceedings when it is probable that a loss has been incurred and the amounts 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 materially 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. As a result, noncontrolling interests are reported as a separate component of equity on the Consolidated Balance Sheets. Earnings or loss attributable to the noncontrolling interests is separately identified on the Consolidated Statements of Operations, and net income or loss and comprehensive income or loss attributable to the noncontrolling interests is separately identified on the Consolidated Statements of Comprehensive Income and Consolidated Statements of Changes in Equity.
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 other facilities used by the California Utilities to provide natural gas and electric utility services, and by Sempra International and Sempra U.S. Gas & Power, including construction work in progress at these operating units. Property, plant and equipment also includes lease improvements and other equipment at Parent, as well as property acquired under a build-to-suit lease included in construction work in progress.
	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 our utility plant and selected non-utility regulated projects in Mexico include an allowance for funds used during construction (AFUDC). We discuss AFUDC below. The cost of non-utility plant includes capitalized interest.
	Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant minus 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 straight-line method over the asset's estimated original composite useful life, the CPUC-prescribed period or the remaining term of the site leases, whichever is shortest.
	The California 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 of the assets.
	Pipeline projects currently under construction by Sempra Mexico that are both regulated by the Comisión Reguladora de Energía (or CRE, the Energy Regulatory Commission) and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC related to equity. Beginning in the fourth quarter of 2013, Sempra Mexico began recording AFUDC equity for its Sonora Pipeline project.
	Sempra International and Sempra U.S. Gas & Power businesses capitalize interest costs incurred to finance capital projects. The California Utilities also capitalize certain interest costs.
Public Utilities Policy [Abstract]	'
Regulatory Matters, Policy	'
	REGULATORY MATTERS
	Effects of Regulation
	The accounting policies of our regulated utility subsidiaries in California, SDG&E and SoCalGas, conform with U.S. GAAP for 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 regulated operations. Under these provisions, a regulated utility records a regulatory asset, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover that asset from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory 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, generally 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 which are passed through to customers in future rates. 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 precedence;
	regulatory 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 rehearings or state court appeals;
	specific approval from a commission; and
	historical experience.
	Our other natural gas distribution utilities, Mobile Gas, Willmut Gas and Ecogas, also apply U.S. GAAP for regulated utilities to their operations.
	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 certain operating and maintenance costs from amounts approved by the CPUC would increase volatility in utility earnings.
	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 related to the San Onofre Nuclear Generating Station (SONGS) plant closure represent management's estimate of what SDG&E will be allowed to recover in rates in the future associated with SDG&E's investment in SONGS as of the plant closure date, the cost of operations since Units 2 and 3 were taken offline, and the cost of purchased replacement power, 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 “Excess Wildfire Claims Cost Recovery at the CPUC” and Note 15 under “SDG&E—2007 Wildfire Litigation.”
	Deferred taxes recoverable in rates are based on current regulatory ratemaking and income tax laws. SDG&E and SoCalGas expect to recover net regulatory assets related to deferred income taxes over the lives of the assets that give rise to the accumulated deferred income tax liabilities. These net assets are included in ratebase.
	Regulatory assets/liabilities related to pension and other postretirement 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 original amortization periods of the losses on reacquired debt. These periods range from 5 months to 14 years for SDG&E and from 8 years to 12 years for SoCalGas.
	Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of 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 replaced under the Smart Meter Program is their undepreciated value. SDG&E is recovering this asset over a 4-year period in ratebase.
	The 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 50-year period.
	Incentive awards are included in our earnings 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 more likely than not that the CPUC would assess a penalty.
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. They record these revenues following the accrual method and recognize them upon delivery and performance. They also record revenue from CPUC-approved incentive awards, some of which require approval by the CPUC prior to being recognized.
	On a monthly basis, SoCalGas accrues natural gas storage contract revenues, which consist of storage reservation and variable charges based on negotiated agreements with terms of up to 15 years.
	Our natural gas utilities outside of California (Mobile Gas, Willmut Gas and Ecogas) apply U.S. GAAP for regulated utilities consistent with the California Utilities.
	Our utilities in South America, which were consolidated as part of our Sempra South American Utilities segment beginning April 6, 2011 as we discuss in Note 3, are Chilquinta Energía S.A. (Chilquinta Energía) and Luz del Sur S.A.A. (Luz del Sur), and their subsidiaries. Chilquinta Energía is an electric distribution utility serving customers in the cities of Valparaiso and Viña del Mar in central Chile. Luz del Sur is an electric distribution utility in the southern zone of metropolitan Lima, Peru. The companies serve primarily regulated customers, and their revenues are based on tariffs that are set by the National Energy Commission (Comisión Nacional de Energía, or CNE) in Chile and the Energy and Mining Investment Supervisory Body (Organismo Supervisor de la Inversión en Energía y Minería, 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 distribution company defined by Chilean law in the case of Chilquinta Energía, 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 (Valor Nuevo de Reemplazo, or VNR) of depreciable assets, charges 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), recovery 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 cover 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 regulatory accounting.
	As we discuss in Note 14, the natural gas supply for SDG&E's and SoCalGas' core natural gas customers is purchased by SoCalGas as a combined procurement portfolio managed by SoCalGas. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service, therefore amounts related to SDG&E are not included in SoCalGas' Consolidated Statements of Operations.
	Energy-Related Businesses
	Sempra South American Utilities
	Sempra South American Utilities generates revenues from providing electric construction services, and recognizes these revenues when services are provided in accordance with contractual agreements.
	Sempra Mexico
	Sempra Mexico's Termoeléctrica de Mexicali generates revenues from selling electricity and/or capacity to the California ISO and to governmental, public utility and wholesale power marketing entities. Sempra Mexico recognizes these revenues as the electricity is delivered and capacity is provided. Sempra Mexico's pipeline operations recognize revenues from the sale and transportation of natural gas as deliveries are made and from fixed capacity 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 service 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.
	Sempra 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.
	Sempra Natural Gas
	Sempra Natural Gas generates revenues from selling electricity and/or capacity from its Mesquite Power facility to the California ISO and to governmental, public utility and wholesale power marketing entities. Sempra Natural Gas recognizes these revenues as the electricity is delivered and capacity is provided. In 2011, Sempra Natural Gas' electricity sales to the DWR accounted for a significant portion of its revenues. This contract ended September 30, 2011. Related to its LNG terminal and marketing operations, Sempra Natural Gas recognizes revenues from the sale of LNG and natural gas as deliveries are made to counterparties, as well as revenues from reservation and usage fees. Sempra Natural Gas also records revenues from contractual counterparty obligations for non-delivery of cargoes. 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 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.
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, which consist primarily of personnel costs, purchased materials and services, litigation expense and rent.
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 Income show the changes in the components of other comprehensive income (OCI), including the amounts attributable to noncontrolling interests.

ACQUISITION_AND_DIVESTITURE_AC

ACQUISITION AND DIVESTITURE ACTIVITY (Policies)	12 Months Ended
	Dec. 31, 2013
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_UNCONSOLIDATED_1

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Policies)	12 Months Ended
	Dec. 31, 2013
Investments	'
Investments in Unconsolidated Entities Policy	'
	We generally account for investments under the equity method when we have an ownership interest of 20 percent to 50 percent. In these cases, our pro rata shares of the entities' net assets are included in Investments on the Consolidated Balance Sheets. These investments are adjusted for our share of each investee's earnings or losses, dividends, and other comprehensive income or loss.
	The carrying value of unconsolidated entities is evaluated 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, 2013
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 changes in the funded status of pension and other postretirement benefit plans in the year in which the changes occur. Generally, those changes 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 defined benefit plans, including separate plans for SDG&E and SoCalGas, which collectively cover substantially all domestic and certain foreign employees, and members of the Sempra Energy board of directors who were participants in a predecessor plan on or before June 1, 1998. The plans generally provide defined benefits based on years of service and either final average or career salary.
	Chilquinta Energía, which was acquired by Sempra Energy in 2011, has an unfunded contributory defined benefit plan covering all employees hired before October 1, 1981 and an unfunded noncontributory termination indemnity obligation covering all employees. The plans generally provide defined benefits to retirees based on date of hire, years of service and final average salary.
	Sempra Energy also has other postretirement benefit plans (PBOP), including separate plans for SDG&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 contributory. 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 health care plan and an energy subsidy plan that provides for reduced energy rates. The health care plan includes benefits for retirees' spouses and dependents.
	Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. These assumptions include
	discount rates
	expected return on plan assets
	health care cost trend rates
	mortality rates
	rate of compensation 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 prior to the beginning of each year and update them as appropriate. We consider current 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 market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Sempra Energy Consolidated (except for SDG&E) and SoCalGas use the asset smoothing method for their pension and other postretirement plans. This method develops an asset value that recognizes realized and unrealized investment gains and losses over 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 the 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, SDG&E and 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 active 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 and 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 authorized by the CPUC. The annual contributions to the pension plans are limited to a minimum required funding amount as determined by the Internal Revenue Service. The annual contributions to the other postretirement plans are equal to the lesser of the maximum tax deductible amount 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 the 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 regulated entities.

SHAREBASED_COMPENSATION_Polici

SHARE-BASED COMPENSATION (Policies)	12 Months Ended
	Dec. 31, 2013
Share-based compensation	'
Share-Based Compensation Policy	'
	SHARE-BASED AWARDS AND COMPENSATION EXPENSE
	We 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 basis over the requisite service period of the award, which is generally 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. Substantially 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 the tax benefits resulting from tax deductions in excess of the tax benefit related to compensation cost recognized for stock option exercises as financing cash flows.
	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-termination 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 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_INSTRUMEN1

DERIVATIVE FINANCIAL INSTRUMENTS (Policies)	12 Months Ended
	Dec. 31, 2013
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 and benchmark interest rate risk. We may also manage foreign exchange rate exposures using derivatives. 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 in 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 revenues, expenses, assets or liabilities that are not presented below.
	We record all 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) undesignated. 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 (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 Statements of Cash Flows.
	In certain cases, we apply the normal purchase or sale exception to derivative accounting 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.
	HEDGE ACCOUNTING
	We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge accounting 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 offsetting the risk that a given future 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 rate 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 locations 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.
	The California Utilities use natural gas energy derivatives, on their customers' behalf, with the objective of managing price risk and basis risks, and lowering natural gas costs. These derivatives include fixed price natural gas positions, options, and basis risk instruments, which are either exchange-traded or over-the-counter financial instruments. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas 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 Consolidated 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 are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, 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 natural 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 of 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.
	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 utilize 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 in 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. 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 natural gas derivatives. Accordingly, interest rate derivatives are generally accounted for as hedges at the California Utilities, as well as at the rest of Sempra Energy's subsidiaries. Separately, Otay Mesa VIE has entered into interest rate swap agreements to moderate its exposure to interest rate changes. This activity was designated as a cash flow hedge as of April 1, 2011.
	In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the physical locations of our assets and other contractual obligations, such as natural gas purchases and sales.
	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. From time to time, we may utilize short-term foreign 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 may also utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries. On February 14, 2013, Sempra Mexico entered into cross-currency swap agreements, which were designated as cash flow hedges. We discuss the notional amount of the swaps in Note 5.
	In addition, Sempra South American Utilities may utilize foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. We 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, 2013
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 as of December 31, 2013 and 2012. 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 valuation 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 “Financial 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 deposits, 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, 2013 and 2012 in the tables below include the following:
	Nuclear decommissioning trusts reflect 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 independent 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). Other debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2).
	We enter into commodity contracts and interest rate derivatives primarily as a means to manage price exposures. We may also manage foreign exchange rate exposures using derivatives. 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 corroborated, 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 models 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). All Level 3 recurring items are related to CRRs at SDG&E, as we discuss below under “Level 3 Information.” We record commodity derivative contracts that are subject to rate recovery as commodity costs that are offset by regulatory account balances and are recovered in rates.
	Investments include marketable securities that we value using a market approach based on closing prices reported in the active market in which the identical security is traded (Level 1).
	SDG&E's Energy and Fuel Procurement department, in conjunction with SDG&E's finance group, is responsible for determining the appropriate fair value methodologies used to value and classify CRRs on an ongoing basis. Inputs used to determine the fair value of CRRs are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to CRRs 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 prices published by the California Independent System Operator (ISO), an objective source. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. At December 31, 2013, the auction prices ranged from $(6) per MWh to $12 per MWh at a given location, and the fair value of these instruments is derived from auction price differences between two locations. At December 31, 2012, the auction prices ranged from $(11) per MWh to $12 per MWh. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two 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. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, 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, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration 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 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 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 calculate the fair value of our investments in affordable housing partnerships using an income approach based on the present value of estimated future cash flows discounted at rates available for similar investments (Level 3).

SHAREHOLDERS_EQUITY_AND_EARNIN1

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Policies)	12 Months Ended
	Dec. 31, 2013
Earnings Per Share [Abstract]	'
Earnings Per Share, Policy [Text Block]	'
	Basic earnings per common share (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.
	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 benefits recognized 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.
	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 compensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation 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).
	RSAs and those RSUs that are solely service-based have a maximum potential of 100 percent vesting and have the same dividend equivalent rights as performance-based RSUs. We include our performance-based RSUs in potential dilutive shares at zero to 150 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 both Sempra Energy stock and the comparative index, dilutive performance-based RSU shares may vary widely from period-to-period. We include our RSAs, which are solely service-based, and those RSUs that are solely service-based in potential dilutive shares at 100 percent.
	RSUs and RSAs may be excluded from potential dilutive shares by the application of unearned compensation in the treasury stock method, as we discuss above, or because performance goals are currently not met.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Policies)	12 Months Ended
	Dec. 31, 2013
concentration of credit risk	'
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 all 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 customers 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, Sempra 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 consider many factors, including the negotiation of supplier and customer agreements, when we evaluate and approve development projects.
Environmental Policy [Abstract]	'
Environmental Costs, Policy	'
	ENVIRONMENTAL ISSUES
	Our operations are subject to federal, state and local environmental laws. We also are subject to regulations related to hazardous wastes, air and water quality, land use, solid waste disposal and the protection of wildlife. These laws and regulations require that we investigate and correct the effects of the release or disposal of materials at sites associated with our past and our present operations. These sites include those at which we have been identified as a Potentially Responsible Party (PRP) under the federal Superfund laws and similar state laws.
	In addition, we are required to obtain numerous governmental permits, licenses and other approvals to construct facilities and operate our businesses. The related costs of environmental monitoring, pollution control equipment, cleanup costs, and emissions fees are significant. Increasing national and international concerns regarding global warming and mercury, carbon dioxide, nitrogen oxide and sulfur dioxide emissions could result in requirements for additional pollution control equipment or significant emissions fees or taxes that could adversely affect Sempra Natural Gas and Sempra Mexico. The California Utilities' costs to operate their facilities in compliance with these laws and regulations generally have been recovered in customer rates.
	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 engineering evaluations. We review our accruals periodically and, as investigations and cleanup 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 legal proceedings when it is probable that a loss has been incurred and the amounts 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 materially 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_POLICIE2

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2013
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
			2013		2012		2013		2012		2013		2012
	Current:
	Overcollected		$	-1,077	$	-643	$	-645	$	-340	$	-432	$	-303
	Undercollected			1,542		897		1,201		735		341		162
	Net current receivable (payable)(1)			465		254		556		395		-91		-141
	Non-current:
	Undercollected(2)			213		―		161		―		52		―
	Total net receivable (payable)(1)		$	678	$	254	$	717	$	395	$	-39	$	-141
	-1	At December 31, 2013 and 2012, the net receivable at SDG&E and the net payable at SoCalGas are shown separately on Sempra Energy's Consolidated Balance Sheets.
	-2	Long-term undercollected balance included in Other Regulatory Assets (long-term) on the Consolidated Balance Sheets.
Schedule Of Regulatory Assets (Liabilities) [Abstract]	'
Schedule of regulatory assets and liabilities	'
	REGULATORY ASSETS (LIABILITIES) AT DECEMBER 31
	(Dollars in millions)
			2013		2012
	SDG&E
	Fixed-price contracts and other derivatives		$	58	$	149
	Costs related to SONGS plant closure			303		―
	Costs related to wildfire litigation			330		364
	Deferred taxes recoverable in rates			788		718
	Pension and other postretirement benefit obligations			106		303
	Removal obligations(1)			-1,403		-1,603
	Unamortized loss on reacquired debt			14		16
	Environmental costs			20		16
	Legacy meters			62		90
	Sunrise Powerlink fire mitigation			115		117
	Other			15		23
	Total SDG&E			408		193
	SoCalGas
	Pension and other postretirement benefit obligations			231		835
	Employee benefit costs			51		58
	Removal obligations(1)			-1,205		-1,103
	Deferred taxes recoverable in rates			110		38
	Unamortized loss on reacquired debt			14		17
	Environmental costs			14		14
	Workers’ compensation			26		27
	Other			―		-2
	Total SoCalGas			-759		-116
	Other Sempra Energy
	Sempra Natural Gas			-11		3
	Sempra Mexico			8		1
	Total Other Sempra Energy			-3		4
	Total Sempra Energy Consolidated		$	-354	$	81
	-1	Related to obligations discussed below in “Asset Retirement Obligations.”
	NET REGULATORY ASSETS (LIABILITIES) AS PRESENTED ON THE CONSOLIDATED BALANCE SHEETS AT DECEMBER 31
	(Dollars in millions)
			2013							2012
			Sempra							Sempra
			Energy							Energy
			Consolidated		SDG&E		SoCalGas			Consolidated		SDG&E		SoCalGas
	Current regulatory assets		$	38	$	29	$	5		$	62	$	49	$	4
	Noncurrent regulatory assets(1)			2,335		1,787		536			2,742		1,747		983
	Current regulatory liabilities(2)			-7		-5		―			-2		―		―
	Noncurrent regulatory liabilities(3)			-2,720		-1,403		-1,300			-2,721		-1,603		-1,103
	Total		$	-354	$	408	$	-759		$	81	$	193	$	-116
	-1	Excludes long-term undercollected balancing accounts of $213 million at Sempra Energy, $161 million at SDG&E and $52 million at SoCalGas recorded in Other Regulatory Assets (long-term).
	-2	Included in Other Current Liabilities.
	-3	At December 31, 2013 and 2012, $97 million and $1 million, respectively, at Sempra Energy Consolidated is 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,
		2013		2012		2011
	Sempra Energy Consolidated
	Allowances for collection of receivables at January 1	$	31	$	29	$	29
	Provisions for uncollectible accounts		16		21		20
	Write-offs of uncollectible accounts		-18		-19		-20
	Allowances for collection of receivables at December 31	$	29	$	31	$	29
	SDG&E
	Allowances for collection of receivables at January 1	$	6	$	6	$	5
	Provisions for uncollectible accounts		4		5		8
	Write-offs of uncollectible accounts		-5		-5		-7
	Allowances for collection of receivables at December 31	$	5	$	6	$	6
	SoCalGas
	Allowances for collection of receivables at January 1	$	14	$	12	$	14
	Provisions for uncollectible accounts		7		12		8
	Write-offs of uncollectible accounts		-9		-10		-10
	Allowances for collection of receivables at December 31	$	12	$	14	$	12
Schedule Of Inventory Balances [Abstract]	'
Schedule of inventory	'
	INVENTORY BALANCES AT DECEMBER 31
	(Dollars in millions)
			Natural Gas					LNG			Materials and supplies				Total
			2013		2012			2013	2012		2013		2012		2013		2012
	SDG&E		$	3	$	3	$	―	$	―	$	83	$	79	$	86	$	82
	SoCalGas			42		128		―		―		27		23		69		151
	Sempra South American Utilities			―		―		―		―		40		34		40		34
	Sempra Mexico			―		―		3		8		9		8		12		16
	Sempra Renewables			―		―		―		―		2		3		2		3
	Sempra Natural Gas			68		109		5		8		5		5		78		122
	Sempra Energy Consolidated		$	113	$	240	$	8	$	16	$	166	$	152	$	287	$	408
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
			and Equipment at					Depreciation rates for
			December 31,					years ended December 31,
			2013		2012			2013		2012		2011
	SDG&E:
	Natural gas operations		$	1,454	$	1,406		2.35	%	3.2	%	3.15	%
	Electric distribution			5,492		5,217		3.36		4.15		4.13
	Electric transmission(1)			3,932		3,714		2.58		2.63		2.74
	Electric generation(2)			1,768		2,242		3.76		4.68		4.92
	Other electric(3)			759		679		7.58		7.92		8.26
	Construction work in progress(1)			941		866		NA		NA		NA
	Total SDG&E			14,346		14,124
	SoCalGas:
	Natural gas operations(4)			11,394		10,756		3.7		3.74		3.62
	Other non-utility			118		129		1.56		1.36		1.62
	Construction work in progress			319		302		NA		NA		NA
	Total SoCalGas			11,831		11,187
								Estimated			Weighted Average
	Other operating units and parent(5):							Useful Lives			Useful Life
	Land and land rights			276		298		20 to 50 years(6)			47
	Machinery and equipment:
	Utility electric distribution operations			1,440		1,459		10 to 46 years			40
	Generating plants			993		1,568		3 to 35 years			31
	LNG terminals			2,094		2,061		3 to 50 years			46
	Pipelines and storage			1,638		1,634		3 to 50 years			42
	Other			212		241		1 to 47 years			13
	Construction work in progress			1,283		692		NA			NA
	Other			294		264		2 to 80 years			29
				8,230		8,217
	Total Sempra Energy Consolidated		$	34,407	$	33,528
	-1	At December 31, 2013, includes $350 million in electric transmission assets and $5 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 $183 million at both December 31, 2013 and 2012, primarily related to variable interest entities of which SDG&E is not the primary beneficiary.
	-3	Includes capital lease assets of $23 million at both December 31, 2013 and 2012.
	-4	Includes capital lease assets of $33 million and $32 million at December 31, 2013 and 2012, respectively.
	-5	December 31, 2013 balances include $155 million, $180 million and $22 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively. December 31, 2012 balances include $144 million, $171 million and $18 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 AND DECOMMISSIONING AMOUNTS
	(Dollars in millions)
			December 31,
			2013		2012
	SDG&E:
	Accumulated depreciation and decommissioning of utility plant in service:
	Electric(1)		$	2,861	$	2,660
	Natural gas			639		601
	Total SDG&E			3,500		3,261
	SoCalGas:
	Accumulated depreciation of natural gas utility plant in service(2)			4,279		4,067
	Accumulated depreciation – other non-utility			85		103
	Total SoCalGas			4,364		4,170
	Other operating units and parent:
	Accumulated depreciation – other(3)			938		806
	Accumulated depreciation of utility electric distribution operations			145		100
				1,083		906
	Total Sempra Energy Consolidated		$	8,947	$	8,337
	-1	Includes accumulated depreciation for assets under capital lease of $26 million and $21 million at December 31, 2013 and 2012, respectively. Includes $199 million 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 $31 million and $28 million at December 31, 2013 and 2012, respectively.
	-3	December 31, 2013 balances include $38 million, $25 million and $2 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively. December 31, 2012 balances include $34 million, $21 million and $1 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,
		2013		2012		2011
	Sempra Energy Consolidated:
	AFUDC related to debt	$	22	$	38	$	40
	AFUDC related to equity		75		96		99
	Other capitalized financing costs		22		52		26
	Total Sempra Energy Consolidated	$	119	$	186	$	165
	SDG&E:
	AFUDC related to debt	$	16	$	30	$	33
	AFUDC related to equity		39		71		80
	Total SDG&E	$	55	$	101	$	113
	SoCalGas:
	AFUDC related to debt	$	6	$	8	$	7
	AFUDC related to equity		17		25		19
	Other capitalized financing costs		1		1		―
	Total SoCalGas	$	24	$	34	$	26
Schedule Of Long Lived Assets Held For Sale [Abstract]	'
Schedule Of Long-lived Assets Held For Sale	'
	(Dollars in millions)		2012
	Property, plant, and equipment, net		$	292
	Inventories			4
	Total assets held for sale			296
	Liability held for sale - asset retirement obligation(1)			-5
	Total		$	291
	-1	Included in Other Current Liabilities on the Consolidated Balance Sheet.
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, 2011		$	949	$	25	$	62	$	1,036
	Acquisition of subsidiary			―		―		10		10
	Foreign currency translation(1)			65		―		―		65
	Balance at December 31, 2012			1,014		25		72		1,111
	Foreign currency translation(1)			-87		―		―		-87
	Balance at December 31, 2013		$	927	$	25	$	72	$	1,024
	-1	We record the offset of this fluctuation to other comprehensive income.
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)	2013		2012
	Storage rights	46	$	138	$	138
	Development rights	50		322		322
	Other	15 years to indefinite		19		19
				479		479
	Less accumulated amortization:
	Storage rights			-16		-13
	Development rights			-34		-27
	Other			-3		-3
				-53		-43
			$	426	$	436
Schedule Of Variable Interest Entities [Abstract]	'
Schedule Of Variable Interest Entities	'
	AMOUNTS ASSOCIATED WITH OTAY MESA VIE
	(Dollars in millions)
							December 31,
							2013		2012
	Cash and cash equivalents						$	17	$	8
	Restricted cash							6		10
	Inventories							2		2
	Other							1		1
	Total current assets							26		21
	Restricted cash							25		22
	Sundry							4		5
	Property, plant and equipment, net							438		466
	Total assets						$	493	$	514
	Current portion of long-term debt						$	10	$	10
	Fixed-price contracts and other derivatives							16		17
	Other							19		8
	Total current liabilities							45		35
	Long-term debt							325		335
	Fixed-price contracts and other derivatives							39		64
	Deferred credits and other							-7		4
	Other noncontrolling interest							91		76
	Total liabilities and equity						$	493	$	514
					Years ended December 31,
					2013		2012		2011
	Operating expenses
	Cost of electric fuel and purchased power				$	-91	$	-83	$	-72
	Operation and maintenance					24		19		19
	Depreciation and amortization					28		26		22
	Total operating expenses					-39		-38		-31
	Operating income					39		38		31
	Other expense, net					―		-1		-1
	Interest expense					-15		-11		-11
	Income before income taxes/Net income					24		26		19
	Earnings attributable to noncontrolling interest					-24		-26		-19
	Earnings				$	―	$	―	$	―
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
			2013		2012			2013		2012			2013		2012
	Balance as of January 1(1)		$	2,056	$	1,925		$	741	$	698		$	1,253	$	1,175
	Accretion expense			97		92			45		42			49		48
	Liabilities incurred			4		21			―		―			―		―
	Reclassification(2)			―		-5			―		―			―		―
	Payments			-49		-2			-48		―			―		-1
	Revisions, GRC-related(3)			-135		―			-30		―			-105		―
	Revisions, other(4)			179		25			205		1			2		31
	Balance as of December 31(1)		$	2,152	$	2,056		$	913	$	741		$	1,199	$	1,253
	-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 Sheets, as we discuss in "Assets Held for Sale" above.
	-3	The decreases in asset retirement obligations in 2013 at SDG&E and SoCalGas are due to revised estimates related to the 2012 General Rate Case (GRC) that received final approval in May 2013. At SDG&E, these revisions included increases in asset service lives ranging from 2 percent to 7 percent, and lower estimated cost of removal. At SoCalGas, the decrease includes increases in asset service lives ranging from 4 percent to 6 percent, partially offset by a higher estimated cost of removal.
	-4	The increase in asset retirement obligations in 2013 at SDG&E is due to revised estimates recorded in the third quarter of 2013 related to the early decommissioning of SONGS Units 2 and 3 (see 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)
	(Dollars in millions)
			Year ended December 31, 2013
					Pension and Other
					Postretirement Benefits
			Foreign								Total
			Currency		Unamortized		Unamortized				Accumulated Other
			Translation		Net Actuarial		Prior Service		Financial		Comprehensive
			Adjustments		Gain (Loss)		Credit (Cost)		Instruments		Income (Loss)
	Sempra Energy Consolidated:
	Balance as of December 31, 2012		$	-240	$	-102	$	1	$	-35	$	-376
	Other comprehensive (loss) income before
	reclassifications			-159		―		―		2		-157
	Amounts reclassified from accumulated other
	comprehensive income			270	-2	29		-1		7		305
	Net other comprehensive income (loss)			111		29		-1		9		148
	Balance as of December 31, 2013		$	-129	$	-73	$	―	$	-26	$	-228
	SDG&E:
	Balance as of December 31, 2012		$	―	$	-12	$	1	$	―	$	-11
	Amounts reclassified from accumulated other
	comprehensive income			―		2		―		―		2
	Net other comprehensive income			―		2		―		―		2
	Balance as of December 31, 2013		$	―	$	-10	$	1	$	―	$	-9
	SoCalGas:
	Balance as of December 31, 2012		$	―	$	-4	$	1	$	-15	$	-18
	Amounts reclassified from accumulated other
	comprehensive (loss) income			―		-1		―		1		―
	Net other comprehensive (loss) income			―		-1		―		1		―
	Balance as of December 31, 2013		$	―	$	-5	$	1	$	-14	$	-18
	-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.
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)
	Year ended December 31, 2013
				Amount reclassified
	Details about accumulated			from accumulated other				Affected line item
	other comprehensive income (loss) components			comprehensive income (loss)				on Consolidated Statement of Operations
	Sempra Energy Consolidated:
	Foreign currency translation adjustments				$	270		Equity Earnings, Net of Income Tax(1)
	Financial instruments:
	Interest rate and foreign exchange instruments				$	11		Interest Expense
	Interest rate instruments					10		Equity Losses, Before Income Tax
	Commodity contracts not subject to							Cost of Natural Gas, Electric Fuel and Purchased
		rate recovery				-1		Power
	Total before income tax					20
						-4		Income Tax Expense
	Net of income tax					16
						-9		Earnings Attributable to Noncontrolling Interests
					$	7
	Pension and other postretirement benefits:
	Net actuarial gain				$	38		-2
	Amortization of actuarial loss					10		-2
	Prior service cost					-1		-2
						-19		Income Tax Expense
	Net of income tax				$	28
	Total reclassifications for the period, net of tax				$	305
	SDG&E:
	Financial instruments:
	Interest rate instruments				$	9		Interest Expense
						-9		Earnings Attributable to Noncontrolling Interest
					$	―
	Pension and other postretirement benefits:
	Net actuarial gain				$	2		-2
	Amortization of actuarial loss					1		-2
						-1		Income Tax Expense
	Net of income tax				$	2
	Total reclassifications for the period, net of tax				$	2
	SoCalGas:
	Financial instruments:
	Interest rate instruments				$	1		Interest Expense
	Pension and other postretirement benefits:
	Net actuarial loss				$	-3		-2
	Amortization of actuarial loss					1		-2
						1		Income Tax Expense
	Net of income tax				$	-1
	Total reclassifications for the period, net of tax				$	―
	-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, 2011 - 2013" in Note 7).
Schedule Of Noncontrolling Interests [Abstract]	'
Schedule Of Noncontrolling Interests	'
	OTHER NONCONTROLLING INTERESTS
	(Dollars in millions)
					December 31,
			Percent Ownership Held by Others		2013		2012
	SDG&E:
	Otay Mesa VIE		100	%	$	91	$	76
	Sempra South American Utilities:
	Chilquinta Energía subsidiaries(1)		24.4 - 43.4			27		29
	Luz del Sur		20.2			222		236
	Tecsur		9.8			3		4
	Sempra Mexico:
	IEnova, S.A.B. de C.V.		18.9			442		―
	Sempra Natural Gas:
	Bay Gas Storage Company, Ltd.		9.1			22		20
	Liberty Gas Storage, LLC		25			14		15
	Southern Gas Transmission Company		49			1		1
	Total Sempra Energy				$	822	$	381
	-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,
			2013		2012		2011
	Electric revenues		$	4,911	$	4,568	$	3,833
	Natural gas revenues			4,398		3,873		4,489
	Total		$	9,309	$	8,441	$	8,322
	-1	Excludes intercompany revenues.
Schedule Of Foreign Currency Translation Adjustments To Equity Method Investments [Abstract]	'
Schedule Of Foreign Currency Translation Adjustments To Equity Method Investments [Text Block]	'
				Upward (downward) adjustment to investments
	Investment		Currency	2011(1)
	Chilquinta Energía		Chilean Peso	$	-10
	Luz del Sur		Peruvian Nuevo Sol		―
	-1	As discussed in Note 3, the cumulative foreign currency translation adjustment balances totaling $54 million in Accumulated Other Comprehensive Income (Loss) as of April 6, 2011 were reclassified to net income as a result of the gain on the remeasurement of our equity method investments in Chilquinta Energía and Luz del Sur during the second quarter of 2011.
Schedule Of Foreign Currency Transaction Gain (Loss) [Abstract]	'
Schedule Of Foreign Currency Transaction Gain (Loss) [Text Block]	'
		Years ended December 31,
	(Dollars in millions)	2013		2012		2011
	Currency transaction gain (loss)	$	-3	$	9	$	11
Schedule Of Due To And From Affiliates [Abstract]	'
Schedule Of Amounts Due To and From Affiliates at SDG&E and SoCalGas	'
	AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
	(Dollars in millions)
			December 31,
			2013		2012
	SDG&E
	Current:
	Due from SoCalGas		$	―	$	37
	Due from various affiliates			1		2
			$	1	$	39
	Due to Sempra Energy		$	25	$	19
	Due to various affiliates			14		―
			$	39	$	19
	Income taxes due from Sempra Energy(1)		$	70	$	12
	SoCalGas
	Current:
	Due from Sempra Energy		$	―	$	24
	Due from various affiliates			21		―
			$	21	$	24
	Due to SDG&E		$	―	$	37
	Due to Sempra Energy			16		―
			$	16	$	37
	Income taxes due from Sempra Energy(1)		$	18	$	99
	-1	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 the companies’ having always filed a separate return.
Schedule Of Revenues From Affiliates [Abstract]	'
Schedule Of Revenues From Unconsolidated Affiliates at the SDG&E and SoCalGas	'
	REVENUES FROM UNCONSOLIDATED AFFILIATES AT SDG&E AND SOCALGAS
	(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
	SDG&E	$	12	$	9	$	7
	SoCalGas		70		46		53
Schedule Of Transactions With Joint Venture [Abstract]	'
Schedule Of Amounts Recorded For Transactions with RBS Sempra Commodities	'
	AMOUNTS RECORDED FOR TRANSACTIONS WITH RBS SEMPRA COMMODITIES(1)
	(Dollars in millions)
						Cost of
				Revenues		Natural Gas
	Sempra Mexico		$	37	$	74
	Sempra Natural Gas			7		3
	-1	With the exception of Sempra Mexico, whose contract with RBS Sempra Commodities expired in July 2011, amounts only include activities prior to May 1, 2011, the date by which substantially all the contracts with RBS Sempra Commodities were assigned to buyers of the joint venture businesses.
Schedule Of Other Income (Expense) [Abstract]	'
Schedule Of Other Income (Expense)	'
	OTHER INCOME, NET
	(Dollars in millions)
			Years ended December 31,
			2013		2012		2011
	Sempra Energy Consolidated:
	Allowance for equity funds used during construction		$	75	$	96	$	99
	Investment gains(1)			39		41		22
	Gains (losses) on interest rate and foreign exchange instruments, net(2)			17		10		-14
	Regulatory interest, net(3)			5		1		2
	Sundry, net			4		24		21
		Total	$	140	$	172	$	130
	SDG&E:
	Allowance for equity funds used during construction		$	39	$	71	$	80
	Regulatory interest, net(3)			4		2		2
	Losses on interest rate instruments(4)			―		―		-1
	Sundry, net			-3		-4		-2
		Total	$	40	$	69	$	79
	SoCalGas:
	Allowance for equity funds used during construction		$	17	$	25	$	19
	Regulatory interest, net(3)			1		-1		―
	Sundry, net			-7		-7		-6
		Total	$	11	$	17	$	13
	-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	Sempra Energy Consolidated includes Otay Mesa VIE and additional instruments.
	-3	Interest on regulatory balancing accounts.
	-4	Related to Otay Mesa VIE.

ACQUISTION_AND_DIVESTITURE_ACT1

ACQUISTION AND DIVESTITURE ACTIVITY (Tables)	12 Months Ended
	Dec. 31, 2013
Deconsolidation (Tables) [Abstract]	'
Schedule Of Deconsolidation [Text Block]	'
	(Dollars in millions)		Copper Mountain Solar 2		Mesquite Solar 1
	Proceeds from sale, net of transaction costs(1)		$	69	$	100
	Property, plant and equipment, net			-266		-461
	Other assets			-30		-72
	Long-term debt, including current portion			146		297
	Other liabilities			19		31
	Gain on sale of assets			-4		-36
	Equity method investments upon deconsolidation		$	-66	$	-141
	-1	Transaction costs were $3 million at each of Copper Mountain Solar 2 and Mesquite Solar 1.
Proforma Revenue (Tables) [Abstract]	'
Schedule of Proforma Revenue [Text Block]	'
			Year ended
	(Dollars in millions)		31-Dec-11
	Revenues		$	10,379
	Earnings(1)			1,079
	-1	Excludes the $277 million gain related to the remeasurement of equity method investments.
Purchase Price Allocation (Tables) [Abstract]	'
Schedule of Purchase Price Allocation [Text Block]	'
	PURCHASE PRICE ALLOCATION
	(Dollars in millions)
				At April 6, 2011
									Other
					Chilean		Peruvian		holding
					entities		entities		companies		Total
	Fair value of businesses acquired:
		Cash consideration (fair value of total
		consideration)		$	495	$	385	$	8	$	888
		Fair value of equity method
		investments immediately prior to
		the acquisition			495		385		2		882
		Fair value of noncontrolling interests			37		242		―		279
	Total fair value of businesses acquired				1,027		1,012		10		2,049
	Recognized amounts of identifiable assets
		acquired and liabilities assumed:
			Cash		219		22		4		245
			Property, plant and equipment		555		931		―		1,486
			Long-term debt		-305		-179		―		-484
			Other net assets (liabilities) acquired		44		-223		6		-173
	Total identifiable net assets				513		551		10		1,074
	Goodwill			$	514	$	461	$	―	$	975

INVESTMENTS_IN_UNCONSOLIDATED_2

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule Of Equity Method And Other Investments [Abstract]	'
Schedule Of Equity Method And Other Investments	'
	EQUITY METHOD AND OTHER INVESTMENTS ON THE CONSOLIDATED BALANCE SHEETS
	(Dollars in millions)
			December 31,
			2013		2012
	Sempra South American Utilities:
	Eletrans(1)		$	-3	$	―
	Sempra Mexico:
	Gasoductos de Chihuahua			379		340
	Sempra Renewables:
	Auwahi Wind Farm			53		72
	Cedar Creek 2 Wind Farm			92		93
	Copper Mountain Solar 2			67		―
	Flat Ridge 2 Wind Farm			292		291
	Fowler Ridge 2 Wind Farm			51		47
	Mehoopany Wind Farm			85		89
	Mesquite Solar 1			67		―
	Sempra Natural Gas:
	Rockies Express Pipeline LLC			329		361
	Parent and other:
	RBS Sempra Commodities LLP			73		126
	Other			―		8
	Total equity method investments			1,485		1,427
	Other(2)			90		89
	Total		$	1,575	$	1,516
	-1	Includes losses on forward exchange contracts as we discuss below.
	-2	Other includes Sempra South American Utilities' $10 million and $11 million in real estate investments at December 31, 2013 and 2012, respectively, and Sempra Natural Gas' $77 million and $74 million investment in industrial development bonds at Mississippi Hub at December 31, 2013 and 2012, respectively.

DEBT_AND_CREDIT_FACILITIES_Tab

DEBT AND CREDIT FACILITIES (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule Of Long Term Debt [Abstract]	'
Schedule Of Long-term Debt	'
	LONG-TERM DEBT
	(Dollars in millions)
			December 31,
			2013		2012
	SDG&E
	First mortgage bonds:
		6.8% June 1, 2015	$	―	$	14
		5.3% November 15, 2015		250		250
		1.65% July 1, 2018(1)		161		161
		5.85% June 1, 2021(1)		―		60
		3% August 15, 2021		350		350
		3.6% September 1, 2023		450		―
		6% June 1, 2026		250		250
		5% to 5.25% December 1, 2027(1)		150		150
		5.875% January and February 2034(1)		176		176
		5.35% May 15, 2035		250		250
		6.125% September 15, 2037		250		250
		4% May 1, 2039(1)		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
				3,912		3,536
	Other long-term debt (unsecured unless otherwise noted):
		5.9% Notes June 1, 2014		15		130
		5.3% Notes July 1, 2021(1)		39		39
		5.5% Notes December 1, 2021(1)		60		60
		4.9% Notes March 1, 2023(1)		25		25
		5.2925% OMEC LLC loan
		payable 2013 through April 2019 (secured by plant assets)		335		345
	Capital lease obligations:
		Purchased-power agreements		176		178
		Other		3		7
				653		784
				4,565		4,320
	Current portion of long-term debt			-29		-16
	Unamortized discount on long-term debt			-11		-12
	Total SDG&E			4,525		4,292
	SoCalGas
	First mortgage bonds:
		5.5% March 15, 2014		250		250
		5.45% April 15, 2018		250		250
		5.75% November 15, 2035		250		250
		5.125% November 15, 2040		300		300
		3.75% September 15, 2042		350		350
				1,400		1,400
	Other long-term debt (unsecured):
		4.75% Notes May 14, 2016(1)		8		8
		5.67% Notes January 18, 2028		5		5
	Capital lease obligations			2		4
				15		17
				1,415		1,417
	Current portion of long-term debt			-252		-4
	Unamortized discount on long-term debt			-4		-4
	Total SoCalGas			1,159		1,409
	LONG-TERM DEBT (CONTINUED)
	(Dollars in millions)
			December 31,
			2013		2012
	Sempra Energy
	Other long-term debt (unsecured):
		6% Notes February 1, 2013		―		400
	8.9% Notes November 15, 2013, including $200 at variable rates after fixed-to-floating
	rate swaps effective January 2011		―		250
	2% Notes March 15, 2014		500		500
	Notes at variable rates (1.01% at December 31, 2013) March 15, 2014		300		300
	6.5% Notes June 1, 2016, including $300 at variable rates after fixed-to-floating
	rate swaps effective January 2011 (4.46% at December 31, 2013)		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
	2.875% Notes October 1, 2022		500		500
	4.05% Notes December 1, 2023		500		―
	6% Notes October 15, 2039		750		750
Market value adjustments for interest rate swaps, net (expire November 2013 and June 2016)			12		19
Build-to-suit lease(2)			14		―
Sempra Global
Other long-term debt (unsecured):
	Commercial paper borrowings at variable rates, classified as long-term debt
	(0.35% weighted average at December 31, 2013)		200		300
Sempra South American Utilities
Other long-term debt (unsecured):
Chilquinta Energía
	2.75% Series A Bonds October 30, 2014(1)		―		86
	4.25% Series B Bonds October 30, 2030(1)		209		224
Luz del Sur
	Bank loans 5.5% to 6.75% payable 2016 through December 2018		70		31
	Notes at 4.75% to 7.09% payable 2014 through October 2022		292		284
Sempra Mexico
Other long-term debt (unsecured):
	Notes February 8, 2018 at variable rates at 2.66% after floating-to-fixed rate cross-currency
	swaps effective February 2013		100		―
	6.3% Notes February 2, 2023 (4.12% after cross-currency swap)		298		―
Sempra Renewables
Other long-term debt (secured):
	Loan at variable rates payable 2014 through December 2028, including $78 at 4.54%
	after floating-to-fixed rate swaps effective June 2012 (2.75% at December 31, 2013)(1)		104		111
	Loans at 2.24% to 2.26% payable 2014 through January 2031		―		286
Sempra Natural Gas
First mortgage bonds (Mobile Gas):
	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(1)		18		17
	9% Notes May 13, 2013		―		1
	8.45% Notes payable 2014 through December 2017, secured		21		25
	3.1% Notes December 30, 2018, secured(1)		5		―
	4.5% Notes July 1, 2024, secured(1)		77		74
	Industrial development bonds at variable rates (0.05% at December 31, 2013)
	August 1, 2037, secured(1)		55		55
			6,437		6,625
Current portion of long-term debt			-866		-705
Unamortized discount on long-term debt			-9		-8
Unamortized premium on long-term debt			7		8
Total other Sempra Energy			5,569		5,920
Total Sempra Energy Consolidated		$	11,253	$	11,621
-1	Callable long-term debt not subject to make-whole provisions.
-2	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
	2014		$	24	$	250	$	866	$	1,140
	2015			260		―		52		312
	2016			10		8		828		846
	2017			10		―		662		672
	2018			171		250		652		1,073
	Thereafter			3,910		905		3,349		8,164
	Total		$	4,385	$	1,413	$	6,409	$	12,207
	-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	$	686	$	8	$	468	$	1,162
	Subject to make-whole provisions		3,350		1,400		4,683		9,433
Schedule Of Segment Long Term Debt [Abstract]	'
Schedule of segment long-term debt	'
	2013 BANK LOAN DRAWS – LUZ DEL SUR
	(Dollars in millions)
			Amount at
	Month Issued		Issuance		Interest Rate		Maturity Date
	June		$	11	5.50%		25-Jun-16
	July			5	6.00%		11-Jul-16
	July			14	5.85%		24-Jul-16
	December			22	6.41%		20-Dec-18

INCOME_TAXES_Tables

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2013
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,
			2013		2012		2011
	Sempra Energy Consolidated
	U.S. federal statutory income tax rate		35	%	35	%	35	%
	Utility depreciation		4		6		3
	Income tax restructuring related to IEnova stock offerings		4		―		―
	State income taxes, net of federal income tax benefit		1		-1		2
	Utility repairs expenditures		-5		-8		-1
	Tax credits		-3		-7		-1
	Non-U.S. earnings taxed at lower statutory income tax rates		-3		-4		-8
	Self-developed software expenditures		-3		-5		-3
	Adjustments to prior years’ income tax items		-3		-1		―
	Allowance for equity funds used during construction		-1		-4		-2
	Variable interest entities		-1		-1		―
	Life insurance contracts		―		-7		―
	Mexican foreign exchange and inflation effects		―		1		-1
	Other, net		1		2		-1
	Effective income tax rate		26	%	6	%	23	%
	SDG&E
	U.S. federal statutory income tax rate		35	%	35	%	35	%
	Depreciation		5		4		4
	State income taxes, net of federal income tax benefit		3		4		5
	Utility repairs expenditures		-4		-4		-1
	Self-developed software expenditures		-3		-3		-3
	Allowance for equity funds used during construction		-2		-4		-4
	Variable interest entity		-1		-1		-1
	Adjustments to prior years’ income tax items		-1		-3		―
	Other, net		-1		-1		-1
	Effective income tax rate		31	%	27	%	34	%
	SoCalGas
	U.S. federal statutory income tax rate		35	%	35	%	35	%
	Depreciation		6		7		6
	State income taxes, net of federal income tax benefit		4		3		4
	Utility repairs expenditures		-9		-12		―
	Self-developed software expenditures		-6		-9		-7
	Adjustments to prior years’ income tax items		-5		―		―
	Allowance for equity funds used during construction		-1		-2		-2
	Other, net		―		-1		-3
	Effective income tax rate		24	%	21	%	33	%
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]	'
		Years ended December 31,
	(Dollars in millions)	2013		2012		2011
	U.S.	$	941	$	442	$	1,011
	Non-U.S.		489		501		712
	Total	$	1,430	$	943	$	1,723
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,
		2013		2012		2011
	Sempra Energy Consolidated
	Current:
	U.S. Federal	$	-70	$	-36	$	76
	U.S. State		-5		-6		-3
	Non-U.S.		107		144		149
	Total		32		102		222
	Deferred:
	U.S. Federal		275		-63		176
	U.S. State		15		3		43
	Non-U.S.		48		20		-45
	Total		338		-40		174
	Deferred investment tax credits		-4		-3		-2
	Total income tax expense	$	366	$	59	$	394
	SDG&E
	Current:
	U.S. Federal	$	9	$	-109	$	-59
	U.S. State		11		14		6
	Total		20		-95		-53
	Deferred:
	U.S. Federal		149		255		253
	U.S. State		24		30		36
	Total		173		285		289
	Deferred investment tax credits		-2		―		1
	Total income tax expense	$	191	$	190	$	237
	SoCalGas
	Current:
	U.S. Federal	$	4	$	-73	$	-6
	U.S. State		-5		24		19
	Total		-1		-49		13
	Deferred:
	U.S. Federal		103		136		128
	U.S. State		16		-6		5
	Total		119		130		133
	Deferred investment tax credits		-2		-2		-3
	Total income tax expense	$	116	$	79	$	143
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,
		2013		2012
	Deferred income tax liabilities:
	Differences in financial and tax bases of depreciable and amortizable assets	$	3,951	$	3,710
	Regulatory balancing accounts		663		770
	Unrealized revenue		15		3
	Loss on reacquired debt		8		9
	Property taxes		50		46
	Difference in financial and tax bases of partnership interests		256		118
	Other deferred income tax liabilities		72		55
	Total deferred income tax liabilities		5,015		4,711
	Deferred income tax assets:
	Tax credits		105		67
	Equity losses		16		16
	Net operating losses		2,023		1,898
	Compensation-related items		128		156
	Postretirement benefits		264		587
	Other deferred income tax assets		14		90
	State income taxes		30		58
	Bad debt allowance		8		8
	Litigation and other accruals not yet deductible		20		7
	Deferred income tax assets before valuation allowances		2,608		2,887
	Less: valuation allowances		96		128
	Total deferred income tax assets		2,512		2,759
	Net deferred income tax liability	$	2,503	$	1,952
	Our policy is to show deferred income taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information.
	DEFERRED INCOME TAXES FOR SDG&E AND SOCALGAS
	(Dollars in millions)
		SDG&E				SoCalGas
		December 31,				December 31,
		2013		2012		2013		2012
	Deferred income tax liabilities:
	Differences in financial and tax bases of
	utility plant and other assets	$	2,040	$	1,947	$	1,045	$	938
	Regulatory balancing accounts		411		344		265		439
	Loss on reacquired debt		3		4		6		7
	Property taxes		36		32		16		15
	Other		25		22		―		―
	Total deferred income tax liabilities		2,515		2,349		1,332		1,399
	Deferred income tax assets:
	Net operating losses		440		446		65		34
	Postretirement benefits		57		137		126		370
	Tax credits		15		16		12		14
	Compensation-related items		13		14		38		48
	State income taxes		22		31		10		18
	Litigation and other accruals not yet deductible		45		38		27		21
	Hedging transaction		1		1		5		7
	Other		4		4		11		9
	Total deferred income tax assets		597		687		294		521
	Net deferred income tax liability	$	1,918	$	1,662	$	1,038	$	878
	Our policy is to show deferred income taxes of VIEs on a net basis, including valuation allowances. See table “Amounts Associated with Otay Mesa VIE” in Note 1 for further information.
	NET DEFERRED INCOME TAX LIABILITY
	(Dollars in millions)
		Sempra Energy
		Consolidated				SDG&E				SoCalGas
		2013		2012		2013		2012		2013		2012
	Current (asset) liability	$	-301	$	-148	$	-103	$	26	$	45	$	-3
	Noncurrent liability		2,804		2,100		2,021		1,636		993		881
	Total	$	2,503	$	1,952	$	1,918	$	1,662	$	1,038	$	878
Income Tax Uncertainties [Abstract]	'
Summary of Income Tax Contingencies	'
	SUMMARY OF UNRECOGNIZED INCOME TAX BENEFITS
	(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
	Sempra Energy Consolidated:
	Total	$	90	$	82	$	72
	Of the total, amounts related to tax positions that,
	if recognized in future years, would
	decrease the effective tax rate	$	-86	$	-81	$	-72
	increase the effective tax rate		19		16		7
	SDG&E:
	Total	$	17	$	12	$	7
	Of the total, amounts related to tax positions that,
	if recognized in future years, would
	decrease the effective tax rate	$	-14	$	-12	$	-7
	increase the effective tax rate		11		12		7
	SoCalGas:
	Total	$	13	$	5	$	―
	Of the total, amounts related to tax positions that,
	if recognized in future years, would
	decrease the effective tax rate	$	-13	$	-5	$	―
	increase the effective tax rate		8		4		―
	RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS
	(Dollars in millions)
		2013		2012		2011
	Sempra Energy Consolidated:
	Balance as of January 1	$	82	$	72	$	97
	Increase in prior period tax positions		26		2		7
	Decrease in prior period tax positions		-24		-1		-26
	Increase in current period tax positions		7		10		3
	Settlements with taxing authorities		-1		-1		-9
	Balance as of December 31	$	90	$	82	$	72
	SDG&E:
	Balance as of January 1	$	12	$	7	$	5
	Increase in prior period tax positions		7		1		―
	Decrease in prior period tax positions		-4		―		―
	Increase in current period tax positions		2		4		2
	Balance as of December 31	$	17	$	12	$	7
	SoCalGas:
	Balance as of January 1	$	5	$	―	$	8
	Increase in prior period tax positions		4		―		2
	Increase in current period tax positions		5		5		―
	Settlements with taxing authorities		-1		―		-10
	Balance as of December 31	$	13	$	5	$	―
	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,
		2013		2012		2011			2013		2012
	Sempra Energy Consolidated:
	Interest expense (income)	$	1	$	―	$	-3		$	4	$	3
	Penalties		―		―		-1			3		3
	SDG&E:
	Interest expense	$	―	$	―	$	―		$	1	$	1
	SoCalGas:
	Interest (income) expense	$	-1	$	―	$	-1		$	―	$	1
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,
		2013		2012		2011
	Sempra Energy Consolidated:
	Expiration of statutes of limitations on tax assessments	$	-7	$	-7	$	-7
	Potential resolution of audit issues with various
	U.S. federal, state and local and non-U.S. taxing authorities		-63		-10		―
		$	-70	$	-17	$	-7
	SDG&E:
	Potential resolution of audit issues with various
	U.S. federal, state and local and non-U.S. taxing authorities	$	-14	$	-5	$	―
	SoCalGas:
	Potential resolution of audit issues with various
	U.S. federal, state and local and non-U.S. taxing authorities	$	-11	$	-4	$	―

EMPLOYEE_BENEFIT_PLANS_Tables

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2013
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
	(Dollars in millions)
			Pension Benefits					Other Postretirement Benefits
	Sempra Energy Consolidated		2013		2012			2013		2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION:
	Net obligation at January 1		$	3,804	$	3,406		$	1,115	$	1,160
	Service cost			109		90			28		25
	Interest cost			148		162			44		52
	Contributions from plan participants			―		―			16		15
	Actuarial (gain) loss			-371		374			-177		-25
	Benefit payments			-293		-217			-55		-56
	Plan amendments			67		8			-3		-56
	Special termination benefits			―		―			5		―
	Settlements			-5		-19			―		―
	Net obligation at December 31			3,459		3,804			973		1,115
	CHANGE IN PLAN ASSETS:
	Fair value of plan assets at January 1			2,558		2,332			873		778
	Actual return on plan assets			396		339			151		97
	Employer contributions			133		123			27		39
	Contributions from plan participants			―		―			16		15
	Benefit payments			-293		-217			-55		-56
	Settlements			-5		-19			―		―
	Fair value of plan assets at December 31			2,789		2,558			1,012		873
	Funded status at December 31		$	-670	$	-1,246		$	39	$	-242
	Net recorded (liability) asset at December 31		$	-670	$	-1,246		$	39	$	-242
	PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
	(Dollars in millions)
		Pension Benefits					Other Postretirement Benefits
	SDG&E	2013		2012			2013		2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION:
	Net obligation at January 1	$	1,067	$	981		$	185	$	182
	Service cost		32		28			8		7
	Interest cost		41		45			8		9
	Contributions from plan participants		―		―			6		6
	Actuarial (gain) loss		-66		87			-19		-5
	Benefit payments		-89		-75			-12		-12
	Plan amendments		―		1			―		-2
	Special termination benefits		―		―			2		―
	Settlements		-4		―			―		―
	Transfer of liability to other plans		-42		―			-7		―
	Net obligation at December 31		939		1,067			171		185
	CHANGE IN PLAN ASSETS:
	Fair value of plan assets at January 1		781		712			126		106
	Actual return on plan assets		117		99			18		13
	Employer contributions		51		45			14		13
	Contributions from plan participants		―		―			6		6
	Benefit payments		-89		-75			-12		-12
	Settlements		-4		―			―		―
	Transfer of assets to other plans		-37		―			-6		―
	Fair value of plan assets at December 31		819		781			146		126
	Funded status at December 31	$	-120	$	-286		$	-25	$	-59
	Net recorded liability at December 31	$	-120	$	-286		$	-25	$	-59
	PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
	(Dollars in millions)
			Pension Benefits					Other Postretirement Benefits
	SoCalGas		2013		2012			2013		2012
	CHANGE IN PROJECTED BENEFIT OBLIGATION:
	Net obligation at January 1		$	2,299	$	2,017		$	873	$	921
	Service cost			67		53			17		16
	Interest cost			90		99			34		41
	Contributions from plan participants			―		―			10		9
	Actuarial (gain) loss			-285		245			-151		-19
	Benefit payments			-169		-120			-40		-41
Plan amendments			66		7			1		-54
Special termination benefits			―		―			2		―
Settlements			―		-2			―		―
Transfer of liability from other plans			42		―			7		―
Net obligation at December 31			2,110		2,299			753		873
CHANGE IN PLAN ASSETS:
Fair value of plan assets at January 1			1,581		1,443			732		658
Actual return on plan assets			250		213			131		83
Employer contributions			59		47			9		23
Contributions from plan participants			―		―			10		9
Benefit payments			-169		-120			-40		-41
Settlements			―		-2			―		―
Transfer of assets from other plans			37		―			6		―
Fair value of plan assets at December 31			1,758		1,581			848		732
Funded status at December 31		$	-352	$	-718		$	95	$	-141
Net recorded (liability) asset at December 31		$	-352	$	-718		$	95	$	-141
Schedule Of Defined Benefit Plans Amounts Recognized In Balance Sheet [Abstract]	'
Schedule Of Defined Benefit Plans, Amounts Recognized In Balance Sheet	'
		Pension Benefits					Other Postretirement Benefits
	(Dollars in millions)	2013		2012			2013		2012
	Sempra Energy Consolidated
	Noncurrent assets	$	―	$	―		$	95	$	―
	Current liabilities		-59		-31			―		-1
	Noncurrent liabilities		-611		-1,215			-56		-241
	Net recorded liability	$	-670	$	-1,246		$	39	$	-242
	SDG&E
	Current liabilities	$	-13	$	-5		$	―	$	―
	Noncurrent liabilities		-107		-281			-25		-59
	Net recorded liability	$	-120	$	-286		$	-25	$	-59
	SoCalGas
	Noncurrent assets	$	―	$	―		$	95	$	―
	Current liabilities		-13		-4			―		―
	Noncurrent liabilities		-339		-714			―		-141
	Net recorded liability	$	-352	$	-718		$	95	$	-141
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
		2013		2012			2013		2012
	Sempra Energy Consolidated
	Net actuarial loss	$	-73	$	-96		$	―	$	-6
	Prior service credit		―		1			―		―
	Total	$	-73	$	-95		$	―	$	-6
	SDG&E
	Net actuarial loss	$	-10	$	-12
	Prior service credit		1		1
	Total	$	-9	$	-11
	SoCalGas
	Net actuarial loss	$	-5	$	-4
	Prior service credit		1		1
	Total	$	-4	$	-3
Schedule Of Defined Benefit Plans Accumulated Benefit Obligation [Abstract]	'
Schedule Of Defined Benefit Plans, Accumulated Benefit Obligation	'
		Sempra Energy Consolidated					SDG&E					SoCalGas
	(Dollars in millions)	2013		2012			2013		2012			2013		2012
	Accumulated benefit obligation	$	3,254	$	3,530		$	923	$	1,041		$	1,944	$	2,080
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	'
	(Dollars in millions)	2013		2012
	Sempra Energy Consolidated
	Projected benefit obligation	$	3,212	$	3,544
	Accumulated benefit obligation		3,027		3,295
	Fair value of plan assets		2,789		2,558
	SDG&E
	Projected benefit obligation	$	899	$	1,025
	Accumulated benefit obligation		886		1,003
	Fair value of plan assets		819		781
	SoCalGas
	Projected benefit obligation	$	2,085	$	2,275
	Accumulated benefit obligation		1,920		2,057
	Fair value of plan assets		1,758		1,581
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
	(Dollars in millions)
		Pension Benefits							Other Postretirement Benefits
	Sempra Energy Consolidated	2013		2012		2011			2013		2012		2011
	Net Periodic Benefit Cost
	Service cost	$	109	$	90	$	83		$	28	$	25	$	31
	Interest cost		148		162		168			44		52		65
	Expected return on assets		-162		-155		-144			-58		-53		-48
	Amortization of:
	Prior service cost (credit)		4		3		4			-4		-4		―
	Actuarial loss		54		47		34			7		12		17
	Settlement charge		2		8		13			―		―		―
	Special termination benefits		―		―		―			5		―		―
	Regulatory adjustment		-20		-29		43			6		7		7
	Total net periodic benefit cost		135		126		201			28		39		72
	Other Changes in Plan Assets and Benefit Obligations
	Recognized in Other Comprehensive Income
	Net (gain) loss		-30		19		23			-8		-6		7
	Prior service cost		1		―		―			―		―		―
	Amortization of actuarial loss		-9		-9		-10			-1		―		―
	Total recognized in other comprehensive income		-38		10		13			-9		-6		7
	Total recognized in net periodic benefit cost and other comprehensive income	$	97	$	136	$	214		$	19	$	33	$	79
	NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
	(Dollars in millions)
		Pension Benefits							Other Postretirement Benefits
	SDG&E	2013		2012		2011			2013		2012		2011
	Net Periodic Benefit Cost
	Service cost	$	32	$	28	$	28		$	8	$	7	$	7
	Interest cost		41		45		49			8		9		10
	Expected return on assets		-52		-47		-46			-8		-8		-8
	Amortization of:
	Prior service cost		2		2		1			4		4		4
	Actuarial loss		14		14		9			―		―		―
	Settlement charge		1		1		1			―		―		―
	Special termination benefits		―		―		―			2		―		―
	Regulatory adjustment		14		6		31			―		1		2
	Total net periodic benefit cost		52		49		73			14		13		15
	Other Changes in Plan Assets and Benefit Obligations
	Recognized in Other Comprehensive Income
	Net (gain) loss		-2		2		1			―		―		―
	Amortization of actuarial loss		-1		-1		-1			―		―		―
	Total recognized in other comprehensive income		-3		1		―			―		―		―
	Total recognized in net periodic benefit cost and other comprehensive income	$	49	$	50	$	73		$	14	$	13	$	15
	NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OTHER COMPREHENSIVE INCOME
	(Dollars in millions)
		Pension Benefits							Other Postretirement Benefits
	SoCalGas	2013		2012		2011			2013		2012		2011
	Net Periodic Benefit Cost
	Service cost	$	67	$	53	$	46		$	17	$	16	$	22
	Interest cost		90		99		99			34		41		53
	Expected return on assets		-98		-96		-85			-48		-44		-40
	Amortization of:
	Prior service cost (credit)		2		2		2			-8		-7		-4
	Actuarial loss		31		23		17			6		11		17
	Settlement charge		―		1		1			―		―		―
	Special termination benefits		―		―		―			2		―		―
	Regulatory adjustment		-34		-36		12			6		5		5
	Total net periodic benefit cost		58		46		92			9		22		53
	Other Changes in Plan Assets and Benefit Obligations
	Recognized in Other Comprehensive Income
	Net loss (gain)		3		-4		2			―		―		―
	Amortization of actuarial loss		-1		-1		-1			―		―		―
	Total recognized in other comprehensive income		2		-5		1			―		―		―
Total recognized in net periodic benefit cost and other comprehensive income	$	60	$	41	$	93		$	9	$	22	$	53
Schedule Of Defined Benefit Plans Assumptions Used In Calculations [Abstract]	'
Schedule Of Defined Benefit Plans, Assumptions Used In Calculations	'
	WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31
			Pension Benefits					Other Postretirement Benefits
			2013		2012			2013		2012
	Sempra Energy Consolidated
	Discount rate		4.84	%	4.04	%		4.95	%	4.09	%
	Rate of compensation increase		3.50-10.00		3.50-9.50			3.50-10.00		3.50-9.50
	SDG&E
	Discount rate		4.69	%	3.94	%		5	%	4.1	%
	Rate of compensation increase		3.50-10.00		3.50-9.50			3.50-10.00		3.50-9.50
	SoCalGas
	Discount rate		4.94	%	4.1	%		4.95	%	4.1	%
	Rate of compensation increase		3.50-10.00		3.50-9.50			3.50-10.00		3.50-9.50
	WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST FOR YEARS ENDED DECEMBER 31
			Pension Benefits							Other Postretirement Benefits
			2013		2012		2011			2013		2012		2011
	Sempra Energy Consolidated
	Discount rate		4.04	%	4.40-5.05	%	4.40-5.14	%		4.09	%	4.10-5.15	%	4.10-5.15	%
	Expected return on plan assets		7		7		7			6.96		6.96		6.25
	Rate of compensation increase		3.50-9.50		3.50-8.50		3.50-8.50			3.50-9.50		3.50-9.50		3.50-9.50
	SDG&E
	Discount rate		3.94	%	4.70-4.80	%	4.70-4.80	%		4.1	%	5.05	%	5.05	%
	Expected return on plan assets		7		7		7			6.81		6.81		6.69
	Rate of compensation increase		3.50-9.50		3.50-8.50		3.50-8.50			N/A		N/A		N/A
	SoCalGas
	Discount rate		4.1	%	4.70-5.05	%	4.70-5.05	%		4.1	%	5.15	%	5.15	%
	Expected return on plan assets		7		7		7			7		7		7
	Rate of compensation increase		3.50-9.50		3.50-8.50		3.50-8.50			3.50-9.50		3.50-9.50		3.50-9.50
Schedule Of Defined Benefit Plans Assumed Health Care Cost Trend Rates [Abstract]	'
Schedule Of Defined Benefit Plans, Assumed Health Care Cost Trend Rates	'
			2013		2012
	ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31:
	Health care cost trend rate		-1		-2
	Rate to which the cost trend rate is assumed to decline (the ultimate trend)		-3		-4
	Year that the rate reaches the ultimate trend		-5		2020
	-1	8.25% for pre-65 retirees and 5.50% for retirees aged 65 years and older. For Mobile Gas, the health care cost trend rate is assumed to be 7.50%.
	-2	10.00% for pre-65 retirees and 8.25% for retirees aged 65 years and older. For Mobile Gas, the health care cost trend rate is assumed to be 8.00%.
	-3	5.00% for pre-65 retirees and 4.50% for retirees aged 65 years and older. For Mobile Gas, the rate to which the cost trend rate is assumed to decline is 5.00%.
	-4	5.00% for pre-65 retirees and 4.75% for retirees aged 65 years and older. For Mobile Gas, the rate to which the cost trend rate is assumed to decline is 5.00%.
	-5	2019 for Mobile Gas plan and 2020 for all other plans.
		Sempra Energy
		Consolidated					SDG&E					SoCalGas
		1%		1%			1%		1%			1%		1%
	(Dollars in millions)	Increase		Decrease			Increase		Decrease			Increase		Decrease
	Effect on total of service and interest
	cost components of net periodic
	postretirement health care benefit cost	$	8	$	-6		$	1	$	-1		$	6	$	-5
	Effect on the health care component of the
	accumulated other postretirement
	benefit obligations		100		-62			8		-6			90		-54
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 — SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
			At fair value as of December 31, 2013
	PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
	SDG&E (see table below)		$	576	$	269	$	6	$	851
	SoCalGas (see table below)			1,157		540		13		1,710
	Other Sempra Energy
	Equity securities:
	Domestic(1)			79		―		―		79
	Foreign			52		―		―		52
	Registered investment companies			11		―		―		11
	Fixed income securities:
	U.S. Treasury securities			1		―		―		1
	Domestic municipal bonds			―		3		―		3
	Foreign government bonds			―		7		―		7
	Domestic corporate bonds(2)			―		38		―		38
	Foreign corporate bonds			―		13		―		13
	Common/collective trusts(3)			―		5		―		5
	Other types of investments:
	Private equity funds(4) (stated at net asset value)			―		―		2		2
	Total other Sempra Energy(5)			143		66		2		211
	Total Sempra Energy Consolidated(6)		$	1,876	$	875	$	21	$	2,772
			At fair value as of December 31, 2012
	PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
	SDG&E (see table below)		$	530	$	241	$	6	$	777
	SoCalGas (see table below)			1,074		485		13		1,572
	Other Sempra Energy
	Equity securities:
	Domestic(1)			77		―		―		77
	Foreign			54		―		―		54
	Registered investment companies			2		―		―		2
	Fixed income securities:
	Domestic municipal bonds			―		3		―		3
	Foreign government bonds			―		5		―		5
	Domestic corporate bonds(2)			―		37		―		37
	Foreign corporate bonds			―		13		―		13
	Common/collective trusts(3)			―		2		―		2
	Other types of investments:
	Private equity funds(4) (stated at net asset value)			―		―		2		2
	Total other Sempra Energy(5)			133		60		2		195
	Total Sempra Energy Consolidated(6)		$	1,737	$	786	$	21	$	2,544
	-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.
	-5	Excludes cash and cash equivalents of $1 million at each of December 31, 2013 and 2012.
	-6	Excludes cash and cash equivalents of $17 million and $14 million at December 31, 2013 and 2012, respectively.
	FAIR VALUE MEASUREMENTS — SDG&E
	(Dollars in millions)
			At fair value as of December 31, 2013
	PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
	Equity securities:
	Domestic(1)		$	317	$	―	$	―	$	317
	Foreign			211		―		―		211
	Foreign preferred			2		―		―		2
	Registered investment companies			44		―		―		44
	Fixed income securities:
	U.S. Treasury securities			2		―		―		2
	Domestic municipal bonds			―		11		―		11
	Foreign government bonds			―		25		―		25
	Domestic corporate bonds(2)			―		152		―		152
	Domestic partnership bonds(2)			―		1		―		1
	Foreign corporate bonds			―		55		―		55
Common/collective trusts(3)			―		25		―		25
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		6		6
Total investment assets(5)		$	576	$	269	$	6	$	851
		At fair value as of December 31, 2012
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	307	$	―	$	―	$	307
Foreign			215		―		―		215
Foreign preferred			2		―		―		2
Registered investment companies			6		―		―		6
Fixed income securities:
Domestic municipal bonds			―		12		―		12
Foreign government bonds			―		22		―		22
Domestic corporate bonds(2)			―		147		―		147
Foreign corporate bonds			―		52		―		52
Common/collective trusts(3)			―		8		―		8
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		6		6
Total investment assets(6)		$	530	$	241	$	6	$	777
-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.
-5	Excludes cash and cash equivalents of $5 million and transfers payable to other plans of $37 million.
-6	Excludes cash and cash equivalents of $4 million.
FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
		At fair value as of December 31, 2013
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	637	$	―	$	―	$	637
Foreign			423		―		―		423
Foreign preferred			4		―		―		4
Registered investment companies			89		―		―		89
Fixed income securities:
U.S. Treasury securities			4		―		―		4
Domestic municipal bonds			―		21		―		21
Foreign government bonds			―		51		―		51
Domestic corporate bonds(2)			―		306		―		306
Domestic partnership bonds(2)			―		2		―		2
Foreign corporate bonds			―		110		―		110
Common/collective trusts(3)			―		50		―		50
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		13		13
Total investment assets(5)		$	1,157	$	540	$	13	$	1,710
		At fair value as of December 31, 2012
PENSION PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	622	$	―	$	―	$	622
Foreign			436		―		―		436
Foreign preferred			4		―		―		4
Registered investment companies			12		―		―		12
Fixed income securities:
Domestic municipal bonds			―		24		―		24
Foreign government bonds			―		44		―		44
Domestic corporate bonds(2)			―		297		―		297
Foreign corporate bonds			―		105		―		105
Common/collective trusts(3)			―		15		―		15
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		13		13
Total investment assets(6)		$	1,074	$	485	$	13	$	1,572
-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.
-5	Excludes cash and cash equivalents of $11 million and transfers receivable from other plans of $37 million.
-6	Excludes cash and cash equivalents of $9 million.
FAIR VALUE MEASUREMENTS — SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
		At fair value as of December 31, 2013
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	105	$	45	$	1	$	151
SoCalGas (see table below)			256		581		2		839
Other Sempra Energy
Equity securities:
Domestic(1)			4		―		―		4
Foreign			4		―		―		4
Registered investment companies			4		―		―		4
Fixed income securities:
Domestic corporate bonds(2)			―		3		―		3
Foreign government bonds			―		1		―		1
Foreign corporate bonds			―		1		―		1
Registered investment companies			―		1		―		1
Total other Sempra Energy			12		6		―		18
Total Sempra Energy Consolidated(3)		$	373	$	632	$	3	$	1,008
		At fair value as of December 31, 2012
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
SDG&E (see table below)		$	87	$	38	$	1	$	126
SoCalGas (see table below)			213		514		2		729
Other Sempra Energy
Equity securities:
Domestic(1)			5		―		―		5
Foreign			1		―		―		1
Foreign preferred			1		―		―		1
Registered investment companies			3		1		―		4
Fixed income securities:
Domestic corporate bonds(2)			―		2		―		2
Foreign government bonds			―		1		―		1
Foreign corporate bonds			―		1		―		1
Total other Sempra Energy			10		5		―		15
Total Sempra Energy Consolidated(4)		$	310	$	557	$	3	$	870
-1	Investments in common stock of domestic corporations.
-2	Bonds of U.S. issuers from diverse industries, primarily investment-grade.
-3	Excludes cash and cash equivalents of $4 million, $3 million and $1 million of which is held in SoCalGas and SDG&E PBOP plan trusts, respectively.
-4	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts.
FAIR VALUE MEASUREMENTS — SDG&E
(Dollars in millions)
		At fair value as of December 31, 2013
OTHER POSTRETIREMENT BENEFIT PLAN - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	37	$	―	$	―	$	37
Foreign			25		―		―		25
Registered investment companies			43		―		―		43
Fixed income securities:
Domestic municipal bonds(2)			―		3		―		3
Domestic corporate bonds(3)			―		18		―		18
Foreign government bonds			―		3		―		3
Foreign corporate bonds			―		6		―		6
Common/collective trusts(4)			―		3		―		3
Registered investment companies			―		12		―		12
Other types of investments:
Private equity funds(5) (stated at net asset value)			―		―		1		1
Total investment assets(6)		$	105	$	45	$	1	$	151
		At fair value as of December 31, 2012
OTHER POSTRETIREMENT BENEFIT PLAN - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	32	$	―	$	―	$	32
Foreign			23		―		―		23
Registered investment companies			32		―		―		32
Fixed income securities:
Domestic municipal bonds(2)			―		3		―		3
Domestic corporate bonds(3)			―		15		―		15
Foreign government bonds			―		2		―		2
Foreign corporate bonds			―		5		―		5
Common/collective trusts(4)			―		1		―		1
Registered investment companies			―		12		―		12
Other types of investments:
Private equity funds(5) (stated at net asset value)			―		―		1		1
Total investment assets		$	87	$	38	$	1	$	126
-1	Investments in common stock of domestic corporations.
-2	Bonds of California municipalities held in SDG&E PBOP plan trusts.
-3	Bonds of U.S. issuers from diverse industries, primarily investment-grade.
-4	Investment in common/collective trusts held in PBOP plan VEBA trusts.
-5	Investments in venture capital and real estate funds.
-6	Excludes cash and cash equivalents of $1 million, all of which is held in SDG&E PBOP plan trusts, and transfers payable to other plans of $6 million.
FAIR VALUE MEASUREMENTS — SOCALGAS
(Dollars in millions)
		At fair value as of December 31, 2013
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	128	$	―	$	―	$	128
Foreign			83		―		―		83
Foreign preferred			1		―		―		1
Registered investment companies			43		―		―		43
Broad market funds			―		220		―		220
Fixed income securities:
U.S. Treasury securities			1		―		―		1
Domestic municipal bonds			―		4		―		4
Domestic corporate bonds(2)			―		60		―		60
Foreign government bonds			―		10		―		10
Foreign corporate bonds			―		22		―		22
Common/collective trusts(3)			―		262		―		262
Registered investment companies			―		3		―		3
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total investment assets(5)		$	256	$	581	$	2	$	839
		At fair value as of December 31, 2012
OTHER POSTRETIREMENT BENEFIT PLANS - INVESTMENT ASSETS			Level 1		Level 2		Level 3		Total
Equity securities:
Domestic(1)		$	118	$	―	$	―	$	118
Foreign			84		―		―		84
Registered investment companies			11		―		―		11
Broad market funds			―		316		―		316
Fixed income securities:
Domestic municipal bonds			―		5		―		5
Domestic corporate bonds(2)			―		57		―		57
Foreign government bonds			―		8		―		8
Foreign corporate bonds			―		20		―		20
Common/collective trusts(3)			―		107		―		107
Registered investment companies			―		1		―		1
Other types of investments:
Private equity funds(4) (stated at net asset value)			―		―		2		2
Total investment assets(6)		$	213	$	514	$	2	$	729
-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.
-4	Investments in venture capital and real estate funds.
-5	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts, and transfers receivable from other plans of $6 million.
-6	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts.
Schedule Of Defined Benefit Plans Level 3 Investment Plan Assets [Abstract]	'
Schedule Of Defined Benefit Plans, Level 3 Investment Plan Assets	'
		Private Equity Funds
		2013					2012
	(Dollars in millions)	SDG&E	SoCalGas	All Other	Sempra Energy Consolidated		SDG&E	SoCalGas	All Other	Sempra Energy Consolidated
	PENSION PLANS
	Total Level 3 investment assets	$6	$13	$2	$21		$6	$13	$2	$21
	Percentage of total investment assets	1%	1%	1%	1%		1%	1%	1%	1%
	OTHER POSTRETIREMENT BENEFIT PLANS
	Total Level 3 investment assets	$1	$2	$-	$3		$1	$2	$-	$3
	Percentage of total investment assets	1%	-%	-%	-%		1%	-%	-%	-%
Schedule Of Defined Benefit Plans Level 3 Reconciliations [Abstract]	'
Schedule Of Defined Benefit Plans, Level 3 Reconciliations	'
	LEVEL 3 RECONCILIATIONS
	(Dollars in millions)
		Private Equity Funds
			SDG&E		SoCalGas		All Other		Sempra Energy Consolidated
	PENSION PLANS
	Balance as of January 1, 2012	$	7	$	15	$	2	$	24
	Unrealized gains		2		4		―		6
	Sales		-3		-6		―		-9
	Balance as of December 31, 2012		6		13		2		21
	Realized gains		1		2		―		3
	Unrealized losses		-1		-1		―		-2
	Sales		―		-1		―		-1
	Balance as of December 31, 2013	$	6	$	13	$	2	$	21
	OTHER POSTRETIREMENT BENEFIT PLANS
	Balance as of January 1, 2012	$	1	$	3	$	―	$	4
	Sales		―		-1		―		-1
	Balance as of December 31, 2012 and 2013	$	1	$	2	$	―	$	3
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	'
		Sempra Energy
	(Dollars in millions)	Consolidated		SDG&E		SoCalGas
	Pension plans	$	199	$	72	$	85
	Other postretirement benefit plans		12		9		―
Schedule Of Defined Benefit Plans Estimated Future Benefit Payments [Abstract]	'
Schedule Of Defined Benefit Plans, Estimated Future Benefit Payments	'
		Sempra Energy Consolidated					SDG&E					SoCalGas
				Other					Other					Other
		Pension		Postretirement			Pension		Postretirement			Pension		Postretirement
	(Dollars in millions)	Benefits		Benefits			Benefits		Benefits			Benefits		Benefits
	2014	$	390	$	47		$	109	$	8		$	234	$	36
	2015		335		52			95		9			202		40
	2016		329		55			89		10			199		43
	2017		317		60			88		11			194		46
	2018		308		64			85		12			188		49
	2019-2023		1,305		346			381		65			772		261
Schedule Of Defined Benefit Plans Contributions To Savings Plans [Abstract]	'
Schedule Of Defined Benefit Plans, Contributions To Savings Plans	'
	(Dollars in millions)	2013		2012		2011
	Sempra Energy Consolidated	$	35	$	34	$	32
	SDG&E		14		16		14
	SoCalGas		17		15		14

SHAREBASED_COMPENSATION_Tables

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013		2012		2011
	Share-based compensation expense, before income taxes	$	38	$	40	$	44
	Income tax benefit		-15		-16		-18
	Share-based compensation expense, net of income taxes	$	23	$	24	$	26
	Net share-based compensation expense, per common share
	Basic	$	0.09	$	0.1	$	0.11
	Diluted	$	0.09	$	0.1	$	0.11
	SHARE-BASED COMPENSATION EXPENSE ― SDG&E AND SOCALGAS
	(Dollars in millions)
		Years ended December 31,
		2013		2012		2011
	SDG&E:
	Compensation expense	$	8	$	8	$	8
	Capitalized compensation cost		3		3		3
	SoCalGas:
	Compensation expense	$	8	$	7	$	9
	Capitalized compensation cost		1		1		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 December 31, 2012		2,701,118	$	51.86
	Exercised		-1,237,348	$	50.32
	Forfeited/canceled		-4,625	$	48.4
	Outstanding at December 31, 2013		1,459,145	$	53.18		4	$	53
	Vested or expected to vest, at December 31, 2013		1,459,145	$	53.18		4	$	53
	Exercisable at December 31, 2013		1,300,745	$	52.86		3.8	$	48
Schedule Of Restricted Stock Awards And Units Valuation Assumptions [Abstract]	'
Schedule Of Restricted Stock Awards And Units Valuation Assumptions	'
		2013		2012		2011
	Risk-free rate of return	0.60%		0.60%		1.50%
	Annual dividend yield	3.30%		3.40%		3.00%
	Stock price volatility	19%		27%		27%
Schedule Of Restricted Stock Awards [Abstract]	'
Schedule Of Restricted Stock Awards	'
	RESTRICTED STOCK AWARDS
				Weighted-
				Average
				Grant-Date
		Shares		Fair Value
	Nonvested at December 31, 2012		24,689	$	56.59
	Granted		4,617	$	75.82
	Vested		-11,837	$	55.49
	Nonvested at December 31, 2013		17,469	$	62.43
	Vested or expected to vest, at December 31, 2013		17,469	$	62.43
Schedule Of Restricted Stock Units [Abstract]	'
Schedule Of Restricted Stock Units	'
	RESTRICTED STOCK UNITS
			Performance-Based				Service-Based
			Restricted Stock Units				Restricted Stock Units
				Weighted-				Weighted-
				Average				Average
				Grant-Date				Grant-Date
			Units	Fair Value			Units	Fair Value
	Nonvested at December 31, 2012		3,400,033	$	42.72		135,241	$	55.42
	Granted		657,168	$	57.55		107,718	$	72.71
	Vested		-864,100	$	36.04		-24,751	$	61.97
	Forfeited		-28,540	$	50.55		-2,610	$	56.23
	Nonvested at December 31, 2013(1)		3,164,561	$	47.55		215,598	$	63.3
	Vested or expected to vest, at December 31, 2013		3,107,020	$	47.45		203,655	$	63.12
	-1	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, up to an additional 50 percent of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.

DERIVATIVE_FINANCIAL_INSTRUMEN2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule Of Commodity Derivative Volumes [Abstract]	'
Schedule Of Commodity Derivative Volumes	'
				December 31,
	Segment and Commodity			2013	2012
	California Utilities:
	SDG&E:
		Natural gas		43 million MMBtu	25 million MMBtu	-1
		Congestion revenue rights		33 million MWh	30 million MWh	-2
	SoCalGas - natural gas			2 million MMBtu	―
	Energy-Related Businesses:
	Sempra Natural Gas:
	Electric power			1 million MWh	1 million MWh
	Natural gas			15 million MMBtu	36 million MMBtu
	Sempra Mexico - natural gas			―	1 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	'
			31-Dec-13			31-Dec-12
	(Dollars in millions)		Notional Debt		Maturities	Notional Debt		Maturities
	Sempra Energy Consolidated
		Cash flow hedges(1)	$	413	2014-2028	$	439	2013-2028
		Fair value hedges		300	2016		500	2013-2016
	SDG&E
		Cash flow hedge(1)		335	2019		345	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)
			31-Dec-13
										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)		$	14	$	12	$	-18	$	-75
	Derivatives not designated as hedging instruments:
	Interest rate and foreign exchange instruments			8		22		-7		-17
	Commodity contracts not subject to rate recovery			47		7		-51		-5
	Associated offsetting commodity contracts			-43		-5		43		5
	Associated offsetting cash collateral			―		―		1		―
	Commodity contracts subject to rate recovery			35		72		-10		-8
	Associated offsetting commodity contracts			-3		-2		3		2
	Net amounts presented on the balance sheet			58		106		-39		-98
	Additional cash collateral for commodity contracts
	not subject to rate recovery			17		―		―		―
	Additional cash collateral for commodity contracts
	subject to rate recovery			31		―		―		―
	Total		$	106	$	106	$	-39	$	-98
	SDG&E:
	Derivatives designated as hedging instruments:
	Interest rate instruments(3)		$	―	$	―	$	-16	$	-39
	Derivatives not designated as hedging instruments:
	Commodity contracts subject to rate recovery			34		72		-9		-8
	Associated offsetting commodity contracts			-3		-2		3		2
	Net amounts presented on the balance sheet			31		70		-22		-45
	Additional cash collateral for commodity contracts
	not subject to rate recovery			1		―		―		―
	Additional cash collateral for commodity contracts
	subject to rate recovery			29		―		―		―
	Total		$	61	$	70	$	-22	$	-45
	SoCalGas:
	Derivatives not designated as hedging instruments:
	Commodity contracts subject to rate recovery		$	1	$	―	$	-1	$	―
	Net amounts presented on the balance sheet			1		―		-1		―
	Additional cash collateral for commodity contracts
	not subject to rate recovery			2		―		―		―
	Additional cash collateral for commodity contracts
	subject to rate recovery			2		―		―		―
	Total		$	5	$	―	$	-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.
	DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS
	(Dollars in millions)
			31-Dec-12
										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 instruments(3)		$	7	$	12	$	-19	$	-64
Commodity contracts not subject to rate recovery			1		―		―		―
Derivatives not designated as hedging instruments:
Interest rate instruments			8		40		-8		-35
Commodity contracts not subject to rate recovery			117		15		-116		-27
Associated offsetting commodity contracts			-102		-12		102		12
Associated offsetting cash collateral			―		―		4		7
Commodity contracts subject to rate recovery			30		35		-35		-1
Associated offsetting commodity contracts			-4		―		4		―
Associated offsetting cash collateral			―		―		22		1
Net amounts presented on the balance sheet			57		90		-46		-107
Additional cash collateral for commodity contracts
not subject to rate recovery			22		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			13		―		―		―
Total		$	92	$	90	$	-46	$	-107
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	-17	$	-64
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery			28		35		-33		-1
Associated offsetting commodity contracts			-3		―		3		―
Associated offsetting cash collateral			―		―		22		1
Net amounts presented on the balance sheet			25		35		-25		-64
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			12		―		―		―
Total		$	38	$	35	$	-25	$	-64
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery		$	2	$	―	$	-2	$	―
Associated offsetting commodity contracts			-1		―		1		―
Net amounts presented on the balance sheet			1		―		-1		―
Additional cash collateral for commodity contracts
not subject to rate recovery			2		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			1		―		―		―
Total		$	4	$	―	$	-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.
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 IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
	(Dollars in millions)
				Gain (loss) on derivatives recognized in earnings
				Years ended December 31,
			Location	2013		2012		2011
	Sempra Energy Consolidated:
		Interest rate instruments	Interest Expense	$	8	$	6	$	9
		Interest rate instruments	Other Income, Net		-7		3		13
		Total(1)		$	1	$	9	$	22
	SoCalGas:
		Interest rate instrument	Interest Expense	$	―	$	―	$	1
		Interest rate instrument	Other Income, Net		―		―		-3
		Total(1)		$	―	$	―	$	-2
	-1	There has been no hedge ineffectiveness on these swaps. Changes in the fair values of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt.
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 IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
	(Dollars in millions)
			Pretax gain (loss) recognized in OCI							Gain (loss) reclassified from AOCI into earnings
			(effective portion)							(effective portion)
			Years ended December 31,							Years ended December 31,
				2013		2012		2011	Location		2013		2012		2011
	Sempra Energy Consolidated:
		Interest rate and foreign
		exchange instruments(1)	$	1	$	-22	$	-42	Interest Expense	$	-11	$	-9	$	-8
									Equity Earnings (Losses),
		Interest rate instruments		15		-10		-32	Before Income Tax		-10		-6		-5
		Commodity contracts not							Cost of Natural Gas, Electric
		subject to rate recovery		-4		-1		―	Fuel and Purchased Power		1		―		―
		Total	$	12	$	-33	$	-74		$	-20	$	-15	$	-13
	SDG&E:
		Interest rate instruments(1)	$	8	$	-16	$	-40	Interest Expense	$	-9	$	-5	$	-5
	SoCalGas:
		Interest rate instrument	$	―	$	―	$	―	Interest Expense	$	-1	$	-2	$	-3
	-1	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. There was a negligible amount of ineffectiveness related to these swaps.
Schedule Of Undesignated Derivative Instruments Impact On Statements Of Operations [Abstract]	'
Schedule Of Undesignated Derivative Impact on the Consolidated Statements of Operations	'
	UNDESIGNATED DERIVATIVE IMPACT ON THE CONSOLIDATED STATEMENTS OF OPERATIONS
	(Dollars in millions)
				Gain (loss) on derivatives recognized in earnings
				Years ended December 31,
			Location	2013		2012		2011
	Sempra Energy Consolidated:
		Interest rate and foreign
		exchange instruments(1)	Other Income, Net	$	17	$	10	$	-14
		Foreign exchange instruments	Equity Earnings, Net of Income Tax		-4		―		―
		Commodity contracts not subject	Revenues: Energy-Related
		to rate recovery	Businesses		-1		7		30
		Commodity contracts not subject	Cost of Natural Gas, Electric
		to rate recovery	Fuel and Purchased Power		―		―		1
		Commodity contracts not subject
		to rate recovery	Other Operation and Maintenance		1		1		1
		Commodity contracts subject	Cost of Electric Fuel
		to rate recovery	and Purchased Power		53		69		-14
		Commodity contracts subject
		to rate recovery	Cost of Natural Gas		―		-2		-2
		Total		$	66	$	85	$	2
	SDG&E:
		Interest rate instruments(1)	Other Income, Net	$	―	$	―	$	-1
		Commodity contracts subject	Cost of Electric Fuel
		to rate recovery	and Purchased Power		53		69		-14
		Total		$	53	$	69	$	-15
	SoCalGas:
		Commodity contracts not subject
		to rate recovery	Operation and Maintenance	$	1	$	1	$	1
		Commodity contracts subject
		to rate recovery	Cost of Natural Gas		―		-2		-2
		Total		$	1	$	-1	$	-1
	-1	Amount for 2011 is related to Otay Mesa VIE. Sempra Energy Consolidated also includes additional instruments.

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule Of Recurring Fair Value Assets Liabilities [Abstract]	'
Schedule Of Recurring Fair Value Measures	'
	RECURRING FAIR VALUE MEASURES ― SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
			At fair value as of December 31, 2013
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts
	Equity securities		$	614	$	―	$	―	$	―	$	614
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			59		58		―		―		117
	Municipal bonds			―		111		―		―		111
	Other securities			―		153		―		―		153
	Total debt securities			59		322		―		―		381
	Total nuclear decommissioning trusts(2)			673		322		―		―		995
	Interest rate instruments			―		56		―		―		56
	Commodity contracts subject to rate recovery			2		1		99		31		133
	Commodity contracts not subject to rate recovery			1		5		―		17		23
	Total		$	676	$	384	$	99	$	48	$	1,207
	Liabilities:
	Interest rate and foreign exchange instruments		$	―	$	117	$	―	$	―	$	117
	Commodity contracts subject to rate recovery			―		13		―		―		13
	Commodity contracts not subject to rate recovery			4		8		―		-5		7
	Total		$	4	$	138	$	―	$	-5	$	137
			At fair value as of December 31, 2012
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts
	Equity securities		$	539	$	―	$	―	$	―	$	539
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			87		69		―		―		156
	Municipal bonds			―		63		―		―		63
	Other securities			―		130		―		―		130
	Total debt securities			87		262		―		―		349
	Total nuclear decommissioning trusts(2)			626		262		―		―		888
	Interest rate instruments			―		68		―		―		68
	Commodity contracts subject to rate recovery			―		―		61		13		74
	Commodity contracts not subject to rate recovery			13		8		―		22		43
	Investments			1		―		―		―		1
	Total		$	640	$	338	$	61	$	35	$	1,074
	Liabilities:
	Interest rate instruments		$	―	$	126	$	―	$	―	$	126
	Commodity contracts subject to rate recovery			23		9		―		-23		9
	Commodity contracts not subject to rate recovery			6		23		―		-11		18
	Total		$	29	$	158	$	―	$	-34	$	153
	-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)
			At fair value as of December 31, 2013
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts
	Equity securities		$	614	$	―	$	―	$	―	$	614
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			59		58		―		―		117
	Municipal bonds			―		111		―		―		111
	Other securities			―		153		―		―		153
	Total debt securities			59		322		―		―		381
	Total nuclear decommissioning trusts(2)			673		322		―		―		995
	Commodity contracts subject to rate recovery			1		1		99		29		130
	Commodity contracts not subject to rate recovery			―		―		―		1		1
Total		$	674	$	323	$	99	$	30	$	1,126
Liabilities:
Interest rate instruments		$	―	$	55	$	―	$	―	$	55
Commodity contracts subject to rate recovery			―		12		―		―		12
Total		$	―	$	67	$	―	$	―	$	67
		At fair value as of December 31, 2012
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts
Equity securities		$	539	$	―	$	―	$	―	$	539
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			87		69		―		―		156
Municipal bonds			―		63		―		―		63
Other securities			―		130		―		―		130
Total debt securities			87		262		―		―		349
Total nuclear decommissioning trusts(2)			626		262		―		―		888
Commodity contracts subject to rate recovery			―		―		61		12		73
Commodity contracts not subject to rate recovery			―		―		―		1		1
Total		$	626	$	262	$	61	$	13	$	962
Liabilities:
Interest rate instruments		$	―	$	81	$	―	$	―	$	81
Commodity contracts subject to rate recovery			23		8		―		-23		8
Total		$	23	$	89	$	―	$	-23	$	89
-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)
		At fair value as of December 31, 2013
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	1	$	―	$	―	$	2	$	3
Commodity contracts not subject to rate recovery			―		―		―		2		2
Total		$	1	$	―	$	―	$	4	$	5
Liabilities:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	―	$	1
Total		$	―	$	1	$	―	$	―	$	1
		At fair value as of December 31, 2012
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	―	$	―	$	―	$	1	$	1
Commodity contracts not subject to rate recovery			1		―		―		2		3
Total		$	1	$	―	$	―	$	3	$	4
Liabilities:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	―	$	1
Total		$	―	$	1	$	―	$	―	$	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,
		2013		2012		2011
	Balance as of January 1	$	61	$	23	$	2
	Realized and unrealized gains		11		31		32
	Allocated transmission instruments		51		58		7
	Settlements		-24		-51		-18
	Balance as of December 31	$	99	$	61	$	23
	Change in unrealized gains or losses relating to
	instruments still held at December 31	$	11	$	17	$	17
Schedule Of Fair Value Of Financial Instruments [Abstract]	'
Schedule Of Fair Value of Financial Instruments	'
	FAIR VALUE OF FINANCIAL INSTRUMENTS
	(Dollars in millions)
			31-Dec-13
			Carrying			Fair Value
			Amount			Level 1		Level 2		Level 3		Total
	Sempra Energy Consolidated:
	Total long-term debt(1)		$	12,022		$	―	$	11,925	$	751	$	12,676
	Preferred stock of subsidiary			20			―		20		―		20
	SDG&E:
	Total long-term debt(2)		$	4,386		$	―	$	4,226	$	335	$	4,561
	SoCalGas:
	Total long-term debt(3)		$	1,413		$	―	$	1,469	$	―	$	1,469
	Preferred stock			22			―		22		―		22
			31-Dec-12
			Carrying			Fair Value
			Amount			Level 1		Level 2		Level 3		Total
	Sempra Energy Consolidated:
	Investments in affordable housing partnerships(4)		$	12		$	―	$	―	$	36	$	36
	Total long-term debt(1)			11,873			―		12,287		956		13,243
	Preferred stock of subsidiaries			99			―		107		―		107
	SDG&E:
	Total long-term debt(2)		$	4,135		$	―	$	4,243	$	345	$	4,588
	Contingently redeemable preferred stock(5)			79			―		85		―		85
	SoCalGas:
	Total long-term debt(3)		$	1,413		$	―	$	1,599	$	―	$	1,599
	Preferred stock			22			―		24		―		24
	-1	Before reductions for unamortized discount (net of premium) of $17 million and $16 million at December 31, 2013 and 2012, respectively, and excluding build-to-suit and capital leases of $195 million and capital leases of $189 million at December 31, 2013 and 2012, respectively, and commercial paper classified as long-term debt of $200 million and $300 million at December 31, 2013 and 2012, respectively. We discuss our long-term debt in Note 5.
	-2	Before reductions for unamortized discount of $11 million and $12 million at December 31, 2013 and 2012, respectively, and excluding capital leases of $179 million and $185 million at December 31, 2013, respectively.
	-3	Before reductions for unamortized discount of $4 million at both December 31, 2013 and 2012 and excluding capital leases of $2 million and $4 million at December 31, 2013 and 2012, respectively.
	-4	Investments in affordable housing partnerships at Parent and Other. At December 31, 2013, the carrying amount and fair value of these investments were negligible.
	-5	On October 15, 2013, SDG&E redeemed all outstanding shares of its contingently redeemable preferred stock for $82 million. We discuss the redemption in Note 11.
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)	2013		2012
	Sempra Energy Consolidated	$	48	$	35
	SDG&E		30		13
	SoCalGas		4		3
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)
						% of
			Estimated		Fair	Fair Value
			Fair		Value	Measure-		Range of
			Value	Valuation Technique	Hierarchy	ment	Inputs Used to Develop Measurement	Inputs
	Investment in
	Rockies Express		$369(1)	Market approach	Level 2	67%	Equity sale offer price	100%
				Probability weighted	Level 3	33%	Combined transportation rate assumption(2)	6% - 78%
				discounted cash flow			Counterparty credit risk on existing contracts	Low
							Operation and maintenance escalation rate	0% - 1%
							Forecasted interest rate on debt to be refinanced	5% - 10%
							Discount rate	8% - 10%
	Investment in
	RBS Sempra
	Commodities		$126(3)	Discounted cash flow	Level 3	100%	Future cash distributions	90% - 110%
	-1	At measurement date of September 30, 2012. At December 31, 2013, our investment in Rockies Express had a carrying value of $329 million, reflecting subsequent equity method activity to record distributions and earnings.
	-2	Transportation rate beyond existing contract terms as a percentage of current mean REX rates.
	-3	At measurement date of September 30, 2011. At December 31, 2013, our investment in RBS Sempra Commodities had a carrying value of $73 million, reflecting subsequent equity method activity to record distributions and losses.

PREFERRED_STOCK_Tables

PREFERRED STOCK (Tables)	12 Months Ended
	Dec. 31, 2013
Preferred Stock (Tables) [Abstract]	'
Schedule Of Preferred Stock	'
	PREFERRED STOCK
				Final Call/
				Redemption	December 31,
				Price	2013		2012
					(in millions)
	Contingently redeemable:
		SDG&E:
		$20 par value, authorized 1,375,000 shares(1):
		5% Series, 375,000 shares outstanding	$	24	$	―	$	8
		4.5% Series, 300,000 shares outstanding	$	21.2		―		6
		4.4% Series, 325,000 shares outstanding	$	21		―		7
		4.6% Series, 373,770 shares outstanding	$	20.25		―		7
		Without par value(1):
		$1.70 Series, 1,400,000 shares outstanding	$	25		―		35
		$1.82 Series, 640,000 shares outstanding	$	26		―		16
		SDG&E - Total contingently redeemable preferred stock				―		79
		Sempra Energy - Total contingently redeemable preferred
		stock of subsidiary			$	―	$	79
	SoCalGas:
	$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 PE					-2		-2
						20		20
		Sempra Energy - Total preferred stock of subsidiary			$	20	$	20
	-1	Represents shares outstanding at December 31, 2012, which were fully redeemed in October 2013.

SHAREHOLDERS_EQUITY_AND_EARNIN2

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013		2012		2011
	Numerator:
	Earnings/Income attributable to common shareholders	$	1,001	$	859	$	1,331
	Denominator:
	Weighted-average common shares outstanding for basic EPS		243,863		241,347		239,720
	Dilutive effect of stock options, restricted stock awards and
	restricted stock units		5,469		5,346		1,803
	Weighted-average common shares outstanding for diluted EPS		249,332		246,693		241,523
	Earnings per share:
	Basic	$	4.1	$	3.56	$	5.55
	Diluted	$	4.01	$	3.48	$	5.51
	Dividends declared per share of common stock	$	2.52	$	2.4	$	1.92
Schedule Of Common Stock Activity [Abstract]	'
Schedule Of Common Stock Activity	'
	COMMON STOCK ACTIVITY
			Years ended December 31,
				2013		2012		2011
	Common shares outstanding, January 1			242,368,836		239,934,681		240,447,416
	Stock options exercised			1,237,348		1,876,303		958,126
	Restricted stock issuances			21,121		2,580		11,876
	Restricted stock units vesting(1)			1,491,170		683,416		2,625
	Shares released from ESOP			―		153,625		350,815
	Shares repurchased(2)			-657,148		-281,769		-1,836,177
	Common shares outstanding, December 31			244,461,327		242,368,836		239,934,681
	-1	Includes dividend equivalents.
	-2	In addition to formal common stock repurchase programs which we discuss below, we also, from time to time, purchase shares of our common stock from restricted stock plan participants who elect to sell a sufficient number of vesting restricted shares to meet minimum statutory tax withholding requirements.
Shareholder Ranking [Abstract]	'
Shareholder Ranking [Text Block]	'
	Four-Year Cumulative Total Shareholder Return Ranking versus S&P 500 Utilities Index(1)		Number of Sempra Energy Common Shares Received for Each Performance-Based Restricted Stock Unit(2)
	75th Percentile or Above		1.5
	50th Percentile		1
	35th Percentile or Below		―
	-1	If Sempra Energy ranks at or above the 50th percentile compared to the S&P 500 Index, participants will receive a minimum of 1.0 share for each RSU.
	-2	Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate.

NUCLEAR_PLANT_Tables

NUCLEAR PLANT (Tables)	12 Months Ended
	Dec. 31, 2013
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, 2013:
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies(1)		$	116	$	3	$	-2	$	117
	Municipal bonds(2)			110		2		-1		111
	Other securities(3)			155		3		-5		153
	Total debt securities			381		8		-8		381
	Equity securities			207		409		-2		614
	Cash and cash equivalents			39		―		―		39
	Total		$	627	$	417	$	-10	$	1,034
	At December 31, 2012:
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies		$	147	$	9	$	―	$	156
	Municipal bonds			57		6		―		63
	Other securities			121		10		-1		130
	Total debt securities			325		25		-1		349
	Equity securities			249		292		-2		539
	Cash and cash equivalents			20		―		―		20
	Total		$	594	$	317	$	-3	$	908
	-1	Maturity dates are 2014-2056.
	-2	Maturity dates are 2014-2062.
	-3	Maturity dates are 2014-2111.
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,
			2013		2012		2011
	Proceeds from sales(1)		$	685	$	723	$	715
	Gross realized gains			26		21		75
	Gross realized losses			-18		-13		-52
	-1	Excludes securities that are held to maturity.

CALIFORNIA_UTILITIES_REGULATOR1

CALIFORNIA UTILITIES' REGULATORY MATTERS (Tables)	12 Months Ended
	Dec. 31, 2013
Regulatory Matters (Tables) [Abstract]	'
Schedule Of Utility Incentive Awards	'
	UTILITY INCENTIVE AWARDS RECORDED IN EARNINGS 2011-2013(1)
	(Dollars in millions)
			Years ended December 31,
			2013			2012		2011
	Sempra Energy Consolidated
	Energy efficiency		$	7		$	6	$	16
	Unbundled natural gas storage and hub services			1			3		4
	Natural gas procurement			5			6		6
	Operational incentives			―			5		3
	Total awards		$	13		$	20	$	29
	SDG&E
	Energy efficiency		$	4		$	3	$	14
	Operational incentives			―			2		1
	Total awards		$	4		$	5	$	15
	SoCalGas
	Energy efficiency		$	3		$	3	$	2
	Unbundled natural gas storage and hub services			1			3		4
	Natural gas procurement			5			6		6
	Operational incentives			―			3		2
	Total awards		$	9		$	15	$	14
	-1	Awards are included in earnings upon CPUC approval of the award.
Schedule of Cost of Capital Decision	'
	COST OF CAPITAL FINAL DECISION SUMMARY
	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%

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule Of Estimated Future Payments Under Natural Gas Contracts [Abstract]	'
Schedule Of Estimated Future Payments Under Natural Gas Contracts	'
	Sempra Energy Consolidated
			Storage and
	(Dollars in millions)		Transportation		Natural Gas(1)		Total(1)
	2014		$	242	$	162	$	404
	2015			239		4		243
	2016			226		4		230
	2017			220		4		224
	2018			202		4		206
	Thereafter			361		16		377
	Total minimum payments		$	1,490	$	194	$	1,684
	-1	Excludes amounts related to LNG purchase agreements as discussed below.
	SoCalGas
	(Dollars in millions)	Transportation		Natural Gas		Total
	2014	$	126	$	57	$	183
	2015		120		1		121
	2016		111		1		112
	2017		107		1		108
	2018		89		1		90
	Thereafter		157		―		157
	Total minimum payments	$	710	$	61	$	771
Schedule Of Payments Under Natural Gas Contracts [Abstract]	'
Schedule Of Payments Under Natural Gas Contracts	'
		Years ended December 31,
	(Dollars in millions)	2013		2012		2011
	Sempra Energy Consolidated	$	1,680	$	1,345	$	1,991
	SoCalGas		1,464		1,222		1,810
Schedule Of Payments Under Purchased Power Contracts [Abstract]	'
Schedule Of Payments Under Purchased Power Contracts	'
		Years ended December 31,
	(Dollars in millions)	2013		2012		2011
	Sempra Energy Consolidated	$	1,377	$	1,205	$	918
	SDG&E		570		381		346
Schedule Of Estimated Future Payments Under Purchased Power Contracts [Abstract]	'
Schedule Of Estimated Future Payments Under Purchased Power Contracts	'
			Sempra
			Energy
	(Dollars in millions)		Consolidated		SDG&E
	2014		$	1,328	$	471
	2015			1,473		543
	2016			1,487		524
	2017			1,494		517
	2018			1,483		488
	Thereafter			11,826		6,349
	Total minimum payments(1)		$	19,091	$	8,892
	-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	'
		Years ended December 31,
	(Dollars in millions)	2013		2012		2011
	Sempra Energy Consolidated	$	81	$	74	$	77
	SDG&E		23		20		18
	SoCalGas		31		26		35
Schedule Of Operating Leases Future Minimum Payments Due [Abstract]	'
Schedule Of Operating Leases, Future Minimum Payments Due	'
		Sempra
		Energy
	(Dollars in millions)	Consolidated		SDG&E		SoCalGas
	2014	$	85	$	23	$	32
	2015		83		22		32
	2016		71		22		25
	2017		74		20		30
	2018		69		17		28
	Thereafter		576		91		174
	Total future rental commitments	$	958	$	195	$	321
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	'
			Sempra
			Energy
	(Dollars in millions)		Consolidated		SDG&E		SoCalGas
	2014		$	4	$	2	$	2
	2015			1		1		―
	Total minimum lease payments		$	5	$	3	$	2
	Present value of net minimum lease payments(1)		$	5	$	3	$	2
	-1	Excludes negligible amounts of interest.
	(Dollars in millions)
		2014	$	24
		2015		24
		2016		24
		2017		24
		2018		24
		Thereafter		394
		Total minimum lease payments(1)		514
		Less: estimated executory costs		-84
		Less: interest(2)		-254
		Present value of net minimum lease payments(3)	$	176
	-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.
	-2	Amount necessary to reduce net minimum lease payments to present value at the inception of the leases.
	-3	Includes $3 million in Current Portion of Long-Term Debt and $173 million in Long-Term Debt on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets at December 31, 2013.
Schedule Of Environmental Remediation Costs Capitalized In Period [Abstract]	'
Schedule Of Environmental Remediation Costs, Capitalized In Period	'
			Years ended December 31,
			2013		2012		2011
	Sempra Energy Consolidated(1)		$	31	$	92	$	144
	SDG&E			13		77		130
	SoCalGas			15		12		13
	-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	'
			# Sites		# Sites
			Completed(1)		In Process
	SDG&E
	Manufactured-gas sites			3		―
	Third-party waste-disposal sites			2		3
	SoCalGas
	Manufactured-gas sites			39		3
	Third-party waste-disposal sites			5		1
	-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	'
					Waste		Former Fossil-		Other
			Manufactured-		Disposal		Fueled Power		Hazardous
			Gas Sites		Sites (PRP)(1)		Plants		Waste Sites		Total
	SDG&E(2)(3)		$	―	$	―	$	5.2	$	0.4	$	5.6
	SoCalGas(3)			14.7		0.2		―		0.2		15.1
	Other			2.2		1.2		―		0.8		4.2
	Total Sempra Energy		$	16.9	$	1.4	$	5.2	$	1.4	$	24.9
	-1	Sites for which we have been identified as a Potentially Responsible Party.
	-2	Does not include SDG&E’s liability for SONGS marine mitigation.
	-3	This includes $5.5 million at SDG&E and $15.1 million at SoCalGas related to hazardous waste sites subject to the Hazardous Waste Collaborative mechanism approved by the CPUC in 1994. This mechanism permits California’s IOUs, including the California Utilities, to recover in rates 90 percent of hazardous waste cleanup costs and related third-party litigation costs, and 70 percent of the related insurance-litigation expenses for certain sites. In addition, the California Utilities have the opportunity to retain a percentage of any recoveries from insurance carriers and other third parties to offset the cleanup and associated litigation costs not recovered in rates.
Schedule Of Build To Suit Lease Future Minimum Payments Due [Abstract]	'
Schedule Of Build To Suit Lease Future Minimum Payments Due	'
	(Dollars in millions)
	2014	$	―
	2015		4
	2016		10
	2017		10
	2018		10
	Thereafter		277
	Total future payments	$	311

SEGMENT_INFORMATION_Tables

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2013
Segment Information (Tables) [Abstract]	'
Schedule of Segment Reporting Information, by Segment	'
	SEGMENT INFORMATION
	(Dollars in millions)
		Years ended December 31,
		2013				2012				2011
	REVENUES
	SDG&E	$	4,066	39	%	$	3,694	38	%	$	3,373	34	%
	SoCalGas		3,736	35			3,282	34			3,816	38
	Sempra South American Utilities		1,495	14			1,441	15			1,080	11
	Sempra Mexico		675	6			605	6			736	7
	Sempra Renewables		82	1			68	1			22	―
	Sempra Natural Gas		908	9			931	10			1,632	16
	Adjustments and eliminations		-2	―			-2	―			-2	―
	Intersegment revenues(1)		-403	-4			-372	-4			-621	-6
	Total	$	10,557	100	%	$	9,647	100	%	$	10,036	100	%
	INTEREST EXPENSE
	SDG&E	$	197			$	173			$	142
	SoCalGas		69				68				69
	Sempra South American Utilities		27				32				34
	Sempra Mexico		17				8				19
	Sempra Renewables		23				22				13
	Sempra Natural Gas		116				98				80
	All other		241				251				233
	Intercompany eliminations		-131				-159				-125
	Total	$	559			$	493			$	465
	INTEREST INCOME
	SDG&E	$	1			$	―			$	―
	SoCalGas		―				―				1
	Sempra South American Utilities		14				15				22
	Sempra Mexico		2				2				1
	Sempra Renewables		20				6				―
	Sempra Natural Gas		88				55				34
	All other		―				4				―
	Intercompany eliminations		-105				-58				-32
	Total	$	20			$	24			$	26
	DEPRECIATION AND AMORTIZATION
	SDG&E	$	494	44	%	$	490	45	%	$	422	43	%
	SoCalGas		383	35			362	33			331	34
	Sempra South American Utilities		59	5			56	5			40	4
	Sempra Mexico		63	6			62	6			63	6
	Sempra Renewables		21	2			16	1			6	1
	Sempra Natural Gas		81	7			93	9			103	11
	All other		12	1			11	1			11	1
	Total	$	1,113	100	%	$	1,090	100	%	$	976	100	%
	INCOME TAX EXPENSE (BENEFIT)
	SDG&E	$	191			$	190			$	237
	SoCalGas		116				79				143
	Sempra South American Utilities		67				78				42
	Sempra Mexico		60				73				37
	Sempra Renewables		-19				-63				-28
	Sempra Natural Gas		40				-157				72
	All other		-89				-141				-109
	Total	$	366			$	59			$	394
	SEGMENT INFORMATION (Continued)
	(Dollars in millions)
			At December 31 or for the years ended December 31,
			2013				2012				2011
	EARNINGS (LOSSES)
	SDG&E(2)		$	404	41	%	$	484	56	%	$	431	32	%
	SoCalGas(3)			364	37			289	34			287	22
	Sempra South American Utilities			153	15			164	19			425	32
	Sempra Mexico			122	12			157	18			192	14
	Sempra Renewables			62	6			61	7			7	1
	Sempra Natural Gas			64	6			-241	-28			115	9
All other			-168	-17			-55	-6			-126	-10
Total		$	1,001	100	%	$	859	100	%	$	1,331	100	%
ASSETS
SDG&E		$	15,377	41	%	$	14,744	40	%	$	13,555	41	%
SoCalGas			9,147	25			9,071	25			8,475	25
Sempra South American Utilities			3,531	10			3,310	9			2,981	9
Sempra Mexico			3,246	9			2,591	7			2,502	8
Sempra Renewables			1,219	3			2,439	7			1,210	4
Sempra Natural Gas			7,200	19			5,145	14			5,738	17
All other			838	2			818	2			442	1
Intersegment receivables			-3,314	-9			-1,619	-4			-1,654	-5
Total		$	37,244	100	%	$	36,499	100	%	$	33,249	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	978	38	%	$	1,237	42	%	$	1,831	64	%
SoCalGas			762	30			639	22			683	24
Sempra South American Utilities			200	8			183	6			110	4
Sempra Mexico			371	14			45	2			16	―
Sempra Renewables			176	7			717	24			248	9
Sempra Natural Gas			83	3			131	4			157	6
All other			2	―			4	―			4	―
Intercompany eliminations(4)			―	―			―	―			-205	-7
Total		$	2,572	100	%	$	2,956	100	%	$	2,844	100	%
GEOGRAPHIC INFORMATION
Long-lived assets(5):
United States		$	22,654	84	%	$	22,698	85	%	$	21,405	85	%
Mexico			2,597	9			2,219	8			2,189	9
South America			1,784	7			1,790	7			1,542	6
Total		$	27,035	100	%	$	26,707	100	%	$	25,136	100	%
Revenues:
United States		$	8,478	80	%	$	7,711	80	%	$	8,521	85	%
South America			1,495	14			1,441	15			1,080	11
Mexico			584	6			495	5			435	4
Total		$	10,557	100	%	$	9,647	100	%	$	10,036	100	%
-1	Revenues for reportable segments include intersegment revenues of:
	$10 million, $70 million, $91 million and $232 million for 2013, $8 million, $46 million, $108 million and $210 million for 2012, and $6 million, $53 million, $300 million and $262 million for 2011 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
-2	After preferred dividends and 2013 call premium on preferred stock.
-3	After preferred dividends.
-4	Amount represents elimination of intercompany sale of El Dorado power plant (renamed Desert Star Energy Center) in 2011, by Sempra Natural Gas to SDG&E.
-5	Includes net property, plant and equipment and investments.

QUARTERLY_FINANCIAL_DATA_Table

QUARTERLY FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2013
Quarterly Financial Data (Tables) [Abstract]	'
Schedule Of Quarterly Financial Data [Text Block]	'
	SEMPRA ENERGY
	(In millions, except per share amounts)
			Quarters ended
			31-Mar		30-Jun		30-Sep		31-Dec
	2013
	Revenues		$	2,650	$	2,651	$	2,551	$	2,705
	Expenses and other income		$	2,298	$	2,353	$	2,119	$	2,357
	Net income		$	178	$	267	$	323	$	320
	Earnings attributable to Sempra Energy		$	178	$	245	$	296	$	282
	Basic per-share amounts(1):
	Net income		$	0.73	$	1.1	$	1.32	$	1.31
	Earnings attributable to Sempra Energy		$	0.73	$	1	$	1.21	$	1.15
	Weighted average common shares outstanding			243.3		243.6		244.1		244.4
	Diluted per-share amounts(1):
	Net income		$	0.72	$	1.07	$	1.29	$	1.28
	Earnings attributable to Sempra Energy		$	0.72	$	0.98	$	1.19	$	1.13
	Weighted average common shares outstanding			247.5		248.5		249.3		249.9
	2012
	Revenues		$	2,383	$	2,089	$	2,507	$	2,668
	Expenses and other income		$	2,026	$	2,141	$	2,178	$	2,359
	Net income		$	251	$	74	$	290	$	305
	Earnings attributable to Sempra Energy		$	236	$	62	$	268	$	293
	Basic per-share amounts(1):
	Net income		$	1.04	$	0.31	$	1.2	$	1.26
	Earnings attributable to Sempra Energy		$	0.98	$	0.26	$	1.11	$	1.21
	Weighted average common shares outstanding			240.6		241.1		241.7		242
	Diluted per-share amounts(1):
	Net income		$	1.02	$	0.3	$	1.18	$	1.23
	Earnings attributable to Sempra Energy		$	0.97	$	0.25	$	1.09	$	1.18
	Weighted average common shares outstanding			243.8		246.3		245.8		247.6
	-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
		31-Mar		30-Jun		30-Sep		31-Dec
	2013
	Operating revenues	$	939	$	1,064	$	1,063	$	1,000
	Operating expenses		771		939		800		774
	Operating income	$	168	$	125	$	263	$	226
	Net income	$	81	$	73	$	139	$	142
	Losses (earnings) attributable to noncontrolling interest		11		-7		-5		-23
	Earnings		92		66		134		119
	Call premium on preferred stock		―		―		-3		―
	Dividends on preferred stock		-1		-1		-2		―
	Earnings attributable to common shares	$	91	$	65	$	129	$	119
	2012
	Operating revenues	$	834	$	780	$	1,092	$	988
	Operating expenses		656		611		822		796
	Operating income	$	178	$	169	$	270	$	192
	Net income	$	112	$	101	$	188	$	114
	Earnings attributable to noncontrolling interest		-6		-5		-12		-3
	Earnings		106		96		176		111
	Dividends on preferred stock		-1		-1		-2		-1
	Earnings attributable to common shares	$	105	$	95	$	174	$	110
	SOCALGAS
	(Dollars in millions)
		Quarters ended
		31-Mar		30-Jun		30-Sep		31-Dec
	2013
	Operating revenues	$	983	$	904	$	807	$	1,042
	Operating expenses		900		725		652		920
	Operating income	$	83	$	179	$	155	$	122
	Net income	$	46	$	119	$	102	$	98
Dividends on preferred stock		―		-1		―		―
Earnings attributable to common shares	$	46	$	118	$	102	$	98
2012
Operating revenues	$	880	$	720	$	728	$	954
Operating expenses		761		625		609		867
Operating income	$	119	$	95	$	119	$	87
Net income	$	66	$	54	$	71	$	99
Dividends on preferred stock		―		-1		―		―
Earnings attributable to common shares	$	66	$	53	$	71	$	99

SCHEDULE_I_CONDENSED_FINANCIAL1

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)	12 Months Ended
	Dec. 31, 2013
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,
		2013		2012		2011
	Interest income	$	42	$	83	$	109
	Interest expense		-239		-247		-242
	Operation and maintenance		-63		-68		-64
	Other income, net		41		66		42
	Income tax benefits		117		145		82
	Loss before equity in earnings of subsidiaries		-102		-21		-73
	Equity in earnings of subsidiaries, net of income taxes		1,103		880		1,404
	Net income/earnings	$	1,001	$	859	$	1,331
	Basic earnings per common share	$	4.1	$	3.56	$	5.55
	Weighted-average number of shares outstanding (thousands)		243,863		241,347		239,720
	Diluted earnings per common share	$	4.01	$	3.48	$	5.51
	Weighted-average number of shares outstanding (thousands)		249,332		246,693		241,523
	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,
			2013		2012
	Assets:
	Cash and cash equivalents		$	6	$	18
	Due from affiliates			132		125
	Deferred income taxes			170		109
	Other current assets			16		16
	Total current assets			324		268
	Investments in subsidiaries			13,866		12,545
	Due from affiliates			802		1,759
	Deferred income taxes			1,466		1,541
	Other assets			555		576
	Total assets		$	17,013	$	16,689
	Liabilities and shareholders’ equity:
	Current portion of long-term debt		$	800	$	652
	Due to affiliates			273		539
	Income taxes payable			64		26
	Other current liabilities			276		260
	Total current liabilities			1,413		1,477
	Long-term debt			4,117		4,409
	Other long-term liabilities			475		521
	Shareholders’ equity			11,008		10,282
	Total liabilities and shareholders’ equity		$	17,013	$	16,689
	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,
		2013		2012		2011
	Net cash used in operating activities	$	-131	$	-809	$	-287
	Dividends received from subsidiary		50		250		50
	Expenditures for property, plant and equipment		-1		-1		-2
	Purchase of trust assets		-5		-6		-7
	Proceeds from sales by trust		10		10		12
	Capital contribution to subsidiaries		-6		―		-200
	Decrease (increase) in loans to affiliates, net		962		-33		82
	Cash provided by (used in) investing activities		1,010		220		-65
	Common stock dividends paid		-606		-550		-440
	Issuances of common stock		62		78		28
	Repurchases of common stock		-45		-16		-18
	Issuances of long-term debt		498		1,100		799
	Payments on long-term debt		-650		-8		-24
	Decrease in loans from affiliates, net		-147		―		-136
	Other		-3		-8		-3
	Cash (used in) provided by financing activities		-891		596		206
	(Decrease) increase in cash and cash equivalents		-12		7		-146
	Cash and cash equivalents, January 1		18		11		157
	Cash and cash equivalents, December 31	$	6	$	18	$	11
	See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Long-Term Debt [Abstract]	'
Schedule of Condensed Long-Term Debt [Text Block]	'
		December 31,		December 31,
	(Dollars in millions)	2013		2012
	6% Notes February 1, 2013	$	―	$	400
	8.9% Notes November 15, 2013, including $200 at variable rates after
	fixed-to-floating rate swaps effective January 2011		―		250
	2% Notes March 15, 2014		500		500
	Notes at variable rates (1.01% at December 31, 2013) March 15, 2014		300		300
	6.5% Notes June 1, 2016, including $300 at variable rates after
	fixed-to-floating rate swaps effective January 2011 (4.46% at December 31, 2013)		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
	2.875% Notes October 1, 2022		500		500
	4.05% Notes December 1, 2023		500		―
	6% Notes October 15, 2039		750		750
	Market value adjustments for interest rate swaps, net
	(expire November 2013 and June 2016)		12		19
	Build-to-suit lease		14		―
			4,926		5,069
	Current portion of long-term debt		-800		-652
	Unamortized discount on long-term debt		-9		-8
	Total long-term debt	$	4,117	$	4,409
Schedule Of Condensed Statements Of Comprehensive Income [Abstract]	'
Schedule Of Condensed Statements Of Comprehensive Income [Text Block]	'
	SEMPRA ENERGY
	CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
	(Dollars in millions)
			Years ended December 31, 2013, 2012 and 2011
			Pretax		Income Tax		Net-of-tax
			Amount		(Expense) Benefit		Amount
	2013:00:00
	Net income		$	884	$	117	$	1,001
	Other comprehensive income:
	Foreign currency translation adjustments			111		―		111
	Pension and other postretirement benefits			47		-19		28
	Financial instruments			13		-4		9
	Total other comprehensive income			171		-23		148
	Comprehensive income		$	1,055	$	94	$	1,149
	2012:00:00
	Net income		$	714	$	145	$	859
	Other comprehensive income (loss):
	Foreign currency translation adjustments			119		―		119
	Pension and other postretirement benefits			-4		2		-2
	Financial instruments			-6		2		-4
	Total other comprehensive income			109		4		113
	Comprehensive income		$	823	$	149	$	972
	2011:00:00
	Net income		$	1,249	$	82	$	1,331
	Other comprehensive loss:
	Foreign currency translation adjustments			-79		3		-76
	Reclassification to net income of foreign
	currency translation adjustment related
	to remeasurement of equity method
	investments			-54		―		-54
	Available-for-sale securities			-2		1		-1
	Pension and other postretirement benefits			-20		8		-12
	Financial instruments			-26		10		-16
	Total other comprehensive loss			-181		22		-159
	Comprehensive income		$	1,068	$	104	$	1,172
	See Notes to Condensed Financial Information of Parent.

OTHER_FINANCIAL_DATA_RESTRICTE

OTHER FINANCIAL DATA - RESTRICTED CASH (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Presentation Of Restricted Cash [Line Items]	'	'
Restricted cash	$24	$46
Restricted Cash and Cash Equivalents, Noncurrent	25	22
Restricted cash, current and noncurrent	49	68
Restricted Cash, Construction Financing [Member] | Sempra Mexico Segment [Member]	'	'
Presentation Of Restricted Cash [Line Items]	'	'
Restricted cash	12	'
Restricted Cash, Construction Financing [Member] | Sempra Renewables Segment [Member]	'	'
Presentation Of Restricted Cash [Line Items]	'	'
Restricted cash	6	35
San Diego Gas and Electric Company and Subsidiary [Member]	'	'
Presentation Of Restricted Cash [Line Items]	'	'
Restricted cash	6	10
Restricted Cash and Cash Equivalents, Noncurrent	25	22
San Diego Gas and Electric Company and Subsidiary [Member] | Restricted Cash, Operating Requirements [Member] | S D G E Segment [Member]	'	'
Presentation Of Restricted Cash [Line Items]	'	'
Restricted cash	6	10
Restricted Cash and Cash Equivalents, Noncurrent	25	22
Restricted cash, current and noncurrent	$31	$32

OTHER_FINANCIAL_DATA_INVENTORY

OTHER FINANCIAL DATA - INVENTORY (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Inventories By Inventory Type [Line Items]	'	'
Energy Related Inventory, Natural Gas in Storage	$113	$240
Energy Related Inventory, LNG	8	16
Energy Related Inventory, Materials And Supplies	166	152
Inventories	287	408
S D G E Segment [Member]	'	'
Inventories By Inventory Type [Line Items]	'	'
Energy Related Inventory, Natural Gas in Storage	3	3
Energy Related Inventory, LNG	0	0
Energy Related Inventory, Materials And Supplies	83	79
Inventories	86	82
So Cal Gas Segment [Member]	'	'
Inventories By Inventory Type [Line Items]	'	'
Energy Related Inventory, Natural Gas in Storage	42	128
Energy Related Inventory, LNG	0	0
Energy Related Inventory, Materials And Supplies	27	23
Inventories	69	151
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	40	34
Inventories	40	34
Sempra Mexico Segment [Member]	'	'
Inventories By Inventory Type [Line Items]	'	'
Energy Related Inventory, Natural Gas in Storage	0	0
Energy Related Inventory, LNG	3	8
Energy Related Inventory, Materials And Supplies	9	8
Inventories	12	16
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	2	3
Inventories	2	3
Sempra Natural Gas Segment [Member]	'	'
Inventories By Inventory Type [Line Items]	'	'
Energy Related Inventory, Natural Gas in Storage	68	109
Energy Related Inventory, LNG	5	8
Energy Related Inventory, Materials And Supplies	5	5
Inventories	$78	$122

OTHER_FINANCIAL_DATA_US_TREASU

OTHER FINANCIAL DATA - U.S. TREASURY GRANT RECEIVABLE (Details) (USD $)	3 Months Ended	12 Months Ended			3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2013	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2013	Jun. 30, 2013
					Mesquite Solar 1 [Member]	Copper Mountain Solar 2 [Member]
U.S. Treasury Grants Receivable [Line Items]	'	'	'	'	'	'
U.S. Treasury grants receivable	'	$0	$258	'	'	'
Proceeds from U.S. Treasury grants	'	238	0	0	164	74
Reduction in tax benefit due to sequestration	5	'	'	'	'	'
Sequestration of U.S. Treasury grants receivable	'	$23	$0	$0	'	'

OTHER_FINANCIAL_DATA_TRANSACTI

OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILATIES (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due to affiliate, current	$4		'		'
Interest rate on due from affiliate	4.00%		'		'
Loan to unconsolidated affiliate, principal	14		'		'
San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due from affiliate, current	1		39		'
Due to affiliate, current	39		19		'
Revenue from related parties	12		9		7
Southern California Gas Company [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due from affiliate, current	21		24		'
Due to affiliate, current	16		37		'
Revenue from related parties	70		46		53
Due to/from Sempra Energy | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due to affiliate, current	25		19		'
Income taxes due from (to) Sempra Energy	70	[1]	12	[1]	'
Due to/from Sempra Energy | Southern California Gas Company [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due from affiliate, current	0		24		'
Due to affiliate, current	16		0		'
Income taxes due from (to) Sempra Energy	18	[1]	99	[1]	'
Subsidiary Of Common Parent S D G E [Member] | Southern California Gas Company [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due to affiliate, current	0		37		'
Subsdiary Of Common Parent So Cal Gas [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due from affiliate, current	0		37		'
Subsidiary Of Common Parent Other Affiliates [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due from affiliate, current	1		2		'
Due to affiliate, current	14		0		'
Subsidiary Of Common Parent Other Affiliates [Member] | Southern California Gas Company [Member]	'		'		'
Transactions With Affiliates Disclosure [Line Items]	'		'		'
Due from affiliate, current	$21		$0		'
[1]	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 the companiesb having always filed a separate return.

OTHER_FINANCIAL_DATA_TRANSACTI1

OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILATIES 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2011
Sempra Mexico Segment [Member]	'
Transactions With Joint Venture [Line Items]	'
Revenues from transactions with RBS Sempra Commodities	$37	[1]
Cost of natural gas from transactions with RBS Sempra Commodities	74	[1]
Sempra Natural Gas Segment [Member]	'
Transactions With Joint Venture [Line Items]	'
Revenues from transactions with RBS Sempra Commodities	7	[1]
Cost of natural gas from transactions with RBS Sempra Commodities	$3	[1]
[1]	With the exception of Sempra Mexico, whose contract with RBS Sempra Commodities expired in July 2011, amounts only include activities prior to May 1, 2011, the date by which substantially all the contracts with RBS Sempra Commodities were assigned to buyers of the joint venture businesses.

OTHER_FINANCIAL_DATA_VARIABLE_

OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITY (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Variable Interest Entities Disclosure [Abstract]	'	'	'
Amounts Associated With Variable Interest Entities, Cash And Cash Equivalents	$17	$8	'
Amounts Associated With Variable Interest Entities, Restricted Cash, Current	6	10	'
Amounts Associated With Variable Interest Entities, Inventories	2	2	'
Amounts Associated With Variable Interest Entities, Other Current Assets	1	1	'
Amounts Associated With Variable Interest Entities, Total Current Assets	26	21	'
Amounts Associated With Variable Interest Entities, Restricted Cash, Noncurrent	25	22	'
Amounts Associated With Variable Interest Entities, Sundry	4	5	'
Amounts Associated With Variable Interest Entities, Property, Plant And Equipment, Net	438	466	'
Amounts Associated With Variable Interest Entities, Total Assets	493	514	'
Amounts Associated With Variable Interest Entities, Current Portion, Long Term Debt	10	10	'
Amounts Associated With Variable Interest Entities, Fixed Price Contracts And Other Derivatives, Current Liability	16	17	'
Amounts Associated With Variable Interest Entities, Other Current Liabilities	19	8	'
Amounts Associated With Variable Interest Entities, Total Current Liabilities	45	35	'
Amounts Associated With Variable Interest Entities, Long Term Debt	325	335	'
Amounts Associated With Variable Interest Entities, Fixed Price Contracts And Other Derivatives, Noncurrent Liability	39	64	'
Amounts Associated With Variable Interest Entities, Deferred Credits And Other	-7	4	'
Amounts Associated With Variable Interest Entities, Other Noncontrolling Interests	91	76	'
Amounts Associated With Variable Interest Entities, Total Liabilities And Equity	493	514	'
Amounts Associated With Variable Interest Entities, Cost Of Electric Fuel And Purchased Power	-91	-83	-72
Amounts Associated With Variable Interest Entities, Operation And Maintenance	24	19	19
Amounts Associated With Variable Interest Entities, Depreciation And Amortization	28	26	22
Amounts Associated With Variable Interest Entities, Total Operating Expenses	-39	-38	-31
Amounts Associated With Variable Interest Entities, Operating Income	39	38	31
Amounts Associated With Variable Interest Entities, Other Income (Expense), Net	0	-1	-1
Amounts Associated With Variable Interest Entities, Interest Expense	-15	-11	-11
Amounts Associated With Variable Interest Entities, Net Income	24	26	19
Amounts Associated With Variable Interest Entities, (Earnings) Losses Attributable Noncontrolling Interests	-24	-26	-19
Amounts Associated With Variable Interest Entities, Earnings	$0	$0	$0

OTHER_FINANCIAL_DATA_NONCONTRO

OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS (Details)

Dec. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Mar. 31, 2013

Mar. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Millions, except Share data, unless otherwise specified

USD ($)

USD ($)

USD ($)

Ownership Interests Held By Others, Southern Gas Transmission [Member]

Ownership Interests Held By Others, Southern Gas Transmission [Member]

Ownership Interests Held By Others, Bay Gas Storage Company [Member]

Ownership Interests Held By Others, Bay Gas Storage Company [Member]

Ownership Interests Held By Others, Liberty Gas Storage [Member]

Ownership Interests Held By Others, Liberty Gas Storage [Member]

Ownership Interests Held By Others IEnova Member [Member]

Ownership Interests Held By Others IEnova Member [Member]

Ownership Interests Held By Others IEnova Member [Member]

Ownership Interests Held By Others IEnova Member [Member]

Ownership Interests Held By Others, Tecsur [Member]

Ownership Interests Held By Others, Tecsur [Member]

Ownership Interests Held By Others, Luz Del Sur [Member]

Ownership Interests Held By Others, Luz Del Sur [Member]

Ownership Interests Held By Others, Chilquinta Energia [Member]

Ownership Interests Held By Others, Chilquinta Energia [Member]

Ownership Interests Held By Others, Otay Mesa VIE [Member]

Ownership Interests Held By Others, Otay Mesa VIE [Member]

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

MXN

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Ownership Interests Held By Others [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of ownership held by others

'

'

'

49.00%

[1]

'

9.10%

[1]

'

25.00%

[1]

'

18.90%

'

'

'

9.80%

'

20.20%

'

'

'

100.00%

'

Percent of ownership held By others, minimum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24.40%

'

'

'

Percent of ownership held by others, maximum

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

43.40%

'

'

'

Amount of ownership interests held by others

$822

'

$381

$1

[1]

$1

[1]

$22

[1]

$20

[1]

$14

[1]

$15

[1]

$442

'

'

$0

$3

$4

$222

$236

$27

$29

$91

$76

Proceeds from sale of noncontrolling interests, net of $25 million in offering costs

'

'

'

'

'

'

'

'

'

'

574

7,100

'

'

'

'

'

'

'

'

'

Common stock shares issued

'

'

'

'

'

'

'

'

'

'

218,110,500

218,110,500

'

'

'

'

'

'

'

'

'

Share price

'

'

'

'

'

'

'

'

'

'

$2.75

34

'

'

'

'

'

'

'

'

'

Minority interest ownership percentage by parent

'

'

'

'

'

'

'

'

'

'

81.10%

81.10%

'

'

'

'

'

'

'

'

'

Foreign currency exchange rate pesos to US dollars

'

'

'

'

'

'

'

'

'

'

12.3841

12.3841

'

'

'

'

'

'

'

'

'

Increase to Shareholders Equity for Sale of Subsidiary shares

'

$135

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Chilquinta EnergC-a has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

OTHER_FINANCIAL_DATA_OTHER_INC

OTHER FINANCIAL DATA - OTHER INCOME (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	$140		$172		$130
San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	40		69		79
Southern California Gas Company [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	11		17		13
Allowance for Cost of Equity Funds Used During Construction [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	75		96		99
Allowance for Cost of Equity Funds Used During Construction [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	39		71		80
Allowance for Cost of Equity Funds Used During Construction [Member] | Southern California Gas Company [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	17		25		19
Regulatory Interest, Net [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	5	[1]	1	[1]	2	[1]
Regulatory Interest, Net [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	4	[1]	2	[1]	2	[1]
Regulatory Interest, Net [Member] | Southern California Gas Company [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	1	[1]	-1	[1]	0	[1]
Gain (Loss) on Investments [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	39	[2]	41	[2]	22	[2]
Fair Value Adjustments on Hedges and Derivative Contracts [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	17	[3]	10	[3]	-14	[3]
Fair Value Adjustments on Hedges and Derivative Contracts [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	0	[4]	0	[4]	-1	[4]
Other Income, Sundry [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	4		24		21
Other Income, Sundry [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	-3		-4		-2
Other Income, Sundry [Member] | Southern California Gas Company [Member]	'		'		'
Component of Other Income, Nonoperating [Line Items]	'		'		'
Other income (expense), net	($7)		($7)		($6)
[1]	Interest on regulatory balancing accounts.
[2]	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.
[3]	Sempra Energy Consolidated includes Otay Mesa VIE and additional instruments.
[4]	Related to Otay Mesa VIE.

OTHER_FINANCIAL_DATA_REGULATOR

OTHER FINANCIAL DATA - REGULATORY MATTERS (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fixed Price Contracts And Other Derivatives [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	$58		$149
Deferred Income Tax Charges [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	788		718
Deferred Income Tax Charges [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	110		38
Pension And Other Postretirement Benefit Obligations [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	106		303
Pension And Other Postretirement Benefit Obligations [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	231		835
Employee Benefit Costs [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	51		58
Asset Retirement Obligation Costs [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	-1,403	[1]	-1,603	[1]
Asset Retirement Obligation Costs [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	-1,205	[1]	-1,103	[1]
Loss on Reacquired Debt [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	14		16
Loss on Reacquired Debt [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	14		17
Environmental Restoration Costs [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	20		16
Environmental Restoration Costs [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	14		14
Workers Compensation Costs [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	26		27
Wildfire Litigation Costs [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	330		364
Costs related to SONGS plant closure [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	303		0
Legacy Meters [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	62		90
Sunrise Powerlink Fire Mitigation [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	115		117
Other Utility Costs [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	15		23
Other Utility Costs [Member] | Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	0		-2
Net Regulatory Assets (Liabilities) S D G E [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	408		193
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)	-759		-116
Net Regulatory Assets (Liabilities) Other [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	-3		4
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	-354		81
Sempra Natural Gas Segment [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	-11		3
Sempra Mexico Segment [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]	'		'
Net Regulatory Assets (Liabilities)	$8		$1
[1]	Related to obligations discussed below in bAsset Retirement Obligations.b

OTHER_FINANCIAL_DATA_REGULATOR1

OTHER FINANCIAL DATA - REGULATORY MATTERS 2 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Regulatory Balancing Accounts [Line Items]	'		'
Overcollected	($1,077)		($643)
Undercollected	1,542		897
Net current receivable (payable)	465	[1]	254	[1]
Undercollected	213	[2]	0	[2]
Total net receviable (payable)	678	[1]	254	[1]
San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Regulatory Balancing Accounts [Line Items]	'		'
Overcollected	-645		-340
Undercollected	1,201		735
Net current receivable (payable)	556	[1]	395	[1]
Undercollected	161	[2]	0	[2]
Total net receviable (payable)	717	[1]	395	[1]
Southern California Gas Company [Member]	'		'
Regulatory Balancing Accounts [Line Items]	'		'
Overcollected	-432		-303
Undercollected	341		162
Net current receivable (payable)	-91	[1]	-141	[1]
Undercollected	52	[2]	0	[2]
Total net receviable (payable)	($39)	[1]	($141)	[1]
[1]	At December 31, 2013 and 2012, the net receivable at SDG&E and the net payable at SoCalGas are shown separately on Sempra Energy's Consolidated Balance Sheets.
[2]	Long-term undercollected balance included in Other Regulatory Assets (long-term) on the Consolidated Balance Sheets.

OTHER_FINANCIAL_DATA_REGULATOR2

OTHER FINANCIAL DATA - REGULATORY MATTERS 3 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Schedule Of Net Regulatory Assets (Liabilities), Balance Sheet Classification [Line Items]	'		'
Total Regulatory Assets, Current	$38		$62
Total Regulatory Assets, Noncurrent	2,335	[1]	2,742	[1]
Total Regulatory Liability, Current	-7	[2]	-2	[2]
Total Regulatory Liability, Noncurrent	-2,720	[3]	-2,721	[3]
Total Net Regulatory Assets (Liabilities)	-354		81
Regulatory liabilities in Deferred Credits and Other	97		1
San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities), Balance Sheet Classification [Line Items]	'		'
Total Regulatory Assets, Current	29		49
Total Regulatory Assets, Noncurrent	1,787	[1]	1,747	[1]
Total Regulatory Liability, Current	-5	[2]	0	[2]
Total Regulatory Liability, Noncurrent	-1,403	[3]	-1,603	[3]
Total Net Regulatory Assets (Liabilities)	408		193
Southern California Gas Company [Member]	'		'
Schedule Of Net Regulatory Assets (Liabilities), Balance Sheet Classification [Line Items]	'		'
Total Regulatory Assets, Current	5		4
Total Regulatory Assets, Noncurrent	536	[1]	983	[1]
Total Regulatory Liability, Current	0	[2]	0	[2]
Total Regulatory Liability, Noncurrent	-1,300	[3]	-1,103	[3]
Total Net Regulatory Assets (Liabilities)	($759)		($116)
[1]	Excludes long-term undercollected balancing accounts of $213 million at Sempra Energy, $161 million at SDG&E and $52 million at SoCalGas recorded in Other Regulatory Assets (long-term).
[2]	Included in Other Current Liabilities.
[3]	At December 31, 2013 and 2012, $97 million and $1 million, respectively, at Sempra Energy Consolidated is included in Deferred Credits and Other.

OTHER_FINANCIAL_DATA_DIVIDENDS

OTHER FINANCIAL DATA - DIVIDENDS AND LOANS (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Restrictions On Dividends Loans And Advances [Line Items]	'
Restricted Net Assets	$6,200
Undistributed Earnings of Equity Method Investments	129
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 and Subsidiary [Member]	'
Restrictions On Dividends Loans And Advances [Line Items]	'
Amount Available For Dividend Distribution And Loans Without Prior Approval From Regulatory Agency	425
FERC Requirement to maintain a common equity ratio at or Above	30.00%
Authorized Capital Structure, Common Equity	52.00%
Restricted Net Assets	4,200
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	1,000
Authorized Capital Structure, Common Equity	52.00%
Restricted Net Assets	$1,500

OTHER_FINANCIAL_DATA_DIVIDENDS1

OTHER FINANCIAL DATA - DIVIDENDS AND LOANS 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
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%
Fowler Ridge 2 Wind Farm [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	37
Cedar Creek 2 Wind Farm [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	34
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	79
Flat Ridge 2 Wind Farm [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	47
Mehoopany Wind Farm [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	19
Copper Mountain Solar 1 [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	11
Copper Mountain Solar 2 [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	14
Mesquite Solar 1 [Member]	'
Significant Restrictions of Subsidiaries [Line Items]	'
Restricted Net Assets of Subsidiary	48

OTHER_FINANCIAL_DATA_FOREIGN_C

OTHER FINANCIAL DATA - FOREIGN CURRENCY TRANSLATION (Details) (USD $)	0 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Apr. 06, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Foreign Currency Translation [Line Items]	'	'	'	'
Foreign Currency Transaction Gain (Loss), before Tax	'	($3)	$9	$11
Reclassification to net income of foreign currency translation adjustment from remeasurement of equity method investments.	54	'	'	'
Peruvian Nuevo Sol [Member]	'	'	'	'
Foreign Currency Translation [Line Items]	'	'	'	'
Equity Method Investment, Functional Currency To Reporting Currency Adjustment	'	'	'	0	[1]
Chilquinta Energia [Member]	'	'	'	'
Foreign Currency Translation [Line Items]	'	'	'	'
Equity Method Investment, Functional Currency To Reporting Currency Adjustment	'	'	'	($10)	[1]
[1]	As discussed in Note 3, the cumulative foreign currency translation adjustment balances totaling $54 million in Accumulated Other Comprehensive Income (Loss) as of April 6, 2011 were reclassified to net income as a result of the gain on the remeasurement of our equity method investments in Chilquinta EnergC-a and Luz del Sur during the second quarter of 2011.

OTHER_FINANCIAL_DATA_REVENUES_

OTHER FINANCIAL DATA - REVENUES DISCLOSURE (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Revenues Disclosure [Abstract]	'		'		'
Natural gas revenues	$4,398	[1]	$3,873	[1]	$4,489	[1]
Electric revenues	4,911	[1]	4,568	[1]	3,833	[1]
Total Utilities Revenues at Sempra Energy Consolidated	$9,309		$8,441		$8,322
[1]	Excludes intercompany revenues.

OTHER_FINANCIAL_DATA_ACCUMULAT

OTHER FINANCIAL DATA - ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	($228)	[1]	($376)	[1]
Amounts reclassified from accumulated other comprehensive income	305	[1]	'
Net other comprehensive income	148	[1]	'
Other comprehensive income before reclassifications	-157	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-228	[1]	-376	[1]
San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-9	[1]	-11	[1]
Amounts reclassified from accumulated other comprehensive income	2	[1]	'
Net other comprehensive income	2	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-9	[1]	-11	[1]
Southern California Gas Company [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-18	[1]	-18	[1]
Amounts reclassified from accumulated other comprehensive income	0	[1]	'
Net other comprehensive income	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-18	[1]	-18	[1]
Foreign Currency Translation Adjustments [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-129	[1]	-240	[1]
Amounts reclassified from accumulated other comprehensive income	270	[1],[2]	'
Net other comprehensive income	111	[1]	'
Other comprehensive income before reclassifications	-159	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-129	[1]	-240	[1]
Foreign Currency Translation Adjustments [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	0	[1]	0	[1]
Amounts reclassified from accumulated other comprehensive income	0	[1]	'
Net other comprehensive income	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	0	[1]	0	[1]
Foreign Currency Translation Adjustments [Member] | Southern California Gas Company [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	0	[1]	0	[1]
Amounts reclassified from accumulated other comprehensive income	0	[1]	'
Net other comprehensive income	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	0	[1]	0	[1]
Unamortized Net Actuarial Loss [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-73	[1]	-102	[1]
Amounts reclassified from accumulated other comprehensive income	29	[1]	'
Net other comprehensive income	29	[1]	'
Other comprehensive income before reclassifications	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-73	[1]	-102	[1]
Unamortized Net Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-10	[1]	-12	[1]
Amounts reclassified from accumulated other comprehensive income	2	[1]	'
Net other comprehensive income	2	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-10	[1]	-12	[1]
Unamortized Net Actuarial Loss [Member] | Southern California Gas Company [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-5	[1]	-4	[1]
Amounts reclassified from accumulated other comprehensive income	-1	[1]	'
Net other comprehensive income	-1	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-5	[1]	-4	[1]
Unamortized Prior Service Credit [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	0	[1]	1	[1]
Amounts reclassified from accumulated other comprehensive income	-1	[1]	'
Net other comprehensive income	-1	[1]	'
Other comprehensive income before reclassifications	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	0	[1]	1	[1]
Unamortized Prior Service Credit [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	1	[1]	1	[1]
Amounts reclassified from accumulated other comprehensive income	0	[1]	'
Net other comprehensive income	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	1	[1]	1	[1]
Unamortized Prior Service Credit [Member] | Southern California Gas Company [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	1	[1]	1	[1]
Amounts reclassified from accumulated other comprehensive income	0	[1]	'
Net other comprehensive income	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	1	[1]	1	[1]
Financial Instrustments [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-26	[1]	-35	[1]
Amounts reclassified from accumulated other comprehensive income	7	[1]	'
Net other comprehensive income	9	[1]	'
Other comprehensive income before reclassifications	2	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	-26	[1]	-35	[1]
Financial Instrustments [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	0	[1]	0	[1]
Amounts reclassified from accumulated other comprehensive income	0	[1]	'
Net other comprehensive income	0	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	0	[1]	0	[1]
Financial Instrustments [Member] | Southern California Gas Company [Member]	'		'
Changes In Components Of Accumulated Other Comprehensive Income [Line Items]	'		'
Component of accumulated other comprehensive income( Loss), beginning balance	-14	[1]	-15	[1]
Amounts reclassified from accumulated other comprehensive income	1	[1]	'
Net other comprehensive income	1	[1]	'
Component of accumulated other comprehensive income (loss), ending balance	($14)	[1]	($15)	[1]
[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.

OTHER_FINANCIAL_DATA_ACCUMULAT1

OTHER FINANCIAL DATA - ACCUMULATED OTHER COMPREHENSIVE INCOME 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	$305
San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	2
Southern California Gas Company [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	0
Before-Tax Amount [Member] | Net Actuarial Gain [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	38	[1]
Before-Tax Amount [Member] | Net Actuarial Gain [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	2	[1]
Before-Tax Amount [Member] | Net Actuarial Loss [Member] | Southern California Gas Company [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-3	[1]
Before-Tax Amount [Member] | Amortization of Actuarial Loss [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	10	[1]
Before-Tax Amount [Member] | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	1	[1]
Before-Tax Amount [Member] | Amortization of Actuarial Loss [Member] | Southern California Gas Company [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	1	[1]
Before-Tax Amount [Member] | Amortization Of Prior Service Credit [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-1	[1]
Interest Expense | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	11
Interest Expense | Interest Rate Instruments [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	9
Interest Expense | Interest Rate Instruments [Member] | Southern California Gas Company [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	1
Cost of Natural Gas, Electric Fuel and Purchased Power [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-1
Equity Earnings Before Income Tax [Member] | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	10
Income Before Tax [Member] | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	20
Income Tax Expense [Member] | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-4
Income Tax Expense [Member] | Amortization of Actuarial Loss [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-19
Income Tax Expense [Member] | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-1
Income Tax Expense [Member] | Amortization of Actuarial Loss [Member] | Southern California Gas Company [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	1
Income After Tax [Member] | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	16
Earnings Attributable To Noncontrolling Interests [Member] | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-9
Earnings Attributable To Noncontrolling Interests [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	-9
Total [Member] | Foreign Currency Translation [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	270	[2]
Total [Member] | Interest Rate Instruments [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	7
Total [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	0
Total [Member] | Amortization of Actuarial Loss [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	28
Total [Member] | Amortization of Actuarial Loss [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	2
Total [Member] | Amortization of Actuarial Loss [Member] | Southern California Gas Company [Member]	'
Reclassifications From Accumulated Other Comprehensive Income [Line Items]	'
Amount reclassified from accumulated other comprehensive income (loss).	($1)
[1]	Amounts are included in the computation of net periodic benefit cost (see "Net Periodic Benefit Cost, 2011 - 2013" 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_COLLECTIO

OTHER FINANCIAL DATA - COLLECTION ALLOWANCES (Details) (Allowance for Doubtful Accounts [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
Allowance balance at January 1	$31	$29	$29
Provisions for uncollectible accounts	16	21	20
Write-offs of uncollectible accounts	-18	-19	-20
Allowance balance at December 31	29	31	29
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
Allowance balance at January 1	6	6	5
Provisions for uncollectible accounts	4	5	8
Write-offs of uncollectible accounts	-5	-5	-7
Allowance balance at December 31	5	6	6
Southern California Gas Company [Member]	'	'	'
Valuation and Qualifying Accounts Disclosure [Line Items]	'	'	'
Allowance balance at January 1	14	12	14
Provisions for uncollectible accounts	7	12	8
Write-offs of uncollectible accounts	-9	-10	-10
Allowance balance at December 31	$12	$14	$12

OTHER_FINANCIAL_DATA_ASSET_RET

OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Asset Retirement Obligations [Line Items]	'		'
Asset Retirement Obligation, Balance as of January 1	$2,056	[1]	$1,925	[1]
Asset Retirement Obligation, Accretion Expense	97		92
Asset Retirement Obligation, Liabilities Incurred	4		21
Asset Retirement Obligation, Reclassification	0	[2]	-5	[2]
Asset Retirement Obligation, Liabilities Settled	-49		-2
Asset Retirement Obligation, Revisions, Related To GRC	-135	[3]	0	[3]
Asset Retirement Obligation, Revisions, Other	179	[4]	25	[4]
Asset Retirement Obligation, Balance as of December 31	2,152	[1]	2,056	[1]
San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Asset Retirement Obligations [Line Items]	'		'
Asset Retirement Obligation, Balance as of January 1	741	[1]	698	[1]
Asset Retirement Obligation, Accretion Expense	45		42
Asset Retirement Obligation, Liabilities Incurred	0		0
Asset Retirement Obligation, Reclassification	0	[2]	0	[2]
Asset Retirement Obligation, Liabilities Settled	-48		0
Asset Retirement Obligation, Revisions, Related To GRC	-30	[3]	0	[3]
Asset Retirement Obligation, Revisions, Other	205	[4]	1	[4]
Asset Retirement Obligation, Balance as of December 31	913	[1]	741	[1]
Southern California Gas Company [Member]	'		'
Asset Retirement Obligations [Line Items]	'		'
Asset Retirement Obligation, Balance as of January 1	1,253	[1]	1,175	[1]
Asset Retirement Obligation, Accretion Expense	49		48
Asset Retirement Obligation, Liabilities Incurred	0		0
Asset Retirement Obligation, Reclassification	0	[2]	0	[2]
Asset Retirement Obligation, Liabilities Settled	0		-1
Asset Retirement Obligation, Revisions, Related To GRC	-105	[3]	0	[3]
Asset Retirement Obligation, Revisions, Other	2	[4]	31	[4]
Asset Retirement Obligation, Balance as of December 31	$1,199	[1]	$1,253	[1]
[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 Sheets, as we discuss in "Assets Held for Sale" above.
[3]	The decreases in asset retirement obligations in 2013 at SDG&E and SoCalGas are due to revised estimates related to the 2012 General Rate Case (GRC) that received final approval in May 2013. At SDG&E, these revisions included increases in asset service lives ranging from 2 percent to 7 percent, and lower estimated cost of removal. At SoCalGas, the decrease includes increases in asset service lives ranging from 4 percent to 6 percent, partially offset by a higher estimated cost of removal.
[4]	The increase in asset retirement obligations in 2013 at SDG&E is due to revised estimates recorded in the third quarter of 2013 related to the early decommissioning of SONGS Units 2 and 3 (see Note 13).

OTHER_FINANCIAL_DATA_OTHER_INT

OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2008	Dec. 31, 2013	Dec. 31, 2012
				Storage Rights [Member]	Storage Rights [Member]	Development Rights [Member]	Development Rights [Member]	Development Rights [Member]	Other Intangible Assets [Member]	Other Intangible Assets [Member]
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'	'	'	'	'	'
Finite-Lived Intangible Assets, Gross	$479	$479	'	$138	$138	$322	$322	$460	$19	$19
Finite-Lived Intangible Assets, Accumulated Amortization	-53	-43	'	-16	-13	-34	-27	'	-3	-3
Finite-Lived Intangible Assets, Net	426	436	'	'	'	'	'	'	'	'
Finite-Lived Intangible Assets Amortization Expense	10	10	10	'	'	'	'	'	'	'
Finite Lived Intangible Assets, Future Amortization Expense Per Year	$10	'	'	'	'	'	'	'	'	'
Finite Lived Intangible Assets, Storage Rights Amortization Period	46	'	'	'	'	'	'	'	'	'
Finite Lived Intangible Assets, Development Rights Amortization Period	50	'	'	'	'	'	'	'	'	'
Finite Lived Intangible Assets, Other Intangibles Amortization Period, Minimum	15	'	'	'	'	'	'	'	'	'

OTHER_FINANCIAL_DATA_GOODWILL_

OTHER FINANCIAL DATA - GOODWILL (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Goodwill [Line Items]	'		'		'
Goodwill, ending balance	$1,024		$1,111		'
Goodwill By Segment Sempra Energy Consolidated [Member]	'		'		'
Goodwill [Line Items]	'		'		'
Foreign currency translation	-87	[1]	65	[1]	'
Goodwill, Acquired During Period	'		10		'
Goodwill, ending balance	1,024		1,111		1,036
Goodwill By Segment, Sempra South American Utilities [Member]	'		'		'
Goodwill [Line Items]	'		'		'
Foreign currency translation	-87	[1]	65	[1]	'
Goodwill, Acquired During Period	'		0		'
Goodwill, ending balance	927		1,014		949
Goodwill By Segment, Sempra Natural Gas [Member]	'		'		'
Goodwill [Line Items]	'		'		'
Foreign currency translation	0	[1]	0	[1]	'
Goodwill, Acquired During Period	'		10		'
Goodwill, ending balance	72		72		62
Goodwill By Segment, Sempra Mexico [Member]	'		'		'
Goodwill [Line Items]	'		'		'
Foreign currency translation	0	[1]	0	[1]	'
Goodwill, Acquired During Period	'		0		'
Goodwill, ending balance	$25		$25		$25
[1]	We record the offset of this fluctuation to other comprehensive income.

OTHER_FINANCIAL_DATA_ASSETS_HE

OTHER FINANCIAL DATA - ASSETS HELD FOR SALE (Details) (USD $)	Dec. 31, 2013	Feb. 28, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Assets Held For Sale Disclosure [Abstract]	'	'	'
Property, plant and equipment, net	'	'	$292
Inventories	'	'	4
Total assets held for sale	0	'	296
Liability held for sale - asset retirement obligation	'	'	-5	[1]
Total assets held for sale, net	'	'	291
Asssets Held For Sale, Proceeds	'	$371	'
[1]	Included in Other Current Liabilities on the Consolidated Balance Sheet.

OTHER_FINANCIAL_DATA_PROPERTY_

OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	$34,407		$33,528		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	8,947		8,337		'
San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	14,346		14,124		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	3,500		3,261		'
Southern California Gas Company [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	11,831		11,187		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	4,364		4,170		'
Gas, Transmission and Distribution Equipment [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	1,454		1,406		'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.35%		3.20%		3.15%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	639		601		'
Gas, Transmission and Distribution Equipment [Member] | Southern California Gas Company [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	11,394	[1]	10,756	[1]	'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.70%		3.74%		3.62%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	4,279	[2]	4,067	[2]	'
Capital Leased Assets, Gross	33		32		'
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation	31		28		'
Electric Distribution [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	5,492		5,217		'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.36%		4.15%		4.13%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	2,861	[3]	2,660	[3]	'
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation	26		21		'
Electric Transmission [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	3,932	[4]	3,714	[4]	'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	2.58%		2.63%		2.74%
Utility Electric Generation Equipment [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	1,768	[5]	2,242	[5]	'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	3.76%		4.68%		4.92%
Capital Leased Assets, Gross	183		183		'
Other Utility Electric Equipment [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	759	[6]	679	[6]	'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	7.58%		7.92%		8.26%
Capital Leased Assets, Gross	23		23		'
Other Plant in Service [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	938	[7]	806	[7]	'
Other Plant in Service [Member] | Southern California Gas Company [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	118		129		'
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service	1.56%		1.36%		1.62%
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	85		103		'
Utility Construction In Progress [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	941	[4]	866	[4]	'
Utility Construction In Progress [Member] | Southern California Gas Company [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	319		302		'
Utility Electric Distribution Operations [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	1,440	[8]	1,459	[8]	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	145		100		'
Property, Plant and Equipment Useful Life, Minimum	10		'		'
Property, Plant and Equipment Useful Life, Maximum	46		'		'
Property, Plant Equipment Weighted Average Useful Life	40		'		'
Land And Land Rights [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	276	[8]	298	[8]	'
Property, Plant and Equipment Useful Life, Minimum	20	[9]	'		'
Property, Plant and Equipment Useful Life, Maximum	50	[9]	'		'
Property, Plant Equipment Weighted Average Useful Life	47	[9]	'		'
Electric Generation Equipment [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	993	[8]	1,568	[8]	'
Property, Plant and Equipment Useful Life, Minimum	3		'		'
Property, Plant and Equipment Useful Life, Maximum	35		'		'
Property, Plant Equipment Weighted Average Useful Life	31		'		'
L N G Receipt Terminals [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	2,094	[8]	2,061	[8]	'
Property, Plant and Equipment Useful Life, Minimum	3		'		'
Property, Plant and Equipment Useful Life, Maximum	50		'		'
Property, Plant Equipment Weighted Average Useful Life	46		'		'
Pipelines And Storage Equipment [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	1,638	[8]	1,634	[8]	'
Property, Plant and Equipment Useful Life, Minimum	3		'		'
Property, Plant and Equipment Useful Life, Maximum	50		'		'
Property, Plant Equipment Weighted Average Useful Life	42		'		'
Other Machinery and Equipment [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	212	[8]	241	[8]	'
Property, Plant and Equipment Useful Life, Minimum	1		'		'
Property, Plant and Equipment Useful Life, Maximum	47		'		'
Property, Plant Equipment Weighted Average Useful Life	13		'		'
Construction in Progress [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	1,283	[8]	692	[8]	'
Other Capitalized Property Plant and Equipment [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	294	[8]	264	[8]	'
Property, Plant and Equipment Useful Life, Minimum	2		'		'
Property, Plant and Equipment Useful Life, Maximum	80		'		'
Property, Plant Equipment Weighted Average Useful Life	29		'		'
Electric Distribution Assets Of SWPL [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	350		'		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	199		'		'
CWIP Assets Of SWPL [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	5		'		'
Plant, Pipeline And Other Distribution Assets Of Ecogas [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	155		144		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	38		34		'
Plant, Pipeline And Other Distribution Assets Of Mobile Gas [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	180		171		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	25		21		'
Plant, Pipeline And Other Distribution Assets Of Willmut Gas [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	22		18		'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	2		1		'
Total Other Operating Units And Parent [Member]	'		'		'
Property, Plant and Equipment [Line Items]	'		'		'
Property, Plant and Equipment, Gross	8,230	[8]	8,217	[8]	'
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment	$1,083		$906		'
[1]	Includes capital lease assets of $33 million and $32 million at December 31, 2013 and 2012, respectively.
[2]	Includes accumulated depreciation for assets under capital lease of $31 million and $28 million at December 31, 2013 and 2012, respectively.
[3]	Includes accumulated depreciation for assets under capital lease of $26 million and $21 million at December 31, 2013 and 2012, respectively. Includes $199 million related to SDG&E's 91-percent interest in the SWPL transmission line, jointly owned by SDG&E and other utilities.
[4]	At December 31, 2013, includes $350 million in electric transmission assets and $5 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.
[5]	Includes capital lease assets of $183 million at both December 31, 2013 and 2012, primarily related to variable interest entities of which SDG&E is not the primary beneficiary.
[6]	Includes capital lease assets of $23 million at both December 31, 2013 and 2012.
[7]	December 31, 2013 balances include $38 million, $25 million and $2 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively. December 31, 2012 balances include $34 million, $21 million and $1 million of accumulated depreciation for utility plant at Ecogas, Mobile Gas and Willmut Gas, respectively.
[8]	December 31, 2013 balances include $155 million, $180 million and $22 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively. December 31, 2012 balances include $144 million, $171 million and $18 million of utility plant, primarily pipelines and other distribution assets, at Ecogas, Mobile Gas and Willmut Gas, respectively.
[9]	Estimated useful lives are for land rights.

OTHER_FINANCIAL_DATA_PROPERTY_1

OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Capital Expenditures Incurred But Not Yet Paid [Line Items]	'	'	'
Capital Expenditures Incurred but Not yet Paid	$437	$357	$368
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Capital Expenditures Incurred But Not Yet Paid [Line Items]	'	'	'
Capital Expenditures Incurred but Not yet Paid	182	153	187
Southern California Gas Company [Member]	'	'	'
Capital Expenditures Incurred But Not Yet Paid [Line Items]	'	'	'
Capital Expenditures Incurred but Not yet Paid	$130	$115	$97

OTHER_FINANCIAL_DATA_PROPERTY_2

OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT 3 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Capitalized Financing Costs Disclosure [Line Items]	'	'	'
AFUDC related to debt	$22	$38	$40
AFUDC related to equiity	75	96	99
Other capitalized financing costs	22	52	26
Capitalized Interest Costs, Including Allowance for Funds Used During Construction, Total	119	186	165
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Capitalized Financing Costs Disclosure [Line Items]	'	'	'
AFUDC related to debt	16	30	33
AFUDC related to equiity	39	71	80
Other capitalized financing costs	0	0	0
Capitalized Interest Costs, Including Allowance for Funds Used During Construction, Total	55	101	113
Southern California Gas Company [Member]	'	'	'
Capitalized Financing Costs Disclosure [Line Items]	'	'	'
AFUDC related to debt	6	8	7
AFUDC related to equiity	17	25	19
Other capitalized financing costs	1	1	0
Capitalized Interest Costs, Including Allowance for Funds Used During Construction, Total	$24	$34	$26

ACQUISTION_AND_DIVESTITURE_ACT2

ACQUISTION AND DIVESTITURE ACTIVITY (Details) (USD $)

12 Months Ended

1 Months Ended

12 Months Ended

9 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

In Millions, except Share data, unless otherwise specified

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

31-May-12

Dec. 31, 2012

Dec. 31, 2011

Apr. 06, 2011

Sep. 13, 2011

Apr. 06, 2011

Dec. 31, 2011

Dec. 31, 2011

Apr. 06, 2011

Oct. 31, 2012

Dec. 31, 2011

Apr. 06, 2011

Apr. 06, 2011

Apr. 06, 2011

Apr. 06, 2011

Willmut Gas [Member]

Willmut Gas [Member]

Willmut Gas [Member]

Chilquinta Energia [Member]

Luz Del Sur [Member]

Luz Del Sur [Member]

South America Acquisition [Member]

South America Acquisition [Member]

South America Acquisition [Member]

LuzLinares [Member]

PurchasePriceAllocationSouthAmericaMember [Member]

PurchasePriceAllocationSouthAmericaMember [Member]

Peruvian Entities [Member]

Chilean Entities [Member]

Other Holding Companies [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage before acquisition

'

'

'

'

'

'

50.00%

'

38.00%

'

'

'

85.00%

'

'

'

'

'

Acquired percentage interest in joint venture

'

'

'

100.00%

'

'

100.00%

'

76.00%

'

'

'

15.00%

'

'

'

'

'

Maximum percent of Luz del Sur minority interests

'

'

'

'

'

'

'

'

14.73%

'

'

'

'

'

'

'

'

'

Ownership percentage after Luz Del Sur tender offer

'

'

'

'

'

'

'

79.82%

'

'

'

'

'

'

'

'

'

'

Additional Shares Purchased From Tender Offer

'

'

'

'

'

'

'

18,918,954

'

'

'

'

'

'

'

'

'

'

Luz Del Sur settlement of public tender offer

'

'

'

'

'

'

'

$43

'

'

'

'

'

'

'

'

'

'

Premium on long term debt related to purchase

'

'

'

'

'

'

'

'

'

'

'

11

'

'

'

'

'

'

Consideration withheld related to purchase

'

'

'

'

'

'

'

'

'

'

'

32

'

'

'

'

'

'

Fair value of businesses acquired [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash consideration (fair value of total consideration)

'

'

'

'

'

'

'

'

'

'

'

611

'

'

888

385

495

8

Fair value of equity method investments immediately prior to the acquisition

'

'

'

'

'

'

'

'

'

'

'

'

'

'

882

385

495

2

Fair value of noncontrolling interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

279

242

37

0

Total fair value of businesses acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,049

1,012

1,027

10

Recognized amounts of identifiable assets acquired and liabilities assumed [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Cash

'

'

'

'

'

'

'

'

'

'

'

'

'

'

245

22

219

4

Property, plant and equipment

'

'

'

17

'

'

'

'

'

'

'

'

'

'

1,486

931

555

0

Long-term debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-484

-179

-305

0

Other net assets acquired

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-173

-223

44

6

Total identifiable net assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,074

551

513

10

Goodwill

'

'

'

10

'

'

'

'

'

'

'

'

'

'

975

461

514

0

Remeasurement of equity method investments

0

0

277

'

'

'

'

'

'

'

277

'

'

'

'

'

'

'

Book value of equity interests

'

'

'

'

'

'

'

'

'

'

'

605

'

'

'

'

'

'

Revenue of acquiree since acquisition date

'

'

'

'

10

'

'

'

'

1,100

'

'

'

'

'

'

'

'

Net Income of acquiree since acquisition date

'

'

'

'

'

'

'

'

'

160

'

'

'

'

'

'

'

'

Earnings of acquiree since acquisition date

'

'

'

'

'

'

'

'

'

135

'

'

'

'

'

'

'

'

Pro forma revenues

'

'

'

'

'

'

'

'

'

'

'

'

'

10,379

'

'

'

'

Pro forma earnings

'

'

'

'

'

'

'

'

'

'

'

'

'

1,079

[1]

'

'

'

'

Business acquisition, Cash paid, net of cash acquired

'

'

'

19

'

'

'

'

'

'

'

'

7

'

'

'

'

'

Incremental proforma revenue

'

'

'

'

7

21

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities Assumed

'

'

'

10

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase of noncontrolling interests

$0

($7)

($43)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

[1]

Excludes the $277 million gain related to the remeasurement of equity method investments.

ACQUISTION_AND_DIVESTITURE_ACT3

ACQUISTION AND DIVESTITURE ACTIVITY 2 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013		Mar. 31, 2013	Sep. 30, 2013
	Mesquite Solar 1 [Member]		Mesquite Power [Member]	Copper Mountain Solar 2 [Member]
Deconsolidation of Business [Line Items]	'		'	'
Proceeds from Sale, net of transaction costs	$100	[1]	'	$69	[1]
Other assets	-72		'	-30
Property, plant and equipment	-461		'	-266
Long-term debt, including current portion	297		'	146
Other liablities	31		'	19
Gain on sale of assets	-36		74	-4
Equity method investments upon deconsolidation.	-141		'	-66
Transaction costs	3		'	3
Gain on sale of assets, after tax	22		44	2
Proceeds from divestiture of businesses	$103		$371	$72
[1]	Transaction costs were $3 million at each of Copper Mountain Solar 2 and Mesquite Solar 1.

INVESTMENTS_IN_UNCONSOLIDATED_3

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) (USD $)

3 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

12 Months Ended

3 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

1 Months Ended

12 Months Ended

12 Months Ended

12 Months Ended

In Millions, unless otherwise specified

Jun. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Mar. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2010

Sep. 30, 2012

Jun. 30, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Other Equity Method Investments And Other Investments [Member]

Other Equity Method Investments And Other Investments [Member]

Other Equity Method Investments [Member]

Other Equity Method Investments [Member]

Other Equity Method Investments [Member]

Sodigas Pampeana And Sodigas Sur [Member]

Sodigas Pampeana And Sodigas Sur [Member]

Sodigas Pampeana And Sodigas Sur [Member]

Sodigas Pampeana And Sodigas Sur [Member]

Chilquinta Energia [Member]

Chilquinta Energia [Member]

Chilquinta Energia [Member]

Chilquinta Energia [Member]

Luz Del Sur [Member]

Luz Del Sur [Member]

Luz Del Sur [Member]

Luz Del Sur [Member]

Rockies Express [Member]

Rockies Express [Member]

Rockies Express [Member]

Rockies Express [Member]

Rockies Express [Member]

Gasoductos De Chihuahua [Member]

Gasoductos De Chihuahua [Member]

Gasoductos De Chihuahua [Member]

Fowler Ridge I I Wind Farm [Member]

Fowler Ridge I I Wind Farm [Member]

Fowler Ridge I I Wind Farm [Member]

Cedar Creek I I Wind Farm [Member]

Cedar Creek I I Wind Farm [Member]

Cedar Creek I I Wind Farm [Member]

R B S Sempra Commodities [Member]

R B S Sempra Commodities [Member]

R B S Sempra Commodities [Member]

Auwahi Wind [Member]

Auwahi Wind [Member]

Auwahi Wind [Member]

Mehoopany Wind Farm [Member]

Mehoopany Wind Farm [Member]

Mehoopany Wind Farm [Member]

Mehoopany Wind Farm [Member]

Flat Ridge 2 Wind Farm [Member]

Flat Ridge 2 Wind Farm [Member]

Flat Ridge 2 Wind Farm [Member]

Flat Ridge 2 Wind Farm [Member]

Copper Mountain Solar 2 [Member]

Copper Mountain Solar 2 [Member]

Mesquite Solar 1 [Member]

Mesquite Solar 1 [Member]

Mesquite Solar 1 [Member]

Eletrans [Member]

Eletrans [Member]

Eletrans [Member]

Other Equity Investments [Member]

Other Equity Investments [Member]

Other Equity Investments [Member]

Other Investments [Member]

Other Investments [Member]

Other Equity Method Investments On Statement of Operations [Member]

Other Equity Method Investments On Statement of Operations [Member]

Other Equity Method Investments On Statement of Operations [Member]

Schedule Of Equity Method And Other Investments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method And Other Investments

'

'

'

'

$1,575

$1,516

$1,485

$1,427

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$329

$361

'

$379

$340

'

$51

$47

'

$92

$93

'

$73

$126

'

$53

$72

'

$89

$85

$89

'

$291

$292

$291

'

$67

$0

$67

$0

'

($3)

$0

'

$0

$8

'

$90

$89

'

'

'

Equity Method Investment, Impairment, Gross Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

-400

0

'

'

'

'

'

'

'

'

'

0

0

-16

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Methold Investment, Income Tax Make-Whole Payment Received

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

41

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Other Equity Earnings (Losses)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

47

47

43

'

'

'

'

'

'

'

'

'

-3

0

-8

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Before Tax

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3

-3

-4

-4

-4

-2

'

'

'

4

0

0

'

-2

0

0

'

-8

1

0

'

'

1

0

0

'

'

'

-1

-1

-4

'

'

31

-319

9

Income (Loss) From Equity Method Investments, Earnings (Losses) Recorded Net Of Tax

'

'

'

'

'

'

24

36

52

'

-11

0

-1

0

[1]

0

[1]

12

[1]

'

0

[1]

0

[1]

12

[1]

'

'

'

'

'

'

39

36

29

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-4

0

0

'

'

'

'

'

'

'

'

Ownership percentage in equity method investee

'

'

'

'

'

'

'

'

'

'

'

'

43.00%

'

'

'

50.00%

'

'

'

38.00%

'

'

25.00%

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

Ownership percentage of minority partner in equity method investee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

25.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership percentage of operating partner in equity method investee

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Realized Gain (Loss) on Disposal

-7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Contributions to equity method investees

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

62

11

'

1

20

88

'

4

291

146

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Equity Method Investment, Other Than Temporary Impairment

'

'

'

'

'

'

'

'

'

-10

'

'

'

'

'

'

'

'

'

'

'

-100

-300

'

'

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'

Equity Method Investment, Other Than Temporary Impairment, Net Of Tax Benefit

'

'

'

'

'

'

'

'

'

-7

'

'

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'

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'

-60

-179

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Proceeds from return of capital

'

'

'

'

'

'

'

'

'

'

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'

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6

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'

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19

'

'

17

13

'

'

148

'

'

'

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'

28

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'

Undistributed Earnings, Equity Method Investments

'

129

107

'

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'

Equity Method Goodwill, Excluding Foreign Currency Translation Adjustments

'

65

65

'

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'

Equity Method Investment, Cumulative Foreign Currency Translation Adjustments

'

270

'

'

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'

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'

Real Estate Investments Held by South American Utilities

'

10

11

'

'

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'

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'

Industrial Development Bonds at Mississippi Hub

'

77

74

'

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Pretax loss on sale of Argentina

-7

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Aftertax loss on sale of Argentina

-4

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Proceeds From Sale Of Equity Method Investments

13

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'

Proceeds from return of capital at Auwahi Wind related to U.S. Treasury grants

'

15

'

'

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'

Accrued Liabilities, Argentina

'

'

'

$250

'

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'

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'

[1]

These investments were accounted for under the equity method until April 6, 2011, when they became consolidated entities upon our acquisition of additional ownership interests.

INVESTMENTS_IN_UNCONSOLIDATED_4

INVESTMENTS IN UNCONSOLIDATED ENTITIES 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Sep. 30, 2011
Investments In Unconsolidated Entities (Details) [Abstract]	'	'	'	'
Distributable income of RBS Sempra Commodities (IFRS basis)	$0	$0	$30	'
Distributions from RBS Sempra Commodities LLP, operating activities	0	0	53	'
Loss on impairment of RBS Sempra Commodities	'	'	-16	'
Loss on impairment of RBS Sempra Commodities, after tax	'	'	-10	'
Investment in RBS Sempra Commodities LLP	73	'	'	126	[1]
Distributions from RBS Sempra Commodities LLP	50	0	623	'
Distributions include sales proceeds and our portion of distributable income	'	'	651	'
Amounts to settle certain liabilities that we owed to RBS	'	'	$28	'
[1]	At measurement date of September 30, 2011. At December 31, 2013, our investment in RBS Sempra Commodities had a carrying value of $73 million, reflecting subsequent equity method activity to record distributions and losses.

DEBT_AND_CREDIT_FACILITIES_Det

DEBT AND CREDIT FACILITIES (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, maximum borrowing capacity	$4,100	'
Committed lines of credit, remaining borrowing capacity	3,400	'
Outstanding commercial paper supported by committed lines of credit classified as long-term debt	200	300
Weighted average interest rate on total short-term debt outstanding	0.64%	0.72%
Line Of Credit Facility, Sempra Energy [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, maximum borrowing capacity	1,067	'
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%	'
Committed lines of credit, capacity for issuance of letters of credit	635	'
Committed lines of credit, letters of credit outstanding	12	'
Line Of Credit Facility, Sempra Global [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, maximum borrowing capacity	2,189	'
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%	'
Outstanding commercial paper supported by committed lines of credit	590	'
Line Of Credit Facility, S D G E [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, maximum borrowing capacity	658	'
Committed lines of credit, remaining borrowing capacity	599	'
Outstanding commercial paper supported by committed lines of credit	59	'
Weighted average interest rate on total short-term debt outstanding	0.13%	'
Line Of Credit Facility, So Cal Gas [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, maximum borrowing capacity	658	'
Committed lines of credit, remaining borrowing capacity	616	'
Outstanding commercial paper supported by committed lines of credit	42	'
Weighted average interest rate on total short-term debt outstanding	0.13%	'
Line Of Credit Facility, California Utilities Combined [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, maximum borrowing capacity	877	'
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%	'
Committed lines of credit, capacity for issuance of letters of credit	200	'
New line of credit capacity	300	'
Line Of Credit Facility, Copper Mountain Solar 2 [Member]	'	'
Line of Credit Facility [Line Items]	'	'
Committed lines of credit, capacity for issuance of letters of credit	$60	'

DEBT_AND_CREDIT_FACILITIES_2_D

DEBT AND CREDIT FACILITIES 2 (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012
Debt Instrument [Line Items]	'		'
Long-term Commercial Paper, Noncurrent	$200,000,000		$300,000,000
Capital Lease Obligations	195,000,000		189,000,000
Current portion of long-term debt	-1,147,000,000		-725,000,000
Debt Instrument, Unamortized Discount	-17,000,000		-16,000,000
Long-term debt	11,253,000,000		11,621,000,000
Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	3,912,000,000		3,536,000,000
Long Term Debt And Capital Lease Obligations, Including Current Portion	4,565,000,000		4,320,000,000
Current portion of long-term debt	-29,000,000		-16,000,000
Debt Instrument, Unamortized Discount	-11,000,000		-12,000,000
Long-term debt	4,525,000,000		4,292,000,000
Debt Instrument, So Cal Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	1,400,000,000		1,400,000,000
Capital Lease Obligations	2,000,000		4,000,000
Long Term Debt And Capital Lease Obligations, Including Current Portion	1,415,000,000		1,417,000,000
Current portion of long-term debt	-252,000,000		-4,000,000
Debt Instrument, Unamortized Discount	-4,000,000		-4,000,000
Long-term debt	1,159,000,000		1,409,000,000
Debt Instrument, Other Sempra Energy [Member]	'		'
Debt Instrument [Line Items]	'		'
Long Term Debt And Capital Lease Obligations, Including Current Portion	6,437,000,000		6,625,000,000
Current portion of long-term debt	-866,000,000		-705,000,000
Debt Instrument, Unamortized Discount	-9,000,000		-8,000,000
Debt Instrument Unamortized Premium	7,000,000		8,000,000
Long-term debt	5,569,000,000		5,920,000,000
Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Build to suit lease	14,000,000	[1]	0	[1]
First Mortgage Bonds, Due March 2014 [Member] | Debt Instrument, So Cal Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.50%		'
First Mortgage Bonds, Due June 2015 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0		14,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.80%		'
Repayments Of First Mortgage Bond	14,000,000		'
Repayment of first mortgage bond stated rate.	6.80%		'
First Mortgage Bonds, Due November 2015 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.30%		'
First Mortgage Bonds, Due April 2018 [Member] | Debt Instrument, So Cal Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.45%		'
First Mortgage Bonds, Due July 2018 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	161,000,000	[2]	161,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	1.65%	[2]	'
First Mortgage Bonds, Due June 2021 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0	[2]	60,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	5.85%	[2]	'
Repayments Of Pollution Control Bond	60,000,000		'
Repayment of pollution control bond stated rate	5.85%		'
First Mortgage Bonds, Due June 2026 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
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	150,000,000	[2]	150,000,000	[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 January And February 2034 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	176,000,000	[2]	176,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	5.88%	[2]	'
First Mortgage Bonds, Due May 2035 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
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	250,000,000		250,000,000
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	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.13%		'
First Mortgage Bonds, Due June 2039 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	300,000,000		300,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.00%		'
First Mortgage Bonds, Due May 2039 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	75,000,000	[2]	75,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	4.00%		'
First Mortgage Bonds, Due May 2040 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
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	500,000,000		500,000,000
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	300,000,000		300,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.13%		'
First Mortgage Bonds, Due August 2021 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	350,000,000		350,000,000
Debt Instrument, Interest Rate, Stated Percentage	3.00%		'
First Mortgage Bonds, Due November 2041 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	3.95%		'
First Mortgage Bonds, Due September 2021 [Member] | Debt Instrument, Mobile Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	20,000,000		20,000,000
Debt Instrument, Interest Rate, Stated Percentage	4.14%		'
First Mortgage Bonds, Due September 2031 [Member] | Debt Instrument, Mobile Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	42,000,000		42,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.00%		'
First Mortgage Bonds, Due April 2042 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	250,000,000		250,000,000
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	350,000,000		350,000,000
Debt Instrument, Interest Rate, Stated Percentage	3.75%		'
First Mortgage Bonds, Due September 2023 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	450,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	3.60%		'
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	653,000,000		784,000,000
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	15,000,000		17,000,000
Commercial Paper [Member] | Debt Instrument, Sempra Global [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	200,000,000		300,000,000
Debt Instrument, Interest Rate at Period End	0.35%		'
Other Long-term Debt, Due February 2013 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0		400,000,000
Debt Instrument, Interest Rate, Stated Percentage	6.00%		'
Other Long-term Debt, Due November 2013 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0		250,000,000
Debt Instrument, Interest Rate, Stated Percentage	8.90%		'
Other Long-term Debt, Due June 2014 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	15,000,000		130,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.90%		'
Repayments Of Pollution Control Bond	115,000,000		'
Repayment of pollution control bond stated rate	5.90%		'
Other Long-term Debt, Due May 2016 [Member] | Debt Instrument, So Cal Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	8,000,000	[2]	8,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	4.75%	[2]	'
Other Long-term Debt, Due June 2016 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	750,000,000		750,000,000
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	500,000,000		500,000,000
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	500,000,000		500,000,000
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	39,000,000	[2]	39,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	5.30%	[2]	'
Other Long-term Debt, Due December 2021 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	60,000,000	[2]	60,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	5.50%	[2]	'
Other Long-term Debt, Due March 2023 [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	25,000,000	[2]	25,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	4.90%	[2]	'
Other Long-term Debt, Due July 2024 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	77,000,000	[2]	74,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	4.50%	[2]	'
Other Long-term Debt, Due January 2028 [Member] | Debt Instrument, So Cal Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	5,000,000		5,000,000
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	750,000,000		750,000,000
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	55,000,000	[2]	55,000,000	[2]
Debt Instrument, Interest Rate at Period End	0.05%	[2]	'
Capital Lease Obligations, Purchased Power Agreements [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Capital Lease Obligations	176,000,000		178,000,000
Capital Lease Obligations, Other [Member] | Debt Instrument, S D G E [Member]	'		'
Debt Instrument [Line Items]	'		'
Capital Lease Obligations	3,000,000		7,000,000
Market Value Adjustment For Interest Rate Swap [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	12,000,000		19,000,000
Other Long-term Debt, Due March 2014 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	500,000,000		500,000,000
Debt Instrument, Interest Rate, Stated Percentage	2.00%		'
Other Long-term Debt, Variable Rate Notes Due March 2014 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	300,000,000		300,000,000
Debt Instrument, Interest Rate at Period End	1.01%		'
Other Long-term Debt Due October 2014 [Member] | Debt Instrument, Chilquinta Energia [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0	[2]	86,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	2.75%	[2]	'
Repayments Of Other Long Term Debt	86,000,000,000		'
Repayment of other long-term debt stated rate.	2.75%		'
Other Long-term Debt, Due October 2030 [Member] | Debt Instrument, Chilquinta Energia [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	209,000,000	[2]	224,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage	4.25%	[2]	'
Other Long-term Debt, Due May 2013 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0		1,000,000
Debt Instrument, Interest Rate, Stated Percentage	9.00%		'
Other Long-term Debt, Due February 2018 [Member] | Debt Instrument, Sempra Mexico [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	100,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	2.66%		'
Debt instrument face amount	102,000,000		'
Other Long-term Debt, Due February 2023 [Member] | Debt Instrument, Sempra Mexico [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	298,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	6.30%		'
Debt Instrument, Interest Rate at Period End	4.12%		'
Debt instrument face amount	306,000,000		'
Other Long-term Debt, Due December 2023 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	500,000,000		0
Debt Instrument, Interest Rate, Stated Percentage	4.05%		'
Other Long-term Debt, Due December 2018 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	5,000,000	[2]	0	[2]
Debt Instrument, Interest Rate, Stated Percentage	3.10%	[2]	'
Other Long Term Debt, Variable Rate Notes Due November 2013 [Member] | Debt Instrument, Parent [Member]	'		'
Debt Instrument [Line Items]	'		'
Debt Instrument, Amount At Variable Rates After Fixed To Floating Swap Effective January 2011	200,000,000		'
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	4.46%		'
Debt Instrument, Amount At Variable Rates After Fixed To Floating Swap Effective January 2011	300,000,000		'
Otay Mesa Energy Center Loan Payable Currently Through April 2019 [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	335,000,000		345,000,000
Debt Instrument, Interest Rate, Stated Percentage	5.29%		'
Other Long Term Debt, Payable Currently Through October 2022 [Member] | Debt Instrument, Luz Del Sur [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	292,000,000		284,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	4.75%		'
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	7.09%		'
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	104,000,000	[2]	111,000,000	[2]
Debt Instrument, Interest Rate at Period End	2.75%	[2]	'
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	4.54%	[2]	'
Debt Instrument, Amount At Fixed Rates After Floating to Fixed Swap	78,000,000	[2]	'
Other Long Term Debt, Payable Currently Through January 2031 [Member] | Debt Instrument, Sempra Renewables [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	0		286,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.24%		'
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	2.26%		'
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	21,000,000		25,000,000
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	600,000,000		600,000,000
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	500,000,000		500,000,000
Debt Instrument, Interest Rate, Stated Percentage	2.88%		'
Other Long-term Debt, Currently Through December 2018 [Member] | Debt Instrument, Luz Del Sur [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	70,000,000		31,000,000
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	5.50%		'
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	6.75%		'
Other Long-term Debt, Currently Through October 2016 [Member] | Debt Instrument, Other Sempra Natural Gas [Member]	'		'
Debt Instrument [Line Items]	'		'
Long-term Debt, Gross	$18,000,000	[2]	$17,000,000	[2]
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Minimum	2.87%		'
Debt Instrument, Interest Rate, Stated Percentage Rate Range, Maximum	3.51%		'
[1]	We discuss this lease in Note 15.
[2]	Callable long-term debt not subject to make-whole provisions.

DEBT_AND_CREDIT_FACILITIES_3_D

DEBT AND CREDIT FACILITIES 3 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Mehoopany Wind Farm [Member]	'	'
Schedule Of Equity Method And Other Investments [Line Items]	'	'
Liability for guarantee obligation associated with cash flow requirements	$11	'
Proceeds From Return Of Capital	13	17
Mehoopany Wind Farm [Member] | Term Loan Due May 2031 [Member]	'	'
Schedule Of Equity Method And Other Investments [Line Items]	'	'
Long-term debt outstanding	162	'
Flat Ridge 2 Wind Farm [Member]	'	'
Schedule Of Equity Method And Other Investments [Line Items]	'	'
Liability for guarantee obligation associated with cash flow requirements	3	'
Proceeds From Return Of Capital	'	148
Flat Ridge 2 Wind Farm [Member] | Term Loan Due June 2023 [Member]	'	'
Schedule Of Equity Method And Other Investments [Line Items]	'	'
Long-term debt outstanding	242	'
Flat Ridge 2 Wind Farm [Member] | Fixed Rate Note Due June 2035 [Member]	'	'
Schedule Of Equity Method And Other Investments [Line Items]	'	'
Long-term debt outstanding	$110	'

DEBT_AND_CREDIT_FACILITIES_4_D

DEBT AND CREDIT FACILITIES 4 (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Schedule Of Long Term Debt Maturities [Line Items]	'
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months	$1,140	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Two	312	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Three	846	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Four	672	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Five	1,073	[1]
Long-term Debt, Maturities, Repayments of Principal after Year Five	8,164	[1]
Long-term Debt Maturities, Total Repayments Of Principal	12,207	[1]
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	24	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Two	260	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Three	10	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Four	10	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Five	171	[1]
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,910	[1]
Long-term Debt Maturities, Total Repayments Of Principal	4,385	[1]
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	250	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Two	0	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Three	8	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Four	0	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Five	250	[1]
Long-term Debt, Maturities, Repayments of Principal after Year Five	905	[1]
Long-term Debt Maturities, Total Repayments Of Principal	1,413	[1]
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	866	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Two	52	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Three	828	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Four	662	[1]
Long-term Debt, Maturities, Repayments of Principal in Year Five	652	[1]
Long-term Debt, Maturities, Repayments of Principal after Year Five	3,349	[1]
Long-term Debt Maturities, Total Repayments Of Principal	$6,409	[1]
[1]	Excludes capital lease obligations, build-to-suit lease and market value adjustments for interest rate swaps.

DEBT_AND_CREDIT_FACILITIES_5_D

DEBT AND CREDIT FACILITIES 5 (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Unsecured Debt [Line Items]	'
Long-term Debt, Unsecured	$6,200
San Diego Gas and Electric Company and Subsidiary [Member]	'
Unsecured Debt [Line Items]	'
Long-term Debt, Unsecured	138
Southern California Gas Company [Member]	'
Unsecured Debt [Line Items]	'
Long-term Debt, Unsecured	$13

DEBT_AND_CREDIT_FACILITIES_6_D

DEBT AND CREDIT FACILITIES 6 (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Schedule Of Callable Long-term Debt [Line Items]	'
Callable Long-term Debt	$1,162
Callable Long term Debt Subject To Make Whole Provisions	9,433
Schedule Of Callable Long-term Debt, S D G E [Member]	'
Schedule Of Callable Long-term Debt [Line Items]	'
Callable Long-term Debt	686
Callable Long term Debt Subject To Make Whole Provisions	3,350
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	1,400
Schedule Of Callable Long-term Debt, Other Sempra Energy [Member]	'
Schedule Of Callable Long-term Debt [Line Items]	'
Callable Long-term Debt	468
Callable Long term Debt Subject To Make Whole Provisions	$4,683

DEBT_AND_CREDIT_FACILITIES_7_D

DEBT AND CREDIT FACILITIES 7 (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
San Diego Gas and Electric Company and Subsidiary [Member]	'
First Mortgage Bonds [Line Items]	'
First Mortgage Bonds, Amount Available For Future Issuance	$3,800
Southern California Gas Company [Member]	'
First Mortgage Bonds [Line Items]	'
First Mortgage Bonds, Amount Available For Future Issuance	$1,060

DEBT_AND_CREDIT_FACILITIES_8_D

DEBT AND CREDIT FACILITIES 8 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010	Dec. 31, 2009
Industrial Development Bonds [Line Items]	'	'	'	'	'
Payments To Acquire Industrial Development Bonds	$3	$53	$84	$42	$75
Industrial Development Bonds, Interest Rate, Stated Percentage	4.50%	'	'	'	'
Redemption of industrial development bonds	'	'	180	'	'
Maximum Long-term Debt Available, Industrial Development Bonds	$265	'	'	'	'

DEBT_AND_CREDIT_FACILITIES_9_D

DEBT AND CREDIT FACILITIES 9 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2013	Dec. 31, 2012	Nov. 30, 2012	Dec. 31, 2011
Sempra Mexico Segment [Member]	'	'	'	'	'
Other Long-Term Debt [Line Items]	'	'	'	'	'
Debt proceeds used for repayment of intercompany debt	'	$357	'	'	'
Copper Mountain Solar 2 [Member]	'	'	'	'	'
Other Long-Term Debt [Line Items]	'	'	'	'	'
Debt instrument, maximum borrowing amount	'	286	'	'	'
Debt instrument, outstanding borrowings	'	146	'	'	'
Debt instrument, interest rate, after floating to fixed swap	'	5.33%	'	'	'
Long-term debt including current portion divested from deconsolidation	146	'	'	'	'
Mesquite Solar 1 [Member]	'	'	'	'	'
Other Long-Term Debt [Line Items]	'	'	'	'	'
Debt instrument, interest rate, stated percentage	'	3.03%	2.24%	2.26%	'
Debt instrument, maximum borrowing amount	'	'	'	'	337
Debt instrument, outstanding borrowings	'	13	33	253	'
Long-term debt including current portion divested from deconsolidation	297	'	'	'	'
Debt instrument, maximum borrowing amount, accrued interest	'	'	'	'	$7

DEBT_AND_CREDIT_FACILITIES_10_

DEBT AND CREDIT FACILITIES 10 (Details) (Debt Instrument, Luz Del Sur [Member], USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
Other Long Term Debt, Due October 2017 [Member]	'
Debt Instrument Segment [Line Items]	'
Long-Term Debt, Luz Del Sur	$30
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	5.81%
Other Long-term Debt, Due December 2021 [Member]	'
Debt Instrument Segment [Line Items]	'
Long-Term Debt, Luz Del Sur	30
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	7.03%
Other Long-term Debt, Due June 2016 [Member]	'
Debt Instrument Segment [Line Items]	'
Long-Term Debt, Luz Del Sur	11
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	5.50%
Other Long Term Debt, Due July 11, 2016 [Member]	'
Debt Instrument Segment [Line Items]	'
Long-Term Debt, Luz Del Sur	5
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	6.00%
Other Long Term Debt, Due July 24, 2016 [Member]	'
Debt Instrument Segment [Line Items]	'
Long-Term Debt, Luz Del Sur	14
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	5.85%
Other Long-term Debt, Due December 2018 [Member]	'
Debt Instrument Segment [Line Items]	'
Long-Term Debt, Luz Del Sur	$22
Debt Instrument, Interest Rate, Stated Percentage, Luz Del Sur	6.41%

INCOME_TAXES_Details

INCOME TAXES (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]	'	'	'
Effective Income Tax Rate Reconciliation, Federal Statutory Income Tax Rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Utility Depreciation	4.00%	6.00%	3.00%
Effective Income Tax Rate Reconciliation Income Tax Restructuring Related To IEnova Stock Offering	4.00%	0.00%	0.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes	1.00%	-1.00%	2.00%
Effective Income Tax Rate Reconciliation, Utility Repair Allowance	-5.00%	-8.00%	-1.00%
Effective Income Tax Rate Reconciliation, Tax Credits	-3.00%	-7.00%	-1.00%
Effective Income Tax Rate Reconciliation, Non-U.S. Earnings Taxed At Lower Statutory Income Tax Rates	-3.00%	-4.00%	-8.00%
Effective Income Tax Rate Reconciliation, Self Developed Software Expenditures	-3.00%	-5.00%	-3.00%
Effective Income Tax Rate Reconciliation, Allowance For Equity Funds Used During Construction	-1.00%	-4.00%	-2.00%
Effective Income Tax Rate Reconciliation, Adjustments to Prior Year Income Tax Items	-3.00%	-1.00%	0.00%
Effective Income Tax Rate Reconciliation, Foreign Exchange And Inflation Effects	0.00%	1.00%	-1.00%
Effective Income Tax Rate Reconciliation, Variable Interest Entities	-1.00%	-1.00%	0.00%
Effective Income Tax Rate Reconciliation, Life Insurance Contract	0.00%	-7.00%	0.00%
Effective Income Tax Rate Reconciliation, Other Adjustments	1.00%	2.00%	-1.00%
Effective Income Tax Rate, Continuing Operations	26.00%	6.00%	23.00%
Income (Loss) from Continuing Operations before Income Taxes, Domestic	$941	$442	$1,011
Income (Loss) from Continuing Operations before Income Taxes, Foreign	489	501	712
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	1,430	943	1,723
Income tax expense related to corporate reorganization	63	'	'
Income tax benefit related to repairs expenditures recorded for full-year 2011	'	22	'
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]	'	'	'
Effective Income Tax Rate Reconciliation, Federal Statutory Income Tax Rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Utility Depreciation	5.00%	4.00%	4.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes	3.00%	4.00%	5.00%
Effective Income Tax Rate Reconciliation, Utility Repair Allowance	-4.00%	-4.00%	-1.00%
Effective Income Tax Rate Reconciliation, Self Developed Software Expenditures	-3.00%	-3.00%	-3.00%
Effective Income Tax Rate Reconciliation, Allowance For Equity Funds Used During Construction	-2.00%	-4.00%	-4.00%
Effective Income Tax Rate Reconciliation, Adjustments to Prior Year Income Tax Items	-1.00%	-3.00%	0.00%
Effective Income Tax Rate Reconciliation, Variable Interest Entities	-1.00%	-1.00%	-1.00%
Effective Income Tax Rate Reconciliation, Other Adjustments	-1.00%	-1.00%	-1.00%
Effective Income Tax Rate, Continuing Operations	31.00%	27.00%	34.00%
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	626	705	692
Southern California Gas Company [Member]	'	'	'
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]	'	'	'
Effective Income Tax Rate Reconciliation, Federal Statutory Income Tax Rate	35.00%	35.00%	35.00%
Effective Income Tax Rate Reconciliation, Utility Depreciation	6.00%	7.00%	6.00%
Effective Income Tax Rate Reconciliation, State and Local Income Taxes	4.00%	3.00%	4.00%
Effective Income Tax Rate Reconciliation, Utility Repair Allowance	-9.00%	-12.00%	0.00%
Effective Income Tax Rate Reconciliation, Self Developed Software Expenditures	-6.00%	-9.00%	-7.00%
Effective Income Tax Rate Reconciliation, Allowance For Equity Funds Used During Construction	-1.00%	-2.00%	-2.00%
Effective Income Tax Rate Reconciliation, Adjustments to Prior Year Income Tax Items	-5.00%	0.00%	0.00%
Effective Income Tax Rate Reconciliation, Other Adjustments	0.00%	-1.00%	-3.00%
Effective Income Tax Rate, Continuing Operations	24.00%	21.00%	33.00%
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	$481	$369	$431

INCOME_TAXES_2_Details

INCOME TAXES 2 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Deferred Tax Assets And Liabilities [Line Items]	'	'
Deferred Tax Liabilities, Property, Plant and Equipment	$3,951	$3,710
Deferred Tax Liabilities, Regulatory Balancing Accounts	663	770
Deferred Tax Liabilities, Tax Deferred Income	15	3
Deferred Tax Liabilities, Loss On Reacquired Debt	8	9
Deferred Tax Liabilities, Property Taxes	50	46
Deferred Tax Liabilities, Investment in Noncontrolled Affiliates	256	118
Deferred Tax Liabilities, Other	72	55
Deferred Tax Liabilities	5,015	4,711
Deferred Tax Assets, Tax Credit Carryforwards, General Business	105	67
Deferred Tax Assets, Equity Method Losses	16	16
Deferred Tax Assets, Net Operating Loss	2,023	1,898
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other	128	156
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits	264	587
Deferred Tax Assets, Other	14	90
Deferred Tax Assets, State Income Taxes	30	58
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Allowance for Doubtful Accounts	8	8
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Loss Reserves	20	7
Deferred Tax Assets, Gross	2,608	2,887
Deferred Tax Assets, Valuation Allowance	96	128
Deferred Tax Assets, Net	2,512	2,759
Net deferred income tax liability	2,503	1,952
Deferred Tax (Assets) Liabilities, Current, Net	-301	-148
Deferred Tax (Assets) Liabilities, Noncurrent, Net	2,804	2,100
San Diego Gas and Electric Company and Subsidiary [Member]	'	'
Deferred Tax Assets And Liabilities [Line Items]	'	'
Deferred Tax Liabilities, Property, Plant and Equipment	2,040	1,947
Deferred Tax Liabilities, Regulatory Balancing Accounts	411	344
Deferred Tax Liabilities, Loss On Reacquired Debt	3	4
Deferred Tax Liabilities, Property Taxes	36	32
Deferred Tax Liabilities, Other	25	22
Deferred Tax Liabilities	2,515	2,349
Deferred Tax Assets, Tax Credit Carryforwards, General Business	15	16
Deferred Tax Assets, Net Operating Loss	440	446
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other	13	14
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits	57	137
Deferred Tax Assets, Other	4	4
Deferred Tax Assets, State Income Taxes	22	31
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Loss Reserves	45	38
Deferred Tax Assets, Hedging Transactions	1	1
Deferred Tax Assets, Net	597	687
Net deferred income tax liability	1,918	1,662
Deferred Tax (Assets) Liabilities, Current, Net	-103	26
Deferred Tax (Assets) Liabilities, Noncurrent, Net	2,021	1,636
Southern California Gas Company [Member]	'	'
Deferred Tax Assets And Liabilities [Line Items]	'	'
Deferred Tax Liabilities, Property, Plant and Equipment	1,045	938
Deferred Tax Liabilities, Regulatory Balancing Accounts	265	439
Deferred Tax Liabilities, Loss On Reacquired Debt	6	7
Deferred Tax Liabilities, Property Taxes	16	15
Deferred Tax Liabilities, Other	0	0
Deferred Tax Liabilities	1,332	1,399
Deferred Tax Assets, Tax Credit Carryforwards, General Business	12	14
Deferred Tax Assets, Net Operating Loss	65	34
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Other	38	48
Deferred Tax Assets, Tax Deferred Expense, Compensation and Benefits, Postretirement Benefits	126	370
Deferred Tax Assets, Other	11	9
Deferred Tax Assets, State Income Taxes	10	18
Deferred Tax Assets, Tax Deferred Expense, Reserves and Accruals, Loss Reserves	27	21
Deferred Tax Assets, Hedging Transactions	5	7
Deferred Tax Assets, Net	294	521
Net deferred income tax liability	1,038	878
Deferred Tax (Assets) Liabilities, Current, Net	45	-3
Deferred Tax (Assets) Liabilities, Noncurrent, Net	$993	$881

INCOME_TAXES_3_Details

INCOME TAXES 3 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Tax Expense (Benefit), Continuing Operations [Line Items]	'	'	'
Current Federal Tax Expense (Benefit)	($70)	($36)	$76
Current State and Local Tax Expense (Benefit)	-5	-6	-3
Current Foreign Tax Expense (Benefit)	107	144	149
Current Income Tax Expense (Benefit)	32	102	222
Deferred Federal Income Tax Expense (Benefit)	275	-63	176
Deferred State and Local Income Tax Expense (Benefit)	15	3	43
Deferred Foreign Income Tax Expense (Benefit)	48	20	-45
Deferred Income Tax Expense (Benefit)	338	-40	174
Investment Tax Credit	-4	-3	-2
Income tax expense (benefit)	366	59	394
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Income Tax Expense (Benefit), Continuing Operations [Line Items]	'	'	'
Current Federal Tax Expense (Benefit)	9	-109	-59
Current State and Local Tax Expense (Benefit)	11	14	6
Current Income Tax Expense (Benefit)	20	-95	-53
Deferred Federal Income Tax Expense (Benefit)	149	255	253
Deferred State and Local Income Tax Expense (Benefit)	24	30	36
Deferred Income Tax Expense (Benefit)	173	285	289
Investment Tax Credit	-2	0	1
Income tax expense (benefit)	191	190	237
Southern California Gas Company [Member]	'	'	'
Income Tax Expense (Benefit), Continuing Operations [Line Items]	'	'	'
Current Federal Tax Expense (Benefit)	4	-73	-6
Current State and Local Tax Expense (Benefit)	-5	24	19
Current Income Tax Expense (Benefit)	-1	-49	13
Deferred Federal Income Tax Expense (Benefit)	103	136	128
Deferred State and Local Income Tax Expense (Benefit)	16	-6	5
Deferred Income Tax Expense (Benefit)	119	130	133
Investment Tax Credit	-2	-2	-3
Income tax expense (benefit)	$116	$79	$143

INCOME_TAXES_4_Details

INCOME TAXES 4 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Deferred Tax Asset Valuation Allowance, Variable Interest Entities [Member]	'	'
Valuation Allowance [Line Items]	'	'
Valuation Allowance, Amount	$60	$108
Deferred Tax Asset Valuation Allowance, Foreign Net Operating Losses [Member]	'	'
Valuation Allowance [Line Items]	'	'
Valuation Allowance, Amount	12	20
Deferred Tax Asset Valuation Allowance, Federal State And Local Net Operating Losses [Member]	'	'
Valuation Allowance [Line Items]	'	'
Valuation Allowance, Amount	84	100
Deferred Tax Asset Valuation Allowance, Other Future US State Temporary Differences Deductions [Member]	'	'
Valuation Allowance [Line Items]	'	'
Valuation Allowance, Amount	'	8
Deferred Tax Asset Valuation Allowance, Expected To Be Released State Of Louisiana [Member] | Maximum [Member]	'	'
Valuation Allowance [Line Items]	'	'
Valuation Allowance, Amount	25	'
Deferred Tax Asset Valuation Allowance, Expected To Be Released State Of Louisiana [Member] | Minimum [Member]	'	'
Valuation Allowance [Line Items]	'	'
Valuation Allowance, Amount	$20	'

INCOME_TAXES_5_Details

INCOME TAXES 5 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net Operating Loss Carryforwards [Line Items]	'	'	'
Remeasurement of equity method investments	$0	$0	($277)
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards, Total	1,200	'	'
Prior Period [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards, Set To Expire	24	'	'
Current Period [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards, Set To Expire	1,200	'	'
Unused Domestic NOL Expiring 2032 [Member] | Southern California Gas Company [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards	172	'	'
Net Operating Loss Carryforward Foreign [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards	61	'	'
Net Operating Loss Carryforward NOLs Subject To Recapture Between 2014 and 2018 Deductions [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards	165	'	'
Net Operating Loss Carryforward NOLs Unused U.S. State NOLs Expiring Between 2014 And 2032 [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards, Total	2,900	'	'
Net Operating Loss Unused U.S. Federal Consolidated NOLs From Excess Tax Deductions Related To Employee Stock Expense [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards	200	'	'
Unused NOL Expiring, Starting In 2031 [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards	5,100	'	'
Mexico [Member]	'	'	'
Net Operating Loss Carryforwards [Line Items]	'	'	'
Net Operating Loss Carryforwards	$182	'	'

INCOME_TAXES_6_Details

INCOME TAXES 6 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Unrecognized Tax Benefits [Line Items]	'	'	'
Unrecognized Tax Benefits, Balance as of January 1	$82	$72	$97
Unrecognized Tax Benefits, Increases Resulting from Prior Period Tax Positions	26	2	7
Unrecognized Tax Benefits, Decreases Resulting from Prior Period Tax Positions	-24	-1	-26
Unrecognized Tax Benefits, Increases Resulting from Current Period Tax Positions	7	10	3
Unrecognized Tax Benefits, Decreases Resulting from Settlements with Taxing Authorities	-1	-1	-9
Unrecognized Tax Benefits, Balance as of December 31	90	82	72
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	-86	-81	-72
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	19	16	7
Unrecognized Tax Benefits, Interest on Income Taxes Expense	1	0	-3
Unrecognized Tax Benefits, Income Tax Penalties Expense	0	0	-1
Unrecognized Tax Benefits Interest On Income Taxes Accrued	4	3	'
Unrecognized Tax Benefits Income Tax Penalties Accrued	3	3	'
Accumulated undistributed earnings of non-U.S. subsidiaries	3,300	'	'
Unrecognized Deferred Tax Liability Related to basis difference and consisting of cumulative undistributed earnings	3,300	'	'
Deferred Income Tax to be recorded if we no longer intend to reinvest undistributed earnings	3,300	'	'
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Unrecognized Tax Benefits [Line Items]	'	'	'
Unrecognized Tax Benefits, Balance as of January 1	12	7	5
Unrecognized Tax Benefits, Increases Resulting from Prior Period Tax Positions	7	1	0
Unrecognized Tax Benefits, Decreases Resulting from Prior Period Tax Positions	-4	0	0
Unrecognized Tax Benefits, Increases Resulting from Current Period Tax Positions	2	4	2
Unrecognized Tax Benefits, Balance as of December 31	17	12	7
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	-14	-12	-7
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	11	12	7
Unrecognized Tax Benefits, Interest on Income Taxes Expense	0	0	0
Unrecognized Tax Benefits Interest On Income Taxes Accrued	1	1	'
Southern California Gas Company [Member]	'	'	'
Unrecognized Tax Benefits [Line Items]	'	'	'
Unrecognized Tax Benefits, Balance as of January 1	5	0	8
Unrecognized Tax Benefits, Increases Resulting from Prior Period Tax Positions	4	0	2
Unrecognized Tax Benefits, Increases Resulting from Current Period Tax Positions	5	-5	0
Unrecognized Tax Benefits, Decreases Resulting from Settlements with Taxing Authorities	-1	0	-10
Unrecognized Tax Benefits, Balance as of December 31	13	5	0
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	-13	-5	0
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	8	4	0
Unrecognized Tax Benefits, Interest on Income Taxes Expense	-1	0	-1
Unrecognized Tax Benefits Interest On Income Taxes Accrued	$0	$1	'

INCOME_TAXES_7_Details

INCOME TAXES 7 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Millions, unless otherwise specified
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]	'	'	'
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	($70)	($17)	($7)
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	-7	-7	-7
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	-63	-10	0
Potential Resolution Of Audit Issues [Member] | San Diego Gas and Electric Company and Subsidiary [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	-14	-5	0
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	($11)	($4)	$0

EMPLOYEE_BENEFIT_PLANS_Details

EMPLOYEE BENEFIT PLANS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Employee Benefit Plans (Details) [Abstract]	'	'		'		'
Dedicated Assets Supporting Supplemental Benefit Plans	'	$506		$510		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]	'	'		'		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-667		-1,456		'
San Diego Gas and Electric Company and Subsidiary [Member]	'	'		'		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]	'	'		'		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-132		-340		'
Southern California Gas Company [Member]	'	'		'		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]	'	'		'		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	0		-141		'
Pension Benefits	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	27		8		'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'		'		'
Defined Benefit Plan, Benefit Obligation, Beginning Balance	3,459	3,804		3,406		'
Defined Benefit Plan, Service Cost	'	109		90		'
Defined Benefit Plan, Interest Cost	'	148		162		'
Defined Benefit Plan, Plan Amendments	'	67		8		'
Defined Benefit Plan, Actuarial Gain (Loss)	'	-371		374		'
Defined Benefit Plan Contributions By Plan Participants	'	0		0		'
Defined Benefit Plan, Special Termination Benefits	'	0		0		'
Defined Benefit Plan, Settlements, Benefit Obligation	'	-5		-19		'
Defined Benefit Plan, Benefits Paid	'	-293		-217		'
Defined Benefit Plan, Benefit Obligation, Ending Balance	'	3,459		3,804		3,406
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	2,789	2,558		2,332		'
Defined Benefit Plan, Actual Return on Plan Assets	'	396		339		'
Defined Benefit Plan, Contributions by Employer	'	133		123		'
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets	'	0		0		'
Defined Benefit Plan, Settlements, Plan Assets	'	-5		-19		'
Defined Benefit Plan, Benefits Paid, Plan Assets	'	-293		-217		'
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	'	2,789		2,558		2,332
Defined Benefit Plan, Funded Status of Plan [Abstract]	'	'		'		'
Defined Benefit Plan, Funded Status of Plan	'	-670		-1,246		'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-670		-1,246		'
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	'	-59		-31		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-611		-1,215		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]	'	'		'		'
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax	'	-73		-96		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax	'	0		1		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax	'	-73		-95		'
Defined Benefit Plan, Accumulated Benefit Obligation	'	3,254		3,530		'
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	'	3,212		3,544		'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation	'	3,027		3,295		'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets	'	2,789		2,558		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Service Cost	'	109		90		83
Defined Benefit Plan, Interest Cost	'	148		162		168
Defined Benefit Plan, Expected Return on Plan Assets	'	-162		-155		-144
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	'	4		3		4
Defined Benefit Plan, Amortization of (Gains) Losses	'	54		47		34
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements	'	2		8		13
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits	'	0		0		0
Defined Benefit Plan, Regulatory Adjustment	'	-20		-29		43
Defined Benefit Plan, Net Periodic Benefit Cost, Total	'	135		126		201
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	'	-30		19		23
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	'	1		0		0
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax	'	-9		-9		-10
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total	'	-38		10		13
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total	'	97		136		214
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)	10	'		'		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.84%		4.04%		'
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	'	4.04%		'		'
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	'	199		'		'
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]	'	'		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	'	390		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	'	335		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	'	329		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	'	317		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	'	308		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	'	1,305		'		'
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%		9.50%		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	'		5.05%		5.14%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	9.50%		8.50%		8.50%
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	'	3.50%		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, Discount Rate	'	'		4.40%		4.40%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	3.50%		3.50%		3.50%
Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	'		1		'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'		'		'
Defined Benefit Plan, Benefit Obligation, Beginning Balance	939	1,067		981		'
Defined Benefit Plan, Service Cost	'	32		28		'
Defined Benefit Plan, Interest Cost	'	41		45		'
Defined Benefit Plan, Plan Amendments	'	0		1		'
Defined Benefit Plan, Actuarial Gain (Loss)	'	-66		87		'
Defined Benefit Plan Contributions By Plan Participants	'	0		0		'
Defined Benefit Plan, Transfers, Benefit Obligation	'	-42		0		'
Defined Benefit Plan, Special Termination Benefits	'	0		0		'
Defined Benefit Plan, Settlements, Benefit Obligation	'	-4		0		'
Defined Benefit Plan, Benefits Paid	'	-89		-75		'
Defined Benefit Plan, Benefit Obligation, Ending Balance	'	939		1,067		981
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	819	781		712		'
Defined Benefit Plan, Actual Return on Plan Assets	'	117		99		'
Defined Benefit Plan, Contributions by Employer	'	51		45		'
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets	'	0		0		'
Defined Benefit Plan, Transfers, Plan Assets	'	-37		0		'
Defined Benefit Plan, Settlements, Plan Assets	'	-4		0		'
Defined Benefit Plan, Benefits Paid, Plan Assets	'	-89		-75		'
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	'	819		781		712
Defined Benefit Plan, Funded Status of Plan [Abstract]	'	'		'		'
Defined Benefit Plan, Funded Status of Plan	'	-120		-286		'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-120		-286		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]	'	'		'		'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	-13		-5		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-107		-281		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]	'	'		'		'
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax	'	-10		-12		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax	'	1		1		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax	'	-9		-11		'
Defined Benefit Plan, Accumulated Benefit Obligation	'	923		1,041		'
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	'	899		1,025		'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation	'	886		1,003		'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets	'	819		781		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Service Cost	'	32		28		28
Defined Benefit Plan, Interest Cost	'	41		45		49
Defined Benefit Plan, Expected Return on Plan Assets	'	-52		-47		-46
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	'	2		2		1
Defined Benefit Plan, Amortization of (Gains) Losses	'	14		14		9
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements	'	1		1		1
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits	'	0		0		0
Defined Benefit Plan, Regulatory Adjustment	'	14		6		31
Defined Benefit Plan, Net Periodic Benefit Cost, Total	'	52		49		73
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	'	-2		2		1
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax	'	-1		-1		-1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total	'	-3		1		0
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total	'	49		50		73
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	'		'		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.69%		3.94%		'
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	'	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	'	72		'		'
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]	'	'		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	'	109		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	'	95		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	'	89		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	'	88		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	'	85		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	'	381		'		'
Pension Benefits | San Diego Gas and Electric Company and Subsidiary [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%		9.50%		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	'		4.80%		4.80%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	9.50%		8.50%		8.50%
Pension Benefits | San Diego Gas and Electric Company and Subsidiary [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	'	3.50%		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, Discount Rate	'	'		4.70%		4.70%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	3.50%		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	'	27		7		'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'		'		'
Defined Benefit Plan, Benefit Obligation, Beginning Balance	2,110	2,299		2,017		'
Defined Benefit Plan, Service Cost	'	67		53		'
Defined Benefit Plan, Interest Cost	'	90		99		'
Defined Benefit Plan, Plan Amendments	'	66		7		'
Defined Benefit Plan, Actuarial Gain (Loss)	'	-285		245		'
Defined Benefit Plan Contributions By Plan Participants	'	0		0		'
Defined Benefit Plan, Transfers, Benefit Obligation	'	42		0		'
Defined Benefit Plan, Special Termination Benefits	'	0		0		'
Defined Benefit Plan, Settlements, Benefit Obligation	'	0		-2		'
Defined Benefit Plan, Benefits Paid	'	-169		-120		'
Defined Benefit Plan, Benefit Obligation, Ending Balance	'	2,110		2,299		2,017
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	1,758	1,581		1,443		'
Defined Benefit Plan, Actual Return on Plan Assets	'	250		213		'
Defined Benefit Plan, Contributions by Employer	'	59		47		'
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets	'	0		0		'
Defined Benefit Plan, Transfers, Plan Assets	'	37		0		'
Defined Benefit Plan, Settlements, Plan Assets	'	0		-2		'
Defined Benefit Plan, Benefits Paid, Plan Assets	'	-169		-120		'
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	'	1,758		1,581		1,443
Defined Benefit Plan, Funded Status of Plan [Abstract]	'	'		'		'
Defined Benefit Plan, Funded Status of Plan	'	-352		-718		'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-352		-718		'
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	'	-13		-4		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-339		-714		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]	'	'		'		'
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax	'	-5		-4		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, Net Prior Service Cost (Credit), After Tax	'	1		1		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax	'	-4		-3		'
Defined Benefit Plan, Accumulated Benefit Obligation	'	1,944		2,080		'
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	'	2,085		2,275		'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation	'	1,920		2,057		'
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets	'	1,758		1,581		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Service Cost	'	67		53		46
Defined Benefit Plan, Interest Cost	'	90		99		99
Defined Benefit Plan, Expected Return on Plan Assets	'	-98		-96		-85
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	'	2		2		2
Defined Benefit Plan, Amortization of (Gains) Losses	'	31		23		17
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Settlements	'	0		1		1
Defined Benefit Plan, Recognized Net (Gain) Loss Due to Special Termination Benefits	'	0		0		0
Defined Benefit Plan, Regulatory Adjustment	'	-34		-36		12
Defined Benefit Plan, Net Periodic Benefit Cost, Total	'	58		46		92
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	'	3		-4		2
Other Comprehensive Income, Reclassification of Defined Benefit Plan's Net Gain (Loss) Recognized in Net Periodic Benefit Cost, before Tax	'	-1		-1		-1
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total	'	2		-5		1
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total	'	60		41		93
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	'		'		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.94%		4.10%		'
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	'	4.10%		'		'
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	'	85		'		'
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]	'	'		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	'	234		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	'	202		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	'	199		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	'	194		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	'	188		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	'	772		'		'
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%		9.50%		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	'		5.05%		5.05%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	9.50%		8.50%		8.50%
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	'	3.50%		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, Discount Rate	'	'		4.70%		4.70%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	3.50%		3.50%		3.50%
Cost of Living Adjustment [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	40		'		'
Cost of Living Adjustment [Member] | Southern California Gas Company [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	39		'		'
Other Postretirement Benefits	'	'		'		'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'		'		'
Defined Benefit Plan, Benefit Obligation, Beginning Balance	'	1,115		1,160		'
Defined Benefit Plan, Service Cost	'	28		25		'
Defined Benefit Plan, Interest Cost	'	44		52		'
Defined Benefit Plan, Plan Amendments	'	-3		-56		'
Defined Benefit Plan, Actuarial Gain (Loss)	'	-177		-25		'
Defined Benefit Plan Contributions By Plan Participants	'	16		15		'
Defined Benefit Plan, Special Termination Benefits	'	5		0		'
Defined Benefit Plan, Settlements, Benefit Obligation	'	0		0		'
Defined Benefit Plan, Benefits Paid	'	-55		-56		'
Defined Benefit Plan, Benefit Obligation, Ending Balance	'	973		1,115		1,160
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	'	873		778		'
Defined Benefit Plan, Actual Return on Plan Assets	'	151		97		'
Defined Benefit Plan, Contributions by Employer	'	27		39		'
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets	'	16		15		'
Defined Benefit Plan, Settlements, Plan Assets	'	0		0		'
Defined Benefit Plan, Benefits Paid, Plan Assets	'	-55		-56		'
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	'	1,012		873		778
Defined Benefit Plan, Funded Status of Plan [Abstract]	'	'		'		'
Defined Benefit Plan, Funded Status of Plan	'	39		-242		'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	39		-242		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]	'	'		'		'
Other Postretirement Defined Benefit Plans, Asset Noncurrent	'	-95		0		'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	0		-1		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	-56		-241		'
Defined Benefit Plan, Accumulated Other Comprehensive Income, After Tax [Abstract]	'	'		'		'
Defined Benefit Plan, Accumulated Other Comprehensive Income Net Gains (Losses), After Tax	'	0		-6		'
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	'	0		-6		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Service Cost	'	28		25		31
Defined Benefit Plan, Interest Cost	'	44		52		65
Defined Benefit Plan, Expected Return on Plan Assets	'	-58		-53		-48
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	'	-4		-4		0
Defined Benefit Plan, Amortization of (Gains) Losses	'	7		12		17
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	'	5		0		0
Defined Benefit Plan, Regulatory Adjustment	'	6		7		7
Defined Benefit Plan, Net Periodic Benefit Cost, Total	'	28		39		72
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	'	-8		-6		7
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	'	-1		0		0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Adjustment, before Tax, Total	'	-9		-6		7
Defined Benefit Plan, Net Periodic Benefit Cost And Other Comprehensive Income, Total	'	19		33		79
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.95%		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%		'		'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	'	6.96%		6.96%		6.25%
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]	'	'		'		'
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	'	'2020	[1]	'2020		'
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	'	8		'		'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	'	-6		'		'
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	'	100		'		'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	'	-62		'		'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	'	12		'		'
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]	'	'		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	'	47		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	'	52		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	'	55		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	'	60		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	'	64		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	'	346		'		'
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%		9.50%		'
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate	'	'		5.15%		5.15%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	9.50%		9.50%		9.50%
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]	'	'		'		'
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	'	8.25%	[2]	10.00%	[3]	'
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	'	5.00%	[4]	5.00%	[5]	'
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	'	3.50%		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, Discount Rate	'	'		4.10%		4.10%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase	'	3.50%		3.50%		3.50%
Defined Benefit Plan, Assumed Health Care Cost Trend Rates [Abstract]	'	'		'		'
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	'	5.50%	[2]	8.25%	[3]	'
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	'	4.50%	[4]	4.75%	[5]	'
Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'	'		'		'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'		'		'
Defined Benefit Plan, Benefit Obligation, Beginning Balance	'	185		182		'
Defined Benefit Plan, Service Cost	'	8		7		'
Defined Benefit Plan, Interest Cost	'	8		9		'
Defined Benefit Plan, Plan Amendments	'	0		-2		'
Defined Benefit Plan, Actuarial Gain (Loss)	'	-19		-5		'
Defined Benefit Plan Contributions By Plan Participants	'	6		6		'
Defined Benefit Plan, Transfers, Benefit Obligation	'	-7		0		'
Defined Benefit Plan, Special Termination Benefits	'	2		0		'
Defined Benefit Plan, Settlements, Benefit Obligation	'	0		0		'
Defined Benefit Plan, Benefits Paid	'	-12		-12		'
Defined Benefit Plan, Benefit Obligation, Ending Balance	'	171		185		182
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	'	126		106		'
Defined Benefit Plan, Actual Return on Plan Assets	'	18		13		'
Defined Benefit Plan, Contributions by Employer	'	14		13		'
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets	'	6		6		'
Defined Benefit Plan, Transfers, Plan Assets	'	-6		0		'
Defined Benefit Plan, Settlements, Plan Assets	'	0		0		'
Defined Benefit Plan, Benefits Paid, Plan Assets	'	-12		-12		'
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	'	146		126		106
Defined Benefit Plan, Funded Status of Plan [Abstract]	'	'		'		'
Defined Benefit Plan, Funded Status of Plan	'	-25		-59		'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	-25		-59		'
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	'	-25		-59		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Service Cost	'	8		7		7
Defined Benefit Plan, Interest Cost	'	8		9		10
Defined Benefit Plan, Expected Return on Plan Assets	'	-8		-8		-8
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	'	4		4		4
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	'	2		0		0
Defined Benefit Plan, Regulatory Adjustment	'	0		1		2
Defined Benefit Plan, Net Periodic Benefit Cost, Total	'	14		13		15
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	'	14		13		15
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	5.00%		4.10%		'
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	'	4.10%		5.05%		5.05%
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Return on Assets	'	6.81%		6.81%		6.69%
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		'		'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	'	-1		'		'
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	'	8		'		'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	'	-6		'		'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	'	9		'		'
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]	'	'		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	'	8		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	'	9		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	'	10		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	'	11		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	'	12		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	'	65		'		'
Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [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%		9.50%		'
Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [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	'	3.50%		3.50%		'
Other Postretirement Benefits | Southern California Gas Company [Member]	'	'		'		'
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward]	'	'		'		'
Defined Benefit Plan, Benefit Obligation, Beginning Balance	'	873		921		'
Defined Benefit Plan, Service Cost	'	17		16		'
Defined Benefit Plan, Interest Cost	'	34		41		'
Defined Benefit Plan, Plan Amendments	'	1		-54		'
Defined Benefit Plan, Actuarial Gain (Loss)	'	-151		-19		'
Defined Benefit Plan Contributions By Plan Participants	'	10		9		'
Defined Benefit Plan, Transfers, Benefit Obligation	'	7		0		'
Defined Benefit Plan, Special Termination Benefits	'	2		0		'
Defined Benefit Plan, Settlements, Benefit Obligation	'	0		0		'
Defined Benefit Plan, Benefits Paid	'	-40		-41		'
Defined Benefit Plan, Benefit Obligation, Ending Balance	'	753		873		921
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]	'	'		'		'
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	'	732		658		'
Defined Benefit Plan, Actual Return on Plan Assets	'	131		83		'
Defined Benefit Plan, Contributions by Employer	'	9		23		'
Defined Benefit Plan, Contributions By Plan Participants, Plan Assets	'	10		9		'
Defined Benefit Plan, Transfers, Plan Assets	'	6		0		'
Defined Benefit Plan, Settlements, Plan Assets	'	0		0		'
Defined Benefit Plan, Benefits Paid, Plan Assets	'	-40		-41		'
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	'	848		732		658
Defined Benefit Plan, Funded Status of Plan [Abstract]	'	'		'		'
Defined Benefit Plan, Funded Status of Plan	'	95		-141		'
Defined Benefit Plan, Amounts Recognized in Balance Sheet	'	95		-141		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities [Abstract]	'	'		'		'
Other Postretirement Defined Benefit Plans, Asset Noncurrent	'	-95		0		'
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities	'	0		0		'
Pension and Other Postretirement Defined Benefit Plans, Liabilities, Noncurrent	'	0		-141		'
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]	'	'		'		'
Defined Benefit Plan, Service Cost	'	17		16		22
Defined Benefit Plan, Interest Cost	'	34		41		53
Defined Benefit Plan, Expected Return on Plan Assets	'	-48		-44		-40
Defined Benefit Plan, Amortization of Prior Service Cost (Credit)	'	-8		-7		-4
Defined Benefit Plan, Amortization of (Gains) Losses	'	6		11		17
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	'	2		0		0
Defined Benefit Plan, Regulatory Adjustment	'	6		5		5
Defined Benefit Plan, Net Periodic Benefit Cost, Total	'	9		22		53
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	'	9		22		53
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]	'	'		'		'
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	'	4.95%		4.10%		'
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	'	4.10%		5.15%		5.15%
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	'	6		'		'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components	'	-5		'		'
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation	'	90		'		'
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation	'	-54		'		'
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	'	0		'		'
Defined Benefit Plan, Estimated Future Benefit Payments [Abstract]	'	'		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Next Twelve Months	'	36		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Two	'	40		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Three	'	43		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Four	'	46		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Year Five	'	49		'		'
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter	'	261		'		'
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%		9.50%		'
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	'	9.50%		9.50%		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	'	3.50%		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	'	3.50%		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	'	'		3		'
Defined Benefit Plan, Effect of Special Termination Benefit on Accumulated Benefit Obligation	'	5		'		'
Life Insurance, Health Reimbursement Arrangement Benefits [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	'		2		'
Defined Benefit Plan, Effect of Special Termination Benefit on Accumulated Benefit Obligation	'	2		'		'
Life Insurance, Health Reimbursement Arrangement Benefits [Member] | Southern California Gas Company [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	'		1		'
Defined Benefit Plan, Effect of Special Termination Benefit on Accumulated Benefit Obligation	'	2		'		'
Executive Life Plan [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	4		'		'
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	'	7.50%	[2]	8.00%	[3]	'
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	'	5.00%	[4]	5.00%	[5]	'
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	'	'2019	[1]	'		'
Dental Benefits [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	1		'		'
Dental Benefits [Member] | Southern California Gas Company [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	1		'		'
Medical Benefits [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	'		53		'
Medical Benefits [Member] | Southern California Gas Company [Member]	'	'		'		'
Defined Benefit Plan, Plan Amendment [Abstract]	'	'		'		'
Defined Benefit Plan, Effect of Plan Amendment on Accumulated Benefit Obligation	'	'		$53		'
[1]	2019 for Mobile Gas plan and 2020 for all other plans.
[2]	8.25% for pre-65 retirees and 5.50% for retirees aged 65 years and older. For Mobile Gas, the health care cost trend rate is assumed to be 7.50%.
[3]	10.00% for pre-65 retirees and 8.25% for retirees aged 65 years and older. For Mobile Gas, the health care cost trend rate is assumed to be 8.00%.
[4]	5.00% for pre-65 retirees and 4.50% for retirees aged 65 years and older. For Mobile Gas, the rate to which the cost trend rate is assumed to decline is 5.00%.
[5]	5.00% for pre-65 retirees and 4.75% for retirees aged 65 years and older. For Mobile Gas, the rate to which the cost trend rate is assumed to decline is 5.00%.

EMPLOYEE_BENEFIT_PLANS_PART_2_

EMPLOYEE BENEFIT PLANS PART 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Pension Benefits	'	'
Private Equity Funds [Line Items]	'	'
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	$21	$24
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	3	'
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	-2	6
Private Equity Funds, Investment Plan Assets, Sales	-1	-9
Private Equity Funds, Investment Plan Assets, Balance at End of Period	21	21
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	1.00%	1.00%
Other Postretirement Benefits	'	'
Private Equity Funds [Line Items]	'	'
Private Equity Funds, Investment Plan Assets, Balance at Beginning of Period	'	4
Private Equity Funds, Investment Plan Assets, Sales	'	-1
Private Equity Funds, Investment Plan Assets, Balance at End of Period	3	3
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	6	7
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	1	'
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	-1	2
Private Equity Funds, Investment Plan Assets, Sales	0	-3
Private Equity Funds, Investment Plan Assets, Balance at End of Period	6	6
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	1.00%	1.00%
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	'	1
Private Equity Funds, Investment Plan Assets, Sales	'	0
Private Equity Funds, Investment Plan Assets, Balance at End of Period	1	1
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	1.00%	1.00%
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	13	15
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	2	'
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	-1	4
Private Equity Funds, Investment Plan Assets, Sales	-1	-6
Private Equity Funds, Investment Plan Assets, Balance at End of Period	13	13
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	1.00%	1.00%
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	'	3
Private Equity Funds, Investment Plan Assets, Sales	'	-1
Private Equity Funds, Investment Plan Assets, Balance at End of Period	2	2
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	2	2
Private Equity Funds, Investment Plan Assets, Realized Gains (Losses)	0	'
Private Equity Funds, Investment Plan Assets, Unrealized Gains (Losses)	0	0
Private Equity Funds, Investment Plan Assets, Sales	0	0
Private Equity Funds, Investment Plan Assets, Balance at End of Period	2	2
Private Equity Funds, Investment Plan Assets, Percentage Of Total Investment Assets	1.00%	1.00%
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
Private Equity Funds, Investment Plan Assets, Sales	'	0
Private Equity Funds, Investment Plan Assets, Balance at End of Period	$0	$0

EMPLOYEE_BENEFIT_PLANS_PART_3_

EMPLOYEE BENEFIT PLANS PART 3 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Chilquinta Energia Profit Sharing [Member]	'	'	'
Profit Sharing Plans [Line Items]	'	'	'
Recorded Annual Profit Sharing Expense	$4	$6	$5
Luz del Sur Profit Sharing [Member]	'	'	'
Profit Sharing Plans [Line Items]	'	'	'
Recorded Annual Profit Sharing Expense	$9	$10	$9

EMPLOYEE_BENEFIT_PLANS_PART_4_

EMPLOYEE BENEFIT PLANS PART 4 (Details) (USD $)	12 Months Ended			24 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012
Savings Plan [Line Items]	'	'	'	'
Defined Contribution Plan Employer Matching Amount	$35	$34	$32	'
Savings Plan, Market Value Of Employer Stock Held By Plan	1,300	1,100	'	1,100
Employee Stock Ownership Plan (ESOP), Shares in ESOP	0	0	153,625	0
Employee Stock Ownership Plan (ESOP), Deferred Shares, Fair Value	'	'	8	'
ESOP debt paid down in 2012 and 2011	'	'	'	34
Dividends used for ESOP debt service in 2011	'	'	1	'
Shares of common stock released from ESOP Trust in 2012 and 2011	'	'	'	504,440
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'	'
Savings Plan [Line Items]	'	'	'	'
Defined Contribution Plan Employer Matching Amount	14	16	14	'
Southern California Gas Company [Member]	'	'	'	'
Savings Plan [Line Items]	'	'	'	'
Defined Contribution Plan Employer Matching Amount	$17	$15	$14	'

EMPLOYEE_BENEFIT_PLANS_PART_5_

EMPLOYEE BENEFIT PLANS PART 5 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets	$5	[1]	$4	[2]
Transfers Payable, Excluded From Fair Value of Defined Benefit Plan Assets	37	[1]	'
Pension Benefits | Southern California Gas Company [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets	11		9
Transfers Receivable, Excluded From Fair Value of Defined Benefit Plan Assets	37		'
Other Postretirement Benefits	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets	4		3
Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [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		'
Transfers Payable, Excluded From Fair Value of Defined Benefit Plan Assets	6		'
Other Postretirement Benefits | Southern California Gas Company [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets	3		3
Transfers Receivable, Excluded From Fair Value of Defined Benefit Plan Assets	6		'
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, Excluding Cash And Cash Equivalents	220		316
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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	220		316
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, Excluding Cash And Cash Equivalents	0		0
Equity Securities, Foreign Preferred [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2		2
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, Excluding Cash And Cash Equivalents	4		4
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, Excluding Cash And Cash Equivalents	1		'
Equity Securities, Foreign Preferred [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, Excluding Cash And Cash Equivalents	'		1
Equity Securities, Foreign Preferred [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2		2
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, Excluding Cash And Cash Equivalents	4		4
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, Excluding Cash And Cash Equivalents	1		'
Equity Securities, Foreign Preferred [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, Excluding Cash And Cash Equivalents	'		1
Equity Securities, Foreign Preferred [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
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, Excluding Cash And Cash Equivalents	0		'
Equity Securities, Foreign Preferred [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, Excluding Cash And Cash Equivalents	'		0
Equity Securities, Foreign Preferred [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		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, Excluding Cash And Cash Equivalents	0		'
Equity Securities, Foreign Preferred [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, Excluding Cash And Cash Equivalents	'		0
Equity Securities, Registered Investment Company [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	44		6
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, Excluding Cash And Cash Equivalents	89		12
Equity Securities, Registered Investment Company [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	11		2
Equity Securities, Registered Investment Company [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	43		32
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, Excluding Cash And Cash Equivalents	43		11
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, Excluding Cash And Cash Equivalents	4		4
Equity Securities, Registered Investment Company [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	44		6
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, Excluding Cash And Cash Equivalents	89		12
Equity Securities, Registered Investment Company [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	11		2
Equity Securities, Registered Investment Company [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	43		32
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, Excluding Cash And Cash Equivalents	43		11
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, Excluding Cash And Cash Equivalents	4		3
Equity Securities, Registered Investment Company [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Equity Securities, Registered Investment Company [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		1
Equity Securities, Registered Investment Company [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Equity Securities, Registered Investment Company [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
US Treasury Securities [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2		'
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, Excluding Cash And Cash Equivalents	4		'
US Treasury Securities [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1		'
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, Excluding Cash And Cash Equivalents	1		'
US Treasury Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2		'
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, Excluding Cash And Cash Equivalents	4		'
US Treasury Securities [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1		'
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, Excluding Cash And Cash Equivalents	1		'
US Treasury Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		'
US Treasury Securities [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		'
US Treasury Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		'
US Treasury Securities [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		'
US Government Agencies Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	11		12
US Government Agencies 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, Excluding Cash And Cash Equivalents	21		24
US Government Agencies Debt Securities [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3		3
US Government Agencies Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3	[3]	3	[3]
US Government Agencies 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, Excluding Cash And Cash Equivalents	4		5
US Government Agencies Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
US Government Agencies 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, Excluding Cash And Cash Equivalents	0		0
US Government Agencies Debt Securities [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
US Government Agencies Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[3]	0	[3]
US Government Agencies 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, Excluding Cash And Cash Equivalents	0		0
US Government Agencies Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	11		12
US Government Agencies 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, Excluding Cash And Cash Equivalents	21		24
US Government Agencies Debt Securities [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3		3
US Government Agencies Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3	[3]	3	[3]
US Government Agencies 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, Excluding Cash And Cash Equivalents	4		5
US Government Agencies Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
US Government Agencies 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, Excluding Cash And Cash Equivalents	0		0
US Government Agencies Debt Securities [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
US Government Agencies Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[3]	0	[3]
US Government Agencies 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, Excluding Cash And Cash Equivalents	0		0
Fixed Income, Registered Investment Company [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	12		12
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, Excluding Cash And Cash Equivalents	3		1
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, Excluding Cash And Cash Equivalents	1		'
Fixed Income, Registered Investment Company [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		'
Fixed Income, Registered Investment Company [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	12		12
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, Excluding Cash And Cash Equivalents	3		1
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, Excluding Cash And Cash Equivalents	1		'
Fixed Income, Registered Investment Company [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		'
Domestic Partnership Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1	[4]	'
Domestic Partnership 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, Excluding Cash And Cash Equivalents	2	[4]	'
Domestic Partnership Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	'
Domestic Partnership 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, Excluding Cash And Cash Equivalents	0	[4]	'
Domestic Partnership Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1	[4]	'
Domestic Partnership 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, Excluding Cash And Cash Equivalents	2	[4]	'
Domestic Partnership Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	'
Domestic Partnership 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, Excluding Cash And Cash Equivalents	0	[4]	'
Foreign Government Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	25		22
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, Excluding Cash And Cash Equivalents	51		44
Foreign Government Debt Securities [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	7		5
Foreign Government Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3		2
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, Excluding Cash And Cash Equivalents	10		8
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, Excluding Cash And Cash Equivalents	1		1
Foreign Government Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Foreign Government Debt Securities [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Foreign Government Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Foreign Government Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	25		22
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, Excluding Cash And Cash Equivalents	51		44
Foreign Government Debt Securities [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	7		5
Foreign Government Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3		2
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, Excluding Cash And Cash Equivalents	10		8
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, Excluding Cash And Cash Equivalents	1		1
Foreign Government Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Foreign Government Debt Securities [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Foreign Government Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Domestic Corporate Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	152	[4]	147	[4]
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, Excluding Cash And Cash Equivalents	306	[4]	297	[4]
Domestic Corporate Debt Securities [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	38	[4]	37	[4]
Domestic Corporate Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	18	[4]	15	[4]
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, Excluding Cash And Cash Equivalents	60	[4]	57	[4]
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, Excluding Cash And Cash Equivalents	3	[4]	2	[4]
Domestic Corporate Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
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, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
Domestic Corporate Debt Securities [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
Domestic Corporate Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
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, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
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, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
Domestic Corporate Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	152	[4]	147	[4]
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, Excluding Cash And Cash Equivalents	306	[4]	297	[4]
Domestic Corporate Debt Securities [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	38	[4]	37	[4]
Domestic Corporate Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	18	[4]	15	[4]
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, Excluding Cash And Cash Equivalents	60	[4]	57	[4]
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, Excluding Cash And Cash Equivalents	3	[4]	2	[4]
Domestic Corporate Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
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, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
Domestic Corporate Debt Securities [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
Domestic Corporate Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
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, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
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, Excluding Cash And Cash Equivalents	0	[4]	0	[4]
Foreign Corporate Debt Securities [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	55		52
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, Excluding Cash And Cash Equivalents	110		105
Foreign Corporate Debt Securities [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	13		13
Foreign Corporate Debt Securities [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	6		5
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, Excluding Cash And Cash Equivalents	22		20
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, Excluding Cash And Cash Equivalents	1		1
Foreign Corporate Debt Securities [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Foreign Corporate Debt Securities [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Foreign Corporate Debt Securities [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Foreign Corporate Debt Securities [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	55		52
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, Excluding Cash And Cash Equivalents	110		105
Foreign Corporate Debt Securities [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	13		13
Foreign Corporate Debt Securities [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	6		5
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, Excluding Cash And Cash Equivalents	22		20
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, Excluding Cash And Cash Equivalents	1		1
Foreign Corporate Debt Securities [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Foreign Corporate Debt Securities [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Foreign Corporate Debt Securities [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Debt Securities, Common Collective Trusts [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	25	[5]	8	[5]
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, Excluding Cash And Cash Equivalents	50	[5]	15	[5]
Debt Securities, Common Collective Trusts [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	5	[5]	2	[5]
Debt Securities, Common Collective Trusts [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3	[6]	1	[6]
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, Excluding Cash And Cash Equivalents	262	[6]	107	[6]
Debt Securities, Common Collective Trusts [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[5]	0	[5]
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, Excluding Cash And Cash Equivalents	0	[5]	0	[5]
Debt Securities, Common Collective Trusts [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[5]	0	[5]
Debt Securities, Common Collective Trusts [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[6]	0	[6]
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, Excluding Cash And Cash Equivalents	0	[6]	0	[6]
Debt Securities, Common Collective Trusts [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	25	[5]	8	[5]
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, Excluding Cash And Cash Equivalents	50	[5]	15	[5]
Debt Securities, Common Collective Trusts [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	5	[5]	2	[5]
Debt Securities, Common Collective Trusts [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3	[6]	1	[6]
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, Excluding Cash And Cash Equivalents	262	[6]	107	[6]
Debt Securities, Common Collective Trusts [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[5]	0	[5]
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, Excluding Cash And Cash Equivalents	0	[5]	0	[5]
Debt Securities, Common Collective Trusts [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[5]	0	[5]
Debt Securities, Common Collective Trusts [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[6]	0	[6]
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, Excluding Cash And Cash Equivalents	0	[6]	0	[6]
Private Equity Funds [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	6	[7]	6	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	13	[7]	13	[7]
Private Equity Funds [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2	[7]	2	[7]
Private Equity Funds [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1	[7]	1	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	2	[7]	2	[7]
Private Equity Funds [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	0	[7]	0	[7]
Private Equity Funds [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	6	[7]	6	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	13	[7]	13	[7]
Private Equity Funds [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2	[7]	2	[7]
Private Equity Funds [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1	[7]	1	[7]
Private Equity Funds [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, Excluding Cash And Cash Equivalents	2	[7]	2	[7]
Total Investment Plan Assets [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	851	[1]	777	[2]
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, Excluding Cash And Cash Equivalents	1,710	[8]	1,572	[9]
Total Investment Plan Assets [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	151	[10]	126
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, Excluding Cash And Cash Equivalents	839	[11]	729	[12]
Total Investment Plan Assets [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	576	[1]	530	[2]
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, Excluding Cash And Cash Equivalents	1,157	[8]	1,074	[9]
Total Investment Plan Assets [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	105	[10]	87
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, Excluding Cash And Cash Equivalents	256	[11]	213	[12]
Total Investment Plan Assets [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	269	[1]	241	[2]
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, Excluding Cash And Cash Equivalents	540	[8]	485	[9]
Total Investment Plan Assets [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	45	[10]	38
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, Excluding Cash And Cash Equivalents	581	[11]	514	[12]
Total Investment Plan Assets [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	6	[1]	6	[2]
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, Excluding Cash And Cash Equivalents	13	[8]	13	[9]
Total Investment Plan Assets [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1	[10]	1
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, Excluding Cash And Cash Equivalents	2	[11]	2	[12]
Total Other Sempra Energy Investment Plan Assets [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	211	[13]	195	[13]
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets	1		1
Total Other Sempra Energy 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, Excluding Cash And Cash Equivalents	18		15
Total Other Sempra Energy Investment Plan Assets [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	143	[13]	133	[13]
Total Other Sempra Energy 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, Excluding Cash And Cash Equivalents	12		10
Total Other Sempra Energy Investment Plan Assets [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	66	[13]	60	[13]
Total Other Sempra Energy 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, Excluding Cash And Cash Equivalents	6		5
Total Other Sempra Energy Investment Plan Assets [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2	[13]	2	[13]
Total Other Sempra Energy 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, Excluding Cash And Cash Equivalents	0		0
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Total SE Consolidated [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	2,772	[14]	2,544	[14]
Cash And Cash Equivalents, Excluded From Fair Value of Defined Benefit Plan Assets	17		14
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Sempra Energy Other Postretirement Benefit Plans [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1,008	[15]	870	[12]
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Level 1 | Total SE Consolidated [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	1,876	[14]	1,737	[14]
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Level 1 | Sempra Energy Other Postretirement Benefit Plans [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	373	[15]	310	[12]
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Level 2 | Total SE Consolidated [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	875	[14]	786	[14]
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Level 2 | Sempra Energy Other Postretirement Benefit Plans [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	632	[15]	557	[12]
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Level 3 | Total SE Consolidated [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	21	[14]	21	[14]
Total Sempra Energy Consolidated Investment Plan Assets [Member] | Level 3 | Sempra Energy Other Postretirement Benefit Plans [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	3	[15]	3	[12]
Equity Securities Domestic [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	317	[16]	307	[16]
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, Excluding Cash And Cash Equivalents	637	[16]	622	[16]
Equity Securities Domestic [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	79	[16]	77	[16]
Equity Securities Domestic [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	37	[16]	32	[16]
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, Excluding Cash And Cash Equivalents	128	[16]	118	[16]
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, Excluding Cash And Cash Equivalents	4	[16]	5	[16]
Equity Securities Domestic [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	317	[16]	307	[16]
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, Excluding Cash And Cash Equivalents	637	[16]	622	[16]
Equity Securities Domestic [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	79	[16]	77	[16]
Equity Securities Domestic [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	37	[16]	32	[16]
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, Excluding Cash And Cash Equivalents	128	[16]	118	[16]
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, Excluding Cash And Cash Equivalents	4	[16]	5	[16]
Equity Securities Domestic [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
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, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
Equity Securities Domestic [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
Equity Securities Domestic [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
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, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
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, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
Equity Securities Domestic [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
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, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
Equity Securities Domestic [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
Equity Securities Domestic [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
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, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
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, Excluding Cash And Cash Equivalents	0	[16]	0	[16]
Equity Securities Foreign [Member] | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	211		215
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, Excluding Cash And Cash Equivalents	423		436
Equity Securities Foreign [Member] | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	52		54
Equity Securities Foreign [Member] | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	25		23
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, Excluding Cash And Cash Equivalents	83		84
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, Excluding Cash And Cash Equivalents	4		1
Equity Securities Foreign [Member] | Level 1 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	211		215
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, Excluding Cash And Cash Equivalents	423		436
Equity Securities Foreign [Member] | Level 1 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	52		54
Equity Securities Foreign [Member] | Level 1 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	25		23
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, Excluding Cash And Cash Equivalents	83		84
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, Excluding Cash And Cash Equivalents	4		1
Equity Securities Foreign [Member] | Level 2 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Equity Securities Foreign [Member] | Level 2 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Equity Securities Foreign [Member] | Level 2 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Equity Securities Foreign [Member] | Level 3 | Pension Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	0		0
Equity Securities Foreign [Member] | Level 3 | Total Other SE [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	0		0
Equity Securities Foreign [Member] | Level 3 | Other Postretirement Benefits | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets [Line Items]	'		'
Defined Benefit Plan, Fair Value Of Plan Assets, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	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, Excluding Cash And Cash Equivalents	$0		$0
[1]	Excludes cash and cash equivalents of $5 million and transfers payable to other plans of $37 million.
[2]	Excludes cash and cash equivalents of $4 million.
[3]	Bonds of California municipalities held in SDG&E PBOP plan trusts.
[4]	Bonds of U.S. issuers from diverse industries, primarily investment-grade.
[5]	Investments in common/collective trusts held in Sempra Energybs Pension Master Trust.
[6]	Investments in common/collective trusts held in PBOP plan VEBA trusts.
[7]	Investments in venture capital and real estate funds.
[8]	Excludes cash and cash equivalents of $11 million and transfers receivable from other plans of $37 million.
[9]	Excludes cash and cash equivalents of $9 million.
[10]	Excludes cash and cash equivalents of $1 million, all of which is held in SDG&E PBOP plan trusts, and transfers payable to other plans of $6 million.
[11]	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts, and transfers receivable from other plans of $6 million.
[12]	Excludes cash and cash equivalents of $3 million, all of which is held in SoCalGas PBOP plan trusts.
[13]	Excludes cash and cash equivalents of $1 million at each of December 31, 2013 and 2012.
[14]	Excludes cash and cash equivalents of $17 million and $14 million at December 31, 2013 and 2012, respectively.
[15]	Excludes cash and cash equivalents of $4 million, $3 million and $1 million of which is held in SoCalGas and SDG&E PBOP plan trusts, respectively.
[16]	Investments in common stock of domestic corporations.

EMPLOYEE_BENEFIT_PLANS_PART_6_

EMPLOYEE BENEFIT PLANS PART 6 (Details)	12 Months Ended
	Dec. 31, 2013
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%
Intermediate Credit [Member]	'
Defined Benefit Plan Assets Target Allocations [Line Items]	'
Defined Benefit Plan Assets Target Allocations Percentage	12.00%
Long Credit [Member]	'
Defined Benefit Plan Assets Target Allocations [Line Items]	'
Defined Benefit Plan Assets Target Allocations Percentage	14.00%
Real Assets [Member]	'
Defined Benefit Plan Assets Target Allocations [Line Items]	'
Defined Benefit Plan Assets Target Allocations Percentage	5.00%

SHAREBASED_COMPENSATION_Detail

SHARE-BASED COMPENSATION (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-Based Compensation (Details) [Abstract]	'	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	7,192,401	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	7,192,401	'	'
Restricted stock units issued by subsidary	1,014,899	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'
Allocated Share-based Compensation Expense	$38	$40	$44
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	-15	-16	-18
Employee Service Share-Based Compensation, Compensation Expense, Net Of Tax	23	24	26
Employee Service Share-Based Compensation, Compensation Expense, Net Of Tax, Per Basic Share	$0.09	$0.10	$0.11
Employee Service Share-Based Compensation, Compensation Expense, Net Of Tax, Per Diluted Share	$0.09	$0.10	$0.11
Employee Service Share-based Compensation, Allocation of Recognized Period Costs, Capitalized Amount	4	4	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	2,701,118	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price, Beginning of Period	$51.86	'	'
Exercised Stock Options	-1,237,348	'	'
Share-based Compensation Arrangements by Share-based Payment Award, Options, Exercises in Period, Weighted Average Exercise Price	$50.32	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period, Total Intrinsic Value	41	45	23
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period	-4,625	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Forfeitures and Expirations in Period, Weighted Average Exercise Price	$48.40	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Number, Ending Balance	1,459,145	2,701,118	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Exercise Price, End of Period	$53.18	$51.86	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Weighted Average Remaining Contractual Term	4	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value	53	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Number	1,459,145	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Exercise Price	$53.18	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Weighted Average Remaining Contractual Term	4	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Outstanding, Aggregate Intrinsic Value	53	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number	1,300,745	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Exercise Price	$52.86	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Weighted Average Remaining Contractual Term	3.8	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Aggregate Intrinsic Value	48	'	'
Employee Service Share-based Compensation, Cash Received from Exercise of Stock Options	62	'	'
San Diego Gas and Electric Company and Subsidiary [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	3	3	3
Southern California Gas Company [Member]	'	'	'
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items]	'	'	'
Allocated Share-based Compensation Expense	8	7	9
Employee Service Share-based Compensation, Allocation of Recognized Period Costs, Capitalized Amount	$1	$1	$1

SHAREBASED_COMPENSATION_2_Deta

SHARE-BASED COMPENSATION 2 (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Share-Based Compensation, Stock Options [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, Vested in Period, Total Fair Value	$2		$4	$7
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	19.00%		27.00%	27.00%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Risk Free Interest Rate	0.60%		0.60%	1.50%
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions, Expected Dividend Rate	3.30%		3.40%	3.00%
Share-Based Compensation, 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, Grants in Period, Weighted Average Grant Date Fair Value	'		$50.17	$43.25
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	29		'	'
Employee Service Share Based Compensation Nonvested Awards Total Compensation Cost Not Yet Recognized During The Period For Recognition	2.4		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Total Fair Value	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	24,689		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period	$56.59		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	4,617		'	'
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		$57.81	$52.96
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-11,837		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$55.49		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Ending Balance	17,469		24,689	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, End of Period	$62.43		$56.59	'
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Outstanding, Number	17,469		'	'
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	$62.43		'	'
Employee Service Share-based Compensation, Nonvested Awards, Total Compensation Cost Not yet Recognized	1		'	'
Employee Service Share Based Compensation Nonvested Awards Total Compensation Cost Not Yet Recognized During The Period For Recognition	1.5		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Total Fair Value	$1		$1	$28
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	3,400,033		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period	$42.72		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	657,168		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$57.55		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-864,100		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$36.04		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	-28,540		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$50.55		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Ending Balance	3,164,561	[1]	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, End of Period	$47.55	[1]	'	'
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Outstanding, Number	3,107,020		'	'
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	$47.45		'	'
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	135,241		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, Beginning of Period	$55.42		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period	107,718		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value	$72.71		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period	-24,751		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$61.97		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period	-2,610		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value	$56.23		'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number, Ending Balance	215,598	[1]	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value, End of Period	$63.30	[1]	'	'
Share-Based Compensation Arrangement By Share-Based Payment Award, Equity Instruments Other Than Options, Vested And Expected To Vest, Outstanding, Number	203,655		'	'
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	$63.12		'	'
[1]	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, up to an additional 50 percent of the shares represented by the units may be issued if Sempra Energy exceeds target performance conditions.

DERIVATIVE_FINANCIAL_INSTRUMEN3

DERIVATIVE FINANCIAL INSTRUMENTS (Details)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012
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)	43	[1]	25	[1]
Commodity derivative volumes, congestion revenue rights (in millions of megawatt hours)	33	[2]	30	[2]
So Cal Gas Segment [Member]	'		'
Schedule Of Commodity Derivative Volumes [Line Items]	'		'
Commodity derivative volumes, natural gas (in millions of million British thermal units)	2	[1]	0	[1]
Sempra Mexico Segment [Member]	'		'
Schedule Of Commodity Derivative Volumes [Line Items]	'		'
Commodity derivative volumes, natural gas (in millions of million British thermal units)	0	[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)	15	[1]	36	[1]
Commodity derivative volumes, electric power (in millions of megawatt hours)	1	[2]	1	[2]
[1]	Million British thermal units
[2]	Megawatt hours

DERIVATIVE_FINANCIAL_INSTRUMEN4

DERIVATIVE FINANCIAL INSTRUMENTS 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012
Cash Flow Hedges	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Notional Amount Of Interest Rate Derivatives	413	[1]	439	[1]
Cash Flow Hedges | Maximum [Member]	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Maturities of interest rate derivatives	'2028	[1]	'2028	[1]
Cash Flow Hedges | Minimum [Member]	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Maturities of interest rate derivatives	'2014	[1]	'2013	[1]
Fair Value Hedges	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Notional Amount Of Interest Rate Derivatives	300		500
Fair Value Hedges | Maximum [Member]	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Maturities of interest rate derivatives	'2016		'2016
Fair Value Hedges | Minimum [Member]	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Maturities of interest rate derivatives	'		'2013
San Diego Gas and Electric Company and Subsidiary [Member] | Cash Flow Hedges	'		'
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]	'		'
Notional Amount Of Interest Rate Derivatives	335	[1]	345	[1]
Maturities of interest rate derivatives	'2019	[1]	'2019	[1]
[1]	Includes Otay Mesa VIE. All of SDG&Ebs amounts relate to Otay Mesa VIE.

DERIVATIVE_FINANCIAL_INSTRUMEN5

DERIVATIVE FINANCIAL INSTRUMENTS 3 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fixed Price Contracts And Other Derivatives, Current Assets [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	$14	[1],[2]	$7	[1],[3]
Commodity contracts not subject to rate recovery	'		1	[1]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Interest rate and foreign exchange instruments	8	[1]	8	[1]
Commodity contracts not subject to rate recovery	47	[1]	117	[1]
Associated offsetting commodity contracts not subject to rate recovery	-43	[1]	-102	[1]
Associated cash collateral commodity contracts not subject to rate recovery	0	[1]	0	[1]
Commodity contracts subject to rate recovery	35	[1]	30	[1]
Associated cash collateral commodity contracts subject to rate recovery	'		0	[1]
Associated offsetting commodity contracts subject to rate recovery	-3	[1]	-4	[1]
Net amount presented on balance sheet	58	[1]	57	[1]
Additional margin posted for commodity contracts not subject to rate recovery	17	[1]	22	[1]
Additional margin posted for commodity contracts subject to rate recovery	31	[1]	13	[1]
Total	106	[1]	92	[1]
Fixed Price Contracts And Other Derivatives, Current Assets [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	0	[2]	0	[3]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Commodity contracts subject to rate recovery	34		28
Associated cash collateral commodity contracts subject to rate recovery	'		0
Associated offsetting commodity contracts subject to rate recovery	-3		-3
Net amount presented on balance sheet	31		25
Additional margin posted for commodity contracts not subject to rate recovery	1		1
Additional margin posted for commodity contracts subject to rate recovery	29		12
Total	61		38
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 subject to rate recovery	1	[1]	2	[1]
Associated offsetting commodity contracts subject to rate recovery	'		-1	[1]
Net amount presented on balance sheet	1	[1]	1	[1]
Additional margin posted for commodity contracts not subject to rate recovery	2	[1]	2	[1]
Additional margin posted for commodity contracts subject to rate recovery	2	[1]	1	[1]
Total	5	[1]	4	[1]
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	12	[2]	12	[3]
Commodity contracts not subject to rate recovery	'		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Interest rate and foreign exchange instruments	22		40
Commodity contracts not subject to rate recovery	7		15
Associated offsetting commodity contracts not subject to rate recovery	-5		-12
Associated cash collateral commodity contracts not subject to rate recovery	0		0
Commodity contracts subject to rate recovery	72		35
Associated cash collateral commodity contracts subject to rate recovery	'		0
Associated offsetting commodity contracts subject to rate recovery	-2		0
Net amount presented on balance sheet	106		90
Additional margin posted for commodity contracts not subject to rate recovery	0		0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	106		90
Fixed Price Contracts And Other Derivatives, Noncurrent Assets [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	0	[2]	0	[3]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Commodity contracts subject to rate recovery	72		35
Associated cash collateral commodity contracts subject to rate recovery	'		0
Associated offsetting commodity contracts subject to rate recovery	-2		0
Net amount presented on balance sheet	70		35
Additional margin posted for commodity contracts not subject to rate recovery	0		0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	70		35
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 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 not subject to rate recovery	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	-18	[2],[3]	-19	[3]
Commodity contracts not subject to rate recovery	'		0	[3]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Interest rate and foreign exchange instruments	-7	[3]	-8	[3]
Commodity contracts not subject to rate recovery	-51	[3]	-116	[3]
Associated offsetting commodity contracts not subject to rate recovery	43	[3]	102	[3]
Associated cash collateral commodity contracts not subject to rate recovery	1	[3]	4	[3]
Commodity contracts subject to rate recovery	-10	[3]	-35	[3]
Associated cash collateral commodity contracts subject to rate recovery	'		22	[3]
Associated offsetting commodity contracts subject to rate recovery	3	[3]	4	[3]
Net amount presented on balance sheet	-39	[3]	-46	[3]
Additional margin posted for commodity contracts not subject to rate recovery	0	[3]	0	[3]
Additional margin posted for commodity contracts subject to rate recovery	0	[3]	0	[3]
Total	-39	[3]	-46	[3]
Fixed Price Contracts And Other Derivatives, Current Liabilities [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	-16	[2]	-17	[3]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Commodity contracts subject to rate recovery	-9		-33
Associated cash collateral commodity contracts subject to rate recovery	'		22
Associated offsetting commodity contracts subject to rate recovery	3		3
Net amount presented on balance sheet	-22		-25
Additional margin posted for commodity contracts not subject to rate recovery	0		0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	-22		-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 subject to rate recovery	-1	[3]	-2	[3]
Associated offsetting commodity contracts subject to rate recovery	'		1	[3]
Net amount presented on balance sheet	-1	[3]	-1	[3]
Additional margin posted for commodity contracts not subject to rate recovery	0	[3]	0	[3]
Additional margin posted for commodity contracts subject to rate recovery	0	[3]	0	[3]
Total	-1	[3]	-1	[3]
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	-75	[2]	-64	[3]
Commodity contracts not subject to rate recovery	'		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Interest rate and foreign exchange instruments	-17		-35
Commodity contracts not subject to rate recovery	-5		-27
Associated offsetting commodity contracts not subject to rate recovery	5		12
Associated cash collateral commodity contracts not subject to rate recovery	0		7
Commodity contracts subject to rate recovery	-8		-1
Associated cash collateral commodity contracts subject to rate recovery	'		1
Associated offsetting commodity contracts subject to rate recovery	2		0
Net amount presented on balance sheet	-98		-107
Additional margin posted for commodity contracts not subject to rate recovery	0		0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	-98		-107
Fixed Price Contracts And Other Derivatives, Noncurrent Liabilities [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]	'		'
Interest rate and foreign exchange instruments	-39	[2]	-64	[3]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]	'		'
Commodity contracts subject to rate recovery	-8		-1
Associated cash collateral commodity contracts subject to rate recovery	'		1
Associated offsetting commodity contracts subject to rate recovery	2		0
Net amount presented on balance sheet	-45		-64
Additional margin posted for commodity contracts not subject to rate recovery	0		0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	-45		-64
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 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 not subject to rate recovery	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&Ebs amounts relate to Otay Mesa VIE.
[3]	Included in Current Liabilities: Other for SoCalGas.

DERIVATIVE_FINANCIAL_INSTRUMEN6

DERIVATIVE FINANCIAL INSTRUMENTS 4 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Cash Flow Hedges	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	$12		($33)		($74)
Gain (loss) reclassified from AOCI into earnings (effective portion)	-20		-15		-13
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)	1	[1]	-22	[1]	-42	[1]
Gain (loss) reclassified from AOCI into earnings (effective portion)	-11	[1]	-9	[1]	-8	[1]
Cash Flow Hedges | Interest Expense | Interest Rate Contract [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	8	[1]	-16	[1]	-40	[1]
Gain (loss) reclassified from AOCI into earnings (effective portion)	-9	[1]	-5	[1]	-5	[1]
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)	0		0		0
Gain (loss) reclassified from AOCI into earnings (effective portion)	-1		-2		-3
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)	15		-10		-32
Gain (loss) reclassified from AOCI into earnings (effective portion)	-10		-6		-5
Cash Flow Hedges | Cost of Natural Gas, Electric Fuel and Purchased Power [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)	-4		-1		0
Gain (loss) reclassified from AOCI into earnings (effective portion)	1		0		0
Fair Value Hedges	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	1	[2]	9	[2]	22	[2]
Fair Value Hedges | Southern California Gas Company [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	0	[2]	0	[2]	-2	[2]
Fair Value Hedges | Interest Expense | Interest Rate Contract [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	8		6		9
Fair Value Hedges | Interest Expense | Interest Rate Contract [Member] | Southern California Gas Company [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	0		0		1
Fair Value Hedges | Other Income, Net | Interest Rate Contract [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	-7		3		13
Fair Value Hedges | Other Income, Net | Interest Rate Contract [Member] | Southern California Gas Company [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	0		0		-3
Undesignated Derivatives	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	66		85		2
Undesignated Derivatives | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	53		69		-15
Undesignated Derivatives | Southern California Gas Company [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	1		-1		-1
Undesignated Derivatives | Other Income, Net | Interest Rate Contract [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	0	[3]	0	[3]	-1	[3]
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	17	[3]	10	[3]	-14	[3]
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		0		0
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	-1		7		30
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		0		1
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	53		69		-14
Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Derivative Instruments, Gain (Loss) [Line Items]	'		'		'
Gain (loss) on derivative recognized in earnings	53		69		-14
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	0		-2		-2
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	0		-2		-2
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		1		1
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		$1		$1
[1]	Amounts include Otay Mesa VIE. All of SDG&Ebs interest rate derivative activity relates to Otay Mesa VIE. There was a negligible amount of ineffectiveness related to these swaps.
[2]	There has been no hedge ineffectiveness on these swaps. Changes in the fair values of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt.
[3]	Amount for 2011 is related to Otay Mesa VIE. Sempra Energy Consolidated also includes additional instruments.

DERIVATIVE_FINANCIAL_INSTRUMEN7

DERIVATIVE FINANCIAL INSTRUMENTS 5 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Reclassification Of Cash Flow Hedge Gain (Loss) [Line Items]	'
Maximum length of time hedged in cash flow hedge	'15
Joint venture maximum length time hedged In cash flow hedge	'22
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	($23)
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	-12
San Diego Gas and Electric Company and Subsidiary [Member]	'
Reclassification Of Cash Flow Hedge Gain (Loss) [Line Items]	'
Maximum length of time hedged in cash flow hedge	'5
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	-11
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	($1)

DERIVATIVE_FINANCIAL_INSTRUMEN8

DERIVATIVE FINANCIAL INSTRUMENTS 6 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative Credit Risk Related Contingent Features [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	$3	$8
Additional Collateral Aggregate Fair Value	3	'
San Diego Gas and Electric Company and Subsidiary [Member]	'	'
Derivative Credit Risk Related Contingent Features [Line Items]	'	'
Derivative, Net Liability Position, Aggregate Fair Value	3	6
Additional Collateral Aggregate Fair Value	$3	'

DERIVATIVE_FINANCIAL_INSTRUMEN9

DERIVATIVE FINANCIAL INSTRUMENTS 7 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Hedge Ineffectiveness [Line Items]	'	'	'
Loss on Cash Flow Hedge Ineffectiveness	$1	$2	$0

FAIR_VALUE_MEASUREMENTS_Detail

FAIR VALUE MEASUREMENTS (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, debt instrument, unamortized amount	$17		$16
Fair value of financial instruments, capital Lease obligations	195		189
Fair value of financial instruments, commercial paper	200		300
San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, debt instrument, unamortized amount	11		12
Fair value of financial instruments, capital Lease obligations	179		185
Southern California Gas Company [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, debt instrument, unamortized amount	4		4
Fair value of financial instruments, capital Lease obligations	2		4
Carrying Amount	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Investments in affordable housing partnerships	'		12	[1]
Fair value of financial instruments, Total long-term debt	12,022	[2]	11,873	[2]
Fair value of financial instruments, Preferred stock of subsidiaries	20		99
Carrying Amount | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Total long-term debt	4,386	[3]	4,135	[3]
Fair value of financial instruments, Contingently redeemable preferred stock	'		79	[4]
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	1,413	[5]	1,413	[5]
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, Investments in affordable housing partnerships	'		36	[1]
Fair value of financial instruments, Total long-term debt	12,676	[2]	13,243	[2]
Fair value of financial instruments, Preferred stock of subsidiaries	20		107
Fair Value | Level 1	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Investments in affordable housing partnerships	'		0	[1]
Fair value of financial instruments, Total long-term debt	0	[2]	0	[2]
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, Investments in affordable housing partnerships	'		0	[1]
Fair value of financial instruments, Total long-term debt	11,925	[2]	12,287	[2]
Fair value of financial instruments, Preferred stock of subsidiaries	20		107
Fair Value | Level 3	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Investments in affordable housing partnerships	'		36	[1]
Fair value of financial instruments, Total long-term debt	751	[2]	956	[2]
Fair value of financial instruments, Preferred stock of subsidiaries	0		0
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Total long-term debt	4,561	[3]	4,588	[3]
Fair value of financial instruments, Contingently redeemable preferred stock	'		85	[4]
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | Level 1	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Total long-term debt	0	[3]	0	[3]
Fair value of financial instruments, Contingently redeemable preferred stock	'		0	[4]
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | Level 2	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Total long-term debt	4,226	[3]	4,243	[3]
Fair value of financial instruments, Contingently redeemable preferred stock	'		85	[4]
Fair Value | San Diego Gas and Electric Company and Subsidiary [Member] | Level 3	'		'
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]	'		'
Fair value of financial instruments, Total long-term debt	335	[3]	345	[3]
Fair value of financial instruments, Contingently redeemable preferred stock	'		0	[4]
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	1,469	[5]	1,599	[5]
Fair value of financial instruments, Preferred stock	22		24
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	0	[5]	0	[5]
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	1,469	[5]	1,599	[5]
Fair value of financial instruments, Preferred stock	22		24
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	0	[5]	0	[5]
Fair value of financial instruments, Preferred stock	$0		$0
[1]	Investments in affordable housing partnerships at Parent and Other. At December 31, 2013, the carrying amount and fair value of these investments were negligible.
[2]	Before reductions for unamortized discount (net of premium) of $17 million and $16 million at December 31, 2013 and 2012, respectively, and excluding build-to-suit and capital leases of $195 million and capital leases of $189 million at December 31, 2013 and 2012, respectively, and commercial paper classified as long-term debt of $200 million and $300 million at December 31, 2013 and 2012, respectively. We discuss our long-term debt in Note 5.
[3]	Before reductions for unamortized discount of $11 million and $12 million at December 31, 2013 and 2012, respectively, and excluding capital leases of $179 million and $185 million at December 31, 2013, respectively.
[4]	On October 15, 2013, SDG&E redeemed all outstanding shares of its contingently redeemable preferred stock for $82 million. We discuss the redemption in Note 11.
[5]	Before reductions for unamortized discount of $4 million at both December 31, 2013 and 2012 and excluding capital leases of $2 million and $4 million at December 31, 2013 and 2012, respectively.

FAIR_VALUE_MEASUREMENTS_2_Deta

FAIR VALUE MEASUREMENTS 2 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net [Line Items]	'	'
Fair value of cash collateral receivables not offset against derivatives	$48	$35
San Diego Gas and Electric Company and Subsidiary [Member]	'	'
Derivative, Fair Value, Gross Amount Not Offset Against Collateral, Net [Line Items]	'	'
Fair value of cash collateral receivables not offset against derivatives	30	13
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	$4	$3

FAIR_VALUE_MEASUREMENTS_3_Deta

FAIR VALUE MEASUREMENTS 3 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Nuclear decommissioning trusts - equity securities	$614		$539
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	117		156
Nuclear decomissioning trusts - Municipal debt securities	111		63
Nuclear decommissioning trusts - Other debt securities	153		130
Nuclear decommissioning trusts - Total debt securities	381		349
Total nuclear decommissioning trusts	995	[1]	888	[1]
Interest rate instruments, assets	56		68
Commodity contracts subject to rate recovery, assets	133		74
Commodity contracts not subject to rate recovery, assets	23		43
Investments	'		1
Assets fair value disclosure, total	1,207		1,074
Interest rate instruments, liabilities	117		126
Commodity contracts subject to rate recovery, liabilities	13		9
Commodity contracts not subject to rate recovery, liabilities	7		18
Liabilities fair value disclosure, total	137		153
San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Nuclear decommissioning trusts - equity securities	614		539
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	117		156
Nuclear decomissioning trusts - Municipal debt securities	111		63
Nuclear decommissioning trusts - Other debt securities	153		130
Nuclear decommissioning trusts - Total debt securities	381		349
Total nuclear decommissioning trusts	995	[1]	888	[1]
Commodity contracts subject to rate recovery, assets	130		73
Commodity contracts not subject to rate recovery, assets	1		1
Assets fair value disclosure, total	1,126		962
Interest rate instruments, liabilities	55		81
Commodity contracts subject to rate recovery, liabilities	12		8
Liabilities fair value disclosure, total	67		89
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	3		1
Commodity contracts not subject to rate recovery, assets	2		3
Assets fair value disclosure, total	5		4
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	614		539
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	59		87
Nuclear decomissioning trusts - Municipal debt securities	0		0
Nuclear decommissioning trusts - Other debt securities	0		0
Nuclear decommissioning trusts - Total debt securities	59		87
Total nuclear decommissioning trusts	673	[1]	626	[1]
Interest rate instruments, assets	0		0
Commodity contracts subject to rate recovery, assets	2		0
Commodity contracts not subject to rate recovery, assets	1		13
Investments	'		1
Assets fair value disclosure, total	676		640
Interest rate instruments, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	0		23
Commodity contracts not subject to rate recovery, liabilities	4		6
Liabilities fair value disclosure, total	4		29
Level 1 | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Nuclear decommissioning trusts - equity securities	614		539
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	59		87
Nuclear decomissioning trusts - Municipal debt securities	0		0
Nuclear decommissioning trusts - Other debt securities	0		0
Nuclear decommissioning trusts - Total debt securities	59		87
Total nuclear decommissioning trusts	673	[1]	626	[1]
Commodity contracts subject to rate recovery, assets	1		0
Commodity contracts not subject to rate recovery, assets	0		0
Assets fair value disclosure, total	674		626
Interest rate instruments, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	0		23
Liabilities fair value disclosure, total	0		23
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	1		0
Commodity contracts not subject to rate recovery, assets	0		1
Assets fair value disclosure, total	1		1
Commodity contracts subject to rate recovery, liabilities	0		0
Liabilities fair value disclosure, total	0		0
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	58		69
Nuclear decomissioning trusts - Municipal debt securities	111		63
Nuclear decommissioning trusts - Other debt securities	153		130
Nuclear decommissioning trusts - Total debt securities	322		262
Total nuclear decommissioning trusts	322	[1]	262	[1]
Interest rate instruments, assets	56		68
Commodity contracts subject to rate recovery, assets	1		0
Commodity contracts not subject to rate recovery, assets	5		8
Investments	'		0
Assets fair value disclosure, total	384		338
Interest rate instruments, liabilities	117		126
Commodity contracts subject to rate recovery, liabilities	13		9
Commodity contracts not subject to rate recovery, liabilities	8		23
Liabilities fair value disclosure, total	138		158
Level 2 | San Diego Gas and Electric Company and Subsidiary [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	58		69
Nuclear decomissioning trusts - Municipal debt securities	111		63
Nuclear decommissioning trusts - Other debt securities	153		130
Nuclear decommissioning trusts - Total debt securities	322		262
Total nuclear decommissioning trusts	322	[1]	262	[1]
Commodity contracts subject to rate recovery, assets	1		0
Commodity contracts not subject to rate recovery, assets	0		0
Assets fair value disclosure, total	323		262
Interest rate instruments, liabilities	55		81
Commodity contracts subject to rate recovery, liabilities	12		8
Liabilities fair value disclosure, total	67		89
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	0		0
Commodity contracts not subject to rate recovery, assets	0		0
Assets fair value disclosure, total	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	0	[1]	0	[1]
Interest rate instruments, assets	0		0
Commodity contracts subject to rate recovery, assets	99		61
Commodity contracts not subject to rate recovery, assets	0		0
Investments	'		0
Assets fair value disclosure, total	99		61
Interest rate instruments, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	0		0
Commodity contracts not subject to rate recovery, liabilities	0		0
Liabilities fair value disclosure, total	0		0
Level 3 | San Diego Gas and Electric Company and Subsidiary [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	0	[1]	0	[1]
Commodity contracts subject to rate recovery, assets	99		61
Commodity contracts not subject to rate recovery, assets	0		0
Assets fair value disclosure, total	99		61
Interest rate instruments, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	0		0
Liabilities fair value disclosure, total	0		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
Commodity contracts not subject to rate recovery, assets	0		0
Assets fair value disclosure, total	0		0
Commodity contracts subject to rate recovery, liabilities	0		0
Liabilities fair value disclosure, total	0		0
NettingAndCollateralMember	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Nuclear decommissioning trusts - equity securities	0	[2]	0	[2]
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	0	[2]	0	[2]
Nuclear decomissioning trusts - Municipal debt securities	0	[2]	0	[2]
Nuclear decommissioning trusts - Other debt securities	0	[2]	0	[2]
Nuclear decommissioning trusts - Total debt securities	0	[2]	0	[2]
Total nuclear decommissioning trusts	0	[1],[2]	0	[1],[2]
Interest rate instruments, assets	0	[2]	0	[2]
Commodity contracts subject to rate recovery, assets	31	[2]	13	[2]
Commodity contracts not subject to rate recovery, assets	17	[2]	22	[2]
Investments	'		0	[2]
Assets fair value disclosure, total	48	[2]	35	[2]
Interest rate instruments, liabilities	0	[2]	0	[2]
Commodity contracts subject to rate recovery, liabilities	0	[2]	-23	[2]
Commodity contracts not subject to rate recovery, liabilities	-5	[2]	-11	[2]
Liabilities fair value disclosure, total	-5	[2]	-34	[2]
NettingAndCollateralMember | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]	'		'
Nuclear decommissioning trusts - equity securities	0	[2]	0	[2]
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	0	[2]	0	[2]
Nuclear decomissioning trusts - Municipal debt securities	0	[2]	0	[2]
Nuclear decommissioning trusts - Other debt securities	0	[2]	0	[2]
Nuclear decommissioning trusts - Total debt securities	0	[2]	0	[2]
Total nuclear decommissioning trusts	0	[1],[2]	0	[1],[2]
Commodity contracts subject to rate recovery, assets	29	[2]	12	[2]
Commodity contracts not subject to rate recovery, assets	1	[2]	1	[2]
Assets fair value disclosure, total	30	[2]	13	[2]
Interest rate instruments, liabilities	0	[2]	0	[2]
Commodity contracts subject to rate recovery, liabilities	0	[2]	-23	[2]
Liabilities fair value disclosure, total	0	[2]	-23	[2]
NettingAndCollateralMember | 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	[2]	1	[2]
Commodity contracts not subject to rate recovery, assets	2	[2]	2	[2]
Assets fair value disclosure, total	4	[2]	3	[2]
Commodity contracts subject to rate recovery, liabilities	0	[2]	0	[2]
Liabilities fair value disclosure, total	$0	[2]	$0	[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, 2013	Dec. 31, 2012	Dec. 31, 2011
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'
Balance at beginning of period	$61,000,000	$23,000,000	$2,000,000
Realized and unrealized gains (losses)	11,000,000	31,000,000	32,000,000
Issuances	51,000,000	58,000,000	7,000,000
Settlements	-24,000,000	-51,000,000	-18,000,000
Balance at end of period	99,000,000	61,000,000	23,000,000
Change in unrealized gains relating to instruments still held at the end of the period	11,000,000	17,000,000	17,000,000
San Diego Gas and Electric Company and Subsidiary [Member] | Maximum [Member]	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'
Congestion Revenue Rights	12	12	'
San Diego Gas and Electric Company and Subsidiary [Member] | Minimum [Member]	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'
Congestion Revenue Rights	($6)	($11)	'

FAIR_VALUE_MEASUREMENTS_5_Deta

FAIR VALUE MEASUREMENTS 5 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2012		Sep. 30, 2011		Dec. 31, 2013
Fai rValue Inputs Assets Quantitative Information [Line Items]	'		'		'
Investment in RBS Sempra Commodities LLP	'		$126	[1]	$73
Investment in Rockies Express	$369	[2]	'		$329
Fair value measurement percentage, of level two hierarchy, for Rockies Express	67.00%		'		'
Fair value measurement percentage, of level three hierarchy, for Rockies Express	33.00%		'		'
Fair value measurement percentage, of level three hierarchy, for RBS Sempra Commodities	'		100.00%		'
Equity Method Investments [Member] | Level 3 | One Hundred Percent [Member] | Minimum [Member]	'		'		'
Fai rValue Inputs Assets Quantitative Information [Line Items]	'		'		'
Fair value inputs, future cash distributions	'		90.00%		'
Equity Method Investments [Member] | Market Approach Valuation Technique [Member] | Level 2 | Sixty Seven Percent [Member] | Stated [Member]	'		'		'
Fai rValue Inputs Assets Quantitative Information [Line Items]	'		'		'
Fair value inputs, equity sale offer price	100.00%		'		'
Equity Method Investments [Member] | Probability Weighted Discounted Cash Flow Valuation Technique [Member] | Level 3 | Thirty Three Percent [Member] | Maximum [Member]	'		'		'
Fai rValue Inputs Assets Quantitative Information [Line Items]	'		'		'
Fair value inputs, combined transportation rate assumption	78.00%	[3]	'		'
Fair value inputs, operating and maintenance escalation rate	1.00%		'		'
Fair value inputs, forecasted interest rate on debt to be refinanced	10.00%		'		'
Fair value inputs, discount rate	10.00%		'		'
Equity Method Investments [Member] | Probability Weighted Discounted Cash Flow Valuation Technique [Member] | Level 3 | Thirty Three Percent [Member] | Minimum [Member]	'		'		'
Fai rValue Inputs Assets Quantitative Information [Line Items]	'		'		'
Fair value inputs, combined transportation rate assumption	6.00%	[3]	'		'
Fair value inputs, operating and maintenance escalation rate	0.00%		'		'
Fair value inputs, forecasted interest rate on debt to be refinanced	5.00%		'		'
Fair value inputs, discount rate	8.00%		'		'
Equity Method Investments [Member] | IncomeApproachValuationTechniqueMember | Level 3 | One Hundred Percent [Member] | Maximum [Member]	'		'		'
Fai rValue Inputs Assets Quantitative Information [Line Items]	'		'		'
Fair value inputs, future cash distributions	'		110.00%		'
[1]	At measurement date of September 30, 2011. At December 31, 2013, our investment in RBS Sempra Commodities had a carrying value of $73 million, reflecting subsequent equity method activity to record distributions and losses.
[2]	At measurement date of September 30, 2012. At December 31, 2013, our investment in Rockies Express had a carrying value of $329 million, reflecting subsequent equity method activity to record distributions and earnings.
[3]	Transportation rate beyond existing contract terms as a percentage of current mean REX rates.

FAIR_VALUE_MEASUREMENTS_6_Deta

FAIR VALUE MEASUREMENTS 6 (Details) (USD $)	3 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2012	Jun. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule Of Equity Method And Other Investments [Line Items]	'	'	'	'	'
Loss on impairment of RBS Sempra Commodities	'	'	'	'	($16)
Loss on impairment of RBS Sempra Commodities, after tax	'	'	'	'	-10
Rockies Express [Member]	'	'	'	'	'
Schedule Of Equity Method And Other Investments [Line Items]	'	'	'	'	'
Equity Method Investment, Other Than Temporary Impairment	-100	-300	'	'	'
Equity Method Investment, Other Than Temporary Impairment, Net Of Tax Benefit	-60	-179	'	'	'
Equity Method Investment, Other Than Temporary Impairment, Gross	'	'	$0	($400)	$0

PREFERRED_STOCK_Details

PREFERRED STOCK (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Jun. 30, 2011

Jun. 30, 2011

Jun. 30, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

In Millions, except Share data, unless otherwise specified

San Diego Gas and Electric Company and Subsidiary [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

Southern California Gas Company [Member]

S D G E Series Preference Stock [Member]

Preferred Stock, Pacific Enterprises [Member]

Preferred Stock, Pacific Enterprises [Member]

Preferred Stock, Pacific Enterprises [Member]

Preferred Stock, So Cal Gas [Member]

So Cal Gas Series Preferred Stock [Member]

So Cal Gas Series Preferred Stock [Member]

Twenty Five Dollar Par, Six Percent Series [Member]

Twenty Five Dollar Par, Six Percent Series [Member]

Twenty Five Dollar Par, Six Percent Seriesa [Member]

Twenty Five Dollar Par, Six Percent Seriesa [Member]

Preference Stock [Member]

So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member]

So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member]

So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member]

Preferred Stock Of Subsidiaries [Member]

Preferred Stock Of Subsidiaries [Member]

Maximum [Member]

Minimum [Member]

San Diego Gas and Electric Company and Subsidiary [Member]

Pacific Enterprises [Member]

Pacific Enterprises [Member]

Pacific Enterprises [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Southern California Gas Company [Member]

Pacific Enterprises [Member]

Pacific Enterprises [Member]

Maximum [Member]

Minimum [Member]

Preferred Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Par or Stated Value Per Share

'

'

'

'

'

'

'

'

'

'

'

'

'

$25

'

$25

'

'

'

'

'

'

'

Preferred Stock, Shares Authorized

50,000,000

50,000,000

25,000,000

'

'

1,000,000

0

'

'

'

5,000,000

'

'

'

'

'

'

5,000,000

'

'

'

'

'

Preferred Stock, Shares Outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

79,011

'

783,032

'

'

50,970

'

'

'

'

Preferred Stock, Redemption Price Per Share

'

'

'

$26

$20.25

'

'

'

$101.50

$100

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred Stock, Value, Outstanding

'

'

'

'

'

'

'

'

'

'

'

$22

$22

$3

$3

$19

$19

'

'

($2)

($2)

$20

$20

Preferred Stock, Liquidation Preference Per Share

'

'

'

'

'

'

'

'

'

'

'

'

'

$25

'

$25

'

'

'

'

'

'

'

Preferred stock redeemed

'

'

82

'

'

'

'

81

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued preferred stock dividends at redemption date

'

'

$1

'

'

'

'

$1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

PREFERRED_STOCK_2_Details

PREFERRED STOCK 2 (Details) (USD $)	Dec. 31, 2013		Dec. 31, 2012
In Millions, except Share data, unless otherwise specified
Contingently Redeemable Preferred Stock [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Contingently redeemable preferred stock	$0	[1]	$79	[1]
Contingently Redeemable, Twenty Dollar Par Series [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Authorized	1,375,000		'
Five Percent Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Outstanding	375,000		'
Redeemable Preferred Stock, Redemption Price Per Share	$24		'
Contingently redeemable preferred stock	0	[1]	8	[1]
Redeemable Preferred Stock, Par Value	$20		'
Four Point Five Percent Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Outstanding	300,000		'
Redeemable Preferred Stock, Redemption Price Per Share	$21.20		'
Contingently redeemable preferred stock	0	[1]	6	[1]
Redeemable Preferred Stock, Par Value	$20		'
Four Point Four Percent Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Outstanding	325,000		'
Redeemable Preferred Stock, Redemption Price Per Share	$21		'
Contingently redeemable preferred stock	0	[1]	7	[1]
Redeemable Preferred Stock, Par Value	$20		'
Four Point Six Percent Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Outstanding	373,770		'
Redeemable Preferred Stock, Redemption Price Per Share	$20.25		'
Contingently redeemable preferred stock	0	[1]	7	[1]
Redeemable Preferred Stock, Par Value	$20		'
Contingently Redeemable, No Par Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Liquidation Preference	$0		'
One Seventy Per Share Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Outstanding	1,400,000		'
Redeemable Preferred Stock, Redemption Price Per Share	$25		'
Contingently redeemable preferred stock	0	[1]	35	[1]
One Eighty Two Per Share Series [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'
Redeemable Preferred Stock [Line Items]	'		'
Redeemable Preferred Stock, Shares Outstanding	640,000		'
Redeemable Preferred Stock, Redemption Price Per Share	$26		'
Contingently redeemable preferred stock	$0	[1]	$16	[1]
[1]	Represents shares outstanding at December 31, 2012, which were fully redeemed in October 2013.

SHAREHOLDERS_EQUITY_AND_EARNIN3

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Details) (USD $)

3 Months Ended

12 Months Ended

In Millions, except Share data in Thousands, unless otherwise specified

Dec. 31, 2013

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Dec. 31, 2012

Sep. 30, 2012

Jun. 30, 2012

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Earnings Per Share Numerator [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Earnings

$282

$296

$245

$178

$293

$268

$62

$236

$1,001

$859

$1,331

Earnings Per Share Denominator [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Weighted-average common shares outstanding for basic EPS

244,400

[1]

244,100

[1]

243,600

[1]

243,300

[1]

242,000

[1]

241,700

[1]

241,100

[1]

240,600

[1]

243,863

241,347

239,720

Dilutive effect of stock options, restricted stock awards and restricted stock units

'

'

'

'

'

'

'

'

5,469

5,346

1,803

Weighted-average common shares outstanding for diluted EPS

249,900

[1]

249,300

[1]

248,500

[1]

247,500

[1]

247,600

[1]

245,800

[1]

246,300

[1]

243,800

[1]

249,332

246,693

241,523

Earnings Per Share [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Basic earnings per common share

$1.15

[1]

$1.21

[1]

$1

[1]

$0.73

[1]

$1.21

[1]

$1.11

[1]

$0.26

[1]

$0.98

[1]

$4.10

$3.56

$5.55

Diluted earnings per common share

$1.13

[1]

$1.19

[1]

$0.98

[1]

$0.72

[1]

$1.18

[1]

$1.09

[1]

$0.25

[1]

$0.97

[1]

$4.01

$3.48

$5.51

Dividends declared per share of common stock

'

'

'

'

'

'

'

'

$2.52

$2.40

$1.92

San Diego Gas and Electric Company and Subsidiary [Member]

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Share Numerator [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Earnings

119

134

66

92

111

176

96

106

411

489

436

Southern California Gas Company [Member]

'

'

'

'

'

'

'

'

'

'

'

Earnings Per Share Numerator [Abstract]

'

'

'

'

'

'

'

'

'

'

'

Earnings

'

'

'

'

'

'

'

'

$365

$290

$288

[1]

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_EARNIN4

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 2 (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
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	40,000	2,083,275
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	900
Restricted Stock [Member]	'	'	'
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]	'	'	'
Antidilutive securities excluded from computation of earnings per share	641,751	1,134,456	4,109,717

SHAREHOLDERS_EQUITY_AND_EARNIN5

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 3 (Details) (USD $)	12 Months Ended
In Billions, except Share data, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
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		'
Employee Stock Ownership Plan (ESOP), Shares in ESOP [Abstract]	'		'		'
Employee Stock Ownership Plan (ESOP), Shares in ESOP	0		0		153,625
Increase (Decrease) in Stockholders' Equity [Roll Forward]	'		'		'
Common Stock, Shares, Outstanding, Beginning Balance	242,368,836		239,934,681		240,447,416
Shares Held In Employee Stock Ownership Plan, Released	0		153,625		350,815
Share-based Compensation Arrangement by Share-based Payment Award, Options, Exercises in Period	1,237,348		1,876,303		958,126
Stock Issued During Period, Shares, Restricted Stock Award, Gross	21,121		2,580		11,876
Stock Issued During Period, Shares, Restricted Stock Units, Vesting	1,491,170	[1]	683,416	[1]	2,625	[1]
Stock Repurchased and Retired During Period, Shares	-657,148	[2]	-281,769	[2]	-1,836,177	[2]
Common Stock, Shares, Outstanding, Ending Balance	244,461,327		242,368,836		239,934,681
Common Stock Repurchase Program [Abstract]	'		'		'
Authorized Share Repurchase Program, Maximum Repurchase, Amount	$2		'		'
Authorized Share Repurchase Program, Maximum Repurchase, Shares	40,000,000		'		'
[1]	Includes dividend equivalents.
[2]	In addition to formal common stock repurchase programs which we discuss below, we also, from time to time, purchase shares of our common stock from restricted stock plan participants who elect to sell a sufficient number of vesting restricted shares to meet minimum statutory tax withholding requirements.

SHAREHOLDERS_EQUITY_AND_EARNIN6

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 4 (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2008	Dec. 31, 2011	Dec. 31, 2010
	Collared Accelerated Share Acquisition Program, April 2008 [Member]	Collared Accelerated Share Acquisition Program, September 2010 [Member]	Collared Accelerated Share Acquisition Program, September 2010 [Member]
Accelerated Share Repurchases [Line Items]	'	'	'
Accelerated Share Repurchases, Settlement Payment or Receipt	$1,000	'	$500
Accelerated Share Repurchases, Shares Received	18,416,241	9,574,435	'
Accelerated Share Repurchases, Final Price Paid Per Share	$54.30	$52.22	'
Accelerated Share Repurchases, Initial Share Delivery	'	'	8,078,000
Accelerated Share Repurchases, Interim Share Delivery	'	1,496,435	'

SHAREHOLDERS_EQUITY_AND_EARNIN7

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 5 (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Restricted Stock Units [Member]	'	'	'
Schedule Of Performance Based Restricted Shares [Line Items]	'	'	'
Contractual vesting percentage minimum	0.00%	'	'
Contractual vesting percentage maximum	150.00%	'	'
Shares excluded from potential dilutive shares	0	7,673	0
Restricted Stock Awards [Member]	'	'	'
Schedule Of Performance Based Restricted Shares [Line Items]	'	'	'
Contractual vesting percentage maximum	100.00%	'	'
Shares excluded from potential dilutive shares	0	1,934	0

SHAREHOLDERS_EQUITY_AND_EARNIN8

SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE 6 (Details)	12 Months Ended
	Dec. 31, 2013
Seventy Fifth Percentile Or Above [Member]	'
Total Shareholder Return Ranking [Line Items]	'
Common Shares Received For Each Restricted Stock Unit	1.5	[1]
Fiftieth Percentile [Member]	'
Total Shareholder Return Ranking [Line Items]	'
Common Shares Received For Each Restricted Stock Unit	1	[1]
Thirty Fifth Percentile Or Below [Member]	'
Total Shareholder Return Ranking [Line Items]	'
Common Shares Received For Each Restricted Stock Unit	0	[1]
[1]	Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate.

NUCLEAR_PLANT_RETIREMENT_Detai

NUCLEAR PLANT RETIREMENT (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
SONGS Plant Investment [Line Items]	'	'	'
Loss from plant closure	$200	$0	$0
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
SONGS Plant Investment [Line Items]	'	'	'
Nuclear Plant, Net Property, Plant and Equipment	516	'	'
Nuclear Plant, Materials Inventory	10	'	'
Nuclear Plant, Replacement Power Costs In Excess Of Authorized	67	'	'
Regulatory Asset, Nuclear Plant Closure	303	'	'
Nuclear Plant, Miscellaneous Costs	35	'	'
Nuclear Plant, Operations And Maintenance Expenses	184	'	'
Nuclear Plant Billed To Customers, Subject To Refund	$125	'	'

NUCLEAR_PLANT_RETIREMENT_2_Det

NUCLEAR PLANT RETIREMENT 2 (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Jun. 06, 2013
			Nuclear Plant, SDGE [Member]	Nuclear Plant, SDGE [Member]
Nuclear Plant [Line Items]	'	'	'	'
Nuclear Plant, Ownership Percentage	'	'	20.00%	'
Nuclear Plant, Replacement Power Costs	'	'	'	$165,000,000
Nuclear Plant, Revenue Recognized Associated with SONGS	'	'	'	300,000,000
Nuclear Plant, Replacement Power Costs Authorized	'	'	98,000,000	'
Authorized Recovery Amount, Nuclear Decommissioning Trust Funding	'	'	8,000,000	'
Requested Recovery Amount, Nuclear Decommissioning Trust Funding	'	'	16,000,000	'
Nuclear decommissioning trusts	1,034,000,000	908,000,000	'	'
Nuclear Plant Proposed Decision Share Of Costs Identified	'	'	182,800,000	'
Nuclear Plant Proposed Decision Share Of Costs To Be Refunded	'	'	19,300,000	'
Nuclear Plant Proposed Decision Steam Generator Costs Identified	'	'	122,000,000	'
Nuclear Plant Proposed Decision Steam Generator Costs To SDGE	'	'	$27,000,000	'

SONGS_NDT_Details

SONGS NDT (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2008
In Millions, unless otherwise specified
Facilities Under Joint Ownership (Details) [Abstract]	'	'
Asset Retirement Obligation, Nuclear Power Plant	$756	'
Utility Share Of Nuclear Decommissioning Costs	'	768
Utility Share Of Nuclear Decommissioning Costs, Adjusted For Inflation	$912	'

SONGS_NDT_2_Details

SONGS NDT 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Cost	$627		$594		'
Gross unrealized gains	417		317		'
Gross unrealized losses	-10		-3		'
Estimated fair value	1,034		908		'
Proceeds from sales	685	[1]	723	[1]	715	[1]
Gross realized gains	26		21		75
Gross realized losses	-18		-13		-52
Total Debt Securities	'		'		'
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Cost	381		325		'
Gross unrealized gains	8		25		'
Gross unrealized losses	-8		-1		'
Estimated fair value	381		349		'
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	116	[2]	147		'
Gross unrealized gains	3	[2]	9		'
Gross unrealized losses	-2	[2]	0		'
Estimated fair value	117	[2]	156		'
Municipal Bonds	'		'		'
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Cost	110	[3]	57		'
Gross unrealized gains	2	[3]	6		'
Gross unrealized losses	-1	[3]	0		'
Estimated fair value	111	[3]	63		'
Other Debt Securities	'		'		'
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Cost	155	[4]	121		'
Gross unrealized gains	3	[4]	10		'
Gross unrealized losses	-5	[4]	-1		'
Estimated fair value	153	[4]	130		'
Equity Securities	'		'		'
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Cost	207		249		'
Gross unrealized gains	409		292		'
Gross unrealized losses	-2		-2		'
Estimated fair value	614		539		'
Cash And Cash Equivalents	'		'		'
Schedule of Available-for-sale Securities [Line Items]	'		'		'
Cost	39		20		'
Gross unrealized gains	0		0		'
Gross unrealized losses	0		0		'
Estimated fair value	$39		$20		'
[1]	Excludes securities that are held to maturity.
[2]	Maturity dates are 2014-2056.
[3]	Maturity dates are 2014-2062.
[4]	Maturity dates are 2014-2111.

CALIFORNIA_UTILITIES_REGULATOR2

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 1 (Details)	Dec. 31, 2013
San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule of Cost of Capital Decision [Line Items]	'
Cost of Capital Authorized Weighting	100.00%
Cost of Capital Weighted Authorized Return On Rate Base	7.79%
Authorized Return On Rate Base Previous	8.40%
Cost Of Capital Average Benchmark Rate	4.73%
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]	'
Schedule of Cost of Capital Decision [Line Items]	'
Cost of Capital Authorized Weighting	100.00%
Cost of Capital Weighted Authorized Return On Rate Base	8.02%
Authorized Return On Rate Base Previous	8.68%
Cost Of Capital Average Benchmark Rate	4.73%
Cost Of Capital Benchmark Rate	4.24%
Cost Of Capital Floor Rate	3.24%
Cost Of Capital Ceiling Rate	5.24%
Cap Structure, Long Term Debt [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule of Cost of Capital Decision [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%
Cap Structure, Long Term Debt [Member] | Southern California Gas Company [Member]	'
Schedule of Cost of Capital Decision [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%
Cap Structure, Preferred Stock [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule of Cost of Capital Decision [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%
Cap Structure, Preferred Stock [Member] | Southern California Gas Company [Member]	'
Schedule of Cost of Capital Decision [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%
Cap Structure, Common Equity [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule of Cost of Capital Decision [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%
Cap Structure, Common Equity [Member] | Southern California Gas Company [Member]	'
Schedule of Cost of Capital Decision [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_REGULATOR3

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 2 (Details) (USD $)	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012	Dec. 31, 2013	Mar. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified	Utility Subsidiaries [Member]	Utility Subsidiaries [Member]	Utility Subsidiaries [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	Southern California Gas Company [Member]	Southern California Gas Company [Member]	Southern California Gas Company [Member]
General Rate Case [Abstract]	'	'	'	'	'	'	'	'	'
General Rate Case, Annual Revenue Requirement Increase Request	'	'	'	$119	'	'	$115	'	'
General Rate Case, Percentage Annual Revenue Requirement Increase Request	'	'	'	7.40%	'	'	6.20%	'	'
General Rate Case Revenue Requirement	'	'	'	1,733	'	'	1,959	'	'
General Rate Case, Total Earnings Impact	'	'	'	'	69	'	'	37	'
General Rate Case, Cumulative Earnings Impact	'	'	'	'	17	52	'	12	25
General Rate Case, Regulatory Asset	'	'	'	324	'	'	104	'	'
General Rate Case, Noncurrent Regulatory Asset	'	'	'	161	'	'	52	'	'
General Rate Case, Revenue Attrition Mechanism Fixed Annual Factor	2.75%	2.75%	2.65%	'	'	'	'	'	'
Wildfire Cost Recovery [Abstract]	'	'	'	'	'	'	'	'	'
Potential After-Tax Earnings Impact	'	'	'	$186	'	'	'	'	'
FERC Rates [Abstract]	'	'	'	'	'	'	'	'	'
FERC Return On Equity Requested	'	'	'	11.30%	'	'	'	'	'
Settlement FERC Return On Equity	'	'	'	10.05%	'	'	'	'	'

CALIFORNIA_UTILITIES_REGULATOR4

CALIFORNIA UTILITIES' REGULATORY MATTERS - UTILITY INCENTIVE AWARDS (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Utility Incentive Awards [Line Items]	'		'		'
Utility Incentive Awards, Energy Efficiency	$7,000,000	[1]	$6,000,000	[1]	$16,000,000	[1]
Utility Incentive Awards, Unbundled Natural Gas Storage And Hub Services	1,000,000	[1]	3,000,000	[1]	4,000,000	[1]
Utility Incentive Awards, Natural Gas Procurement	5,000,000	[1]	6,000,000	[1]	6,000,000	[1]
Utility Incentive Awards, Operational Incentives	0	[1]	5,000,000	[1]	3,000,000	[1]
Utility Incentive Awards	13,000,000	[1]	20,000,000	[1]	29,000,000	[1]
San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Utility Incentive Awards [Line Items]	'		'		'
Utility Incentive Awards, Energy Efficiency	4,000,000	[1]	3,000,000	[1]	14,000,000	[1]
Utility Incentive Awards, Operational Incentives	0	[1]	2,000,000	[1]	1,000,000	[1]
Utility Incentive Awards	4,000,000	[1]	5,000,000	[1]	15,000,000	[1]
Approved Energy Efficiency Award 2009 Program	'		'		13,700,000
Approved Energy Efficiency Award 2010-2012 Program	'		3,300,000		'
Approved Energy Efficiency Award 2011 Program	3,900,000		'		'
Southern California Gas Company [Member]	'		'		'
Utility Incentive Awards [Line Items]	'		'		'
Utility Incentive Awards, Energy Efficiency	3,000,000	[1]	3,000,000	[1]	2,000,000	[1]
Utility Incentive Awards, Unbundled Natural Gas Storage And Hub Services	1,000,000	[1]	3,000,000	[1]	4,000,000	[1]
Utility Incentive Awards, Natural Gas Procurement	5,000,000	[1]	6,000,000	[1]	6,000,000	[1]
Utility Incentive Awards, Operational Incentives	0	[1]	3,000,000	[1]	2,000,000	[1]
Utility Incentive Awards	9,000,000	[1]	15,000,000	[1]	14,000,000	[1]
Recorded Gas Cost Incentive Mechanism Award	5,400,000		6,200,000		6,000,000
Unrecorded Gas Cost Incentive Mechanism Award	5,800,000		'		'
Approved Energy Efficiency Award 2009 Program	'		'		2,000,000
Approved Energy Efficiency Award 2010-2012 Program	'		2,700,000		'
Approved Energy Efficiency Award 2011 Program	3,100,000		'		'
Hub Services First Tier Net Revenue Shared 90-10	15,000,000		'		'
Hub Services Second Tier Net Revenue Shared 75-25	15,000,000		'		'
Hub Services Maximum Annual Shareholder Portion Net Revenue	$20,000,000		'		'
[1]	Awards are included in earnings upon CPUC approval of the award.

CALIFORNIA_REGUALTORY_MATTERS_

CALIFORNIA REGUALTORY MATTERS - SCHEDULE OF UTILITY PROJECTS (Details) (USD $)	Dec. 31, 2013
In Millions, unless otherwise specified
East County Substation [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost, Upper Range	$450
Estimated Project Cost, Lower Range	425
Pipeline Safety Phase 1 [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost	3,100
Pipeline Safety Phase 1 [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost	600
Estimated Capital Investment	230
Requested Project Funding	240
Pipeline Safety Phase 1 [Member] | Southern California Gas Company [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost	2,500
Estimated Capital Investment	1,200
Requested Project Funding	1,500
South Orange County Reliability Enhancement [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost, Upper Range	500
Estimated Project Cost, Lower Range	450
Aliso Canyon Natural Gas Storage Compressor Replacement [Member] | Southern California Gas Company [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost	200
Cleveland National Forest Transmissions Projects [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost, Upper Range	450
Estimated Project Cost, Lower Range	400
South Bay Substation Member [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost, Upper Range	175
Estimated Project Cost, Lower Range	145
Southern Gas System Member [Member] | Utility Subsidiaries [Member]	'
Schedule Of Utility Projects [Line Items]	'
Estimated Project Cost, Upper Range	650
Estimated Project Cost, Lower Range	$600

COMMITMENTS_AND_CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - LONG-TERM PURCHASE COMMITMENT (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	$1,317		'	'
Contractual Commitments, Payments Due In Two Years	393		'	'
Contractual Commitments, Payments Due In Three Years	116		'	'
Contractual Commitments, Payments Due In Four Years	112		'	'
Contractual Commitments, Payments Due In Five Years	24		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	47		'	'
Contractual Commitments, Payments Due, Total	2,009		'	'
S D G E Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	177		'	'
Contractual Commitments, Payments Due In Two Years	32		'	'
Contractual Commitments, Payments Due In Three Years	28		'	'
Contractual Commitments, Payments Due In Four Years	27		'	'
Contractual Commitments, Payments Due In Five Years	23		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	45		'	'
Long-term Purchase Commitment, Amount	332		'	'
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	404	[1]	'	'
Contractual Commitments, Payments Due In Two Years	243	[1]	'	'
Contractual Commitments, Payments Due In Three Years	230	[1]	'	'
Contractual Commitments, Payments Due In Four Years	224	[1]	'	'
Contractual Commitments, Payments Due In Five Years	206	[1]	'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	377	[1]	'	'
Contractual Commitments, Payments Due, Total	1,684	[1]	'	'
Long-term Purchase Commitment, Payments In Period	1,680		1,345	1,991
Natural Gas Contracts [Member] | So Cal Gas Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	183		'	'
Contractual Commitments, Payments Due In Two Years	121		'	'
Contractual Commitments, Payments Due In Three Years	112		'	'
Contractual Commitments, Payments Due In Four Years	108		'	'
Contractual Commitments, Payments Due In Five Years	90		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	157		'	'
Contractual Commitments, Payments Due, Total	771		'	'
Long-term Purchase Commitment, Payments In Period	1,464		1,222	1,810
Natural Gas Transportation Contracts [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	242		'	'
Contractual Commitments, Payments Due In Two Years	239		'	'
Contractual Commitments, Payments Due In Three Years	226		'	'
Contractual Commitments, Payments Due In Four Years	220		'	'
Contractual Commitments, Payments Due In Five Years	202		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	361		'	'
Contractual Commitments, Payments Due, Total	1,490		'	'
Natural Gas Transportation Contracts [Member] | So Cal Gas Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	126		'	'
Contractual Commitments, Payments Due In Two Years	120		'	'
Contractual Commitments, Payments Due In Three Years	111		'	'
Contractual Commitments, Payments Due In Four Years	107		'	'
Contractual Commitments, Payments Due In Five Years	89		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	157		'	'
Contractual Commitments, Payments Due, Total	710		'	'
Natural Gas Supply Contracts [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	162	[1]	'	'
Contractual Commitments, Payments Due In Two Years	4	[1]	'	'
Contractual Commitments, Payments Due In Three Years	4	[1]	'	'
Contractual Commitments, Payments Due In Four Years	4	[1]	'	'
Contractual Commitments, Payments Due In Five Years	4	[1]	'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	16	[1]	'	'
Contractual Commitments, Payments Due, Total	194	[1]	'	'
Natural Gas Supply Contracts [Member] | So Cal Gas Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	57		'	'
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	61		'	'
Purchased Power Contracts [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	1,328		'	'
Contractual Commitments, Payments Due In Two Years	1,473		'	'
Contractual Commitments, Payments Due In Three Years	1,487		'	'
Contractual Commitments, Payments Due In Four Years	1,494		'	'
Contractual Commitments, Payments Due In Five Years	1,483		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	11,826		'	'
Contractual Commitments, Payments Due, Total	19,091	[2]	'	'
Long-term Purchase Commitment, Payments In Period	1,377		1,205	918
Purchased Power Contracts [Member] | S D G E Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	471		'	'
Contractual Commitments, Payments Due In Two Years	543		'	'
Contractual Commitments, Payments Due In Three Years	524		'	'
Contractual Commitments, Payments Due In Four Years	517		'	'
Contractual Commitments, Payments Due In Five Years	488		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	6,349		'	'
Contractual Commitments, Payments Due, Total	8,892	[2]	'	'
Long-term Purchase Commitment, Payments In Period	570		381	346
Purchased Power Contracts [Member] | Sempra Renewables Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Guarantee Obligations Maximum Exposure	165		'	'
Guarantee Obligations Current Carrying Value	2		'	'
Debt Service Operations [Member] | Sempra Renewables Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Guarantee Obligations Maximum Exposure	328		'	'
Guarantee Obligations Current Carrying Value	17		'	'
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	58		'	'
Contractual Commitment Future Annual Payment Amount	3		'	'
Contractual Commitment Present Value Future Payments, Regulatory Asset	115		'	'
Contractual Commitment Future Payments, Liability	115		'	'
East County Substation [Member] | S D G E Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Long-term Purchase Commitment, Payments In Period	87		'	'
Liquefied Natural Gas Contracts [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Long Term Purchase Commitment Estimated Annual Escalation After 2023	1.00%		'	'
Liquefied Natural Gas Contracts [Member] | Sempra Natural Gas Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	670		'	'
Contractual Commitments, Payments Due In Two Years	662		'	'
Contractual Commitments, Payments Due In Three Years	654		'	'
Contractual Commitments, Payments Due In Four Years	658		'	'
Contractual Commitments, Payments Due In Five Years	678		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	8,300		'	'
Nuclear Plant Maintenance [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Long-term Purchase Commitment, Amount	132		'	'
Natural Gas Infrastructure Construction [Member] | S D G E Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Long-term Purchase Commitment, Amount	113		'	'
Natural Gas Infrastructure Construction [Member] | So Cal Gas Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	190		'	'
Contractual Commitments, Payments Due In Two Years	84		'	'
Contractual Commitments, Payments Due In Three Years	84		'	'
Contractual Commitments, Payments Due In Four Years	84		'	'
Contractual Commitments, Payments Due, Total	442		'	'
Long-term Contracts [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Purchase Commitment Component Percentage	31.00%		'	'
Other Owned Generation [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Purchase Commitment Component Percentage	55.00%		'	'
Spot Market Purchases [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Purchase Commitment Component Percentage	14.00%		'	'
Renewable Energy Contracts Expiring Through 2039 [Member] | San Diego Gas and Electric Company and Subsidiary [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Purchase Commitment Component Percentage	25.40%		'	'
Luz del Sur Hydroelectric Power Plant [Member] | Sempra South American Utilities Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Total	15		'	'
Sempra South American Utilities Construction [Member] | Sempra South American Utilities Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	27		'	'
Contractual Commitments, Payments Due, Total	27		'	'
Sempra Renewables Construction [Member] | Sempra Renewables Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	524		'	'
Contractual Commitments, Payments Due In Two Years	41		'	'
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	1		'	'
Contractual Commitments, Payments Due, Total	569		'	'
Sempra Rockies Marketing [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	14		'	'
Contractual Commitments, Payments Due In Two Years	14		'	'
Contractual Commitments, Payments Due In Three Years	14		'	'
Contractual Commitments, Payments Due In Four Years	14		'	'
Contractual Commitments, Payments Due In Five Years	33		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	50		'	'
Operations And Maintenance Mesquite Power [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	2		'	'
Contractual Commitments, Payments Due In Two Years	2		'	'
Contractual Commitments, Payments Due In Three Years	2		'	'
Contractual Commitments, Payments Due In Four Years	2		'	'
Contractual Commitments, Payments Due In Five Years	2		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	25		'	'
Contractual Commitments, Payments Due, Total	35		'	'
Sempra Natural Gas Construction [Member] | Sempra Natural Gas Segment [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	8		'	'
Contractual Commitments, Payments Due, Total	8		'	'
Energia Sierra Juarez Wind And Sasabe Guaymas Projects [Member]	'		'	'
Long-term Purchase Commitment [Line Items]	'		'	'
Contractual Commitments, Payments Due, Current	391		'	'
Contractual Commitments, Payments Due In Two Years	236		'	'
Contractual Commitments, Payments Due In Three Years	3		'	'
Contractual Commitments, Payments Due In Four Years	0		'	'
Contractual Commitments, Payments Due In Five Years	0		'	'
Unrecorded Unconditional Purchase Obligation, Due after Five Years	1		'	'
Contractual Commitments, Payments Due, Total	$631		'	'
[1]	Excludes amounts related to LNG purchase agreements as 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.

COMMITMENTS_AND_CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - CAPITAL LEASES (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2011
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	$195		$189	'
HQ Build To Suit Lease [Member]	'		'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'		'	'
Capital Leases, Future Minimum Payments Due, Current	0		'	'
Capital Leases, Future Minimum Payments Due in Two Years	4		'	'
Capital Leases, Future Minimum Payments Due in Three Years	10		'	'
Capital Leases, Future Minimum Payments Due in Four Years	10		'	'
Capital Leases, Future Minimum Payments Due in Five Years	10		'	'
Capital Leases, Future Minimum Payments Due Thereafter	277		'	'
Capital Leases, Future Minimum Payments Due, Total	311		'	'
Utility Fleet Leases [Member]	'		'	'
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	5		11	'
Capital Leases, Future Minimum Payments Due [Abstract]	'		'	'
Capital Leases, Future Minimum Payments Due, Current	4		'	'
Capital Leases, Future Minimum Payments Due in Two Years	1		'	'
Capital Leases, Future Minimum Payments Due, Total	5		'	'
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments, Total	5	[1]	'	'
Capital Leases, Income Statement of Lessee [Abstract]	'		'	'
Capital Leases, Income Statement, Amortization Expense	7		13	15
Power Purchase Agreements [Member]	'		'	'
Capital Leases, Future Minimum Payments Due [Abstract]	'		'	'
Capital Leases, Future Minimum Payments Due, Current	24		'	'
Capital Leases, Future Minimum Payments Due in Two Years	24		'	'
Capital Leases, Future Minimum Payments Due in Three Years	24		'	'
Capital Leases, Future Minimum Payments Due in Four Years	24		'	'
Capital Leases, Future Minimum Payments Due in Five Years	24		'	'
Capital Leases, Future Minimum Payments Due Thereafter	394		'	'
Capital Leases, Future Minimum Payments Due, Total	514	[2]	'	'
Capital Leases, Future Minimum Payments, Executory Costs	-84		'	'
Capital Leases, Future Minimum Payments, Interest Included in Payments	-254	[3]	'	'
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments, Total	176	[4]	'	'
Capital Leases, Current portion	3		'	'
Capital leases, Noncurrent portion	173		'	'
San Diego Gas and Electric Company and Subsidiary [Member]	'		'	'
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	179		185	'
San Diego Gas and Electric Company and Subsidiary [Member] | Utility Fleet Leases [Member]	'		'	'
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	3		7	'
Capital Leases, Future Minimum Payments Due [Abstract]	'		'	'
Capital Leases, Future Minimum Payments Due, Current	2		'	'
Capital Leases, Future Minimum Payments Due in Two Years	1		'	'
Capital Leases, Future Minimum Payments Due, Total	3		'	'
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments, Total	3	[1]	'	'
Capital Leases, Income Statement of Lessee [Abstract]	'		'	'
Capital Leases, Income Statement, Amortization Expense	4		7	7
San Diego Gas and Electric Company and Subsidiary [Member] | Power Purchase Agreements [Member]	'		'	'
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	176		'	'
Capital Lease Term (Years)	25		'	'
Capital Leases, Income Statement of Lessee [Abstract]	'		'	'
Capital Leases, Income Statement, Amortization Expense	2		2	2
Southern California Gas Company [Member]	'		'	'
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	2		4	'
Southern California Gas Company [Member] | Utility Fleet Leases [Member]	'		'	'
Capital Lease Obligations [Abstract]	'		'	'
Capital lease obligations	2		4	'
Capital Leases, Future Minimum Payments Due [Abstract]	'		'	'
Capital Leases, Future Minimum Payments Due, Current	2		'	'
Capital Leases, Future Minimum Payments Due in Two Years	0		'	'
Capital Leases, Future Minimum Payments Due, Total	2		'	'
Capital Leases, Future Minimum Payments, Present Value of Net Minimum Payments, Total	2	[1]	'	'
Capital Leases, Income Statement of Lessee [Abstract]	'		'	'
Capital Leases, Income Statement, Amortization Expense	$3		$6	$8
[1]	Excludes negligible amounts of interest.
[2]	This amount will be recorded over the lives of the leases as Cost of Electric Fuel and Purchased Power on Sempra Energybs and SDG&Ebs Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs.
[3]	Amount necessary to reduce net minimum lease payments to present value at the inception of the leases.
[4]	Includes $3 million in Current Portion of Long-Term Debt and $173 million in Long-Term Debt on Sempra Energybs and SDG&Ebs Consolidated Balance Sheets at December 31, 2013.

COMMITMENTS_AND_CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - OPERATING LEASES (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Operating Leases, Rent Expense [Abstract]	'	'	'
Operating Leases, Rent Expense	$81	$74	$77
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Current	85	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	83	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	71	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	74	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	69	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	576	'	'
Operating Leases, Future Minimum Payments Due, Total	958	'	'
Operating Leases, Annual Rent Escalation [Abstract]	'	'	'
Operating Leases, Annual Rent Escalation, Range, Minimum	2.00%	'	'
Operating Leases, Annual Rent Escalation, Range, Maximum	6.00%	'	'
Utility Subsidiaries [Member]	'	'	'
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
Operating Leases, Aggregate Maximum Lease Limit	125	'	'
Operating Leases, Lease Limit Utilized	113	'	'
San Diego Gas and Electric Company and Subsidiary [Member]	'	'	'
Operating Leases, Rent Expense [Abstract]	'	'	'
Operating Leases, Rent Expense	23	20	18
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Current	23	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	22	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	22	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	20	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	17	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	91	'	'
Operating Leases, Future Minimum Payments Due, Total	195	'	'
Operating Leases, Annual Rent Escalation [Abstract]	'	'	'
Operating Leases, Annual Rent Escalation, Range, Minimum	4.00%	'	'
Operating Leases, Annual Rent Escalation, Range, Maximum	6.00%	'	'
Southern California Gas Company [Member]	'	'	'
Operating Leases, Rent Expense [Abstract]	'	'	'
Operating Leases, Rent Expense	31	26	35
Operating Leases, Future Minimum Payments Due [Abstract]	'	'	'
Operating Leases, Future Minimum Payments Due, Current	32	'	'
Operating Leases, Future Minimum Payments, Due in Two Years	32	'	'
Operating Leases, Future Minimum Payments, Due in Three Years	25	'	'
Operating Leases, Future Minimum Payments, Due in Four Years	30	'	'
Operating Leases, Future Minimum Payments, Due in Five Years	28	'	'
Operating Leases, Future Minimum Payments, Due Thereafter	174	'	'
Operating Leases, Future Minimum Payments Due, Total	$321	'	'
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_CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) (USD $)	12 Months Ended
	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Environmental Issues [Line Items]	'		'		'
Environmental Costs Recognized, Capitalized in Period	$31,000,000	[1]	$92,000,000	[1]	$144,000,000	[1]
San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'
Environmental Issues [Line Items]	'		'		'
Environmental Costs Recognized, Capitalized in Period	13,000,000		77,000,000		130,000,000
Environmental Site Liabilities Covered By Mechanism	5,500,000		'		'
Southern California Gas Company [Member]	'		'		'
Environmental Issues [Line Items]	'		'		'
Environmental Costs Recognized, Capitalized in Period	15,000,000		12,000,000		13,000,000
Environmental Site Liabilities Covered By Mechanism	$15,100,000		'		'
[1]	In cases of non-wholly owned affiliates, includes only our share.

COMMITMENTS_AND_CONTINGENCIES_6

COMMITMENTS AND CONTINGENCIES - SITE CONTINGENCY (Details) (USD $)	12 Months Ended
	Dec. 31, 2013
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	$24,900,000
Site Contingency, S D G E [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	5,600,000	[1],[2]
Estimated mitigation costs, recoverable in rates	14,000,000
Site Contingency, So Cal Gas [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	15,100,000	[2]
Site Contingency, Other Sempra Energy [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	4,200,000
Manufactured Gas Sites [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	16,900,000
Manufactured Gas Sites [Member] | Site Contingency, S D G E [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	0	[1],[2]
Site Contingency, Sites Completed	3	[3]
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	14,700,000	[2]
Site Contingency, Sites Completed	39	[3]
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	2,200,000
Waste Disposal Sites [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	1,400,000	[4]
Waste Disposal Sites [Member] | Site Contingency, S D G E [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	0	[1],[2],[4]
Site Contingency, Sites Completed	2	[3]
Site Contingency, Sites In Process	3
Waste Disposal Sites [Member] | Site Contingency, So Cal Gas [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	200,000	[2],[4]
Site Contingency, Sites Completed	5	[3]
Site Contingency, Sites In Process	1
Waste Disposal Sites [Member] | Site Contingency, Other Sempra Energy [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	1,200,000	[4]
Former Fossil Fueled Power Plants [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	5,200,000
Former Fossil Fueled Power Plants [Member] | Site Contingency, S D G E [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	5,200,000	[1],[2]
Former Fossil Fueled Power Plants [Member] | Site Contingency, So Cal Gas [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	0	[2]
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	1,400,000
Other Hazardous Waste Sites [Member] | Site Contingency, S D G E [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	400,000	[1],[2]
Other Hazardous Waste Sites [Member] | Site Contingency, So Cal Gas [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	200,000	[2]
Other Hazardous Waste Sites [Member] | Site Contingency, Other Sempra Energy [Member]	'
Site Contingency [Line Items]	'
Site Contingency, Accrual, Undiscounted Amount	$800,000
[1]	Does not include SDG&Ebs liability for SONGS marine mitigation.
[2]	This includes $5.5 million at SDG&E and $15.1 million at SoCalGas related to hazardous waste sites subject to the Hazardous Waste Collaborative mechanism approved by the CPUC in 1994. This mechanism permits Californiabs IOUs, including the California Utilities, to recover in rates 90 percent of hazardous waste cleanup costs and related third-party litigation costs, and 70 percent of the related insurance-litigation expenses for certain sites. In addition, the California Utilities have the opportunity to retain a percentage of any recoveries from insurance carriers and other third parties to offset the cleanup and associated litigation costs not recovered in rates.
[3]	There may be on-going compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.
[4]	Sites for which we have been identified as a Potentially Responsible Party.

COMMITMENTS_AND_CONTINGENCIES_7

COMMITMENTS AND CONTINGENCIES - LEGAL (Details) (Loss from Catastrophes [Member], S D G E Segment [Member], USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Loss from Catastrophes [Member] | S D G E Segment [Member]	'	'	'
Loss From Loss Contingencies [Line Items]	'	'	'
Loss Contingency, Loss In Period, Net Of Income Tax Effect	$300	($6,000)	($13,000)

COMMITMENTS_AND_CONTINGENCIES_8

COMMITMENTS AND CONTINGENCIES - LOSS ON CONTINGENCIES (Details)	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Apr. 30, 2010	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
	USD ($)	San Diego Gas and Electric Company and Subsidiary [Member]	Southern California Gas Company [Member]	Loss from Catastrophes [Member]	Loss from Catastrophes [Member]	Liberty Gas Storage Litigation [Member]	HMRC VAT Claim [Member]	Sunrise Powerlink Construction [Member]	Sunrise San Diego County Mechanics Lien [Member]	Sunrise Imperial County Mechanics Lien [Member]	Rim Rock [Member]
		USD ($)	USD ($)	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	USD ($)	Parent Company [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]
				USD ($)	USD ($)		GBP (£)	USD ($)	USD ($)	USD ($)	USD ($)
Loss Contingencies [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Loss Contingency Accrual, at Carrying Value	$154,000,000	$146,000,000	$100,000	'	$104,000,000	'	'	'	'	'	'
Loss Contingency, Accrual Carrying Value, Current	'	'	'	'	63,000,000	'	'	'	'	'	'
Loss Contingency, Accrual Carrying Value, Noncurrent	'	'	'	'	41,000,000	'	'	'	'	'	'
Payments for Legal Settlements	'	'	'	14,750,000	'	'	'	'	'	'	'
Litigation Settlement, Gross	'	'	'	'	824,000,000	'	'	'	'	'	'
Claims Payments By Insurers To All Claimants	'	'	'	'	1,600,000,000	'	'	'	'	'	'
Percentage of Total Claims to be Paid by Company	'	'	'	'	57.50%	'	'	'	'	'	'
Total Individual And Business Claims	'	'	'	'	380,000,000	'	'	'	'	'	'
Liability Insurance Coverage, Maximum	'	1,100,000,000	'	'	'	'	'	'	'	'	'
Loss Contingency, Monetary Damages Sought	'	'	'	'	'	56,700,000	'	'	'	'	'
Loss Contingency, Counterclaim Minimum	'	'	'	'	'	215,000,000	'	'	'	'	'
Payments For Legal Settlements In Excess Of Recovered Amounts	'	'	'	'	344,000,000	'	'	'	'	'	'
VAT Tax Claim Amount	'	'	'	'	'	'	86,000,000	'	'	'	'
Regulatory Assets Arising From Wildfire Litigation Costs	'	'	'	'	330,000,000	'	'	'	'	'	'
Portion of Regulatory Assets Arising From Wildfire Litigation Related To CPUC-Regulated Operations	'	'	'	'	315,000,000	'	'	'	'	'	'
Potential After-Tax Earnings Impact	'	186,000,000	'	'	'	'	'	'	'	'	'
Fixed Fee Contract Amount	'	'	'	'	'	'	'	456,000,000	'	'	'
Unbilled Change Orders	'	'	'	'	'	'	'	180,300,000	99,200,000	81,100,000	'
Estimated Tax Equity Investment	'	'	'	'	'	'	'	'	'	'	$285,000,000

COMMITMENTS_AND_CONTINGENCIES_9

COMMITMENTS AND CONTINGENCIES - NUCLEAR FUEL DISPOSAL (Details) (San Diego Gas and Electric Company and Subsidiary [Member], USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
San Diego Gas and Electric Company and Subsidiary [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

Recovered_Sheet1

COMMITMENTS AND CONTINGENCIES - SCHEDULE OF NUCLEAR INSURANCE (Details) (San Diego Gas and Electric Company and Subsidiary [Member], USD $)	Dec. 31, 2013
San Diego Gas and Electric Company and Subsidiary [Member]	'
Schedule Of Nuclear Insurance [Line Items]	'
Nuclear Liability Insurance Coverage, Maximum	$375,000,000
Secondary Financial Protection, Maximum	13,200,000,000
Secondary Financial Protection, Company Contribution, Maximum	50,930,000
Secondary Financial Protection, Company Contribution, Annual Maximum	7,600,000
Nuclear Property Insurance Coverage, Maximum	2,750,000,000
Nuclear Property Damage Insurance, Premium Assessment	9,700,000
Nuclear Property Insurance Terrorism Coverage, Maximum	3,240,000,000
Nuclear Property Damage Insurance, Deductible Per Event	$2,500,000

SEGMENT_INFORMATION_Details

SEGMENT INFORMATION (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Entity-Wide Revenue, Major Customer [Abstract]	'		'		'
Entity-Wide Revenue, Major Customer, Percentage	'		'		6.00%
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	$10,557		$9,647		$10,036
Segment reporting information, Percentage of Total Consolidated Revenues	100.00%		100.00%		100.00%
Segment reporting information, Interest Expense	559		493		465
Segment reporting information, Interest Income	20		24		26
Segment reporting information, Depreciation and Amortization	1,113		1,090		976
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	100.00%		100.00%		100.00%
Segment reporting information, Income Tax Expense (Benefit)	366		59		394
Segment reporting information, earnings (losses)	1,001		859		1,331
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 & Equipment	2,572		2,956		2,844
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	100.00%		100.00%		100.00%
Segment reporting information, Assets	37,244		36,499		33,249
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, Revenues	4,066		3,694		3,373
Segment reporting information, Percentage of Total Consolidated Revenues	39.00%		38.00%		34.00%
Segment reporting information, Interest Expense	197		173		142
Segment reporting information, Interest Income	1		0		0
Segment reporting information, Depreciation and Amortization	494		490		422
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	44.00%		45.00%		43.00%
Segment reporting information, Income Tax Expense (Benefit)	191		190		237
Segment reporting information, earnings (losses)	404	[1]	484	[1]	431	[1]
Segment reporting information, Percentage of Consolidated Earnings (Losses)	41.00%		56.00%		32.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	978		1,237		1,831
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	38.00%		42.00%		64.00%
Segment reporting information, Assets	15,377		14,744		13,555
Segment reporting information, Percentage of Consolidated Assets	41.00%		40.00%		41.00%
Segment Reporting Information, Intersegment Revenue	10		8		6
So Cal Gas Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	3,736		3,282		3,816
Segment reporting information, Percentage of Total Consolidated Revenues	35.00%		34.00%		38.00%
Segment reporting information, Interest Expense	69		68		69
Segment reporting information, Interest Income	0		0		1
Segment reporting information, Depreciation and Amortization	383		362		331
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	35.00%		33.00%		34.00%
Segment reporting information, Income Tax Expense (Benefit)	116		79		143
Segment reporting information, earnings (losses)	364	[2]	289	[2]	287	[2]
Segment reporting information, Percentage of Consolidated Earnings (Losses)	37.00%		34.00%		22.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	762		639		683
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	30.00%		22.00%		24.00%
Segment reporting information, Assets	9,147		9,071		8,475
Segment reporting information, Percentage of Consolidated Assets	25.00%		25.00%		25.00%
Segment Reporting Information, Intersegment Revenue	70		46		53
All Other Segments [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Interest Expense	241		251		233
Segment reporting information, Interest Income	0		4		0
Segment reporting information, Depreciation and Amortization	12		11		11
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	1.00%		1.00%		1.00%
Segment reporting information, Income Tax Expense (Benefit)	-89		-141		-109
Segment reporting information, earnings (losses)	-168		-55		-126
Segment reporting information, Percentage of Consolidated Earnings (Losses)	-17.00%		-6.00%		-10.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	2		4		4
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	0.00%		0.00%		0.00%
Segment reporting information, Assets	838		818		442
Segment reporting information, Percentage of Consolidated Assets	2.00%		2.00%		1.00%
Adjustments and Intercompany Eliminations Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	-2		-2		-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	-131		-159		-125
Segment reporting information, Interest Income	-105		-58		-32
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	0		0		-205	[3]
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	0.00%		0.00%		-7.00%
Intersegment Revenues Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	-403	[4]	-372	[4]	-621	[4]
Segment reporting information, Percentage of Total Consolidated Revenues	-4.00%		-4.00%		-6.00%
Intersegment Receivables Segment [Member]	'		'		'
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Assets	-3,314		-1,619		-1,654
Segment reporting information, Percentage of Consolidated Assets	-9.00%		-4.00%		-5.00%
Sempra South American Utilities Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	1,495		1,441		1,080
Segment reporting information, Percentage of Total Consolidated Revenues	14.00%		15.00%		11.00%
Segment reporting information, Interest Expense	27		32		34
Segment reporting information, Interest Income	14		15		22
Segment reporting information, Depreciation and Amortization	59		56		40
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	5.00%		5.00%		4.00%
Segment reporting information, Income Tax Expense (Benefit)	67		78		42
Segment reporting information, earnings (losses)	153		164		425
Segment reporting information, Percentage of Consolidated Earnings (Losses)	15.00%		19.00%		32.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	200		183		110
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	8.00%		6.00%		4.00%
Segment reporting information, Assets	3,531		3,310		2,981
Segment reporting information, Percentage of Consolidated Assets	10.00%		9.00%		9.00%
Sempra Mexico Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	675		605		736
Segment reporting information, Percentage of Total Consolidated Revenues	6.00%		6.00%		7.00%
Segment reporting information, Interest Expense	17		8		19
Segment reporting information, Interest Income	2		2		1
Segment reporting information, Depreciation and Amortization	63		62		63
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	6.00%		6.00%		6.00%
Segment reporting information, Income Tax Expense (Benefit)	60		73		37
Segment reporting information, earnings (losses)	122		157		192
Segment reporting information, Percentage of Consolidated Earnings (Losses)	12.00%		18.00%		14.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	371		45		16
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	14.00%		2.00%		0.00%
Segment reporting information, Assets	3,246		2,591		2,502
Segment reporting information, Percentage of Consolidated Assets	9.00%		7.00%		8.00%
Segment Reporting Information, Intersegment Revenue	91		108		300
Sempra Renewables Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	82		68		22
Segment reporting information, Percentage of Total Consolidated Revenues	1.00%		1.00%		0.00%
Segment reporting information, Interest Expense	23		22		13
Segment reporting information, Interest Income	20		6		0
Segment reporting information, Depreciation and Amortization	21		16		6
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	2.00%		1.00%		1.00%
Segment reporting information, Income Tax Expense (Benefit)	-19		-63		-28
Segment reporting information, earnings (losses)	62		61		7
Segment reporting information, Percentage of Consolidated Earnings (Losses)	6.00%		7.00%		1.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	176		717		248
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	7.00%		24.00%		9.00%
Segment reporting information, Assets	1,219		2,439		1,210
Segment reporting information, Percentage of Consolidated Assets	3.00%		7.00%		4.00%
Sempra Natural Gas Segment [Member]	'		'		'
Segment Reporting Information, Profit (Loss) [Abstract]	'		'		'
Segment reporting information, Revenues	908		931		1,632
Segment reporting information, Percentage of Total Consolidated Revenues	9.00%		10.00%		16.00%
Segment reporting information, Interest Expense	116		98		80
Segment reporting information, Interest Income	88		55		34
Segment reporting information, Depreciation and Amortization	81		93		103
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	7.00%		9.00%		11.00%
Segment reporting information, Income Tax Expense (Benefit)	40		-157		72
Segment reporting information, earnings (losses)	64		-241		115
Segment reporting information, Percentage of Consolidated Earnings (Losses)	6.00%		-28.00%		9.00%
Segment Reporting Information, Additional Information [Abstract]	'		'		'
Segment reporting information, Expenditures for Property, Plant & Equipment	83		131		157
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	3.00%		4.00%		6.00%
Segment reporting information, Assets	7,200		5,145		5,738
Segment reporting information, Percentage of Consolidated Assets	19.00%		14.00%		17.00%
Segment Reporting Information, Intersegment Revenue	$232		$210		$262
[1]	After preferred dividends and 2013 call premium on preferred stock.
[2]	After preferred dividends.
[3]	Amount represents elimination of intercompany sale of El Dorado power plant (renamed Desert Star Energy Center) in 2011, by Sempra Natural Gas to SDG&E.
[4]	Revenues for reportable segments include intersegment revenues of $10 million, $70 million, $91 million and $232 million for 2013, $8 million, $46 million, $108 million and $210 million for 2012, and $6 million, $53 million, $300 million and $262 million for 2011 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.

SEGMENT_INFORMATION_2_Details

SEGMENT INFORMATION 2 (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013		Dec. 31, 2012		Dec. 31, 2011
Entity-Wide Disclosure On Geographic Areas [Line Items]	'		'		'
Assets, geographical	$27,035	[1]	$26,707	[1]	$25,136	[1]
Assets. percentage geographical	100.00%		100.00%		100.00%
Revenues, geographical	10,557		9,647		10,036
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	22,654	[1]	22,698	[1]	21,405	[1]
Assets. percentage geographical	84.00%		85.00%		85.00%
Revenues, geographical	8,478		7,711		8,521
Revenues, percentage geographical	80.00%		80.00%		85.00%
Entity-Wide Disclosure On Geographic Areas Mexico [Member]	'		'		'
Entity-Wide Disclosure On Geographic Areas [Line Items]	'		'		'
Assets, geographical	2,597	[1]	2,219	[1]	2,189	[1]
Assets. percentage geographical	9.00%		8.00%		9.00%
Revenues, geographical	584		495		435
Revenues, percentage geographical	6.00%		5.00%		4.00%
Entity-Wide Disclosure On Geographic Areas, South America [Member]	'		'		'
Entity-Wide Disclosure On Geographic Areas [Line Items]	'		'		'
Assets, geographical	1,784	[1]	1,790	[1]	1,542	[1]
Assets. percentage geographical	7.00%		7.00%		6.00%
Revenues, geographical	$1,495		$1,441		$1,080
Revenues, percentage geographical	14.00%		15.00%		11.00%
[1]	Includes net property, plant and equipment and investments.

SELECTED_QUARTERLY_FINANCIAL_D

SELECTED QUARTERLY FINANCIAL DATA (Details) (USD $)	3 Months Ended							6 Months Ended	12 Months Ended	3 Months Ended
In Millions, unless otherwise specified	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2012	Jun. 30, 2012	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2012	Jun. 30, 2012	Dec. 31, 2011	Dec. 31, 2013	Jun. 30, 2013
					San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	San Diego Gas and Electric Company and Subsidiary [Member]	Southern California Gas Company [Member]	Southern California Gas Company [Member]
Significant Items Affecting Quarterly Results [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Quarterly Financial Data, Loss from SONGS plant closure (pre-tax)	$200	'	'	'	$200	'	'	'	'	'	'
Quarterly Financial Data, Loss from SONGS plant closure (after-tax)	119	'	'	'	119	'	'	'	'	'	'
Quarterly Financial Data, Gain on sale of mesquite power (pre-tax)	'	74	'	'	'	'	'	'	'	'	'
Quarterly Financial Data, Gain on sale of mesquite power (after-tax)	'	44	'	'	'	'	'	'	'	'	'
Quarterly Financial Data, Impact on revenue from retroactive application of 2012 GRC	131	'	'	'	90	'	'	'	'	'	'
Quarterly Financial Data, Impact on net income and earnings from retroactive application of 2012 GRC	106	'	'	'	69	'	'	'	'	'	'
Quarterly Financial Data, Incremental cost of renewable energy and other purchased power	'	'	'	'	19	'	'	'	'	'	'
Quarterly Financial Data, Income tax benefit related to life insurance held to term	54	'	'	'	'	'	'	'	'	'	'
Quarterly Financial Data, Higher favorable resolution of prior year tax issues	'	'	'	'	'	'	'	'	'	12	'
Quarterly Financial Data, Income tax benefit related to repairs expenditures recorded for first six months of 2012	'	'	'	'	'	'	'	11	'	'	'
Quarterly Financial Data, Income tax benefit related to repairs expenditures recorded for full-year 2011	'	'	'	'	'	'	'	'	22	'	'
Quarterly Financial Data, Increased CPUC base operating margin as result of 2012 GRC	'	'	'	'	'	'	'	'	'	19	'
Quarterly Financial Data, Purchased power to replace power from SONGS closure	'	'	'	'	18	27	'	'	'	'	'
Quarterly Financial Data, Other purchased power	'	'	'	'	94	'	'	'	'	'	'
Quarterly Financial Data, Income tax expense related to corporate reorganization	'	63	'	'	'	'	'	'	'	'	'
Quarterly Financial Data, Retroactive application of 2012 GRC (pre-tax)	'	'	'	'	'	'	'	'	'	'	41
Quarterly Financial Data, Retroactive application of 2012 GRC (after-tax)	'	'	'	'	'	'	'	'	'	'	37
Quarterly Financial Data, Loss on impairment of Rockies Express	'	'	100	300	'	'	'	'	'	'	'
Quarterly Financial Data, Loss on impairment of Rockies Express, after tax	'	'	60	179	'	'	'	'	'	'	'
Quarterly Financial Data, Increase in operating revenues due to higher authorized revenues from electric transmission	67	68	'	'	67	68	'	'	'	'	'
Quarterly Financial Data, Increase in cost of electric fuel and purchased power	112	46	'	'	112	46	'	'	'	'	'
Quarterly Financial Data, Income tax benefit related to repair expenditures	'	'	'	'	'	'	$33	'	'	$26	'

SELECTED_QUARTERLY_FINANCIAL_D1

SELECTED QUARTERLY FINANCIAL DATA 2 (Details) (USD $)	3 Months Ended																12 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Dec. 31, 2013		Sep. 30, 2013		Jun. 30, 2013		Mar. 31, 2013		Dec. 31, 2012		Sep. 30, 2012		Jun. 30, 2012		Mar. 31, 2012		Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Selected Quarterly Financial Information [Line Items]	'		'		'		'		'		'		'		'		'	'	'
Quarterly Financial Data, Revenues	$2,705		$2,551		$2,651		$2,650		$2,668		$2,507		$2,089		$2,383		'	'	'
Quarterly Financial Data, Expenses And Other Income	2,357		2,119		2,353		2,298		2,359		2,178		2,141		2,026		'	'	'
Quarterly Financial Data, Net Income	320		323		267		178		305		290		74		251		'	'	'
Quarterly Financial Data, Earnings	282		296		245		178		293		268		62		236		1,001	859	1,331
Quarterly Financial Data, Dividends On Preferred Stock	0		0		'		0		'		'		'		'		'	'	'
Quarterly Financial Data, Net Income Per Share, Basic	$1.31	[1]	$1.32	[1]	$1.10	[1]	$0.73	[1]	$1.26	[1]	$1.20	[1]	$0.31	[1]	$1.04	[1]	'	'	'
Quarterly Financial Data, Earnings Per Share, Basic	$1.15	[1]	$1.21	[1]	$1	[1]	$0.73	[1]	$1.21	[1]	$1.11	[1]	$0.26	[1]	$0.98	[1]	$4.10	$3.56	$5.55
Quarterly Financial Data, Weighted Average Number Of Shares Outstanding, Basic	244,400	[1]	244,100	[1]	243,600	[1]	243,300	[1]	242,000	[1]	241,700	[1]	241,100	[1]	240,600	[1]	243,863	241,347	239,720
Quarterly Financial Data, Net Income Per Share, Diluted	$1.28	[1]	$1.29	[1]	$1.07	[1]	$0.72	[1]	$1.23	[1]	$1.18	[1]	$0.30	[1]	$1.02	[1]	'	'	'
Quarterly Financial Data, Earnings Per Share, Diluted	$1.13	[1]	$1.19	[1]	$0.98	[1]	$0.72	[1]	$1.18	[1]	$1.09	[1]	$0.25	[1]	$0.97	[1]	$4.01	$3.48	$5.51
Quarterly Financial Data, Weighted Average Number Of Shares Outstanding, Diluted	249,900	[1]	249,300	[1]	248,500	[1]	247,500	[1]	247,600	[1]	245,800	[1]	246,300	[1]	243,800	[1]	249,332	246,693	241,523
San Diego Gas and Electric Company and Subsidiary [Member]	'		'		'		'		'		'		'		'		'	'	'
Selected Quarterly Financial Information [Line Items]	'		'		'		'		'		'		'		'		'	'	'
Quarterly Financial Data, Revenues	1,000		1,063		1,064		939		988		1,092		780		834		'	'	'
Quarterly Financial Data, Expenses And Other Income	774		800		939		771		796		822		611		656		'	'	'
Quarterly Financial Data, Operating Income	226		263		125		168		192		270		169		178		'	'	'
Quarterly Financial Data, Net Income	142		139		73		81		114		188		101		112		'	'	'
Quarterly Financial Data, (Earnings) Losses Attributable To Noncontrolling Interests	-23		-5		-7		11		-3		-12		-5		-6		'	'	'
Quarterly Financial Data, Earnings	119		134		66		92		111		176		96		106		411	489	436
Quarterly Financial Data, Call Premium On Preferred Stock	0		-3		0		0		'		'		'		'		'	'	'
Quarterly Financial Data, Dividends On Preferred Stock	0		-2		-1		-1		-1		-2		-1		-1		'	'	'
Quarterly Financial Data, Earnings Attributable To Common Shares	119		129		65		91		110		174		95		105		'	'	'
Southern California Gas Company [Member]	'		'		'		'		'		'		'		'		'	'	'
Selected Quarterly Financial Information [Line Items]	'		'		'		'		'		'		'		'		'	'	'
Quarterly Financial Data, Revenues	1,042		807		904		983		954		728		720		880		'	'	'
Quarterly Financial Data, Expenses And Other Income	920		652		725		900		867		609		625		761		'	'	'
Quarterly Financial Data, Operating Income	122		155		179		83		87		119		95		119		'	'	'
Quarterly Financial Data, Net Income	98		102		119		46		99		71		54		66		'	'	'
Quarterly Financial Data, Earnings	'		'		'		'		'		'		'		'		365	290	288
Quarterly Financial Data, Dividends On Preferred Stock	'		'		-1		'		0		0		-1		0		'	'	'
Quarterly Financial Data, Earnings Attributable To Common Shares	$98		$102		$118		$46		$99		$71		$53		$66		'	'	'
[1]	Earnings per share are computed independently for each of the quarters and therefore may not sum to the total for the year.

SUBSEQUENT_EVENT_Details

SUBSEQUENT EVENT (Details) (USD $)	Jan. 31, 2014
In Millions, unless otherwise specified
Subsequent Event (Details) [Abstract]	'
Book Value Held For Sale	$287

SCHEDULE_I_CONDENSED_FINANCIAL2

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, STATEMENT OF OPERATIONS (Details) (USD $)	12 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule I, Condensed Financial Information of Parent, Statement of Operations [Abstract]	'	'	'
Schedule I, Condensed Financial Information of Parent, Interest income	$42	$83	$109
Schedule I, Condensed Financial Information of Parent, Interest expense	-239	-247	-242
Schedule I, Condensed Financial Information of Parent, Operation and maintenance	-63	-68	-64
Schedule I, Condensed Financial Information of Parent, Other income, net	41	66	42
Schedule I, Condensed Financial Information of Parent, Income tax benefits	117	145	82
Schedule I, Condensed Financial Information of Parent, Loss before equity in earnings of subsidiaries	-102	-21	-73
Schedule I, Condensed Financial Information of Parent, Equity in earnings of subsidiaries, net of income taxes	1,103	880	1,404
Schedule I, Condensed Financial Information of Parent, Net income/earnings	$1,001	$859	$1,331
Schedule I, Condensed Financial Information of Parent, Basic earnings per common share	$4.10	$3.56	$5.55
Schedule I, Condensed Financial Information of Parent, Weighted average number of shares outstanding, Basic	243,863	241,347	239,720
Schedule I, Condensed Financial Information of Parent, Diluted earnings per common share	$4.01	$3.48	$5.51
Schedule I, Condensed Financial Information of Parent, Weighted average number of shares outstanding, Diluted	249,332	246,693	241,523

SCHEDULE_I_CONDENSED_FINANCIAL3

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, STATEMENT OF COMPREHENSIVE INCOME (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Before-Tax Amount [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Schedule of Comprehensive Income [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Net Income	$884	$714	$1,249
Schedule I, Condensed Financial Information of Parent, Foreign Currency Translation Adjustments	111	119	-79
Schedule I, Condensed Financial Information of Parent, Reclassification To Net Income Of Foreign Currency Translation Adjustment Related To Equity Method Investments	'	'	-54
Schedule I, Condensed Financial Information of Parent, Available For Sale Securities	'	'	-2
Schedule I, Condensed Financial Information of Parent, Pension And Other Postretirement Benefits	47	-4	-20
Schedule I, Condensed Financial Information of Parent, Financial Instruments	13	-6	-26
Schedule I, Condensed Financial Information of Parent, Total Other Comprehensive Income Loss	171	109	-181
Schedule I, Condensed Financial Information of Parent, Total Comprehensive Income	1,055	823	1,068
Income Tax (Expense) Benefit [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Schedule of Comprehensive Income [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Net Income	117	145	82
Schedule I, Condensed Financial Information of Parent, Foreign Currency Translation Adjustments	0	0	3
Schedule I, Condensed Financial Information of Parent, Reclassification To Net Income Of Foreign Currency Translation Adjustment Related To Equity Method Investments	'	'	0
Schedule I, Condensed Financial Information of Parent, Available For Sale Securities	'	'	1
Schedule I, Condensed Financial Information of Parent, Pension And Other Postretirement Benefits	-19	2	8
Schedule I, Condensed Financial Information of Parent, Financial Instruments	-4	2	10
Schedule I, Condensed Financial Information of Parent, Total Other Comprehensive Income Loss	-23	4	22
Schedule I, Condensed Financial Information of Parent, Total Comprehensive Income	94	149	104
Net-Of-Tax Amount [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Schedule of Comprehensive Income [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Net Income	1,001	859	1,331
Schedule I, Condensed Financial Information of Parent, Foreign Currency Translation Adjustments	111	119	-76
Schedule I, Condensed Financial Information of Parent, Reclassification To Net Income Of Foreign Currency Translation Adjustment Related To Equity Method Investments	'	'	-54
Schedule I, Condensed Financial Information of Parent, Available For Sale Securities	'	'	-1
Schedule I, Condensed Financial Information of Parent, Pension And Other Postretirement Benefits	28	-2	-12
Schedule I, Condensed Financial Information of Parent, Financial Instruments	9	-4	-16
Schedule I, Condensed Financial Information of Parent, Total Other Comprehensive Income Loss	148	113	-159
Schedule I, Condensed Financial Information of Parent, Total Comprehensive Income	$1,149	$972	$1,172

SCHEDULE_I_CONDENSED_FINANCIAL4

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, BALANCE SHEETS (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Assets:	'	'
Schedule I, Condensed Financial Information of Parent, Cash and cash equivalents	$6	$18
Schedule I, Condensed Financial Information of Parent, Due from affiliates	132	125
Schedule I, Condensed Financial Information Of Parent Deferred Income Taxes Current	170	109
Schedule I, Condensed Financial Information of Parent, Other current assets	16	16
Schedule I, Condensed Financial Information of Parent, Total current assets	324	268
Schedule I, Condensed Financial Information of Parent, Investments in subsidiaries	13,866	12,545
Schedule I, Condensed Financial Information of Parent, Due from affiliates	802	1,759
Schedule I, Condensed Financial Information of Parent, Deferred income taxes	1,466	1,541
Schedule I, Condensed Financial Information of Parent, Other assets	555	576
Schedule I, Condensed Financial Information of Parent, Total assets	17,013	16,689
Liabilities and shareholders' equity:	'	'
Schedule I, Condensed Financial Information of Parent, Current portion of long-term debt	800	652
Schedule I, Condensed Financial Information of Parent, Current due to affiliates	273	539
Schedule I, Condensed Financial Information of Parent, Income taxes payable	64	26
Schedule I, Condensed Financial Information of Parent, Other current liabilities	276	260
Schedule I, Condensed Financial Information of Parent, Total current liabilities	1,413	1,477
Schedule I, Condensed Financial Information of Parent, Long-term debt	4,117	4,409
Schedule I, Condensed Financial Information of Parent, Other long-term liabilities	475	521
Schedule I, Condensed Financial Information of Parent, Shareholders' equity	11,008	10,282
Schedule I, Condensed Financial Information of Parent, Total liabilities and shareholders' equity	$17,013	$16,689

SCHEDULE_I_CONDENSED_FINANCIAL5

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, CASH FLOWS (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule I, Condensed Financial Information of Parent, Cash Flows [Abstract]	'	'	'
Schedule I, Condensed Financial Information of Parent, Net cash (used in) provided by operating activities	($131)	($809)	($287)
Schedule I, Condensed Financial Information of Parent, Dividends received from subsidiaries	50	250	50
Schedule I, Condensed Financial Information of Parent, Expenditures for property, plant and equipment	-1	-1	-2
Schedule I, Condensed Financial Information of Parent, Purchase of trust assets	-5	-6	-7
Schedule I, Condensed Financial Information of Parent, Proceeds from sales by trust	10	10	12
Schedule I, Condensed Financial Information Of Parent, Capital Contribution To Subsidiary	-6	0	-200
Schedule I, Condensed Financial Information of Parent, (Increase) decrease in loans to affiliates, net	962	-33	82
Schedule I, Condensed Financial Information of Parent, Cash (used in) provided by investing activities	1,010	220	-65
Schedule I, Condensed Financial Information of Parent, Common stock dividends paid	-606	-550	-440
Schedule I, Condensed Financial Information of Parent, Issuances of common stock	62	78	28
Schedule I, Condensed Financial Information of Parent, Repurchases of common stock	-45	-16	-18
Schedule I, Condensed Financial Information of Parent, Issuances of long-term debt	498	1,100	799
Schedule I, Condensed Financial Information of Parent, Payments on long-term debt	-650	-8	-24
Schedule I, Condensed Financial Information of Parent, (Decrease) increase in loans from affiliates, net	-147	0	-136
Schedule I, Condensed Financial Information of Parent, Other	-3	-8	-3
Schedule I, Condensed Financial Information of Parent, Cash provided by (used in) financing activities	-891	596	206
Schedule I, Condensed Financial Information of Parent, (Decrease) increase in cash and cash equivalents	-12	7	-146
Schedule I, Condensed Financial Information of Parent, Cash and cash equivalents, Beginning of period	18	11	157
Schedule I, Condensed Financial Information of Parent, Cash and cash equivalents, End of period	$6	$18	$11

SCHEDULE_I_CONDENSED_FINANCIAL6

SCHEDULE I, CONDENSED FINANCIAL INFORMATION OF PARENT, FOOTNOTES (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	$4,926	$5,069	'
Schedule I, Condensed Financial Information of Parent, Current portion of long-term debt	-800	-652	'
Schedule I, Condensed Financial Information of Parent, Unamortized discount on long-term debt	-9	-8	'
Schedule I, Condensed Financial Information of Parent, Long-term debt	4,117	4,409	'
Schedule I, Condensed Financial Information of Parent, Build-To-Suit Lease	14	0	'
Schedule I, Condensed Financial Information of Parent, Footnotes [Abstract]	'	'	'
Schedule I, Condensed Financial Information of Parent, Other Income, Net, Gain (Loss) on Investments	39	41	22
Schedule I, Condensed Financial Information of Parent, Long Term Debt, Maturities, Repayments of principal in next twelve months	800	'	'
Schedule I, Condensed Financial Information of Parent, Long Term Debt, Maturities, Repayments of principal in year three	750	'	'
Schedule I, Condensed Financial Information of Parent, Long Term Debt, Maturities, Repayments of principal in year four	600	'	'
Schedule I, Condensed Financial Information of Parent, Long Term Debt, Maturities, Repayments of principal in year five	500	'	'
Schedule I, Condensed Financial Information of Parent, Long Term Debt, Maturities, Repayments of principal after year five	2,300	'	'
Schedule I, Condensed Financial Information of Parent, Long-term debt, due February 2013 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	0	400	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	6.00%	'	'
Schedule I, Condensed Financial Information of Parent, Long-term debt, due November 2013 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	0	250	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	8.90%	'	'
Schedule I, Condensed Financial Information of Parent, Long-term debt, due March 2014 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	500	500	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	2.00%	'	'
Schedule I, Condensed Financial Information of Parent, Variable rate notes, due March 2014 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	300	300	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate at period end	1.01%	'	'
Schedule I, Condensed Financial Information of Parent, Long-term debt, due June 2018 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	500	500	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	6.15%	'	'
Schedule I, Condensed Financial Information of Parent, Long-term debt, due February 2019 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	500	500	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	9.80%	'	'
Schedule I, Condensed Financial Information of Parent, Long-term debt, due October 2039 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	750	750	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	6.00%	'	'
Schedule I, Condensed Financial Information of Parent, Market Value Adjustment For Interest Rate Swaps, Net [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Market value adjustment for interest rate swap	12	19	'
Schedule I Condensed Financial Information of Parent, Variable Rate Notes Due November 2013 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate at period end	8.05%	'	'
Schedule I Condensed Financial Information of Parent, Variable Rate Notes Due June 2016 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate at period end	4.46%	'	'
Schedule I Condensed Financial Information of Parent, Long-term debt, due June 2016 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	750	750	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	6.50%	'	'
Schedule I Condensed Financial Information of Parent, Long-Term Debt Due April 2017 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	600	600	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	2.30%	'	'
Schedule I Condensed Financial Information of Parent, Long-Term Debt Due October 2022 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	500	500	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	2.88%	'	'
Schedule I Condensed Financial Information of Parent, Long-Term Debt Due December 2023 [Member]	'	'	'
Schedule I, Condensed Financial Information of Parent, Long-Term Debt [Line Items]	'	'	'
Schedule I, Condensed Financial Information of Parent, Debt instrument principal outstanding	$500	$0	'
Schedule I, Condensed Financial Information of Parent, Debt instrument, interest rate, stated percentage	4.05%	'	'