Southern California Gas Company PFD 6% (SOCGM) 10-Q 5 May 15 2015 Q1 Quarterly report Financial data

DOCUMENT_AND_ENTITY_INFORMATIO

DOCUMENT AND ENTITY INFORMATION	3 Months Ended
	Mar. 31, 2015	Apr. 29, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	Sempra Energy
Document Type	10-Q
Document Period End Date	31-Mar-15
Amendment Flag	FALSE
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Shares Outstanding		247,580,092
Entity Central Index Key	1032208
Trading Symbol	SRE

CONDENSED_CONSOLIDATED_BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)	Mar. 31, 2015		Dec. 31, 2014
Current assets:
Cash and cash equivalents	$377,000,000		$570,000,000	[1]
Restricted cash	10,000,000		11,000,000	[1]
Trade accounts receivable	1,081,000,000		1,242,000,000	[1]
Other accounts and notes receivable	175,000,000		152,000,000	[1]
Due from unconsolidated affiliates	5,000,000		38,000,000	[1]
Income taxes receivable	53,000,000		45,000,000	[1]
Deferred income taxes, net current assets	244,000,000		305,000,000	[1]
Inventories	255,000,000		396,000,000	[1]
Regulatory balancing accounts, undercollected	718,000,000		746,000,000	[1]
Fixed-price contracts and other derivatives, current assets	89,000,000		93,000,000	[1]
Assets held for sale, power plant	295,000,000		293,000,000	[1]
Other current assets	354,000,000		293,000,000	[1]
Total current assets	3,656,000,000		4,184,000,000	[1]
Investments And Other Assets [Abstract]
Restricted cash, noncurrent	23,000,000		29,000,000	[1]
Due from unconsolidated affiliate	195,000,000		188,000,000	[1]
Other regulatory assets	3,046,000,000		3,031,000,000	[1]
Nuclear decommissioning trusts	1,150,000,000		1,131,000,000	[1]
Other investments	2,772,000,000		2,848,000,000	[1]
Goodwill	903,000,000		931,000,000	[1]
Other intangible assets	412,000,000		415,000,000	[1]
Sundry	682,000,000		561,000,000	[1]
Dedicated assets in support of certain benefit plans	476,000,000		512,000,000	[1]
Total investments and other assets	9,659,000,000		9,646,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	35,901,000,000		35,407,000,000	[1]
Less accumulated depreciation and amortization	-9,665,000,000		-9,505,000,000	[1]
Property, plant and equipment, net	26,236,000,000		25,902,000,000	[1]
Total assets	39,551,000,000		39,732,000,000	[1]
Current liabilities:
Short-term debt	795,000,000		1,733,000,000	[1]
Accounts payable - trade	907,000,000		1,198,000,000	[1]
Accounts payable - other	137,000,000		155,000,000	[1]
Due to unconsolidated affiliates	0		2,000,000	[1]
Dividends and interest payable	344,000,000		282,000,000	[1]
Accrued compensation and benefits	238,000,000		373,000,000	[1]
Current portion of long-term debt	477,000,000		469,000,000	[1]
Fixed-price contracts and other derivatives, current liabilities	50,000,000		55,000,000	[1]
Customer deposits	155,000,000		153,000,000	[1]
Other current liabilities	667,000,000		649,000,000	[1]
Total current liabilities	3,770,000,000		5,069,000,000	[1]
Long-term debt	13,012,000,000		12,167,000,000	[1]
Deferred Credits And Other Liabilities [Abstract]
Customer advances for construction	144,000,000		144,000,000	[1]
Pension and other postretirement benefit obligations, net of plan assets	1,077,000,000		1,064,000,000	[1]
Deferred income taxes, net noncurrent liabilities	3,019,000,000		3,003,000,000	[1]
Deferred investment tax credits	35,000,000		37,000,000	[1]
Regulatory liabilities arising from removal obligations	2,755,000,000		2,741,000,000	[1]
Asset retirement obligations	2,066,000,000		2,048,000,000	[1]
Fixed-price contracts and other derivatives, noncurrent liabilities	274,000,000		255,000,000	[1]
Deferred credits and other	1,118,000,000		1,104,000,000	[1]
Total deferred credits and other liabilities	10,488,000,000		10,396,000,000	[1]
Equity:
Preferred stock	0		0	[1]
Common stock	2,514,000,000		2,484,000,000	[1]
Retained earnings	9,603,000,000		9,339,000,000	[1]
Accumulated other comprehensive income (loss)	-613,000,000	[2]	-497,000,000	[1],[2]
Total shareholders' equity	11,504,000,000		11,326,000,000	[1]
Preferred stock of subsidiaries	20,000,000		20,000,000	[1]
Other noncontrolling interests	757,000,000		754,000,000	[1]
Total equity	12,281,000,000		12,100,000,000	[1]
Total liabilities and equity	39,551,000,000		39,732,000,000	[1]
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	23,000,000		8,000,000	[1]
Restricted cash	7,000,000		8,000,000	[1]
Trade accounts receivable	297,000,000		285,000,000	[1]
Other accounts and notes receivable	36,000,000		35,000,000	[1]
Due from unconsolidated affiliates	41,000,000		1,000,000	[1]
Inventories	69,000,000		73,000,000	[1]
Regulatory balancing accounts, undercollected	659,000,000		711,000,000	[1]
Other regulatory assets	101,000,000		54,000,000	[1]
Fixed-price contracts and other derivatives, current assets	44,000,000		44,000,000	[1]
Other current assets	107,000,000		125,000,000	[1]
Total current assets	1,384,000,000		1,344,000,000	[1]
Investments And Other Assets [Abstract]
Restricted cash, noncurrent	12,000,000		11,000,000	[1]
Deferred taxes recoverable in rates	833,000,000		824,000,000	[1]
Other regulatory assets	1,015,000,000		1,086,000,000	[1]
Nuclear decommissioning trusts	1,150,000,000		1,131,000,000	[1]
Sundry	369,000,000		282,000,000	[1]
Total investments and other assets	3,379,000,000		3,334,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	15,643,000,000		15,478,000,000	[1]
Less accumulated depreciation and amortization	-3,921,000,000		-3,860,000,000	[1]
Property, plant and equipment, net	11,722,000,000		11,618,000,000	[1]
Total assets	16,485,000,000		16,296,000,000	[1]
Current liabilities:
Short-term debt	0		246,000,000	[1]
Accounts payable - trade	310,000,000		441,000,000	[1]
Due to unconsolidated affiliates	2,000,000		21,000,000	[1]
Income taxes payable	30,000,000		30,000,000	[1]
Deferred income taxes, net current liabilities	114,000,000		53,000,000	[1]
Accrued compensation and benefits	66,000,000		124,000,000	[1]
Current portion of long-term debt	401,000,000		365,000,000	[1]
Fixed-price contracts and other derivatives, current liabilities	38,000,000		40,000,000	[1]
Customer deposits	72,000,000		71,000,000	[1]
Other current liabilities	242,000,000		237,000,000	[1]
Interest payable	51,000,000		40,000,000	[1]
Asset Retirement Obligation Current	105,000,000		120,000,000	[1]
Total current liabilities	1,431,000,000		1,788,000,000	[1]
Long-term debt	4,668,000,000		4,319,000,000	[1]
Deferred Credits And Other Liabilities [Abstract]
Customer advances for construction	41,000,000		41,000,000	[1]
Pension and other postretirement benefit obligations, net of plan assets	220,000,000		216,000,000	[1]
Deferred income taxes, net noncurrent liabilities	2,122,000,000		2,121,000,000	[1]
Deferred investment tax credits	21,000,000		22,000,000	[1]
Regulatory liabilities arising from removal obligations	1,587,000,000		1,557,000,000	[1]
Asset retirement obligations	746,000,000		754,000,000	[1]
Fixed-price contracts and other derivatives, noncurrent liabilities	151,000,000		153,000,000	[1]
Deferred credits and other	360,000,000		333,000,000	[1]
Total deferred credits and other liabilities	5,248,000,000		5,197,000,000	[1]
Equity:
Common stock	1,338,000,000		1,338,000,000	[1]
Retained earnings	3,753,000,000		3,606,000,000	[1]
Accumulated other comprehensive income (loss)	-12,000,000		-12,000,000	[1]
Total shareholders' equity	5,079,000,000		4,932,000,000	[1]
Other noncontrolling interests	59,000,000		60,000,000	[1]
Total equity	5,138,000,000		4,992,000,000
Total liabilities and equity	16,485,000,000		16,296,000,000	[1]
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	21,000,000		85,000,000	[1]
Trade accounts receivable	437,000,000		586,000,000	[1]
Other accounts and notes receivable	68,000,000		51,000,000	[1]
Due from unconsolidated affiliates	61,000,000		4,000,000	[1]
Income taxes receivable	0		5,000,000	[1]
Inventories	109,000,000		181,000,000	[1]
Regulatory balancing accounts, undercollected	59,000,000		35,000,000	[1]
Other regulatory assets	6,000,000		5,000,000	[1]
Other current assets	62,000,000		36,000,000	[1]
Total current assets	823,000,000		988,000,000	[1]
Investments And Other Assets [Abstract]
Regulatory assets arising from pension and other postretirement benefit obligations	633,000,000		617,000,000	[1]
Other regulatory assets	532,000,000		472,000,000	[1]
Other post retirement benefit assets, net of plan liabilities	4,000,000		4,000,000	[1]
Sundry	147,000,000		136,000,000	[1]
Total investments and other assets	1,316,000,000		1,229,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	13,130,000,000		12,886,000,000	[1]
Less accumulated depreciation and amortization	-4,706,000,000		-4,642,000,000	[1]
Property, plant and equipment, net	8,424,000,000		8,244,000,000	[1]
Total assets	10,563,000,000		10,461,000,000	[1]
Current liabilities:
Short-term debt	0		50,000,000	[1]
Accounts payable - trade	344,000,000		532,000,000	[1]
Accounts payable - other	84,000,000		88,000,000	[1]
Due to unconsolidated affiliates	0		13,000,000	[1]
Income taxes payable	100,000,000		0	[1]
Deferred income taxes, net current liabilities	56,000,000		53,000,000	[1]
Accrued compensation and benefits	104,000,000		129,000,000	[1]
Customer deposits	75,000,000		75,000,000	[1]
Other current liabilities	148,000,000		149,000,000	[1]
Total current liabilities	911,000,000		1,089,000,000	[1]
Long-term debt	1,906,000,000		1,906,000,000	[1]
Deferred Credits And Other Liabilities [Abstract]
Customer advances for construction	101,000,000		102,000,000	[1]
Pension and other postretirement benefit obligations, net of plan assets	650,000,000		633,000,000	[1]
Deferred income taxes, net noncurrent liabilities	1,249,000,000		1,212,000,000	[1]
Deferred investment tax credits	15,000,000		16,000,000	[1]
Regulatory liabilities arising from removal obligations	1,150,000,000		1,167,000,000	[1]
Asset retirement obligations	1,280,000,000		1,255,000,000	[1]
Deferred credits and other	306,000,000		300,000,000	[1]
Total deferred credits and other liabilities	4,751,000,000		4,685,000,000	[1]
Equity:
Preferred stock	22,000,000		22,000,000	[1]
Common stock	866,000,000		866,000,000	[1]
Retained earnings	2,125,000,000		1,911,000,000	[1]
Accumulated other comprehensive income (loss)	-18,000,000		-18,000,000	[1]
Total shareholders' equity	2,995,000,000		2,781,000,000	[1]
Total equity	2,995,000,000		2,781,000,000
Total liabilities and equity	$10,563,000,000		$10,461,000,000	[1]
[1]	Derived from audited financial statements.
[2]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.

CONDENSED_CONSOLIDATED_BALANCE1

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Property, plant and equipment related to VIE	$403	$410
Long-term debt related to VIE	312	315
Shareholders' equity:
Preferred stock, shares authorized	50	50
Preferred stock, shares issued	0	0
Common stock, shares authorized	750	750
Common stock, shares outstanding	247	246
San Diego Gas and Electric Company [Member]
Property, plant and equipment related to VIE	403	410
Long-term debt related to VIE	$312	$315
Shareholders' equity:
Common stock, shares authorized	255	255
Common stock, shares outstanding	117	117
Southern California Gas Company [Member]
Shareholders' equity:
Common stock, shares authorized	100	100
Common stock, shares outstanding	91	91

CONDENSED_CONSOLIDATED_STATEME

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	3 Months Ended
In Millions, except Share data in Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
REVENUES
Utilities	$2,422	$2,485
Energy-related businesses	260	310
Total revenues	2,682	2,795
Utilities [Abstract]
Cost of natural gas	-346	-620
Cost of electric fuel and purchased power	-481	-510
Energy-related businesses [Abstract]
Cost of natural gas, electric fuel and purchased power	-98	-138
Other cost of sales	-35	-38
Operation and maintenance	-658	-676
Depreciation and amortization	-303	-286
Plant closure adjustment (loss)	21	13
Franchise fees and other taxes	-107	-105
Gain on sale of equity interest and assets	0	27
Equity (losses) earnings before income tax
Equity (losses) earnings, other	19	17
Other income (expense), net	39	40
Interest income	7	4
Interest expense	-134	-136
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	606	387
Income tax (expense) benefit	-163	-127
Equity earnings, net of income tax	15	6
Net income	458	266
Losses (earnings) attributable to noncontrolling interests	-21	-19
Earnings	437	247
Basic earnings per common share:
Basic earnings per common share	$1.76	$1.01
Basic earnings per common share, weighted-average number of shares outstanding (thousands)	247,722	245,277
Diluted earnings per common share:
Diluted earnings per common share	$1.74	$0.99
Diluted earnings per common share, weighted-average number of shares outstanding (thousands)	251,206	249,669
Dividends declared per share of common stock	$0.70	$0.66
San Diego Gas and Electric Company [Member]
Utility operating revenues
Electric	805	811
Natural gas	161	176
Total utility operating revenues	966	987
Utility operating expenses
Utility cost of natural gas	54	75
Utility cost of electric fuel and purchased power	228	266
Utility operation and maintenance	217	252
Utility depreciation	145	130
Utility franchise fees and other taxes	61	56
Utility plant closure (adjustment) loss	-21	-13
Total utility operating expenses	684	766
Utility operating income	282	221
Equity (losses) earnings before income tax
Other income (expense), net	9	13
Interest expense	-52	-50
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	239	184
Income tax (expense) benefit	-88	-83
Net income	151	101
Losses (earnings) attributable to noncontrolling interests	-4	-2
Earnings	147	99
Southern California Gas Company [Member]
Utility operating revenues
Total utility operating revenues	1,048	1,085
Utility operating expenses
Utility cost of natural gas	267	508
Utility operation and maintenance	314	305
Utility depreciation	113	105
Utility franchise fees and other taxes	34	38
Total utility operating expenses	728	956
Utility operating income	320	129
Equity (losses) earnings before income tax
Other income (expense), net	8	4
Interest expense	-19	-17
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	309	116
Income tax (expense) benefit	-95	-38
Net income	214	78
Earnings	$214	$78

CONDENSED_CONSOLIDATED_STATEME1

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Net income	$458	$266
Before-Tax Amount [Member]
Net income	600	374
Comprehensive income, net of income tax
Foreign currency translation adjustments	-62	-43
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	2	5
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	-89	-8
Other Comprehensive Income (Loss), Net of Tax, Total	-149	-46
Total Comprehensive Income	451	328
Income Tax (Expense) Benefit [Member]
Net income	-163	-127
Comprehensive income, net of income tax
Foreign currency translation adjustments	0	0
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	-1	-2
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	34	3
Other Comprehensive Income (Loss), Net of Tax, Total	33	1
Total Comprehensive Income	-130	-126
Net-of-Tax Amount [Member]
Net income	437	247
Comprehensive income, net of income tax
Foreign currency translation adjustments	-62	-43
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1	3
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	-55	-5
Other Comprehensive Income (Loss), Net of Tax, Total	-116	-45
Total Comprehensive Income	321	202
Noncontrolling Interests [Member]
Net income	21	19
Comprehensive income, net of income tax
Foreign currency translation adjustments	-8	-2
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	-5	0
Other Comprehensive Income (Loss), Net of Tax, Total	-13	-2
Total Comprehensive Income	8	17
Total Equity [Member]
Net income	458	266
Comprehensive income, net of income tax
Foreign currency translation adjustments	-70	-45
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1	3
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	-60	-5
Other Comprehensive Income (Loss), Net of Tax, Total	-129	-47
Total Comprehensive Income	329	219
San Diego Gas and Electric Company [Member]
Net income	151	101
San Diego Gas and Electric Company [Member] | Before-Tax Amount [Member]
Net income	235	182
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0
Other Comprehensive Income (Loss), Net of Tax, Total	0
Total Comprehensive Income	235	182
San Diego Gas and Electric Company [Member] | Income Tax (Expense) Benefit [Member]
Net income	-88	-83
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0
Other Comprehensive Income (Loss), Net of Tax, Total	0
Total Comprehensive Income	-88	-83
San Diego Gas and Electric Company [Member] | Net-of-Tax Amount [Member]
Net income	147	99
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0
Other Comprehensive Income (Loss), Net of Tax, Total	0
Total Comprehensive Income	147	99
San Diego Gas and Electric Company [Member] | Noncontrolling Interests [Member]
Net income	4	2
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	-2
Other Comprehensive Income (Loss), Net of Tax, Total	-2
Total Comprehensive Income	2	2
San Diego Gas and Electric Company [Member] | Total Equity [Member]
Net income	151	101
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	-2
Other Comprehensive Income (Loss), Net of Tax, Total	-2
Total Comprehensive Income	149	101
Southern California Gas Company [Member]
Net income	214	78
Southern California Gas Company [Member] | Before-Tax Amount [Member]
Net income	309	116
Comprehensive income, net of income tax
Total Comprehensive Income	309	116
Southern California Gas Company [Member] | Income Tax (Expense) Benefit [Member]
Net income	-95	-38
Comprehensive income, net of income tax
Total Comprehensive Income	-95	-38
Southern California Gas Company [Member] | Net-of-Tax Amount [Member]
Net income	214	78
Comprehensive income, net of income tax
Total Comprehensive Income	$214	$78

CONDENSED_CONSOLIDATED_STATEME2

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$458		$266
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	303		286
Deferred income taxes and investment tax credits	131		95
Gain on sale of equity interest and assets	0		-27
Plant closure (adjustment) loss	-21		-13
Equity earnings	-34		-23
Fixed-price contracts and other derivatives	11		-3
Other	-27		-24
Net change in other working capital components	19		234
Changes in other assets	-42		94
Changes in other liabilities	13		19
Net cash provided by operating activities	811		904
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	-780		-801
Expenditures for investments	-34		-12
Proceeds from sale of equity interest and assets, net of cash sold	0		66
Distributions from investments	1		3
Purchases of nuclear decommissioning and other trust assets	-95		-198
Proceeds from sales by nuclear decommissioning and other trusts	94		195
Decrease in restricted cash	25		23
Increase in restricted cash	-18		-27
Advances to unconsolidated affiliates	-5		-17
Other cash flows from investing activities	9		-2
Proceeds From Payments For Long Term Loans For Related Parties	33		0
Net cash used in investing activities	-770		-770
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	-149		-154
Proceeds from issuances of common stock	17		11
Repurchases of common stock	-65		-37
Issuances of long-term debt	938		1,188
Payments on long-term debt	-654		-1,138
Increase (decrease) in short-term debt, net	-363		-69
Other cash flows from financing activities	45		6
Net cash provided by (used in) financing activities	-231		-193
Effect of exchange rate changes on cash and cash equivalents	-3		-1
Increase (decrease) in cash and cash equivalents	-193		-60
Cash and cash equivalents, beginning of period	570	[1]	904
Cash and cash equivalents, end of period	377		844
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	83		91
Income tax payments, net of refunds	42		41
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	272		249
Increase in capital lease obligations for investments in property, plant and equipment	0		60
Acquisition Of Business [Abstract]
Assets acquired	10		0
Accrued purchase price	-6		0
Liabilities Assumed	-2		0
Cash paid	2		0
Dividends declared but not paid	181		168
Financing of build-to-suit property	27		9
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	151		101
Adjustments to reconcile net income to net cash provided by operating activities:
Utility depreciation and amortization	145		130
Deferred income taxes and investment tax credits	56		57
Utility plant closure (adjustment) loss	-21		-13
Fixed-price contracts and other derivatives	-1		-2
Other	-1		-9
Net change in other working capital components	7		-76
Changes in other assets	-48		63
Changes in other liabilities	11		10
Net cash provided by operating activities	299		261
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	-355		-294
Purchases of nuclear decommissioning trust assets	-94		-198
Proceeds from sales by nuclear decommissioning trusts	94		195
Decrease in restricted cash	10		10
Increase in restricted cash	-10		-10
Increase in loans to affiliates, net	-66		0
Net cash used in investing activities	-421		-297
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	388		0
Payments on long-term debt	-3		-3
Increase (decrease) in short-term debt, net	-246		31
Distributions to noncontrolling interests	-2		-7
Net cash provided by (used in) financing activities	137		21
Increase (decrease) in cash and cash equivalents	15		-15
Cash and cash equivalents, beginning of period	8	[1]	27
Cash and cash equivalents, end of period	23		12
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	39		36
Income tax payments, net of refunds	31		0
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	103		99
Increase in capital lease obligations for investments in property, plant and equipment	0		60
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	214		78
Adjustments to reconcile net income to net cash provided by operating activities:
Utility depreciation and amortization	113		105
Deferred income taxes and investment tax credits	-9		26
Other	-6		0
Net change in other working capital components	85		197
Changes in other assets	-19		18
Changes in other liabilities	-3		3
Net cash provided by operating activities	375		427
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	-315		-260
Advances to unconsolidated affiliates	-74		-117
Net cash used in investing activities	-389		-377
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	0		248
Payments on long-term debt	0		-250
Increase (decrease) in short-term debt, net	-50		-42
Other cash flows from financing activities	0		-1
Net cash provided by (used in) financing activities	-50		-45
Increase (decrease) in cash and cash equivalents	-64		5
Cash and cash equivalents, beginning of period	85	[1]	27
Cash and cash equivalents, end of period	21		32
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	17		12
Income tax payments, net of refunds	-3		30
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$129		$111
[1]	Derived from audited financial statements.

GENERAL

GENERAL	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
General	NOTE 1. GENERAL
	IMPACT OF SEASONALIZATION AT SEMPRA ENERGY AND SOUTHERN CALIFORNIA GAS COMPANY
	In the first quarter of 2015, Southern California Gas Company (SoCalGas) adopted a California Public Utilities Commission (CPUC) decision in the Triennial Cost Allocation Proceeding (TCAP) requiring SoCalGas to recognize annual authorized revenue for core natural gas customers using seasonal factors established in the TCAP, instead of recognizing such revenue ratably over the year as was previously required. This “seasonalization” resulted in $163 million higher operating revenues and $113 million higher earnings for Sempra Energy and SoCalGas in the first quarter of 2015 compared to the same period in 2014. While this seasonalization will cause variability in comparable revenue and earnings from quarter to quarter within the year, it will not impact full-year 2015 results nor have any impact on cash flow. Accordingly, substantially all of SoCalGas’ annual earnings will be recognized in the first and fourth quarters of the year. We discuss the CPUC decision further in Note 10.
	PRINCIPLES OF CONSOLIDATION
	Sempra Energy
	Sempra Energy’s Condensed 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 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 12.
	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.
	Our Sempra Mexico segment includes the operating companies of our subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), as well as certain holding companies and risk management activity. We discuss IEnova further in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 2014 (the Annual Report), which includes the combined reports for Sempra Energy, SDG&E and SoCalGas.
	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 herein and in the Notes to Consolidated Financial Statements in the Annual Report.
	SDG&E
	SDG&E’s Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E is the primary beneficiary, as we discuss in Note 5 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’ Condensed Consolidated Financial Statements include its accounts and the de minimis accounts of inactive subsidiaries. SoCalGas’ common stock is wholly owned by Pacific Enterprises, 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.
	We have prepared the Condensed Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after March 31, 2015 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. These adjustments are only of a normal, recurring nature.
	All December 31, 2014 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2014 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim-period-reporting provisions of U.S. GAAP and the Securities and Exchange Commission.
	We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We follow the same accounting policies for interim reporting purposes, except for the adoption of new accounting standards as we discuss in Note 2.
	You should read the information in this Quarterly Report in conjunction with the Annual Report.
	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 México, S. de R.L. de C.V. (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 U.S. GAAP provisions governing regulated operations, as we discuss in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report

NEW_ACCOUNTING_STANDARDS

NEW ACCOUNTING STANDARDS	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
New Accounting Standards	NOTE 2. NEW ACCOUNTING STANDARDS
	We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures.
	SEMPRA ENERGY, SDG&E AND SOCALGAS
	Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers” (ASU 2014-09): ASU 2014-09 provides accounting guidance for revenue arising from contracts with customers and affects all entities that enter into contracts to provide goods or services to their customers. The guidance also provides a model for the measurement and recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach.
	As issued, ASU 2014-09 will become effective on January 1, 2017; however, the Financial Accounting Standards Board has proposed a one-year delay in the effective date that is pending review. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.
	ASU 2015-03, “Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs” (ASU 2015-03): ASU 2015-03 provides guidance on the financial statement presentation of debt issuance costs and requires an entity to present debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related long-term debt liability. This guidance must be applied using a full retrospective approach for all periods presented in the period of adoption.
	We will adopt ASU 2015-03 for our annual reporting period ending December 31, 2015. The adoption will not affect our results of operations or cash flows. Deferred debt issuance costs that are the subject of ASU 2015-03 are included in Sundry on the Sempra Energy, SDG&E and SoCalGas Condensed Consolidated Balance Sheets and total $85 million, $33 million, and $15 million at March 31, 2015, respectively, and $84 million, $33 million, and $15 million at December 31, 2014, respectively.

RECENT_INVESTMENT_ACTIVITY

RECENT INVESTMENT ACTIVITY	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Recent Investment Activity	DECONSOLIDATION OF SUBSIDIARY
	(Dollars in millions)
			Copper Mountain Solar 3
			At March 13, 2014
	Proceeds from sale, net of negligible transaction costs		$	68
	Cash			-2
	Property, plant and equipment, net			-247
	Other assets			-11
	Accounts payable and accrued expenses			82
	Long-term debt, including current portion			97
	Other liabilities			3
	Accumulated other comprehensive income			-2
	Gain on sale of equity interest			-27
	(Increase) in equity method investment upon deconsolidation		$	-39
	In March 2015, Sempra Renewables acquired a 100-percent interest in the Black Oak Getty Wind project, a 78-MW wind farm under development in Stearns County, Minnesota. The wind farm has a 20-year power purchase agreement with Minnesota Municipal Power Agency. The total acquisition cost for the project is $8 million, of which $2 million was paid in cash at closing, and $6 million is payable contingent on certain events as the project is further developed.
	SEMPRA NATURAL GAS
	Asset Held for Sale, Power Plant
	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.
	In January 2014, management approved a formal plan to market and sell the remaining 625-MW block of the Mesquite Power plant, and in October 2014, Sempra Natural Gas entered into a definitive agreement to sell the remaining block of the plant. The asset is classified as held for sale at March 31, 2015. In April 2015, Sempra Natural Gas sold the remaining block of the plant, together with a related power sales contract. Sempra Natural Gas received net cash proceeds of $345 million, and expects to recognize a pretax gain on the sale of approximately $58 million ($34 million after-tax) in the second quarter of 2015, subject to certain post-closing adjustments related to working capital.
	At March 31, 2015, the carrying amount of the major classes of assets and related liability held for sale associated with the plant included the following:
	ASSET HELD FOR SALE, POWER PLANT
	(Dollars in millions)
			31-Mar-15
	Property, plant, and equipment, net		$	291
	Inventories			4
	Total assets held for sale			295
	Liability held for sale - asset retirement obligation(1)			-6
	Total		$	289
	-1	Included in Other Current Liabilities on the Condensed Consolidated Balance Sheet.

INVESTMENTS_IN_UNCONSOLIDATED_

INVESTMENTS IN UNCONSOLIDATED ENTITIES	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Investments in Unconsolidated Entities	NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES
	We provide additional information concerning our equity method investments in Notes 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report.
	SEMPRA RENEWABLES
	Sempra Renewables invested cash of $17 million and $12 million in its joint ventures during the three months ended March 31, 2015 and 2014, respectively.
	SEMPRA NATURAL GAS
	During the three months ended March 31, 2015, Sempra Natural Gas invested $3 million of cash in its joint venture, Cameron LNG Holdings, LLC (Cameron LNG Holdings or Cameron LNG JV), and capitalized $12 million of interest related to its investment.

OTHER_FINANCIAL_DATA

OTHER FINANCIAL DATA	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Other Financial Data	NOTE 5. OTHER FINANCIAL DATA
	INVENTORIES
	The components of inventories by segment are as follows:
	INVENTORY BALANCES
	(Dollars in millions)
			Natural gas				Liquefied natural gas				Materials and supplies				Total
			31-Mar-15		31-Dec-14		31-Mar-15		31-Dec-14		31-Mar-15		31-Dec-14		31-Mar-15		31-Dec-14
	SDG&E		$	6	$	8	$	―	$	―	$	63	$	65	$	69	$	73
	SoCalGas			83		155		―		―		26		26		109		181
	Sempra South American
	Utilities			―		―		―		―		32		33		32		33
	Sempra Mexico			―		―		7		9		9		9		16		18
	Sempra Renewables			―		―		―		―		2		2		2		2
	Sempra Natural Gas			22		83		4		5		1		1		27		89
	Sempra Energy
	Consolidated		$	111	$	246	$	11	$	14	$	133	$	136	$	255	$	396
	GOODWILL
	We discuss goodwill in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. The decrease in goodwill from $931 million at December 31, 2014 to $903 million at March 31, 2015 is due to foreign currency translation at Sempra South American Utilities. We record the offset of this fluctuation in Other Comprehensive Income (Loss).
	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. We determine if SDG&E 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, holds no equity in OMEC LLC 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. Accordingly, SDG&E and Sempra Energy have consolidated Otay Mesa VIE. Otay Mesa VIE’s equity of $59 million at March 31, 2015 and $60 million at December 31, 2014 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E.
	OMEC LLC has a loan outstanding of $322 million at March 31, 2015, 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 7.
	Cameron LNG JV
	Sempra Energy’s equity-method investment in Cameron LNG JV is considered to be a VIE generally due to contractual provisions that transfer certain risks to customers. Sempra Energy is not the primary beneficiary because we do not have the power to direct the most significant activities of Cameron LNG JV. We will continue to evaluate Cameron LNG JV for any changes that may impact our determination of the primary beneficiary. The carrying value of our investment in Cameron LNG JV was $969 million and $1,007 million at March 31, 2015 and December 31, 2014, respectively. Our maximum exposure to loss includes the carrying value of our investment and the guarantees discussed in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.
	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 March 31, 2015. 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 Condensed Consolidated Statements of Operations 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 in the table below generally correspond to SDG&E’s Condensed Consolidated Statements of Operations.
	AMOUNTS ASSOCIATED WITH OTAY MESA VIE
	(Dollars in millions)
		Three months ended March 31,
		2015		2014
	Operating expenses
	Cost of electric fuel and purchased power	$	-18	$	-18
	Operation and maintenance		4		5
	Depreciation		6		7
	Total operating expenses		-8		-6
	Operating income		8		6
	Interest expense		-4		-4
	Income before income taxes/Net income		4		2
	Earnings attributable to noncontrolling interest		-4		-2
	Earnings attributable to common shares	$	―	$	―
	We provide additional information regarding Otay Mesa VIE in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.
	PENSION AND OTHER POSTRETIREMENT BENEFITS
	Net Periodic Benefit Cost
	The following three tables provide the components of net periodic benefit cost:
	NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
		Pension benefits				Other postretirement benefits
		Three months ended March 31,
		2015		2014		2015		2014
	Service cost	$	30	$	26	$	7	$	6
	Interest cost		39		41		12		12
	Expected return on assets		-44		-43		-17		-16
	Amortization of:
Prior service cost (credit)		3		2		-1		-1
Actuarial loss		8		5		―		―
Settlement		―		3		―		―
Regulatory adjustment		-29		-24		―		―
Total net periodic benefit cost	$	7	$	10	$	1	$	1
NET PERIODIC BENEFIT COST – SDG&E
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2015		2014		2015		2014
Service cost	$	8	$	8	$	2	$	2
Interest cost		10		11		2		2
Expected return on assets		-14		-14		-3		-3
Amortization of:
Prior service cost		―		―		1		1
Actuarial loss		2		1		―		―
Regulatory adjustment		-5		-5		-2		-2
Total net periodic benefit cost	$	1	$	1	$	―	$	―
NET PERIODIC BENEFIT COST – SOCALGAS
(Dollars in millions)
	Pension benefits				Other postretirement benefits
	Three months ended March 31,
	2015		2014		2015		2014
Service cost	$	19	$	16	$	5	$	4
Interest cost		25		25		9		9
Expected return on assets		-27		-26		-14		-13
Amortization of:
Prior service cost (credit)		2		2		-2		-2
Actuarial loss		5		2		―		―
Regulatory adjustment		-24		-19		2		2
Total net periodic benefit cost	$	―	$	―	$	―	$	―
Benefit Plan Contributions
The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2015:
BENEFIT PLAN CONTRIBUTIONS
(Dollars in millions)
	Sempra Energy
	Consolidated		SDG&E		SoCalGas
Contributions through March 31, 2015:
Pension plans	$	15	$	1	$	1
Other postretirement benefit plans		1		―		―
Total expected contributions in 2015:
Pension plans	$	31	$	3	$	2
Other postretirement benefit plans		11		8		―
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 $476 million and $512 million at March 31, 2015 and December 31, 2014, respectively.
EARNINGS PER SHARE
The following table provides the per share computations for our earnings for the three months ended March 31, 2015 and 2014. 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 period. 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
(Dollars in millions, except per share amounts; shares in thousands)
		Three months ended March 31,
		2015		2014
Numerator:
Earnings/Income attributable to common shares		$	437	$	247
Denominator:
Weighted-average common shares
	outstanding for basic EPS		247,722		245,277
Dilutive effect of stock options, restricted
	stock awards and restricted stock units		3,484		4,392
Weighted-average common shares
	outstanding for diluted EPS		251,206		249,669
Earnings per share:
Basic		$	1.76	$	1.01
Diluted		$	1.74	$	0.99
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 of dilutive common stock equivalents excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). We had no such antidilutive stock options outstanding for the three months ended March 31, 2015 or 2014.
For the three months ended March 31, 2015 and 2014, we had no stock options outstanding that were antidilutive because of the unearned compensation and windfall tax benefits included in the assumed proceeds under the treasury stock method.
The dilution from unvested restricted stock awards (RSAs) and restricted stock units (RSUs) is also based on the treasury stock method. Proceeds equal to the unearned compensation and windfall tax benefits recognized, minus tax shortfalls recognized, related to the awards and units are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits 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 614 antidilutive RSUs from the application of unearned compensation in the treasury stock method for the three months ended March 31, 2015. There were no such antidilutive RSAs or RSUs for the three months ended March 31, 2014.
Our performance-based RSUs include awards that vest at the end of three-year (for awards granted in 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. Targets for our EPS RSUs were developed based on Sempra Energy’s long-term earnings-per-share growth guidance as well as analyst consensus long-term earnings-per-share growth estimates for S&P 500 Utilities Index peer companies. TSR RSUs represent the right to receive from zero to 1.5 shares (2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate.
Our RSAs, which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above. We include RSAs and these RSUs in potential dilutive shares at 100 percent, subject to the application of the treasury stock method. We include our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of both Sempra Energy stock and the comparative indices, dilutive TSR RSU shares may vary widely from period-to-period. If it were assumed that performance goals for all performance-based RSUs were met at maximum levels and if the treasury stock method were not applied to any of our RSAs or RSUs, the incremental potential dilutive shares would be 1,285,193 and 1,142,023 for the three months ended March 31, 2015 and 2014, respectively.
SHARE-BASED COMPENSATION
We discuss our share-based compensation plans in Note 8 of the Notes to Consolidated Financial Statements in the Annual Report. We recorded share-based compensation expense, net of income taxes, of $8 million and $7 million for the three months ended March 31, 2015 and 2014, respectively. Pursuant to our Sempra Energy share-based compensation plans, Sempra Energy’s compensation committee granted 300,719 TSR RSUs, 76,505 EPS RSUs and 127,753 RSUs issued either as service-based awards or in connection with certain other performance goals during the three months ended March 31, 2015, primarily in January.
During the three months ended March 31, 2015, IEnova issued 148,781 RSUs from the IEnova 2013 Long-Term Incentive Plan, under which awards are cash settled at vesting based on the price of IEnova common stock.
CAPITALIZED FINANCING COSTS
Capitalized financing costs include capitalized interest costs and, primarily at the California Utilities, an allowance for funds used during construction (AFUDC) related to both debt and equity financing of construction projects.
Pipeline projects currently under construction by Sempra Mexico and Sempra Natural Gas that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC related to equity.
Sempra International and Sempra U.S. Gas & Power businesses capitalize interest costs incurred to finance capital projects and interest on equity method investments that have not commenced planned principal operations. The California Utilities also capitalize certain interest costs.
The following table shows capitalized financing costs for the three months ended March 31, 2015 and 2014.
CAPITALIZED FINANCING COSTS
(Dollars in millions)
		Three months ended March 31,
		2015		2014
Sempra Energy Consolidated:
AFUDC related to debt		$	6	$	6
AFUDC related to equity			27		25
Other capitalized financing costs			17		8
Total Sempra Energy Consolidated		$	50	$	39
SDG&E:
AFUDC related to debt		$	3	$	4
AFUDC related to equity			8		11
Total SDG&E		$	11	$	15
SoCalGas:
AFUDC related to debt		$	3	$	2
AFUDC related to equity			9		5
Total SoCalGas		$	12	$	7
COMPREHENSIVE INCOME
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)
SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
				Pension and other
				postretirement benefits
		Foreign								Total
		currency		Unamortized		Unamortized				accumulated other
		translation		net actuarial		prior service		Financial		comprehensive
		adjustments		gain (loss)		cost		instruments		income (loss)
		Three months ended March 31, 2015 and 2014
2015:00:00
Balance as of December 31, 2014		$	-322	$	-83	$	-2	$	-90	$	-497
Other comprehensive loss before
reclassifications			-62		―		―		-54		-116
Amounts reclassified from accumulated other
comprehensive income (loss)			―		1		―		-1		―
Net other comprehensive income (loss)			-62		1		―		-55		-116
Balance as of March 31, 2015		$	-384	$	-82	$	-2	$	-145	$	-613
2014:00:00
Balance as of December 31, 2013		$	-129	$	-73	$	―	$	-26	$	-228
Other comprehensive loss before
reclassifications			-43		―		―		-14		-57
Amounts reclassified from accumulated other
comprehensive income			―		3		―		9		12
Net other comprehensive income (loss)			-43		3		―		-5		-45
Balance as of March 31, 2014		$	-172	$	-70	$	―	$	-31	$	-273
-1	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated			Amounts reclassified
other comprehensive income (loss)			from accumulated other						Affected line item on Condensed
components			comprehensive income (loss)						Consolidated Statements of Operations
			Three months ended March 31,
			2015			2014
Sempra Energy Consolidated:
Financial instruments:
Interest rate and foreign exchange instruments			$	6		$	3		Interest Expense
Interest rate instruments				―			2		Gain on Sale of Equity Interest
Interest rate instruments				3			3		Equity Earnings, Before Income Tax
Commodity contracts not subject									Revenues: Energy-Related
	to rate recovery			-7			10		Businesses
Total before income tax				2			18
				1			-6		Income Tax Expense
Net of income tax				3			12
				-4			-3		Earnings Attributable to Noncontrolling Interests
			$	-1		$	9
Pension and other postretirement benefits:
Amortization of actuarial loss			$	2		$	5		See (1) below
				-1			-2		Income Tax Expense
Net of income tax			$	1		$	3
Total reclassifications for the period, net of tax			$	―		$	12
SDG&E:
Financial instruments:
Interest rate instruments			$	3		$	3		Interest Expense
				-3			-3		Earnings Attributable to Noncontrolling Interest
			$	―		$	―
-1	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).
For the three months ended March 31, 2015 and 2014, Other Comprehensive Income, excluding amounts attributable to noncontrolling interests, at SDG&E and SoCalGas was negligible, and reclassifications out of Accumulated Other Comprehensive Income (Loss) to Net Income were also negligible for SoCalGas.
SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS
The following two tables provide reconciliations of changes in Sempra Energy’s and SDG&E’s shareholders’ equity and noncontrolling interests for the three months ended March 31, 2015 and 2014. The only change in SoCalGas’ equity for the three months ended March 31, 2015 and 2014 was comprehensive income and a negligible amount of preferred stock dividends declared.
SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS ― SEMPRA ENERGY CONSOLIDATED
(Dollars in millions)
			Sempra Energy		Non-
			shareholders’		controlling		Total
			equity		interests		equity
Balance at December 31, 2014		$	11,326	$	774	$	12,100
Comprehensive income			321		8		329
Share-based compensation expense			13		―		13
Common stock dividends declared			-173		―		-173
Issuance of common stock			30		―		30
Repurchase of common stock			-65		―		-65
Tax benefit related to share-based compensation			52		―		52
Distributions to noncontrolling interests			―		-5		-5
Balance at March 31, 2015		$	11,504	$	777	$	12,281
Balance at December 31, 2013		$	11,008	$	842	$	11,850
Comprehensive income			202		17		219
Share-based compensation expense			10		―		10
Common stock dividends declared			-162		―		-162
Issuance of common stock			11		―		11
Repurchase of common stock			-37		―		-37
Tax benefit related to share-based compensation			8		―		8
Equity contributed by noncontrolling interest			―		1		1
Distributions to noncontrolling interests			―		-11		-11
Balance at March 31, 2014		$	11,040	$	849	$	11,889
SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST ― SDG&E
(Dollars in millions)
		SDG&E		Non-
		shareholder’s		controlling		Total
		equity		interest		equity
Balance at December 31, 2014	$	4,932	$	60	$	4,992
Comprehensive income		147		2		149
Distributions to noncontrolling interest		―		-3		-3
Balance at March 31, 2015	$	5,079	$	59	$	5,138
Balance at December 31, 2013	$	4,628	$	91	$	4,719
Comprehensive income		99		2		101
Distributions to noncontrolling interest		―		-6		-6
Balance at March 31, 2014	$	4,727	$	87	$	4,814
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 Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income.
Preferred Stock
At Sempra Energy, the preferred stock of SoCalGas is presented as a noncontrolling interest and preferred stock dividends are charges against income related to noncontrolling interests. We provide additional information concerning preferred stock in Note 11 of the Notes to Consolidated Financial Statements in the Annual Report.
At March 31, 2015 and December 31, 2014, 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 Condensed Consolidated Balance Sheets:
OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
		Percent ownership held by others
		March 31,		December 31,			March 31,		December 31,
		2015		2014			2015		2014
SDG&E:
Otay Mesa VIE		100	%	100	%	$	59	$	60
Sempra South American Utilities:
Chilquinta Energía subsidiaries(1)		23.5 – 43.4		23.6 – 43.4			23		23
Luz del Sur		16.4		16.4			174		177
Tecsur		9.8		9.8			3		4
Sempra Mexico:
IEnova, S.A.B. de C.V.		18.9		18.9			460		452
Sempra Natural Gas:
Bay Gas Storage Company, Ltd.		9.1		9.1			23		23
Liberty Gas Storage, LLC		25		25			14		14
Southern Gas Transmission Company		49		49			1		1
Total Sempra Energy						$	757	$	754
-1	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages amongst these subsidiaries.
TRANSACTIONS WITH AFFILIATES
Current and noncurrent amounts due from unconsolidated affiliates on the Sempra Energy Condensed Consolidated Balance Sheets are as follows:
DUE FROM UNCONSOLIDATED AFFILIATES(1)
(Dollars in millions)
			31-Mar-15		31-Dec-14
Sempra South American Utilities:
Eletrans S.A.:
4% Note(2)		$	46	$	41
Sempra Mexico:
Affiliates of joint venture with PEMEX:
Note due November 13, 2017(3)			44		44
Note due November 14, 2018(3)			41		40
Note due November 14, 2018(3)			33		33
Note due November 14, 2018(3)			8		8
Energía Sierra Juárez:
Note due June 15, 2018(4)			23		22
Other(5)			5		38
Total		$	200	$	226
-1	Amounts include principal balances plus accumulated interest outstanding.
-2	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A., an affiliate of Chilquinta Energía.
-3	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.67 percent at March 31, 2015), to finance the Los Ramones Norte pipeline project.
-4	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.55 percent at March 31, 2015), to finance the first phase of the Energía Sierra Juárez wind project.
-5	Amounts represent accounts receivable from various Sempra Renewables and Sempra Mexico 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. Also, from time-to-time, SDG&E and SoCalGas may loan surplus cash to Sempra Energy at interest rates based on one-month commercial paper rates. Amounts due to/from affiliates are as follows:
AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
(Dollars in millions)
		31-Mar-15			31-Dec-14
SDG&E:
Current:
Due from Sempra Energy		$	40		$	―
Due from various affiliates			1			1
		$	41		$	1
Due to Sempra Energy		$	―		$	17
Due to SoCalGas			2			4
		$	2		$	21
Income taxes due from Sempra Energy(1)		$	15		$	16
SoCalGas:
Current:
Due from Sempra Energy		$	59		$	―
Due from SDG&E			2			4
		$	61		$	4
Due to Sempra Energy		$	―		$	13
Income taxes due (to) from Sempra Energy(1)		$	-107		$	9
-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)
	Three months ended March 31,
	2015		2014
SDG&E	$	3	$	3
SoCalGas		19		18
OTHER INCOME, NET
Other Income, Net on the Condensed Consolidated Statements of Operations consists of the following:
OTHER INCOME, NET
(Dollars in millions)
		Three months ended March 31,
		2015		2014
Sempra Energy Consolidated:
Allowance for equity funds used during construction		$	27	$	25
Investment gains(1)			9		8
Regulatory interest, net(2)			1		1
Foreign currency losses			-1		―
Gains on interest rate and foreign exchange instruments, net			―		2
Sundry, net			3		4
Total		$	39	$	40
SDG&E:
Allowance for equity funds used during construction		$	8	$	11
Regulatory interest, net(2)			1		1
Sundry, net			―		1
Total		$	9	$	13
SoCalGas:
Allowance for equity funds used during construction		$	9	$	5
Sundry, net			-1		-1
Total		$	8	$	4
-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	Interest on regulatory balancing accounts.
INCOME TAXES
INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
					Effective					Effective
			Income tax		income			Income tax		income
			expense		tax rate			expense		tax rate
			Three months ended March 31,
			2015					2014
Sempra Energy Consolidated		$	163		27	%	$	127		33	%
SDG&E			88		37			83		45
SoCalGas			95		31			38		33
Changes in Income Tax Expense and Effective Income Tax Rates
Sempra Energy Consolidated
The increase in income tax expense in the three months ended March 31, 2015 was mainly due to higher pretax income primarily from SoCalGas, offset by a lower effective tax rate. The lower effective tax rate was primarily due to a $17 million charge in 2014 to reduce certain tax regulatory assets attributed to SDG&E’s investment in San Onofre Nuclear Generating Station (SONGS) that we discuss in Note 9.
Sempra Energy, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted effective tax rate anticipated for the full year, as required by U.S. GAAP. The income tax effect of items that can be reliably forecasted are factored into the forecasted effective tax rate and their impact is recognized proportionately over the year. The forecasted items, anticipated on a full year basis, may include, among others:
utility self-developed software expenditures
repairs to certain utility plant assets
renewable energy income tax credits
deferred income tax benefits related to renewable energy projects
exclusions from taxable income of the equity portion of AFUDC
depreciation on a certain portion of utility plant assets
U.S. tax on repatriation of current year earnings from non-U.S. subsidiaries
Items that cannot be reliably forecasted (e.g., adjustments related to prior years’ income tax items, remeasurement of deferred tax asset valuation allowances, Mexican currency translation and inflation adjustments, and deferred income tax benefit associated with the impairment of a book investment) are recorded in the interim period in which they actually occur, which can result in variability to income tax expense.
SDG&E
The increase in SDG&E’s income tax expense in the three months ended March 31, 2015 was mainly due to higher pretax income, offset by a lower effective tax rate, primarily from the $17 million charge in 2014 to reduce certain tax regulatory assets attributed to SDG&E’s investment in SONGS discussed in Note 9.
The results for Sempra Energy Consolidated and SDG&E include Otay Mesa VIE, which is not included in Sempra Energy’s federal or state income tax returns but is consolidated for financial statement purposes, and therefore, Sempra Energy Consolidated’s and SDG&E’s effective income tax rates are impacted by the VIE’s stand-alone effective income tax rate. We discuss Otay Mesa VIE above in “Variable Interest Entities.”
SoCalGas
The increase in SoCalGas’ income tax expense in the three months ended March 31, 2015 was mainly due to higher pretax income, partially offset by a lower effective tax rate that was primarily due to higher exclusions from taxable income of the equity portion of AFUDC. Higher pretax income was primarily due to recognizing core gas authorized revenue during interim periods based on seasonal factors beginning January 1, 2015 in accordance with the TCAP, compared to recognizing such revenue ratably over the year in 2014. We discuss the impact of the TCAP decision further in Note 10.
For SDG&E and SoCalGas, 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 impacts 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 assets
the equity portion of AFUDC
a portion of the cost of removal of utility plant assets
utility self-developed software expenditures
depreciation on a certain portion of utility plant assets
The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico and Sempra Natural Gas has similar flow-through treatment.
We provide additional information about our accounting for income taxes in Notes 1 and 6 of the Notes to Consolidated Financial Statements in the Annual Report.

DEBT_AND_CREDIT_FACILITIES

DEBT AND CREDIT FACILITIES	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Debt and Credit Facilities	NOTE 6. DEBT AND CREDIT FACILITIES
	LINES OF CREDIT
	At March 31, 2015, Sempra Energy Consolidated had an aggregate of $4.1 billion in three primary committed lines of credit for Sempra Energy, Sempra Global and the California Utilities to provide liquidity and to support commercial paper, the major components of which we detail below. Available unused credit on these lines at March 31, 2015 was $3.3 billion. Some of Sempra Energy’s subsidiaries, primarily our foreign operations, have additional general purpose credit facilities, aggregating $843 million at March 31, 2015. Available unused credit on these lines totaled $648 million at March 31, 2015.
	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 March 31, 2015 and December 31, 2014, 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 March 31, 2015, Sempra Energy had no outstanding borrowings or letters of credit 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 March 31, 2015 and December 31, 2014, Sempra Energy was in compliance with this and all other financial covenants under the credit facility.
	At March 31, 2015, Sempra Global had $731 million of commercial paper outstanding supported by the facility.
	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 $300 million for both utilities. 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 March 31, 2015 and December 31, 2014, 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 March 31, 2015, SDG&E had $100 million of commercial paper outstanding, classified as current portion of Long-Term Debt, supported by the facility at an interest rate of 0.40 percent. SoCalGas had no outstanding borrowings supported by the facility. Available unused credit on the line at March 31, 2015 was $558 million and $658 million at SDG&E and SoCalGas, respectively, subject to the $877 million maximum combined credit limit.
	Sempra Mexico
	In 2014, IEnova entered into an agreement for a $200 million, U.S. dollar-denominated, three-year corporate revolving credit facility to finance working capital and for general corporate purposes. The lender is Banco Santander, (México), S.A., Institución de Banca Múltiple, Grupo Financiero Santander Mexico. At March 31, 2015, IEnova had $50 million of outstanding borrowings supported by the facility, and available unused credit on the line was $150 million.
	Also in 2014, IEnova entered into an agreement for a $100 million, U.S. dollar-denominated, three-year corporate revolving credit facility to finance working capital and for general corporate purposes. The lender is Sumitomo Mitsui Banking Corporation. At March 31, 2015, IEnova had $25 million of outstanding borrowings supported by the facility, and available unused credit on the line was $75 million.
	WEIGHTED AVERAGE INTEREST RATES
	The weighted average interest rates on the total short-term debt at Sempra Energy Consolidated were 0.72 percent and 0.70 percent at March 31, 2015 and December 31, 2014, respectively. At December 31, 2014, the weighted average interest rates on total short-term debt for SDG&E and SoCalGas were 0.27 percent and 0.25 percent, respectively.
	LONG-TERM DEBT
	Sempra Energy
	In March 2015, Sempra Energy publicly offered and sold $500 million of 2.40-percent, fixed-rate notes maturing in 2020. Sempra Energy used the proceeds from this offering to repay outstanding commercial paper.
	SDG&E
	In March 2015, SDG&E publicly offered and sold $140 million of first mortgage bonds maturing in 2017 at a variable rate of three-month LIBOR plus 0.20 percent (0.47 percent at March 31, 2015) and $250 million of 1.914-percent amortizing first mortgage bonds maturing in 2022. SDG&E used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes.
	INTEREST RATE SWAPS
	We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 7.

DERIVATIVE_FINANCIAL_INSTRUMEN

DERIVATIVE FINANCIAL INSTRUMENTS	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Derivative Financial Instruments	NOTE 7. 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 Condensed 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 (loss) (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Condensed 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, for the benefit of customers, 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 California Public Utilities Commission (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 Condensed 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 Condensed 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: liquefied natural gas (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 Condensed 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 Condensed 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 March 31, 2015 and December 31, 2014 as follows:
	NET ENERGY DERIVATIVE VOLUMES
	Segment and Commodity			31-Mar-15	31-Dec-14
	California Utilities:
	SDG&E:
	Natural gas			57 million MMBtu	55 million MMBtu	-1
	Congestion revenue rights			24 million MWh	27 million MWh	-2
	SoCalGas - natural gas			1 million MMBtu	1 million MMBtu
	Energy-Related Businesses:
	Sempra Natural Gas - natural gas			7 million MMBtu	29 million MMBtu
	-1	Million British thermal units
	-2	Megawatt hours
	In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the 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. 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 March 31, 2015 and December 31, 2014, the net notional amounts of our interest rate derivatives, excluding the cross-currency swaps discussed below, were:
	INTEREST RATE DERIVATIVES
	(Dollars in millions)
			31-Mar-15			31-Dec-14
			Notional debt		Maturities	Notional debt		Maturities
	Sempra Energy Consolidated:
	Cash flow hedges(1)		$	396	2015-2028	$	399	2015-2028
	Fair value hedges			300	2016		300	2016
	SDG&E:
	Cash flow hedge(1)			322	2019		325	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 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 and joint ventures.
	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 of the Notes to Consolidated Financial Statements in the Annual Report.
	FINANCIAL STATEMENT PRESENTATION
	Each Condensed Consolidated Balance Sheet reflects the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets at March 31, 2015 and December 31, 2014, including the amount of cash collateral receivables that were not offset, as the cash collateral is in excess of liability positions.
	DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
	(Dollars in millions)
			31-Mar-15
										Deferred
										credits
				Current				Current		and other
				assets:				liabilities:		liabilities:
				Fixed-price		Investments		Fixed-price		Fixed-price
				contracts		and other		contracts		contracts
				and other		assets:		and other		and other
				derivatives(1)		Sundry		derivatives(2)		derivatives
	Sempra Energy Consolidated:
	Derivatives designated as hedging instruments:
	Interest rate and foreign exchange instruments(3)		$	10	$	3	$	-17	$	-130
	Derivatives not designated as hedging instruments:
	Interest rate and foreign exchange instruments			11		28		-7		-25
	Commodity contracts not subject to rate recovery			129		25		-137		-22
	Associated offsetting commodity contracts			-123		-21		123		21
	Associated offsetting cash collateral			―		―		10		1
Commodity contracts subject to rate recovery			28		76		-35		-33
Associated offsetting commodity contracts			-1		―		1		―
Associated offsetting cash collateral			―		―		27		27
Net amounts presented on the balance sheet			54		111		-35		-161
Additional cash collateral for commodity contracts
not subject to rate recovery			16		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			19		―		―		―
Total(4)		$	89	$	111	$	-35	$	-161
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	-16	$	-32
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery			―		―		-1		―
Associated offsetting cash collateral			―		―		1		―
Commodity contracts subject to rate recovery			26		76		-34		-33
Associated offsetting cash collateral			―		―		27		27
Net amounts presented on the balance sheet			26		76		-23		-38
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			17		―		―		―
Total(4)		$	44	$	76	$	-23	$	-38
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		$	―	$	―	$	-2	$	―
Associated offsetting cash collateral			―		―		2		―
Commodity contracts subject to rate recovery			2		―		-1		―
Associated offsetting commodity contracts			-1		―		1		―
Net amounts presented on the balance sheet			1		―		―		―
Additional cash collateral for commodity contracts
not subject to rate recovery			1		―		―		―
Additional cash collateral for commodity contracts
subject to rate recovery			2		―		―		―
Total		$	4	$	―	$	―	$	―
-1	Included in Current Assets: Other for SoCalGas.
-2	Included in Current Liabilities: Other for SoCalGas.
-3	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
-4	Normal purchase contracts previously measured at fair value are excluded.
DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
		31-Dec-14
									Deferred
									credits
			Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price		Investments		Fixed-price		Fixed-price
			contracts		and other		contracts		contracts
			and other		assets:		and other		and other
			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(3)		$	10	$	3	$	-17	$	-109
Commodity contracts not subject to rate recovery			25		―		―		―
Derivatives not designated as hedging instruments:
Interest rate instruments			8		27		-7		-22
Commodity contracts not subject to rate recovery			143		32		-135		-29
Associated offsetting commodity contracts			-129		-27		129		27
Associated offsetting cash collateral			-11		―		―		―
Commodity contracts subject to rate recovery			36		76		-36		-20
Associated offsetting commodity contracts			-3		-1		3		1
Associated offsetting cash collateral			―		―		23		13
Net amounts presented on the balance sheet			79		110		-40		-139
Additional cash collateral for commodity contracts
subject to rate recovery			14		―		―		―
Total(4)		$	93	$	110	$	-40	$	-139
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	-16	$	-31
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery			32		76		-32		-20
Associated offsetting commodity contracts			―		-1		―		1
Associated offsetting cash collateral			―		―		23		13
Net amounts presented on the balance sheet			32		75		-25		-37
Additional cash collateral for commodity contracts
subject to rate recovery			12		―		―		―
Total(4)		$	44	$	75	$	-25	$	-37
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery		$	4	$	―	$	-4	$	―
Associated offsetting commodity contracts			-3		―		3		―
Net amounts presented on the balance sheet			1		―		-1		―
Additional cash collateral for commodity contracts
subject to rate recovery			2		―		―		―
Total		$	3	$	―	$	-1	$	―
-1	Included in Current Assets: Other for SoCalGas.
-2	Included in Current Liabilities: Other for SoCalGas.
-3	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
-4	Normal purchase contracts previously measured at fair value are excluded.
The effects of derivative instruments designated as hedges on the Condensed Consolidated Statements of Operations and in Other Comprehensive Income (Loss) (OCI) and Accumulated Other Comprehensive Income (Loss) (AOCI) for the three months ended March 31 were
FAIR VALUE HEDGE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
			Gain (loss) on derivatives recognized in earnings
			Three months ended March 31,
		Location	2015		2014
Sempra Energy Consolidated:
Interest rate instruments		Interest Expense	$	2	$	3
Interest rate instruments		Other Income, Net		1		-4
Total(1)			$	3	$	-1
-1	There was no hedge ineffectiveness on these swaps in the three months ended March 31, 2015 and $2 million in the three months ended March 31, 2014. All other 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 and recorded in Other Income, Net.
CASH FLOW HEDGE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
		Pretax gain (loss) recognized						Gain (loss) reclassified from AOCI
		in OCI (effective portion)						into earnings (effective portion)
		Three months ended March 31,						Three months ended March 31,
		2015		2014			Location	2015		2014
Sempra Energy Consolidated:
Interest rate and foreign
exchange instruments(1)		$	-18	$	-3		Interest Expense	$	-6	$	-3
							Gain on Sale of Equity
Interest rate instruments			―		-2		Interest		―		-2
							Equity Earnings,
Interest rate instruments			-78		-15		Before Income Tax		-3		-3
Commodity contracts not subject							Revenues: Energy-Related
to rate recovery			-1		-6		Businesses		7		-10
Total(2)		$	-97	$	-26			$	-2	$	-18
SDG&E:
Interest rate instruments(1)(2)		$	-5	$	-3		Interest Expense	$	-3	$	-3
-1	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
-2	There was a negligible amount of ineffectiveness related to these hedges in 2015 and 2014.
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 $13 million in noncontrolling interests, of which $12 million is related to Otay Mesa VIE at SDG&E) related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts that are currently outstanding mature.
SoCalGas expects that negligible losses, which are net of income tax benefit, 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 March 31, 2015 is approximately 14 years and 4 years for Sempra Energy Consolidated and SDG&E, respectively. The maximum term of hedged interest rate variability is 20 years, and is related to debt at Sempra Renewables’ equity method investees.
The effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations for the three months ended March 31 were
UNDESIGNATED DERIVATIVE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Dollars in millions)
			Gain (loss) on derivatives recognized in earnings
			Three months ended March 31,
		Location	2015		2014
Sempra Energy Consolidated:
Foreign exchange instruments		Equity Earnings,
		Net of Income Tax	$	-1	$	-2
Commodity contracts not subject		Revenues: Energy-Related
to rate recovery		Businesses		3		-5
Commodity contracts subject		Cost of Electric Fuel
to rate recovery		and Purchased Power		-20		12
Commodity contracts subject
to rate recovery		Cost of Natural Gas		1		2
Total			$	-17	$	7
SDG&E:
Commodity contracts subject		Cost of Electric Fuel
to rate recovery		and Purchased Power	$	-20	$	12
SoCalGas:
Commodity contracts subject
to rate recovery		Cost of Natural Gas	$	1	$	2
CONTINGENT FEATURES
For Sempra Energy Consolidated 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 Consolidated, the total fair value of this group of derivative instruments in a net liability position at March 31, 2015 and December 31, 2014 is $7 million and $9 million, respectively. At March 31, 2015, if the credit ratings of Sempra Energy were reduced below investment grade, $7 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 was $4 million and $2 million at March 31, 2015 and December 31, 2014, respectively. At March 31, 2015, if the credit ratings of SDG&E were reduced below investment grade, $4 million of additional assets could be required to be posted as collateral for these derivative contracts.
For Sempra Energy Consolidated, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the 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	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Fair Value Measurements	NOTE 8. FAIR VALUE MEASUREMENTS
	We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We have not changed the valuation techniques or inputs we use to measure fair value during the three months ended March 31, 2015.
	Recurring Fair Value Measures
	The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2015 and December 31, 2014. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the 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 7 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 March 31, 2015 and December 31, 2014 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)
			Fair value at March 31, 2015
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts:
	Equity securities		$	666	$	―	$	―	$	―	$	666
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			58		53		―		―		111
	Municipal bonds			―		142		―		―		142
	Other securities			―		212		―		―		212
	Total debt securities			58		407		―		―		465
	Total nuclear decommissioning trusts(2)			724		407		―		―		1,131
	Interest rate and foreign exchange instruments			―		52		―		―		52
	Commodity contracts not subject to rate recovery			2		8		―		16		26
	Commodity contracts subject to rate recovery			―		1		102		19		122
	Total		$	726	$	468	$	102	$	35	$	1,331
	Liabilities:
	Interest rate and foreign exchange instruments		$	―	$	179	$	―	$	―	$	179
	Commodity contracts not subject to rate recovery			6		9		―		-11		4
	Commodity contracts subject to rate recovery			―		67		―		-54		13
	Total		$	6	$	255	$	―	$	-65	$	196
			Fair value at December 31, 2014
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts:
	Equity securities		$	655	$	―	$	―	$	―	$	655
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			62		47		―		―		109
	Municipal bonds			―		129		―		―		129
	Other securities			―		207		―		―		207
	Total debt securities			62		383		―		―		445
	Total nuclear decommissioning trusts(2)			717		383		―		―		1,100
	Interest rate and foreign exchange instruments			―		48		―		―		48
	Commodity contracts not subject to rate recovery			28		16		―		-11		33
	Commodity contracts subject to rate recovery			―		1		107		14		122
	Total		$	745	$	448	$	107	$	3	$	1,303
	Liabilities:
	Interest rate and foreign exchange instruments		$	―	$	155	$	―	$	―	$	155
	Commodity contracts not subject to rate recovery			3		9		―		-4		8
	Commodity contracts subject to rate recovery			―		52		―		-36		16
	Total		$	3	$	216	$	―	$	-40	$	179
	-1	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
	-2	Excludes cash balances and cash equivalents.
	RECURRING FAIR VALUE MEASURES – SDG&E
	(Dollars in millions)
			Fair value at March 31, 2015
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts:
	Equity securities		$	666	$	―	$	―	$	―	$	666
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			58		53		―		―		111
Municipal bonds			―		142		―		―		142
Other securities			―		212		―		―		212
Total debt securities			58		407		―		―		465
Total nuclear decommissioning trusts(2)			724		407		―		―		1,131
Commodity contracts not subject to rate recovery			―		―		―		1		1
Commodity contracts subject to rate recovery			―		―		102		17		119
Total		$	724	$	407	$	102	$	18	$	1,251
Liabilities:
Interest rate instruments		$	―	$	48	$	―	$	―	$	48
Commodity contracts not subject to rate recovery			1		―		―		-1		―
Commodity contracts subject to rate recovery			―		67		―		-54		13
Total		$	1	$	115	$	―	$	-55	$	61
		Fair value at December 31, 2014
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	655	$	―	$	―	$	―	$	655
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			62		47		―		―		109
Municipal bonds			―		129		―		―		129
Other securities			―		207		―		―		207
Total debt securities			62		383		―		―		445
Total nuclear decommissioning trusts(2)			717		383		―		―		1,100
Commodity contracts subject to rate recovery			―		―		107		12		119
Total		$	717	$	383	$	107	$	12	$	1,219
Liabilities:
Interest rate instruments		$	―	$	47	$	―	$	―	$	47
Commodity contracts not subject to rate recovery			1		―		―		-1		―
Commodity contracts subject to rate recovery			―		51		―		-36		15
Total		$	1	$	98	$	―	$	-37	$	62
-1	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
-2	Excludes cash balances and cash equivalents.
RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
		Fair value at March 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts not subject to rate recovery		$	―	$	―	$	―	$	1	$	1
Commodity contracts subject to rate recovery			―		1		―		2		3
Total		$	―	$	1	$	―	$	3	$	4
Liabilities:
Commodity contracts not subject to rate recovery		$	2	$	―	$	―	$	-2	$	―
Total		$	2	$	―	$	―	$	-2	$	―
		Fair value at December 31, 2014
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	2	$	3
Total		$	―	$	1	$	―	$	2	$	3
Liabilities:
Commodity contracts not subject to rate recovery		$	2	$	―	$	―	$	-2	$	―
Commodity contracts subject to rate recovery			―		1		―		―		1
Total		$	2	$	1	$	―	$	-2	$	1
-1	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
Level 3 Information
The following table sets forth reconciliations of changes in the fair value of Congestion Revenue Rights (CRRs) classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E:
LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Three months ended March 31,
	2015		2014
Balance at January 1	$	107	$	99
Realized and unrealized gains		6		1
Allocated transmission instruments		―		1
Settlements		-11		-6
Balance at March 31	$	102	$	95
Change in unrealized gains or losses relating to
instruments still held at March 31	$	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 (CAISO), an objective source. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following calendar year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. From January 1, 2015 to December 31, 2015 the auction prices range from $(16) per MWh to $8 per MWh at a given location, and from January 1, 2014 to December 31, 2014 the auction prices ranged from $(6) per MWh to $12 per MWh at a given location. The fair value of these instruments is derived from auction price differences between two locations. 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 7. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Condensed 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. The following table provides the carrying amounts and fair values of certain other financial instruments at March 31, 2015 and December 31, 2014:
FAIR VALUE OF FINANCIAL INSTRUMENTS
(Dollars in millions)
		31-Mar-15
		Carrying			Fair value
		amount			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Total long-term debt(1)(2)		$	13,176		$	―	$	13,889	$	895	$	14,784
Preferred stock of subsidiary			20			―		23		―		23
SDG&E:
Total long-term debt(2)(3)		$	4,849		$	―	$	5,061	$	422	$	5,483
SoCalGas:
Total long-term debt(4)		$	1,913		$	―	$	2,167	$	―	$	2,167
Preferred stock			22			―		25		―		25
		31-Dec-14
		Carrying			Fair value
		amount			Level 1		Level 2		Level 3		Total
Sempra Energy Consolidated:
Total long-term debt(1)(2)		$	12,347		$	―	$	12,782	$	917	$	13,699
Preferred stock of subsidiary			20			―		23		―		23
SDG&E:
Total long-term debt(2)(3)		$	4,461		$	―	$	4,563	$	425	$	4,988
SoCalGas:
Total long-term debt(4)		$	1,913		$	―	$	2,124	$	―	$	2,124
Preferred stock			22			―		25		―		25
-1	Before reductions for unamortized discount (net of premium) of $23 million and $21 million at March 31, 2015 and December 31, 2014, respectively, and excluding build-to-suit and capital leases of $336 million and $310 million at March 31, 2015 and December 31, 2014, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
-2	Level 3 instruments include $322 million and $325 million at March 31, 2015 and December 31, 2014, respectively, related to Otay Mesa VIE.
-3	Before reductions for unamortized discount of $12 million and $11 million at March 31, 2015 and December 31, 2014, respectively, and excluding capital leases of $232 million and $234 million at March 31, 2015 and December 31, 2014, respectively.
-4	Before reductions for unamortized discount of $7 million and $8 million at March 31, 2015 and December 31, 2014, respectively, and excluding capital leases of $1 million at December 31, 2014.
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 provide the fair values for the securities held in the nuclear decommissioning trust funds related to SONGS in Note 9 below.

NUCLEAR_PLANT

NUCLEAR PLANT	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Nuclear Plant	NOTE 9. SAN ONOFRE NUCLEAR GENERATING STATION (SONGS)
	SDG&E has a 20-percent ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which ceased operations in June 2013. On June 6, 2013, Southern California Edison Company (Edison), the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the Nuclear Regulatory Commission (NRC) to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC.
	SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of expenses and capital expenditures. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Condensed Consolidated Statements of Operations.
	SONGS Outage and Retirement
	Background
	As part of the Steam Generator Replacement Project (SGRP), the steam generators were replaced in SONGS Units 2 and 3, and the Units returned to service in 2010 and 2011, respectively. Both Units were shut down in early 2012 after a water leak occurred in the Unit 3 steam generator. Edison concluded that the leak was due to unexpected wear from tube-to-tube contact. At the time the leak was identified, Edison also inspected and tested Unit 2 and subsequently found unexpected tube wear in Unit 2’s steam generator. 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 for Edison 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 repairs or modifications would be required to return the Unit to service in a safe manner. The NRC was reviewing the restart plan for Unit 2 proposed by Edison when 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 replacement steam generators were designed and provided by Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). In July 2013, SDG&E filed a lawsuit against MHI seeking to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators. In October 2013, Edison instituted arbitration proceedings against MHI seeking damages as well. We discuss these proceedings in Note 11.
	Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII)
	SONGS OII
	In November 2012, in response to the outage, the CPUC issued the SONGS OII, pursuant to California Public Utilities’ Code Section 455.5, which applies to cost recovery issues resulting from long-term outages of operating assets. The SONGS OII consolidated most SONGS outage-related issues into a single proceeding. The SONGS OII, among other things, designated all revenues associated with the investment in, and operation of, SONGS since January 1, 2012 as subject to refund to customers, pending the outcome of all phases of the proceeding. The SONGS OII proceeding was intended to determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outage, including purchased replacement power costs, which are typically recovered through the Energy Resource Recovery Account (ERRA).
	Entry Into Settlement Agreement
	Pursuant to CPUC rules concerning settlements, SDG&E, Edison, The Utility Reform Network (TURN), and the CPUC Office of Ratepayer Advocates (ORA) held a settlement conference in March 2014 to discuss the terms to resolve the SONGS OII, and in April 2014, SDG&E, along with Edison, TURN, ORA and two other intervenors who joined the Settlement Agreement to the SONGS OII proceeding (collectively, the Settling Parties), filed a Settlement Agreement with the CPUC. On September 5, 2014, the CPUC issued a ruling proposing specific changes that included, as they relate to SDG&E, greater ratepayer benefit from third party cost recoveries and funding of a research program to reduce greenhouse gas emissions at a shareholder cost of $1 million per year for 5 years.
	On September 23, 2014, the Settling Parties executed an Amended and Restated Settlement Agreement (Amended Settlement Agreement), which amended the Settlement Agreement to adopt all of the modifications and clarifications requested in the CPUC ruling. On October 9, 2014, the CPUC issued a proposed decision approving the Amended Settlement Agreement, which was adopted by the CPUC as a final decision on November 20, 2014.
	As approved by the CPUC, the Amended Settlement Agreement constitutes a complete and final resolution of the SONGS OII and related CPUC proceedings regarding the SGRP at SONGS and the related outage and subsequent shutdown of SONGS. This resolution also required the compliance filing referenced below under “Accounting and Financial Impacts.” The Amended Settlement Agreement does not affect on-going or future proceedings before the NRC, or litigation or arbitration related to potential future recoveries from third parties (except for the allocation to ratepayers of any recoveries as described below) or proceedings addressing decommissioning activities and costs.
	In November 2014, in accordance with the Amended Settlement Agreement, SDG&E filed an advice letter seeking authority from the CPUC, among other things, to implement the terms and establish the revenue requirement in accordance with the Amended Settlement Agreement in rates starting January 1, 2015. In December 2014, the CPUC approved the advice letter and authorized SDG&E to update rates accordingly, subject to revision pending the results of a CPUC review of the changes to the revenue requirement proposed by SDG&E for consistency with the terms of the approved settlement decision. In March 2015, SDG&E received a final disposition letter from the CPUC confirming that SDG&E’s proposed rate changes were in compliance with the approved settlement decision.
	In April 2015, a petition for modification (PFM) was filed with the CPUC by Alliance for Nuclear Responsibility (A4NR), an intervenor in the SONGS OII proceeding, regarding the CPUC decision approving the Amended Settlement Agreement. SDG&E is unable to determine what actions the CPUC will take in response to the PFM.
	We discuss the terms of the Amended Settlement Agreement in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.
	Accounting and Financial Impacts
	Through March 31, 2015, the cumulative after-tax loss from plant closure recorded by Sempra Energy and SDG&E is $127 million, including a reduction in the after-tax loss of $13 million recorded in the first quarter of 2015 based on the CPUC’s approval in March 2015 of SDG&E’s compliance filing and establishment of the SONGS settlement revenue requirement.
	In the second quarter of 2013, based on an initial assessment of the financial impact of the outcome of the SONGS OII proceeding, SDG&E reported an after-tax loss from plant closure of $119 million. In the first quarter of 2014, after entering into the Settlement Agreement, SDG&E recorded a $9 million increase in the after-tax loss. In the fourth quarter of 2014, based on the compliance filing regarding SDG&E’s annual revenue requirement and the timing of refunds to ratepayers, SDG&E recorded an increase to the loss, after-tax, of $12 million.
	The regulatory asset for the expected recovery of SONGS costs, consistent with the Amended Settlement Agreement, is $294 million ($41 million current and $253 million long-term) at March 31, 2015 and is recorded on the Condensed Consolidated Balance Sheets in Other Current Assets and Regulatory Assets Noncurrent at Sempra Energy and in Regulatory Assets Current and Other Regulatory Assets Noncurrent at SDG&E.
	NRC Proceedings
	In December 2013, Edison received a final NRC Inspection Report that identified a violation for the failure to verify the adequacy of the thermal-hydraulic and flow-induced vibration design of the Unit 3 replacement steam generator. In January 2014, Edison provided a response to the NRC Inspection Report stating that MHI, as contracted by Edison to prepare the SONGS replacement steam generator design, was the party responsible for validating the design of the steam generators.
	In addition, the NRC issued an Inspection Report to MHI containing a Notice of Nonconformance for its flawed computer modeling in the design of the replacement steam generators.
	Because SONGS has ceased operation, NRC inspection oversight of SONGS will now be continued through the NRC’s Decommissioning Power Reactor Inspection Program to verify that decommissioning activities are being conducted safely, that spent fuel is safely stored 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. We discuss the process of decommissioning SONGS in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.
	In accordance with state and federal requirements and regulations, SDG&E has assets held in trusts, referred to as the Nuclear Decommissioning Trusts (NDT), to fund decommissioning costs for SONGS Units 1, 2 and 3. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work will be done when Units 2 and 3 are decommissioned. At March 31, 2015, the fair value of SDG&E’s NDT assets was $1.2 billion. Except for the use of funds for the planning of decommissioning activities or NDT administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In February 2014, SDG&E filed a request with the CPUC for such authorization for costs incurred in 2013. In April 2015, SDG&E withdrew its pending request and filed a new request based on updated decommissioning cost information, seeking authorization to access trust funds for decommissioning costs incurred in 2013. SDG&E expects CPUC approval of the request in 2015. Until CPUC approval to access the NDT to pay for such costs is received, SDG&E will use working capital to pay for any SONGS Units 2 and 3 decommissioning costs incurred, and such expenditures will be reimbursed from the NDT upon that approval.
	We discuss the NDT and matters related to its funding and the funding of decommissioning costs by the NDT further in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report.
	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 Condensed 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 NDT:
	NUCLEAR DECOMMISSIONING TRUSTS
	(Dollars in millions)
						Gross		Gross		Estimated
						unrealized		unrealized		fair
				Cost		gains		losses		value
	At March 31, 2015:
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies(1)		$	103	$	8	$	―	$	111
	Municipal bonds(2)			134		8		―		142
	Other securities(3)			211		9		-8		212
	Total debt securities			448		25		-8		465
	Equity securities			218		452		-4		666
	Cash and cash equivalents			19		―		―		19
	Total		$	685	$	477	$	-12	$	1,150
	At December 31, 2014:
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies		$	103	$	6	$	―	$	109
	Municipal bonds			121		8		―		129
	Other securities			206		7		-6		207
	Total debt securities			430		21		-6		445
	Equity securities			215		444		-4		655
	Cash and cash equivalents			30		1		―		31
	Total		$	675	$	466	$	-10	$	1,131
	-1	Maturity dates are 2015-2060.
	-2	Maturity dates are 2015-2114.
	-3	Maturity dates are 2015-2111.
	The following table shows the proceeds from sales of securities in the NDT and gross realized gains and losses on those sales:
	SALES OF SECURITIES
	(Dollars in millions)
		Three months ended March 31,
		2015		2014
Proceeds from sales(1)		$	94	$	195
Gross realized gains			2		4
Gross realized losses			-4		-4
-1	Excludes securities that are held to maturity.
Net unrealized gains (losses) are included in Regulatory Liabilities Arising from Removal Obligations on Sempra Energy’s and SDG&E’s Condensed Consolidated Balance Sheets. We determine the cost of securities in the trusts on the basis of specific identification.
We provide additional information about SONGS in Note 11.

CALIFORNIA_UTILITIES_REGULATOR

CALIFORNIA UTILITIES' REGULATORY MATTERS	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Sempra Utilities' Regulatory Matters	NOTE 10. CALIFORNIA UTILITIES' REGULATORY MATTERS
	We discuss regulatory matters affecting our California Utilities in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and details of any new matters below.
	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.
	The California Utilities filed their 2016 General Rate Case (2016 GRC) applications in November 2014. These filings requested revenue requirement increases of $133 million and $256 million for SDG&E and SoCalGas, respectively, over their 2015 revenue requirements. In February 2015, the CPUC issued a scoping memo setting the schedule for the proceeding, including the issuance of a proposed decision by the end of 2015. In March 2015, the California Utilities revised their requests to make various updates and reflect the impact of the Tax Increase Prevention Act signed into law in December 2014. At SoCalGas, this resulted in a reduction of $10 million compared to its original request, or a total revenue requirement in 2016 of $2.342 billion. This is an increase of $246 million or 12 percent over 2015, excluding the impact of the 2015 revenue requirement increase discussed below under “Increase to CPUC-Authorized Annual Revenue Requirement.” At SDG&E, the March 2015 revised request resulted in a reduction of $6 million compared to its original request, or a total revenue requirement in 2016 of $1.905 billion. This is an increase of $111 million or 6 percent over 2015. This increase includes an adjustment of $16 million to the comparable 2015 estimated revenue requirement since the November 2014 filings.
	The ORA served its report and testimony in the 2016 GRC on April 24, 2015. The California Utilities are in the process of analyzing the ORA’s report and financial model. The ORA recommends an increase of $70 million (3.3 percent over 2015) in 2016 compared to SoCalGas’ request of a $246 million increase. The ORA further recommended increases for SoCalGas of $76 million (3.5 percent) and $78 million (3.5 percent) in 2017 and 2018, respectively. With regard to SDG&E, the ORA recommends a $62 million (3.5 percent less than 2015) decrease in 2016 compared to SDG&E’s request for a $111 million increase. In 2017 and 2018, the ORA recommends increases of $61 million (3.5 percent) and $63 million (3.5 percent), respectively. In addition, the ORA recommends that SDG&E and SoCalGas continue a four-year rate case cycle (2016-2019), rather than adopt a three-year cycle. Testimony from other intervening parties is due on May 15, 2015 with ten days of public participation hearings from May 12 through June 10, 2015. The California Utilities plan on filing rebuttal testimony to the ORA’s and other intervenors’ testimony by June 12, 2015.
	We provide additional information regarding the 2016 GRC in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
	Natural Gas Pipeline Operations Safety Assessments
	In June 2014, the CPUC issued a final decision in the Triennial Cost Allocation Proceeding (TCAP) addressing SDG&E’s and SoCalGas’ Pipeline Safety Enhancement Plan (PSEP). Specifically, the decision:
	approved the utilities’ model for implementing PSEP;
	approved a process, including a reasonableness review, to determine the amount that the utilities will be authorized to recover from ratepayers for the interim costs incurred through the date of the final decision to implement PSEP, which is recorded in the regulatory accounts authorized by the CPUC as noted above;
	approved balancing account treatment, subject to a reasonableness review, for incremental costs yet to be incurred to implement PSEP; and
	established the criteria to determine the amounts that would not be eligible for cost recovery, including:
	certain costs incurred or to be incurred searching for pipeline test records,
	the cost of pressure testing pipelines installed after July 1, 1961 for which the company has not found sufficient records of testing, and
	any undepreciated balances for pipelines installed after 1961 that were replaced due to insufficient documentation of pressure testing.
	As a result of this decision, SoCalGas recorded an after-tax earnings charge of $5 million in 2014 for costs incurred in prior periods for which SoCalGas was disallowed recovery. After taking the amounts disallowed for recovery into consideration, as of March 31, 2015, SDG&E and SoCalGas have recorded PSEP costs of $4 million and $104 million, respectively, in the CPUC-authorized regulatory account. In regard to requesting recovery from customers for PSEP costs incurred and recorded in accordance with the TCAP decision, SDG&E and SoCalGas are authorized to file an application with the CPUC for recovery of such costs up to the date of the TCAP decision and then annually for costs incurred through the end of each calendar year beginning with the period ending December 31, 2015. SoCalGas and SDG&E currently expect to file such applications no later than the third quarter of the year following and would expect a decision from the CPUC approximately 12 to 18 months following the date of the application (i.e., a decision on the recovery of costs recorded in the PSEP regulatory accounts as of December 31, 2015 would be expected by mid-2017).
	In response to this significant delay in receiving the authority to recover PSEP costs incurred from customers, in October 2014, SDG&E and SoCalGas filed a petition for modification with the CPUC requesting authority to begin to recover PSEP costs from customers in the year in which the costs are incurred, subject to refund pending the results of a reasonableness review by the CPUC, instead of in a subsequent year. This request is pending at the CPUC.
	In December 2014, SDG&E and SoCalGas filed an application with the CPUC for recovery of $0.1 million and $46 million, respectively, in costs recorded in the regulatory account through June 11, 2014. We expect a decision on this application in the first half of 2016.
	In July 2014, the ORA and TURN filed a joint application for rehearing of the CPUC’s June 2014 final decision. The ORA and TURN alleged that the CPUC made a legal error in directing that ratepayers, not shareholders, be responsible for the costs associated with testing or replacing transmission pipelines that were installed between January 1, 1956 and July 1, 1961 for which the California Utilities do not have a record of a pressure test. In November 2014, the CPUC denied the ORA and TURN request for rehearing of the decision adopting the PSEP. In December 2014, ORA and TURN sought rehearing of the CPUC’s decision on rehearing. In late December 2014, SoCalGas and SDG&E filed their opposition to this second application for rehearing, and are continuing to implement PSEP in accordance with the June 2014 CPUC decision. In March 2015, the CPUC issued a decision denying ORA’s and TURN’s second request for rehearing, but keeping the record in the proceeding open to admit additional evidence on the limited issue of pressure testing of pipelines installed between January 1, 1956 and July 1, 1961. As part of this review, the CPUC will allow parties to submit additional evidence relevant to this narrow issue to ensure a complete record, with no additional discovery allowed. The ORA and TURN filed their responses on May 1, 2015.
	We provide additional information regarding these rulemaking proceedings and the California Utilities’ PSEP in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
	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 Project, the project will enhance reliability on the southern portions of the California Utilities’ integrated natural gas transmission system (Southern System). The estimated cost of the project, as originally filed, is between $800 million to $850 million. As originally proposed, the project consisted of three components: 1) constructing an approximately 60-mile, 36-inch natural gas transmission pipeline between the SoCalGas Adelanto compressor station and the Moreno pressure limiting station; 2) upgrading the Adelanto compressor station; and 3) constructing an approximately 31-mile, 36-inch pipeline from the Moreno pressure limiting station to a pressure limiting station in Whitewater. In November 2014, the California Utilities revised the scope of the proposed project to only include connecting the Adelanto compressor station and Moreno pressure limiting station with approximately 65 miles of 36-inch pipeline and upgrading the Adelanto compressor station, and eliminating the Moreno-Whitewater pipeline. The estimated cost of the revised project, including updated cost estimates, remains unchanged from the original cost estimate of between $800 million and $850 million, while providing comparable benefits for customers. In March 2015, the CPUC issued a revised scoping ruling establishing a schedule, directing that the Moreno-Whitewater portion of the original project be excluded from scope and that any other future projects would be addressed separately. If approved by the CPUC and subject to environmental permitting, given the revised project scope and updated schedule in this proceeding, the project could commence construction in 2017 and be in service by the end of 2019.
	We provide additional information about the project in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report.
	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.
	We provide additional information regarding these incentive mechanisms in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and below.
	Natural Gas Procurement
	In February 2015, the CPUC issued a final decision approving SoCalGas’ application for a gas cost incentive mechanism (GCIM) award of $13.7 million for natural gas procured for its core customers during the 12-month period ending March 31, 2014. SoCalGas recorded this award in the first quarter of 2015.
	SDG&E MATTERS
	SONGS
	We discuss regulatory and other matters related to SONGS in Note 9.
	Power Procurement and Resource Planning
	Cleveland National Forest Transmission Projects
	SDG&E filed an application with the CPUC in October 2012 for a permit to construct various transmission line replacement projects in and around the Cleveland National Forest (CNF). The proposed projects will replace and fire-harden five existing transmission lines and six existing distribution 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 draft environmental impact report (EIR/EIS), developed jointly by the CPUC and USFS, was issued in September 2014 and a final EIR/EIS is expected in the second quarter of 2015. SDG&E currently expects a CPUC decision on the transmission projects in the second 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.
	Sycamore-Peñasquitos Transmission Project
	In March 2014, the CAISO selected SDG&E, as a result of a competitive bid process, to construct the Sycamore-Peñasquitos 230-kilovolt (kV) transmission project, which will provide a 16.7-mile transmission connection between SDG&E’s Sycamore Canyon and Peñasquitos substations. In July 2014, the CPUC notified SDG&E that the application requesting a Certificate of Public Convenience and Necessity (CPCN) to construct the line, which was filed with the CPUC in April 2014, is complete. The estimated $120 million to $150 million project was identified by the CAISO and a state task force as necessary to ensure grid reliability given the closure of SONGS. The project will also serve to strengthen renewable energy infrastructure in the region. In October 2014, SDG&E filed a request with the Federal Energy Regulatory Commission (FERC) seeking, among other things, a 100 basis point return on equity (ROE) adder for this project. In April 2015, FERC issued an order granting SDG&E’s request for 100 percent abandoned plant cost recovery, but denying an ROE adder for the project. SDG&E expects a CPUC decision on the project in the first half of 2016, with the line expected to be in service in mid-2017.
	South Orange County Reliability Enhancement
	SDG&E filed an application with the CPUC in May 2012 requesting a CPCN for the South Orange County Reliability Enhancement project, as we discuss in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report. A draft environmental report was issued in the first quarter of 2015, and SDG&E expects a final CPUC decision on the estimated $400 million to $500 million project in the first half of 2016. As the project is planned in phases, SDG&E currently expects the entire project to be in service in 2020.
	SOCALGAS MATTERS
	Triennial Cost Allocation Proceeding (TCAP) – Adoption of Seasonal Factors
	The TCAP decision issued by the CPUC in June 2014 for SoCalGas included, among other matters, the requirement for SoCalGas to apply seasonal factors throughout the year to SoCalGas’ annual authorized revenue for its core natural gas customers effective January 1, 2015. Core customers are primarily residential and small commercial and industrial customers. The seasonal factors adopted are based on the core demand forecast provided by SoCalGas in the TCAP application. Prior to this decision, this annual authorized revenue was recognized ratably over the year. While this “seasonalization” will not impact SoCalGas’ total calendar year revenue or earnings for 2015 or beyond, and does not change the annual total authorized revenue or our earnings from that revenue, it will cause variability in revenue and earnings from quarter to quarter. We expect that as a result of applying the seasonal factors during interim periods to the annual authorized revenue requirement, the core natural gas customer authorized revenue recognized in the first and fourth quarters of each year beginning with 2015 will be higher (approximately 34 percent in the first quarter and 29 percent in the fourth quarter) than that recognized in the second and third quarters of each year (approximately 21 percent in the second quarter and 16 percent in the third quarter). This compares to recognizing 25 percent of the annual authorized revenue in each quarter in prior years. As a result, beginning in 2015, substantially all of SoCalGas’ annual earnings will be recognized in the first and fourth quarters of the year.
	Seasonalization will not impact interim period cash flows or customers’ bills. However, it should reduce the interim period variability in regulatory balancing accounts, as we expect customer billings to more closely align with interim period revenue recognition. This seasonalization is consistent with SDG&E’s natural gas and power distribution authorized revenue treatment.
	The CPUC regulatory framework authorizes SoCalGas to recover the actual cost of natural gas procured and delivered to its core customers in rates substantially as incurred. The regulatory framework also permits SoCalGas to recover its cost of operations, including depreciation of its fixed assets, in authorized revenue based on estimated annual natural gas demand forecasts approved in the TCAP, and any difference between actual gas demand and the annual natural gas demand approved in the TCAP is recovered in authorized revenue in the subsequent year. This design, commonly known as “decoupling,” is intended to minimize any impact on SoCalGas’ earnings of changes in the cost of natural gas procured and any variability in customer demand for natural gas. The adoption of applying seasonal factors to authorized annual requirement for interim periods does not change the application of decoupling.
	Increase to CPUC-Authorized Annual Revenue Requirement
	In July 2011, SoCalGas updated its testimony in the 2012 GRC to reflect the impact of the extension of temporary bonus depreciation by the Tax Relief, Unemployment Insurance Reauthorization, and Job Creation Act of 2010 (2010 Tax Act). The 2010 Tax Act’s extension of bonus depreciation for U.S. federal income tax purposes for years 2010 through 2012 resulted in significant additional tax depreciation deductions. These additional deductions generated U.S. federal net operating losses (NOLs) and the creation of an NOL-based deferred tax asset. The 2012 GRC decision denied recovery of any return associated with the NOL-based deferred tax asset unless an Internal Revenue Service (IRS) Private Letter Ruling (PLR) was obtained, at which point SoCalGas would be authorized to file an advice letter seeking an increase to its revenue requirement. In February 2015, the IRS issued a PLR that agreed with SoCalGas’ position that the denial of any return on the NOL-based deferred tax asset was a violation of tax normalization rules.
	In March 2015, SoCalGas filed an advice letter to provide the PLR to the CPUC and request an increase to its authorized GRC revenue requirement for 2012 through 2015 to comply with the normalization requirements as interpreted by the IRS in the PLR. In April 2015, the CPUC approved SoCalGas’ advice letter. The approved increases to the pretax annual revenue requirements are $6.4 million for 2012, $6.3 million for 2013, $6.4 million for 2014 and $6.6 million for 2015. The resulting increase to after-tax earnings of an aggregate of $11.3 million for years 2012 through 2014 and $1.4 million related to the first quarter of 2015 will be recorded in the second quarter of 2015 with the remaining 2015 after-tax earnings of $2.5 million resulting from this being recognized over the last three quarters of the year.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Commitments and Contingencies	NOTE 11. COMMITMENTS AND CONTINGENCIES
	LEGAL PROCEEDINGS
	We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could 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 March 31, 2015, Sempra Energy’s accrued liabilities for material legal proceedings, including associated legal fees and costs of litigation, on a consolidated basis, were $57 million. At March 31, 2015, accrued liabilities for material legal proceedings for SDG&E and SoCalGas were $39 million and $12 million, respectively.
	SDG&E
	2007 Wildfire Litigation
	In October 2007, San Diego County experienced several catastrophic wildfires. Reports issued by the California Department of Forestry and Fire Protection (Cal Fire) concluded that two of these fires (the Witch and Rice fires) were SDG&E “power line caused” and that a third fire (the Guejito fire) occurred when a wire securing a Cox Communications’ (Cox) fiber optic cable came into contact with an SDG&E power line “causing an arc and starting the fire.”
	A September 2008 staff report issued by the CPUC’s Consumer Protection and Safety Division, now known as the Safety and Enforcement Division, reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice 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 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. They asserted various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without regard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines. SDG&E has resolved almost all of these lawsuits. Four of these cases have been scheduled for damages-only trials in 2015, where the value of any compensatory damages resulting from the fires will be determined.
	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 party contractors and Cox. 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 agreed to 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. Through March 31, 2015, SDG&E has expended $493 million in excess of amounts covered by insurance and amounts recovered from third parties to pay for the settlement of wildfire claims and related costs.
	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 now settled almost all of these claims of the approximately 6,500 plaintiffs for a total of approximately $1.3 billion. Substantially all of the remaining plaintiffs have submitted settlement demands and damage estimates, which total approximately $60 million. SDG&E does not expect additional plaintiffs to file lawsuits given the applicable statutes of limitation, but could receive additional settlement demands and damage estimates from existing plaintiffs until those cases are resolved. SDG&E has established reserves for the wildfire litigation as we discuss below.
	SDG&E has concluded that it is probable that it will be permitted to recover in rates a substantial portion of the costs incurred to resolve wildfire claims in excess of its liability insurance coverage and the amounts recovered from third parties. Accordingly, although such recovery will require future regulatory approval, at March 31, 2015, Sempra Energy and SDG&E have recorded assets of $372 million in Other Regulatory Assets (long-term) on their Condensed Consolidated Balance Sheets, including $367 million related to CPUC-regulated operations, which represents the amount substantially equal to the aggregate amount it has paid and 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 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. 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 March 31, 2015, the resulting after-tax charge against earnings would have been up to approximately $217 million. Recovery of these costs 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 results of operations and cash flows.
	We provide additional information about excess wildfire claims cost recovery and related CPUC actions in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report and discuss how we assess the probability of recovery of our regulatory assets in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.
	Sunrise Powerlink Electric Transmission Line
	In February 2011, opponents of the Sunrise Powerlink, a 500-kV electric transmission line between the Imperial Valley and the San Diego region that was energized and placed in service in June 2012, filed a lawsuit in Sacramento County Superior Court against the State Water Resources Control Board and SDG&E alleging that the water quality certification issued by the Board under the Federal Clean Water Act violated the California Environmental Quality Act. The Superior Court denied the plaintiffs’ petition in July 2012, and the plaintiffs have appealed.
	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 counterclaim against Edison. On March 14, 2014, MHI’s motion to stay the United States District Court proceeding was granted with instructions that require the parties to allow SDG&E to participate in the ongoing Edison/MHI arbitration. As a result, SDG&E is now participating in the arbitration as a claimant and respondent.
	Investment in Wind Farm
	In 2011, the CPUC and FERC approved SDG&E’s estimated $285 million tax equity investment in a wind farm project and its purchase of renewable energy credits from that project. SDG&E’s contractual obligations to both invest in the Rim Rock wind farm and to purchase renewable energy credits from the wind farm under the power purchase agreement are subject to the satisfaction of certain conditions which, if not achieved, would allow SDG&E to terminate the power purchase agreement and not make the investment. In December 2013, SDG&E received a closing notice from the project developer indicating that all such conditions had been met. SDG&E responded to the closing notice asserting that the contractual conditions had not been satisfied. On December 19, 2013, SDG&E filed a complaint against the project developer in San Diego Superior Court, asking that the court determine that SDG&E is entitled to terminate both the investment contract and the power purchase agreement due to the project developer’s failure to satisfy certain conditions. The project developer filed a separate complaint against SDG&E in Montana state court asking that court to determine that SDG&E breached the investment contract and the power purchase agreement, and asking for several categories of relief, including requiring SDG&E to invest in the project, requiring SDG&E to continue performing under the power purchase agreement, and payment of damages.
	On January 27, 2014, the Montana court ordered SDG&E to continue making payments under the power purchase agreement pending a hearing on the project developer’s preliminary injunction motion. On March 14, 2014, SDG&E notified the project developer that the investment agreement expired by its own terms because a closing had not occurred by that date. The project developer is disputing SDG&E’s position. On March 28, 2014, SDG&E filed an amended complaint against the project developer in San Diego seeking damages and declaratory relief that SDG&E was entitled to terminate the power purchase agreement and to permit the investment agreement to expire. On April 25, 2014, the Montana court granted the project developer’s preliminary injunction motion to prevent SDG&E from terminating the power purchase agreement on the grounds that the project developer would be irreparably harmed if the payments were not made while the parties’ respective rights were being determined in the litigation. The court did not rule on the merits of the parties’ claims. On July 18, 2014, the Montana Supreme Court determined that the parties’ contractual agreement to resolve any disputes in San Diego was mandatory, and ordered that the Montana action be dismissed. The San Diego court has scheduled a trial in January 2016.
	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 four of the seven lawsuits for an amount that is not significant.
	Sempra Mexico
	Permit Challenges and Property Disputes
	Sempra Mexico has been engaged in a long-running land dispute relating to property adjacent to its Energía Costa Azul LNG terminal near Ensenada, Mexico. Ownership of the adjacent property is not required by any of the environmental or other regulatory permits issued for the operation of the terminal. A claimant to the adjacent property has nonetheless 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 municipality of Ensenada opened an administrative proceeding and sought to temporarily close the terminal based on claims of irregularities in municipal permits issued six years earlier. This attempt was promptly countermanded by Mexican federal and Baja California state authorities. No terminal permits or operations were affected as a result of these proceedings or events and the terminal has continued to operate normally. In the second quarter of 2014, the municipality of Ensenada dismissed the administrative proceeding, which is subject to an administrative appeal, pending for resolution before the Administrative Court of Baja California. 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 also filed complaints in the federal Agrarian Court challenging the refusal of the Secretaría de la 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. Sempra Energy has disputed the claims and allegations in this lawsuit.
	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 in March 2014, issued a resolution denying the relief sought by the plaintiff on the grounds its action was not timely presented. 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.
	Two real property cases have been filed 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 purchased another of the terminal parcels, on the grounds the purchase price was unfair. Sempra Mexico expects further proceedings on the remaining two matters.
	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.
	Since April 2012, a total of 11 lawsuits have been filed against Mobile Gas in Mobile County Circuit Court alleging that in the first half of 2008 Mobile Gas spilled tert-butyl mercaptan, an odorant added to natural gas for safety reasons, in Eight Mile, Alabama. The lawsuits include approximately 350 individual plaintiffs and a putative class action, allege nuisance and negligence causes of action, and seek unspecified compensatory and punitive damages. An initial trial involving eight plaintiffs is scheduled for trial in June 2015.
	Other Litigation
	Sempra Energy holds a noncontrolling interest in RBS Sempra Commodities LLP (RBS Sempra Commodities), a limited liability partnership in the process of being liquidated. The Royal Bank of Scotland plc (RBS), our partner in the joint venture, was notified by the United Kingdom’s Revenue and Customs Department (HMRC) that it was investigating value-added tax (VAT) refund claims made by various businesses in connection with the purchase and sale of carbon credit allowances. HMRC advised RBS that it had determined that it had grounds to deny such claims by RBS related to transactions by RBS Sempra Energy Europe (RBS SEE), a former indirect subsidiary of RBS Sempra Commodities that was sold to JP Morgan. HMRC asserted that RBS was not entitled to reduce its VAT liability by VAT paid during 2009 because RBS 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 a protective assessment of £86 million for the VAT paid in connection with these transactions. In October 2014, RBS filed a Notice of Appeal of the September 2012 assessment with the First-tier Tribunal. As a condition of the appeal, RBS was required to pay the assessed amount. The payment also stops the accrual of interest that could arise should it ultimately be determined that RBS has a liability for some of the tax. Our remaining balance in RBS Sempra Commodities is accounted for under the equity method. The investment balance of $71 million at March 31, 2015 reflects remaining distributions expected to be received from the partnership as it is liquidated. The timing and amount of distributions may be impacted by these matters. We discuss RBS Sempra Commodities further in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report.
	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 resolved 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, employment litigation, product liability, property damage and other claims. Juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases.
	CONTRACTUAL COMMITMENTS
	We discuss below significant changes in the first three months of 2015 to contractual commitments discussed in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.
	Natural Gas Contracts
	SoCalGas’ natural gas purchase and pipeline capacity commitments have decreased by $43 million since December 31, 2014, primarily due to fulfillment of payment obligations and changes to forecasted gas prices in the first three months of 2015. Net future payments are expected to decrease by $41 million in 2015, and $2 million thereafter compared to December 31, 2014.
	Sempra Natural Gas’ natural gas purchase and transportation commitments have decreased by $69 million since December 31, 2014, primarily due to payments on existing contracts in the first three months of 2015. Net future payments are expected to decrease by $54 million in 2015, increase by $1 million in 2016, and decrease by $16 million in 2020 and thereafter compared to December 31, 2014.
	LNG Purchase Agreement
	Sempra Natural Gas has a purchase agreement for the supply of LNG to the Energía Costa Azul terminal. The agreement is priced using a predetermined formula based on natural gas market indices. Although this contract specifies a number of cargoes to be delivered, under its terms, the customer may divert certain cargoes, which would reduce amounts paid under the contracts by Sempra Natural Gas.
	Sempra Natural Gas’ commitment under the LNG purchase agreement, reflecting changes in forward prices since December 31, 2014 and actual transactions for the first three months of 2015, are expected to decrease by $138 million in 2015, $83 million in 2016, $93 million in 2017, $109 million each year in 2018 and 2019, and $937 million thereafter compared to December 31, 2014. These amounts are based on forward prices of the index applicable to the contract from 2015 to 2024 and an estimated one percent escalation per year beyond 2024. The LNG commitment amounts above are based on Sempra Natural Gas’ commitment to accept the maximum possible delivery of cargoes under the agreement. Actual LNG purchases in the current and prior years have been significantly lower than the maximum amounts possible.
	Purchased-Power Contracts
	SDG&E’s commitments under purchased-power contracts have decreased by $339 million since December 31, 2014. Net future payments are therefore expected to decrease by $20 million in 2015, $16 million in 2016, $17 million in 2017, $18 million in 2018, $23 million in 2019 and $245 million thereafter compared to December 31, 2014.
	Capital Leases – Power Purchase Agreements
	In the first quarter of 2015, SDG&E entered into a CPUC-approved 25-year power purchase agreement with a peaker plant facility that is under construction. Beginning with the initial delivery of the contracted power, scheduled in June 2017, the power purchase agreement will be accounted for as a capital lease. Future minimum lease payments under the new power purchase agreement are as follows
	FUTURE MINIMUM PAYMENTS – POWER PURCHASE AGREEMENT
	(Dollars in millions)
	2015		$	―
	2016			―
	2017			38
	2018			65
	2019			65
	Thereafter			1,460
	Total minimum lease payments(1)			1,628
	Less: estimated executory costs			-392
	Less: interest(2)			-736
	Present value of net minimum lease payments		$	500
	-1	This amount will be recorded over the life of the lease as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Condensed Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs, which are recovered in rates.
	-2	Amount necessary to reduce net minimum lease payments to estimated present value at the inception of the lease.
Construction and Development Projects
In the first three months of 2015, significant net decreases to contractual commitments at SDG&E were $54 million, primarily due to fulfillment of payment obligations partially offset by an increase in commitments. Net future payments under these contractual commitments are expected to decrease by $95 million in 2015, increase by $20 million in 2016, decrease by $4 million in 2017, and increase by $1 million in 2018 and $24 million in 2019 compared to December 31, 2014.
In the first three months of 2015, significant net decreases to contractual commitments at SoCalGas were $62 million, primarily due to payments on existing contracts partially offset by an increase in commitments in the first three months of 2015. Net future payments under these contractual commitments are expected to decrease by $72 million in 2015, and increase by $7 million in 2016 and $3 million in 2017, compared to December 31, 2014.
In the first three months of 2015, significant increases to contractual commitments at Sempra Mexico were $12 million, all to be expended in 2015, related to pipeline projects.
In the first three months of 2015, significant increases to contractual commitments at Sempra Natural Gas were $26 million, primarily for natural gas transportation projects. The future payments under these contractual commitments are all expected to be made in 2015.
Guarantees
We discuss guarantees related to Sempra Energy in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report.
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 could 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). 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 outages in early 2012 and the resultant plant closure in June 2013.
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.
U.S. DEPARTMENT OF ENERGY (DOE) 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. SDG&E will seek recovery for these costs from the appropriate sources, including, but not limited to, SDG&E’s Nuclear Decommissioning Trust. SDG&E will also continue to support Edison in its pursuit of legal claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel.
We provide additional information about SONGS in Note 9

SEGMENT_INFORMATION

SEGMENT INFORMATION	3 Months Ended
	Mar. 31, 2015
Notes to Consolidated Financial Statements [Abstract]
Segment Information	NOTE 12. 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.
	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, Minnesota, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States.
	Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities, natural gas distribution utilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. Sempra Natural Gas also owns and operates the Mesquite Power plant, a natural gas-fired electric generation asset. In April 2015, Sempra Natural Gas sold the remaining 625-MW block of Mesquite Power, as we discuss in Note 3.
	Sempra South American Utilities and Sempra Mexico comprise our Sempra International operating unit. Sempra Renewables and Sempra Natural Gas comprise our Sempra U.S. Gas & Power operating unit.
	We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC. The California Utilities’ operations are based on rates set by the CPUC and the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report.
	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.
	The following tables show selected information by segment from our Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of parent organizations.
	SEGMENT INFORMATION
	(Dollars in millions)
			Three months ended March 31,
			2015				2014
	REVENUES
	SDG&E		$	966	36	%	$	987	35	%
	SoCalGas			1,048	39			1,085	39
	Sempra South American Utilities			389	15			378	14
	Sempra Mexico			163	6			201	7
	Sempra Renewables			8	―			6	―
	Sempra Natural Gas			197	7			260	9
	Intersegment revenues(1)			-89	-3			-122	-4
	Total		$	2,682	100	%	$	2,795	100	%
	INTEREST EXPENSE
	SDG&E		$	52			$	50
	SoCalGas			19				17
	Sempra South American Utilities			5				8
	Sempra Mexico			5				4
	Sempra Renewables			1				―
	Sempra Natural Gas			21				32
	All other			63				58
	Intercompany eliminations			-32				-33
	Total		$	134			$	136
	INTEREST INCOME
	Sempra South American Utilities		$	4			$	3
	Sempra Mexico			2				―
	Sempra Natural Gas			19				31
	Intercompany eliminations			-18				-30
	Total		$	7			$	4
	DEPRECIATION AND AMORTIZATION
	SDG&E		$	145	48	%	$	130	45	%
	SoCalGas			113	37			105	37
	Sempra South American Utilities			13	4			14	5
	Sempra Mexico			17	6			16	6
	Sempra Renewables			2	1			1	―
	Sempra Natural Gas			12	4			17	6
	All other			1	―			3	1
	Total		$	303	100	%	$	286	100	%
	INCOME TAX EXPENSE (BENEFIT)
	SDG&E		$	88			$	83
	SoCalGas			95				38
	Sempra South American Utilities			16				15
	Sempra Mexico			8				12
	Sempra Renewables			-17				-6
	Sempra Natural Gas			2				6
	All other			-29				-21
	Total		$	163			$	127
	SEGMENT INFORMATION (CONTINUED)
	(Dollars in millions)
			Three months ended March 31,
			2015				2014
	EQUITY EARNINGS (LOSSES)
Earnings recorded before tax:
Sempra Renewables		$	2			$	2
Sempra Natural Gas			17				15
Total		$	19			$	17
(Losses) earnings recorded net of tax:
Sempra South American Utilities		$	-1			$	-2
Sempra Mexico			16				8
Total		$	15			$	6
EARNINGS (LOSSES)
SDG&E		$	147	34	%	$	99	40	%
SoCalGas(2)			214	49			78	32
Sempra South American Utilities			41	9			35	14
Sempra Mexico			47	11			42	17
Sempra Renewables			13	3			28	11
Sempra Natural Gas			2	―			9	4
All other			-27	-6			-44	-18
Total		$	437	100	%	$	247	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	355	46	%	$	294	37	%
SoCalGas			315	40			260	33
Sempra South American Utilities			31	4			32	4
Sempra Mexico			55	7			75	9
Sempra Renewables			3	1			99	12
Sempra Natural Gas			10	1			40	5
All other			11	1			1	―
Total		$	780	100	%	$	801	100	%
		31-Mar-15				31-Dec-14
ASSETS
SDG&E		$	16,485	42	%	$	16,296	41	%
SoCalGas			10,563	27			10,461	26
Sempra South American Utilities			3,350	8			3,379	9
Sempra Mexico			3,502	9			3,488	9
Sempra Renewables			1,277	3			1,338	3
Sempra Natural Gas			6,032	15			6,436	16
All other			960	2			895	2
Intersegment receivables			-2,618	-6			-2,561	-6
Total		$	39,551	100	%	$	39,732	100	%
INVESTMENTS IN EQUITY METHOD INVESTEES
Sempra South American Utilities		$	-8			$	-8
Sempra Mexico			439				434
Sempra Renewables			859				911
Sempra Natural Gas			1,319				1,347
All other			163				164
Total		$	2,772			$	2,848
-1	Revenues for reportable segments include intersegment revenues of $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 and $3 million, $18 million, $22 million and $79 million for the three months ended March 31, 2014 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
-2	After preferred dividends.

SIGNIFICANT_ACCOUNTING_POLICIE

SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 2015
Significant Accounting Policies
New Accounting Standards Policy	NOTE 2. NEW ACCOUNTING STANDARDS
	We describe below recent pronouncements that have had or may have a significant effect on our financial statements. We do not discuss recent pronouncements that are not anticipated to have an impact on or are unrelated to our financial condition, results of operations, cash flows or disclosures.
	SEMPRA ENERGY, SDG&E AND SOCALGAS
	Accounting Standards Update (ASU) 2014-09, “Revenue from Contracts with Customers” (ASU 2014-09): ASU 2014-09 provides accounting guidance for revenue arising from contracts with customers and affects all entities that enter into contracts to provide goods or services to their customers. The guidance also provides a model for the measurement and recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach.
	As issued, ASU 2014-09 will become effective on January 1, 2017; however, the Financial Accounting Standards Board has proposed a one-year delay in the effective date that is pending review. We have not yet selected a transition method nor have we determined the effect of the standard on our ongoing financial reporting.
	ASU 2015-03, “Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs” (ASU 2015-03): ASU 2015-03 provides guidance on the financial statement presentation of debt issuance costs and requires an entity to present debt issuance costs in the balance sheet as a direct deduction from the carrying amount of the related long-term debt liability. This guidance must be applied using a full retrospective approach for all periods presented in the period of adoption.
	We will adopt ASU 2015-03 for our annual reporting period ending December 31, 2015. The adoption will not affect our results of operations or cash flows. Deferred debt issuance costs that are the subject of ASU 2015-03 are included in Sundry on the Sempra Energy, SDG&E and SoCalGas Condensed Consolidated Balance Sheets and total $85 million, $33 million, and $15 million at March 31, 2015, respectively, and $84 million, $33 million, and $15 million at December 31, 2014, respectively.
Consolidation Variable Interest Entity Policy	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.
Noncontrolling Interest Policy	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 Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income.
Earnings Per Share Policy	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 period. 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 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 of dilutive common stock equivalents excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options).
	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 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.
	Our performance-based RSUs include awards that vest at the end of three-year (for awards granted in 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. Targets for our EPS RSUs were developed based on Sempra Energy’s long-term earnings-per-share growth guidance as well as analyst consensus long-term earnings-per-share growth estimates for S&P 500 Utilities Index peer companies. TSR RSUs represent the right to receive from zero to 1.5 shares (2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate.
	Our RSAs, which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above. We include RSAs and these RSUs in potential dilutive shares at 100 percent, subject to the application of the treasury stock method. We include our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method.
Interim period effective tax rate policy	Sempra Energy, SDG&E and SoCalGas record income taxes for interim periods utilizing a forecasted effective tax rate anticipated for the full year, as required by U.S. GAAP. The income tax effect of items that can be reliably forecasted are factored into the forecasted effective tax rate and their impact is recognized proportionately over the year. The forecasted items, anticipated on a full year basis, may include, among others:
	utility self-developed software expenditures
	repairs to certain utility plant assets
	renewable energy income tax credits
	deferred income tax benefits related to renewable energy projects
	exclusions from taxable income of the equity portion of AFUDC
	depreciation on a certain portion of utility plant assets
	U.S. tax on repatriation of current year earnings from non-U.S. subsidiaries
	Items that cannot be reliably forecasted (e.g., adjustments related to prior years’ income tax items, remeasurement of deferred tax asset valuation allowances, Mexican currency translation and inflation adjustments, and deferred income tax benefit associated with the impairment of a book investment) are recorded in the interim period in which they actually occur, which can result in variability to income tax expense.
	For SDG&E and SoCalGas, 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 impacts 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 assets
	the equity portion of AFUDC
	a portion of the cost of removal of utility plant assets
	utility self-developed software expenditures
	depreciation on a certain portion of utility plant assets
	The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico and Sempra Natural Gas has similar flow-through treatment.
Fair Value Measurement Policy	Recurring Fair Value Measures
	The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at March 31, 2015 and December 31, 2014. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the 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 7 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 March 31, 2015 and December 31, 2014 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 (CAISO), an objective source. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following calendar year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. From January 1, 2015 to December 31, 2015 the auction prices range from $(16) per MWh to $8 per MWh at a given location, and from January 1, 2014 to December 31, 2014 the auction prices ranged from $(6) per MWh to $12 per MWh at a given location. The fair value of these instruments is derived from auction price differences between two locations. 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 7. Realized gains and losses associated with CRRs are recorded in Cost of Electric Fuel and Purchased Power, which is recoverable in rates, on the Condensed 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).
Derivatives Policy	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 Condensed 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 (loss) (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Condensed 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, for the benefit of customers, 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 California Public Utilities Commission (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 Condensed 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 Condensed 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: liquefied natural gas (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 Condensed 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 Condensed 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.
	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. 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.
	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 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 and joint ventures.
	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 of the Notes to Consolidated Financial Statements in the Annual Report.
Legal Costs Policy	LEGAL PROCEEDINGS
	We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated.
Segment Policy	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.

RECENT_INVESTMENT_ACTIVITY_Tab

RECENT INVESTMENT ACTIVITY (Tables)	3 Months Ended
	Mar. 31, 2015
Recent Investment Activity (Tables) [Abstract]
Schedule of Business Deconsolidation Table	DECONSOLIDATION OF SUBSIDIARY
	(Dollars in millions)
			Copper Mountain Solar 3
			At March 13, 2014
	Proceeds from sale, net of negligible transaction costs		$	68
	Cash			-2
	Property, plant and equipment, net			-247
	Other assets			-11
	Accounts payable and accrued expenses			82
	Long-term debt, including current portion			97
	Other liabilities			3
	Accumulated other comprehensive income			-2
	Gain on sale of equity interest			-27
	(Increase) in equity method investment upon deconsolidation		$	-39
	ASSET HELD FOR SALE, POWER PLANT
	(Dollars in millions)
			31-Mar-15
	Property, plant, and equipment, net		$	291
	Inventories			4
	Total assets held for sale			295
	Liability held for sale - asset retirement obligation(1)			-6
	Total		$	289
	-1	Included in Other Current Liabilities on the Condensed Consolidated Balance Sheet.

OTHER_FINANCIAL_DATA_Tables

OTHER FINANCIAL DATA (Tables)	3 Months Ended
	Mar. 31, 2015
Other Financial Data (Tables) [Abstract]
Net Periodic Benefit Cost Table	NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
		Pension benefits				Other postretirement benefits
		Three months ended March 31,
		2015		2014		2015		2014
	Service cost	$	30	$	26	$	7	$	6
	Interest cost		39		41		12		12
	Expected return on assets		-44		-43		-17		-16
	Amortization of:
	Prior service cost (credit)		3		2		-1		-1
	Actuarial loss		8		5		―		―
	Settlement		―		3		―		―
	Regulatory adjustment		-29		-24		―		―
	Total net periodic benefit cost	$	7	$	10	$	1	$	1
	NET PERIODIC BENEFIT COST – SDG&E
	(Dollars in millions)
		Pension benefits				Other postretirement benefits
		Three months ended March 31,
		2015		2014		2015		2014
	Service cost	$	8	$	8	$	2	$	2
	Interest cost		10		11		2		2
	Expected return on assets		-14		-14		-3		-3
	Amortization of:
	Prior service cost		―		―		1		1
	Actuarial loss		2		1		―		―
	Regulatory adjustment		-5		-5		-2		-2
	Total net periodic benefit cost	$	1	$	1	$	―	$	―
	NET PERIODIC BENEFIT COST – SOCALGAS
	(Dollars in millions)
		Pension benefits				Other postretirement benefits
		Three months ended March 31,
		2015		2014		2015		2014
	Service cost	$	19	$	16	$	5	$	4
	Interest cost		25		25		9		9
	Expected return on assets		-27		-26		-14		-13
	Amortization of:
	Prior service cost (credit)		2		2		-2		-2
	Actuarial loss		5		2		―		―
	Regulatory adjustment		-24		-19		2		2
	Total net periodic benefit cost	$	―	$	―	$	―	$	―
Contributions to Benefit Plans Table	BENEFIT PLAN CONTRIBUTIONS
	(Dollars in millions)
		Sempra Energy
		Consolidated		SDG&E		SoCalGas
	Contributions through March 31, 2015:
	Pension plans	$	15	$	1	$	1
	Other postretirement benefit plans		1		―		―
	Total expected contributions in 2015:
	Pension plans	$	31	$	3	$	2
	Other postretirement benefit plans		11		8		―
Earnings Per Share Computations Table	EARNINGS PER SHARE COMPUTATIONS
	(Dollars in millions, except per share amounts; shares in thousands)
			Three months ended March 31,
			2015		2014
	Numerator:
	Earnings/Income attributable to common shares		$	437	$	247
	Denominator:
	Weighted-average common shares
		outstanding for basic EPS		247,722		245,277
	Dilutive effect of stock options, restricted
		stock awards and restricted stock units		3,484		4,392
	Weighted-average common shares
		outstanding for diluted EPS		251,206		249,669
	Earnings per share:
	Basic		$	1.76	$	1.01
	Diluted		$	1.74	$	0.99
Capitalized Financing Costs Table	CAPITALIZED FINANCING COSTS
	(Dollars in millions)
			Three months ended March 31,
			2015		2014
	Sempra Energy Consolidated:
	AFUDC related to debt		$	6	$	6
	AFUDC related to equity			27		25
	Other capitalized financing costs			17		8
	Total Sempra Energy Consolidated		$	50	$	39
	SDG&E:
	AFUDC related to debt		$	3	$	4
	AFUDC related to equity			8		11
	Total SDG&E		$	11	$	15
	SoCalGas:
	AFUDC related to debt		$	3	$	2
	AFUDC related to equity			9		5
	Total SoCalGas		$	12	$	7
Changes in Components of Accumulated Comprehensive Income Table	CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
	SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
					Pension and other
					postretirement benefits
			Foreign								Total
			currency		Unamortized		Unamortized				accumulated other
			translation		net actuarial		prior service		Financial		comprehensive
			adjustments		gain (loss)		cost		instruments		income (loss)
			Three months ended March 31, 2015 and 2014
	2015:00:00
	Balance as of December 31, 2014		$	-322	$	-83	$	-2	$	-90	$	-497
	Other comprehensive loss before
	reclassifications			-62		―		―		-54		-116
	Amounts reclassified from accumulated other
	comprehensive income (loss)			―		1		―		-1		―
	Net other comprehensive income (loss)			-62		1		―		-55		-116
	Balance as of March 31, 2015		$	-384	$	-82	$	-2	$	-145	$	-613
	2014:00:00
	Balance as of December 31, 2013		$	-129	$	-73	$	―	$	-26	$	-228
	Other comprehensive loss before
	reclassifications			-43		―		―		-14		-57
	Amounts reclassified from accumulated other
	comprehensive income			―		3		―		9		12
	Net other comprehensive income (loss)			-43		3		―		-5		-45
	Balance as of March 31, 2014		$	-172	$	-70	$	―	$	-31	$	-273
	-1	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
Reclassifications out of AOCI Table	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
	(Dollars in millions)
	Details about accumulated			Amounts reclassified
	other comprehensive income (loss)			from accumulated other						Affected line item on Condensed
	components			comprehensive income (loss)						Consolidated Statements of Operations
				Three months ended March 31,
				2015			2014
	Sempra Energy Consolidated:
	Financial instruments:
	Interest rate and foreign exchange instruments			$	6		$	3		Interest Expense
	Interest rate instruments				―			2		Gain on Sale of Equity Interest
	Interest rate instruments				3			3		Equity Earnings, Before Income Tax
	Commodity contracts not subject									Revenues: Energy-Related
		to rate recovery			-7			10		Businesses
	Total before income tax				2			18
					1			-6		Income Tax Expense
	Net of income tax				3			12
					-4			-3		Earnings Attributable to Noncontrolling Interests
				$	-1		$	9
	Pension and other postretirement benefits:
	Amortization of actuarial loss			$	2		$	5		See (1) below
					-1			-2		Income Tax Expense
	Net of income tax			$	1		$	3
	Total reclassifications for the period, net of tax			$	―		$	12
	SDG&E:
	Financial instruments:
	Interest rate instruments			$	3		$	3		Interest Expense
					-3			-3		Earnings Attributable to Noncontrolling Interest
				$	―		$	―
	-1	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).
Shareholders' Equity and Noncontrolling Interests Table	SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS ― SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
				Sempra Energy		Non-
				shareholders’		controlling		Total
				equity		interests		equity
	Balance at December 31, 2014		$	11,326	$	774	$	12,100
	Comprehensive income			321		8		329
	Share-based compensation expense			13		―		13
	Common stock dividends declared			-173		―		-173
	Issuance of common stock			30		―		30
	Repurchase of common stock			-65		―		-65
	Tax benefit related to share-based compensation			52		―		52
	Distributions to noncontrolling interests			―		-5		-5
	Balance at March 31, 2015		$	11,504	$	777	$	12,281
	Balance at December 31, 2013		$	11,008	$	842	$	11,850
	Comprehensive income			202		17		219
	Share-based compensation expense			10		―		10
	Common stock dividends declared			-162		―		-162
	Issuance of common stock			11		―		11
	Repurchase of common stock			-37		―		-37
	Tax benefit related to share-based compensation			8		―		8
	Equity contributed by noncontrolling interest			―		1		1
	Distributions to noncontrolling interests			―		-11		-11
	Balance at March 31, 2014		$	11,040	$	849	$	11,889
	SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST ― SDG&E
	(Dollars in millions)
			SDG&E		Non-
			shareholder’s		controlling		Total
			equity		interest		equity
	Balance at December 31, 2014	$	4,932	$	60	$	4,992
	Comprehensive income		147		2		149
	Distributions to noncontrolling interest		―		-3		-3
	Balance at March 31, 2015	$	5,079	$	59	$	5,138
	Balance at December 31, 2013	$	4,628	$	91	$	4,719
	Comprehensive income		99		2		101
	Distributions to noncontrolling interest		―		-6		-6
	Balance at March 31, 2014	$	4,727	$	87	$	4,814
Amounts Due To and From Affiliates at SDG&E and SoCalGas Table	AMOUNTS DUE TO AND FROM AFFILIATES AT SDG&E AND SOCALGAS
	(Dollars in millions)
			31-Mar-15			31-Dec-14
	SDG&E:
	Current:
	Due from Sempra Energy		$	40		$	―
	Due from various affiliates			1			1
			$	41		$	1
	Due to Sempra Energy		$	―		$	17
	Due to SoCalGas			2			4
			$	2		$	21
	Income taxes due from Sempra Energy(1)		$	15		$	16
	SoCalGas:
	Current:
	Due from Sempra Energy		$	59		$	―
	Due from SDG&E			2			4
			$	61		$	4
	Due to Sempra Energy		$	―		$	13
	Income taxes due (to) from Sempra Energy(1)		$	-107		$	9
	-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 Table	REVENUES FROM UNCONSOLIDATED AFFILIATES AT SDG&E AND SOCALGAS
	(Dollars in millions)
		Three months ended March 31,
		2015		2014
	SDG&E	$	3	$	3
	SoCalGas		19		18
Other Income and Expense Table	OTHER INCOME, NET
	(Dollars in millions)
			Three months ended March 31,
			2015		2014
	Sempra Energy Consolidated:
	Allowance for equity funds used during construction		$	27	$	25
	Investment gains(1)			9		8
	Regulatory interest, net(2)			1		1
	Foreign currency losses			-1		―
	Gains on interest rate and foreign exchange instruments, net			―		2
	Sundry, net			3		4
	Total		$	39	$	40
	SDG&E:
	Allowance for equity funds used during construction		$	8	$	11
	Regulatory interest, net(2)			1		1
	Sundry, net			―		1
	Total		$	9	$	13
	SoCalGas:
	Allowance for equity funds used during construction		$	9	$	5
	Sundry, net			-1		-1
	Total		$	8	$	4
	-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	Interest on regulatory balancing accounts.
Income Tax Expense and Effective Income Tax Rates Table	INCOME TAX EXPENSE AND EFFECTIVE INCOME TAX RATES
	(Dollars in millions)
						Effective					Effective
				Income tax		income			Income tax		income
				expense		tax rate			expense		tax rate
				Three months ended March 31,
				2015					2014
	Sempra Energy Consolidated		$	163		27	%	$	127		33	%
	SDG&E			88		37			83		45
	SoCalGas			95		31			38		33
Variable Interest Entity Table	AMOUNTS ASSOCIATED WITH OTAY MESA VIE
	(Dollars in millions)
		Three months ended March 31,
		2015		2014
	Operating expenses
	Cost of electric fuel and purchased power	$	-18	$	-18
	Operation and maintenance		4		5
	Depreciation		6		7
	Total operating expenses		-8		-6
	Operating income		8		6
	Interest expense		-4		-4
	Income before income taxes/Net income		4		2
	Earnings attributable to noncontrolling interest		-4		-2
	Earnings attributable to common shares	$	―	$	―
Ownership Interests Held By Others Table	OTHER NONCONTROLLING INTERESTS
	(Dollars in millions)
			Percent ownership held by others
			March 31,		December 31,			March 31,		December 31,
			2015		2014			2015		2014
	SDG&E:
	Otay Mesa VIE		100	%	100	%	$	59	$	60
	Sempra South American Utilities:
	Chilquinta Energía subsidiaries(1)		23.5 – 43.4		23.6 – 43.4			23		23
	Luz del Sur		16.4		16.4			174		177
	Tecsur		9.8		9.8			3		4
	Sempra Mexico:
	IEnova, S.A.B. de C.V.		18.9		18.9			460		452
	Sempra Natural Gas:
	Bay Gas Storage Company, Ltd.		9.1		9.1			23		23
	Liberty Gas Storage, LLC		25		25			14		14
	Southern Gas Transmission Company		49		49			1		1
	Total Sempra Energy						$	757	$	754
	-1	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages amongst these subsidiaries.
Inventory Table	INVENTORY BALANCES
	(Dollars in millions)
			Natural gas				Liquefied natural gas				Materials and supplies				Total
			31-Mar-15		31-Dec-14		31-Mar-15		31-Dec-14		31-Mar-15		31-Dec-14		31-Mar-15		31-Dec-14
	SDG&E		$	6	$	8	$	―	$	―	$	63	$	65	$	69	$	73
	SoCalGas			83		155		―		―		26		26		109		181
	Sempra South American
	Utilities			―		―		―		―		32		33		32		33
	Sempra Mexico			―		―		7		9		9		9		16		18
	Sempra Renewables			―		―		―		―		2		2		2		2
	Sempra Natural Gas			22		83		4		5		1		1		27		89
	Sempra Energy
	Consolidated		$	111	$	246	$	11	$	14	$	133	$	136	$	255	$	396
Afiliate Loans Table	DUE FROM UNCONSOLIDATED AFFILIATES(1)
	(Dollars in millions)
				31-Mar-15		31-Dec-14
	Sempra South American Utilities:
	Eletrans S.A.:
	4% Note(2)		$	46	$	41
	Sempra Mexico:
	Affiliates of joint venture with PEMEX:
	Note due November 13, 2017(3)			44		44
	Note due November 14, 2018(3)			41		40
	Note due November 14, 2018(3)			33		33
	Note due November 14, 2018(3)			8		8
	Energía Sierra Juárez:
	Note due June 15, 2018(4)			23		22
	Other(5)			5		38
	Total		$	200	$	226
	-1	Amounts include principal balances plus accumulated interest outstanding.
	-2	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A., an affiliate of Chilquinta Energía.
	-3	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.67 percent at March 31, 2015), to finance the Los Ramones Norte pipeline project.
	-4	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.55 percent at March 31, 2015), to finance the first phase of the Energía Sierra Juárez wind project.
	-5	Amounts represent accounts receivable from various Sempra Renewables and Sempra Mexico joint venture investments.

DERIVATIVE_FINANCIAL_INSTRUMEN1

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Financial Instruments (Tables) [Abstract]
Commodity Derivative Volumes Table	NET ENERGY DERIVATIVE VOLUMES
	Segment and Commodity			31-Mar-15	31-Dec-14
	California Utilities:
	SDG&E:
	Natural gas			57 million MMBtu	55 million MMBtu	-1
	Congestion revenue rights			24 million MWh	27 million MWh	-2
	SoCalGas - natural gas			1 million MMBtu	1 million MMBtu
	Energy-Related Businesses:
	Sempra Natural Gas - natural gas			7 million MMBtu	29 million MMBtu
	-1	Million British thermal units
	-2	Megawatt hours
Notional Amounts of Interest Rate Derivatives Table	INTEREST RATE DERIVATIVES
	(Dollars in millions)
			31-Mar-15			31-Dec-14
			Notional debt		Maturities	Notional debt		Maturities
	Sempra Energy Consolidated:
	Cash flow hedges(1)		$	396	2015-2028	$	399	2015-2028
	Fair value hedges			300	2016		300	2016
	SDG&E:
	Cash flow hedge(1)			322	2019		325	2019
	-1	Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE.
Derivative Instruments on the Condensed Consolidated Balance Sheets Table	DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
	(Dollars in millions)
			31-Mar-15
										Deferred
										credits
				Current				Current		and other
				assets:				liabilities:		liabilities:
				Fixed-price		Investments		Fixed-price		Fixed-price
				contracts		and other		contracts		contracts
				and other		assets:		and other		and other
				derivatives(1)		Sundry		derivatives(2)		derivatives
	Sempra Energy Consolidated:
	Derivatives designated as hedging instruments:
	Interest rate and foreign exchange instruments(3)		$	10	$	3	$	-17	$	-130
	Derivatives not designated as hedging instruments:
	Interest rate and foreign exchange instruments			11		28		-7		-25
	Commodity contracts not subject to rate recovery			129		25		-137		-22
	Associated offsetting commodity contracts			-123		-21		123		21
	Associated offsetting cash collateral			―		―		10		1
	Commodity contracts subject to rate recovery			28		76		-35		-33
	Associated offsetting commodity contracts			-1		―		1		―
	Associated offsetting cash collateral			―		―		27		27
	Net amounts presented on the balance sheet			54		111		-35		-161
	Additional cash collateral for commodity contracts
	not subject to rate recovery			16		―		―		―
	Additional cash collateral for commodity contracts
	subject to rate recovery			19		―		―		―
	Total(4)		$	89	$	111	$	-35	$	-161
	SDG&E:
	Derivatives designated as hedging instruments:
	Interest rate instruments(3)		$	―	$	―	$	-16	$	-32
	Derivatives not designated as hedging instruments:
	Commodity contracts not subject to rate recovery			―		―		-1		―
	Associated offsetting cash collateral			―		―		1		―
	Commodity contracts subject to rate recovery			26		76		-34		-33
	Associated offsetting cash collateral			―		―		27		27
	Net amounts presented on the balance sheet			26		76		-23		-38
	Additional cash collateral for commodity contracts
	not subject to rate recovery			1		―		―		―
	Additional cash collateral for commodity contracts
	subject to rate recovery			17		―		―		―
	Total(4)		$	44	$	76	$	-23	$	-38
	SoCalGas:
	Derivatives not designated as hedging instruments:
	Commodity contracts not subject to rate recovery		$	―	$	―	$	-2	$	―
	Associated offsetting cash collateral			―		―		2		―
	Commodity contracts subject to rate recovery			2		―		-1		―
	Associated offsetting commodity contracts			-1		―		1		―
	Net amounts presented on the balance sheet			1		―		―		―
	Additional cash collateral for commodity contracts
	not subject to rate recovery			1		―		―		―
	Additional cash collateral for commodity contracts
	subject to rate recovery			2		―		―		―
	Total		$	4	$	―	$	―	$	―
	-1	Included in Current Assets: Other for SoCalGas.
	-2	Included in Current Liabilities: Other for SoCalGas.
	-3	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
	-4	Normal purchase contracts previously measured at fair value are excluded.
	DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS
	(Dollars in millions)
			31-Dec-14
										Deferred
										credits
				Current				Current		and other
			assets:				liabilities:		liabilities:
			Fixed-price		Investments		Fixed-price		Fixed-price
			contracts		and other		contracts		contracts
			and other		assets:		and other		and other
			derivatives(1)		Sundry		derivatives(2)		derivatives
Sempra Energy Consolidated:
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments(3)		$	10	$	3	$	-17	$	-109
Commodity contracts not subject to rate recovery			25		―		―		―
Derivatives not designated as hedging instruments:
Interest rate instruments			8		27		-7		-22
Commodity contracts not subject to rate recovery			143		32		-135		-29
Associated offsetting commodity contracts			-129		-27		129		27
Associated offsetting cash collateral			-11		―		―		―
Commodity contracts subject to rate recovery			36		76		-36		-20
Associated offsetting commodity contracts			-3		-1		3		1
Associated offsetting cash collateral			―		―		23		13
Net amounts presented on the balance sheet			79		110		-40		-139
Additional cash collateral for commodity contracts
subject to rate recovery			14		―		―		―
Total(4)		$	93	$	110	$	-40	$	-139
SDG&E:
Derivatives designated as hedging instruments:
Interest rate instruments(3)		$	―	$	―	$	-16	$	-31
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery			32		76		-32		-20
Associated offsetting commodity contracts			―		-1		―		1
Associated offsetting cash collateral			―		―		23		13
Net amounts presented on the balance sheet			32		75		-25		-37
Additional cash collateral for commodity contracts
subject to rate recovery			12		―		―		―
Total(4)		$	44	$	75	$	-25	$	-37
SoCalGas:
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery		$	4	$	―	$	-4	$	―
Associated offsetting commodity contracts			-3		―		3		―
Net amounts presented on the balance sheet			1		―		-1		―
Additional cash collateral for commodity contracts
subject to rate recovery			2		―		―		―
Total		$	3	$	―	$	-1	$	―
-1	Included in Current Assets: Other for SoCalGas.
-2	Included in Current Liabilities: Other for SoCalGas.
-3	Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE.
-4	Normal purchase contracts previously measured at fair value are excluded.
Fair Value Hedge Impact on the Condensed Consolidated Statements of Operations Table	FAIR VALUE HEDGE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
	(Dollars in millions)
				Gain (loss) on derivatives recognized in earnings
				Three months ended March 31,
			Location	2015		2014
	Sempra Energy Consolidated:
	Interest rate instruments		Interest Expense	$	2	$	3
	Interest rate instruments		Other Income, Net		1		-4
	Total(1)			$	3	$	-1
	-1	There was no hedge ineffectiveness on these swaps in the three months ended March 31, 2015 and $2 million in the three months ended March 31, 2014. All other 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 and recorded in Other Income, Net.
Cash Flow Hedge Impact on the Condensed Consolidated Statements of Operations Table	CASH FLOW HEDGE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
	(Dollars in millions)
			Pretax gain (loss) recognized						Gain (loss) reclassified from AOCI
			in OCI (effective portion)						into earnings (effective portion)
			Three months ended March 31,						Three months ended March 31,
			2015		2014			Location	2015		2014
	Sempra Energy Consolidated:
	Interest rate and foreign
	exchange instruments(1)		$	-18	$	-3		Interest Expense	$	-6	$	-3
								Gain on Sale of Equity
	Interest rate instruments			―		-2		Interest		―		-2
								Equity Earnings,
	Interest rate instruments			-78		-15		Before Income Tax		-3		-3
	Commodity contracts not subject							Revenues: Energy-Related
	to rate recovery			-1		-6		Businesses		7		-10
	Total(2)		$	-97	$	-26			$	-2	$	-18
	SDG&E:
	Interest rate instruments(1)(2)		$	-5	$	-3		Interest Expense	$	-3	$	-3
	-1	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
	-2	There was a negligible amount of ineffectiveness related to these hedges in 2015 and 2014.
Undesignated Derivative Impact on the Condensed Consolidated Statements of Operations Table	UNDESIGNATED DERIVATIVE IMPACT ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
	(Dollars in millions)
				Gain (loss) on derivatives recognized in earnings
				Three months ended March 31,
			Location	2015		2014
	Sempra Energy Consolidated:
	Foreign exchange instruments		Equity Earnings,
			Net of Income Tax	$	-1	$	-2
	Commodity contracts not subject		Revenues: Energy-Related
	to rate recovery		Businesses		3		-5
	Commodity contracts subject		Cost of Electric Fuel
	to rate recovery		and Purchased Power		-20		12
	Commodity contracts subject
	to rate recovery		Cost of Natural Gas		1		2
	Total			$	-17	$	7
	SDG&E:
	Commodity contracts subject		Cost of Electric Fuel
	to rate recovery		and Purchased Power	$	-20	$	12
	SoCalGas:
	Commodity contracts subject
	to rate recovery		Cost of Natural Gas	$	1	$	2

FAIR_VALUE_MEASUREMENTS_Tables

FAIR VALUE MEASUREMENTS (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Measurements (Tables) [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED
	(Dollars in millions)
			Fair value at March 31, 2015
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts:
	Equity securities		$	666	$	―	$	―	$	―	$	666
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			58		53		―		―		111
	Municipal bonds			―		142		―		―		142
	Other securities			―		212		―		―		212
	Total debt securities			58		407		―		―		465
	Total nuclear decommissioning trusts(2)			724		407		―		―		1,131
	Interest rate and foreign exchange instruments			―		52		―		―		52
	Commodity contracts not subject to rate recovery			2		8		―		16		26
	Commodity contracts subject to rate recovery			―		1		102		19		122
	Total		$	726	$	468	$	102	$	35	$	1,331
	Liabilities:
	Interest rate and foreign exchange instruments		$	―	$	179	$	―	$	―	$	179
	Commodity contracts not subject to rate recovery			6		9		―		-11		4
	Commodity contracts subject to rate recovery			―		67		―		-54		13
	Total		$	6	$	255	$	―	$	-65	$	196
			Fair value at December 31, 2014
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts:
	Equity securities		$	655	$	―	$	―	$	―	$	655
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			62		47		―		―		109
	Municipal bonds			―		129		―		―		129
	Other securities			―		207		―		―		207
	Total debt securities			62		383		―		―		445
	Total nuclear decommissioning trusts(2)			717		383		―		―		1,100
	Interest rate and foreign exchange instruments			―		48		―		―		48
	Commodity contracts not subject to rate recovery			28		16		―		-11		33
	Commodity contracts subject to rate recovery			―		1		107		14		122
	Total		$	745	$	448	$	107	$	3	$	1,303
	Liabilities:
	Interest rate and foreign exchange instruments		$	―	$	155	$	―	$	―	$	155
	Commodity contracts not subject to rate recovery			3		9		―		-4		8
	Commodity contracts subject to rate recovery			―		52		―		-36		16
	Total		$	3	$	216	$	―	$	-40	$	179
	-1	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
	-2	Excludes cash balances and cash equivalents.
	RECURRING FAIR VALUE MEASURES – SDG&E
	(Dollars in millions)
			Fair value at March 31, 2015
				Level 1		Level 2		Level 3		Netting(1)		Total
	Assets:
	Nuclear decommissioning trusts:
	Equity securities		$	666	$	―	$	―	$	―	$	666
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies			58		53		―		―		111
	Municipal bonds			―		142		―		―		142
	Other securities			―		212		―		―		212
	Total debt securities			58		407		―		―		465
	Total nuclear decommissioning trusts(2)			724		407		―		―		1,131
	Commodity contracts not subject to rate recovery			―		―		―		1		1
	Commodity contracts subject to rate recovery			―		―		102		17		119
	Total		$	724	$	407	$	102	$	18	$	1,251
	Liabilities:
Interest rate instruments		$	―	$	48	$	―	$	―	$	48
Commodity contracts not subject to rate recovery			1		―		―		-1		―
Commodity contracts subject to rate recovery			―		67		―		-54		13
Total		$	1	$	115	$	―	$	-55	$	61
		Fair value at December 31, 2014
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Nuclear decommissioning trusts:
Equity securities		$	655	$	―	$	―	$	―	$	655
Debt securities:
Debt securities issued by the U.S. Treasury and other
U.S. government corporations and agencies			62		47		―		―		109
Municipal bonds			―		129		―		―		129
Other securities			―		207		―		―		207
Total debt securities			62		383		―		―		445
Total nuclear decommissioning trusts(2)			717		383		―		―		1,100
Commodity contracts subject to rate recovery			―		―		107		12		119
Total		$	717	$	383	$	107	$	12	$	1,219
Liabilities:
Interest rate instruments		$	―	$	47	$	―	$	―	$	47
Commodity contracts not subject to rate recovery			1		―		―		-1		―
Commodity contracts subject to rate recovery			―		51		―		-36		15
Total		$	1	$	98	$	―	$	-37	$	62
-1	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
-2	Excludes cash balances and cash equivalents.
RECURRING FAIR VALUE MEASURES – SOCALGAS
(Dollars in millions)
		Fair value at March 31, 2015
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts not subject to rate recovery		$	―	$	―	$	―	$	1	$	1
Commodity contracts subject to rate recovery			―		1		―		2		3
Total		$	―	$	1	$	―	$	3	$	4
Liabilities:
Commodity contracts not subject to rate recovery		$	2	$	―	$	―	$	-2	$	―
Total		$	2	$	―	$	―	$	-2	$	―
		Fair value at December 31, 2014
			Level 1		Level 2		Level 3		Netting(1)		Total
Assets:
Commodity contracts subject to rate recovery		$	―	$	1	$	―	$	2	$	3
Total		$	―	$	1	$	―	$	2	$	3
Liabilities:
Commodity contracts not subject to rate recovery		$	2	$	―	$	―	$	-2	$	―
Commodity contracts subject to rate recovery			―		1		―		―		1
Total		$	2	$	1	$	―	$	-2	$	1
-1	Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset.
Recurring Fair Value Measures Level 3 Rollforward Table	LEVEL 3 RECONCILIATIONS
	(Dollars in millions)
		Three months ended March 31,
		2015		2014
	Balance at January 1	$	107	$	99
	Realized and unrealized gains		6		1
	Allocated transmission instruments		―		1
	Settlements		-11		-6
	Balance at March 31	$	102	$	95
	Change in unrealized gains or losses relating to
	instruments still held at March 31	$	1	$	―
Fair Value of Financial Instruments Table	FAIR VALUE OF FINANCIAL INSTRUMENTS
	(Dollars in millions)
			31-Mar-15
			Carrying			Fair value
			amount			Level 1		Level 2		Level 3		Total
	Sempra Energy Consolidated:
	Total long-term debt(1)(2)		$	13,176		$	―	$	13,889	$	895	$	14,784
	Preferred stock of subsidiary			20			―		23		―		23
	SDG&E:
	Total long-term debt(2)(3)		$	4,849		$	―	$	5,061	$	422	$	5,483
	SoCalGas:
	Total long-term debt(4)		$	1,913		$	―	$	2,167	$	―	$	2,167
	Preferred stock			22			―		25		―		25
			31-Dec-14
			Carrying			Fair value
			amount			Level 1		Level 2		Level 3		Total
	Sempra Energy Consolidated:
	Total long-term debt(1)(2)		$	12,347		$	―	$	12,782	$	917	$	13,699
	Preferred stock of subsidiary			20			―		23		―		23
	SDG&E:
	Total long-term debt(2)(3)		$	4,461		$	―	$	4,563	$	425	$	4,988
	SoCalGas:
	Total long-term debt(4)		$	1,913		$	―	$	2,124	$	―	$	2,124
	Preferred stock			22			―		25		―		25
	-1	Before reductions for unamortized discount (net of premium) of $23 million and $21 million at March 31, 2015 and December 31, 2014, respectively, and excluding build-to-suit and capital leases of $336 million and $310 million at March 31, 2015 and December 31, 2014, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
	-2	Level 3 instruments include $322 million and $325 million at March 31, 2015 and December 31, 2014, respectively, related to Otay Mesa VIE.
	-3	Before reductions for unamortized discount of $12 million and $11 million at March 31, 2015 and December 31, 2014, respectively, and excluding capital leases of $232 million and $234 million at March 31, 2015 and December 31, 2014, respectively.
	-4	Before reductions for unamortized discount of $7 million and $8 million at March 31, 2015 and December 31, 2014, respectively, and excluding capital leases of $1 million at December 31, 2014.

NUCLEAR_PLANT_Tables

NUCLEAR PLANT (Tables)	3 Months Ended
	Mar. 31, 2015
Schedule of Nuclear Decommissioning Trusts Investments [Abstract]
Schedule of Nuclear Decommissioning Trusts Investments	NUCLEAR DECOMMISSIONING TRUSTS
	(Dollars in millions)
						Gross		Gross		Estimated
						unrealized		unrealized		fair
				Cost		gains		losses		value
	At March 31, 2015:
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies(1)		$	103	$	8	$	―	$	111
	Municipal bonds(2)			134		8		―		142
	Other securities(3)			211		9		-8		212
	Total debt securities			448		25		-8		465
	Equity securities			218		452		-4		666
	Cash and cash equivalents			19		―		―		19
	Total		$	685	$	477	$	-12	$	1,150
	At December 31, 2014:
	Debt securities:
	Debt securities issued by the U.S. Treasury and other
	U.S. government corporations and agencies		$	103	$	6	$	―	$	109
	Municipal bonds			121		8		―		129
	Other securities			206		7		-6		207
	Total debt securities			430		21		-6		445
	Equity securities			215		444		-4		655
	Cash and cash equivalents			30		1		―		31
	Total		$	675	$	466	$	-10	$	1,131
	-1	Maturity dates are 2015-2060.
	-2	Maturity dates are 2015-2114.
	-3	Maturity dates are 2015-2111.
	SALES OF SECURITIES
	(Dollars in millions)
			Three months ended March 31,
			2015		2014
	Proceeds from sales(1)		$	94	$	195
	Gross realized gains			2		4
	Gross realized losses			-4		-4
	-1	Excludes securities that are held to maturity.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES (Tables)	3 Months Ended
	Mar. 31, 2015
Commitments And Contingencies (Tables) [Abstract]
Schedule Of Capital Leases, Future Minimum Payments Due	FUTURE MINIMUM PAYMENTS – POWER PURCHASE AGREEMENT
	(Dollars in millions)
	2015		$	―
	2016			―
	2017			38
	2018			65
	2019			65
	Thereafter			1,460
	Total minimum lease payments(1)			1,628
	Less: estimated executory costs			-392
	Less: interest(2)			-736
	Present value of net minimum lease payments		$	500
	-1	This amount will be recorded over the life of the lease as Cost of Electric Fuel and Purchased Power on Sempra Energy’s and SDG&E’s Condensed Consolidated Statements of Operations. This expense will receive ratemaking treatment consistent with purchased-power costs, which are recovered in rates.
	-2	Amount necessary to reduce net minimum lease payments to estimated present value at the inception of the lease.

SEGMENT_INFORMATION_Tables

SEGMENT INFORMATION (Tables)	3 Months Ended
	Mar. 31, 2015
Segment Information (Tables) [Abstract]
Segment Information Table	SEGMENT INFORMATION
	(Dollars in millions)
			Three months ended March 31,
			2015				2014
	REVENUES
	SDG&E		$	966	36	%	$	987	35	%
	SoCalGas			1,048	39			1,085	39
	Sempra South American Utilities			389	15			378	14
	Sempra Mexico			163	6			201	7
	Sempra Renewables			8	―			6	―
	Sempra Natural Gas			197	7			260	9
	Intersegment revenues(1)			-89	-3			-122	-4
	Total		$	2,682	100	%	$	2,795	100	%
	INTEREST EXPENSE
	SDG&E		$	52			$	50
	SoCalGas			19				17
	Sempra South American Utilities			5				8
	Sempra Mexico			5				4
	Sempra Renewables			1				―
	Sempra Natural Gas			21				32
	All other			63				58
	Intercompany eliminations			-32				-33
	Total		$	134			$	136
	INTEREST INCOME
	Sempra South American Utilities		$	4			$	3
	Sempra Mexico			2				―
	Sempra Natural Gas			19				31
	Intercompany eliminations			-18				-30
	Total		$	7			$	4
	DEPRECIATION AND AMORTIZATION
	SDG&E		$	145	48	%	$	130	45	%
	SoCalGas			113	37			105	37
	Sempra South American Utilities			13	4			14	5
	Sempra Mexico			17	6			16	6
	Sempra Renewables			2	1			1	―
	Sempra Natural Gas			12	4			17	6
	All other			1	―			3	1
	Total		$	303	100	%	$	286	100	%
	INCOME TAX EXPENSE (BENEFIT)
	SDG&E		$	88			$	83
	SoCalGas			95				38
	Sempra South American Utilities			16				15
	Sempra Mexico			8				12
	Sempra Renewables			-17				-6
	Sempra Natural Gas			2				6
	All other			-29				-21
	Total		$	163			$	127
	SEGMENT INFORMATION (CONTINUED)
	(Dollars in millions)
			Three months ended March 31,
			2015				2014
	EQUITY EARNINGS (LOSSES)
	Earnings recorded before tax:
	Sempra Renewables		$	2			$	2
	Sempra Natural Gas			17				15
	Total		$	19			$	17
	(Losses) earnings recorded net of tax:
	Sempra South American Utilities		$	-1			$	-2
	Sempra Mexico			16				8
	Total		$	15			$	6
	EARNINGS (LOSSES)
	SDG&E		$	147	34	%	$	99	40	%
	SoCalGas(2)			214	49			78	32
	Sempra South American Utilities			41	9			35	14
Sempra Mexico			47	11			42	17
Sempra Renewables			13	3			28	11
Sempra Natural Gas			2	―			9	4
All other			-27	-6			-44	-18
Total		$	437	100	%	$	247	100	%
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E		$	355	46	%	$	294	37	%
SoCalGas			315	40			260	33
Sempra South American Utilities			31	4			32	4
Sempra Mexico			55	7			75	9
Sempra Renewables			3	1			99	12
Sempra Natural Gas			10	1			40	5
All other			11	1			1	―
Total		$	780	100	%	$	801	100	%
		31-Mar-15				31-Dec-14
ASSETS
SDG&E		$	16,485	42	%	$	16,296	41	%
SoCalGas			10,563	27			10,461	26
Sempra South American Utilities			3,350	8			3,379	9
Sempra Mexico			3,502	9			3,488	9
Sempra Renewables			1,277	3			1,338	3
Sempra Natural Gas			6,032	15			6,436	16
All other			960	2			895	2
Intersegment receivables			-2,618	-6			-2,561	-6
Total		$	39,551	100	%	$	39,732	100	%
INVESTMENTS IN EQUITY METHOD INVESTEES
Sempra South American Utilities		$	-8			$	-8
Sempra Mexico			439				434
Sempra Renewables			859				911
Sempra Natural Gas			1,319				1,347
All other			163				164
Total		$	2,772			$	2,848
-1	Revenues for reportable segments include intersegment revenues of $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 and $3 million, $18 million, $22 million and $79 million for the three months ended March 31, 2014 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.
-2	After preferred dividends.

GENERAL_Details

GENERAL (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015
Seasonality [Line Items]
Higher Earnings Due To Seasonality	$113
Higher Utility Revenue Due to Seasonality	163
Southern California Gas Company [Member]
Seasonality [Line Items]
Higher Earnings Due To Seasonality	113
Higher Utility Revenue Due to Seasonality	$163

New_Accounting_Policy_details

New Accounting Policy (details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
New Accounting Policy [Line Items]
Deferred Finance Costs Net	$85	$84
San Diego Gas and Electric Company [Member]
New Accounting Policy [Line Items]
Deferred Finance Costs Net	33	33
Southern California Gas Company [Member]
New Accounting Policy [Line Items]
Deferred Finance Costs Net	$15	$15

RECENT_INVESTMENT_ACTIVITY_Det

RECENT INVESTMENT ACTIVITY (Details) (Copper Mountain Solar 3 [Member], USD $)	0 Months Ended
In Millions, unless otherwise specified	Mar. 13, 2014
Copper Mountain Solar 3 [Member]
Deconsolidation of business [Line Items]
Proceeds from sale, net of transaction costs	$68
Cash	-2
Property, plant and equipment, net	-247
Other assets	-11
Accounts payable and accrued expenses	82
Long-term debt including current portion	97
Other liabilities	3
Accumulated other comprehensive income	-2
Gain on sale of equity interests	-27
Equity method investments upon deconsolidation	($39)

RECENT_INVESTMENT_ACTIVITY_2_D

RECENT INVESTMENT ACTIVITY 2 (Details) (USD $)	3 Months Ended		0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Mar. 13, 2014	Apr. 09, 2015
Business Acquisition [Line Items]
Liabilities Assumed	($2)	$0
Copper Mountain Solar 3 [Member]
Business Acquisition [Line Items]
Equity Method Investment Ownership Percentage			50.00%
Deconsolidation Gain Or Loss Amount After Tax			16
Proceeds from sale, net of cash sold			66
Mesquite Power [Member]
Business Acquisition [Line Items]
Deconsolidation Gain Or Loss Amount After Tax				34
Proceeds from sale, net of cash sold				345
Deconsolidation Gain Or Loss Amount				58
Black Oak Getty Wind [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)	2
Equity Method Investment Ownership Percentage			100.00%
Contingent payments to acquire a business	6
Total business acquisition costs	$8

RECENT_INVESTMENT_ACTIVITY_3_D

RECENT INVESTMENT ACTIVITY 3 (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Recent Investment Activity (Details) [Abstract]
Property, plant and equipment, net	$291
Inventories	4
Total assets held for sale	295		293	[1]
Liability held for sale - asset retirement obligation	-6	[2]
Total assets held for sale, net	$289
[1]	Derived from audited financial statements.
[2]	Included in Other Current Liabilities on the Condensed Consolidated Balance Sheet.

INVESTMENTS_IN_UNCONSOLIDATED_1

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Schedule of Equity Method Investments [Line Items]
Equity Method Investments in Joint Ventures, capitalized interest	$17	$8
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Equity investments In Joint Ventures	17	12
Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Equity investments In Joint Ventures	3
Equity Method Investments in Joint Ventures, capitalized interest	$12

OTHER_FINANCIAL_DATA_VARIABLE_

OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Variable Interest Entities [Line Items]
Cost Of Electric Fuel And Purchased Power From Utilities	$481	$510
Other operation and maintenance	658	676
Depreciation and amortization	303	286
Other income (expense), net	39	40
Interest expense	134	136
Net income	458	266
Earnings attributable to noncontrolling interest	-21	-19
Earnings attributable to common shares	437	247
Cameron LNG Holdings [Member]
Schedule Of Equity Method And Other Investments [Line Items]
Equity Method And Other Investments	969		1,007
Otay Mesa VIE [Member]
Variable Interest Entities [Line Items]
Cost Of Electric Fuel And Purchased Power From Utilities	-18	-18
Other operation and maintenance	4	5
Depreciation and amortization	6	7
Operating Expenses	-8	-6
Utility operating income	8	6
Interest expense	-4	-4
Net income	4	2
Earnings attributable to noncontrolling interest	-4	-2
Earnings attributable to common shares	0	0
Equity of variable interest entity	59		60
Secured debt of variable interest entity	$322

OTHER_FINANCIAL_DATA_GOODWILL_

OTHER FINANCIAL DATA - GOODWILL (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Goodwill [Line Items]
Goodwill, Beginning Balance	$903	$931	[1]
Goodwill, Ending Balance	$903	$931	[1]
[1]	Derived from audited financial statements.

OTHER_FINANCIAL_DATA_PENSION_A

OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Pension Benefits
Net Periodic Benefit Cost
Service cost	$30	$26
Interest cost	39	41
Expected return on assets	-44	-43
Amortization of prior service cost	3	2
Amortization of actuarial loss	8	5
Settlement	0	3
Regulatory adjustment	-29	-24
Total net periodic benefit cost	7	10
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions to pension plans	15
Expected contributions to benefit plans	31
Pension Benefits | San Diego Gas and Electric Company [Member]
Net Periodic Benefit Cost
Service cost	8	8
Interest cost	10	11
Expected return on assets	-14	-14
Amortization of prior service cost	0	0
Amortization of actuarial loss	2	1
Regulatory adjustment	-5	-5
Total net periodic benefit cost	1	1
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions to pension plans	1
Expected contributions to benefit plans	3
Pension Benefits | Southern California Gas Company [Member]
Net Periodic Benefit Cost
Service cost	19	16
Interest cost	25	25
Expected return on assets	-27	-26
Amortization of prior service cost	2	2
Amortization of actuarial loss	5	2
Regulatory adjustment	-24	-19
Total net periodic benefit cost	0	0
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions to pension plans	1
Expected contributions to benefit plans	2
Other Postretirement Benefits
Net Periodic Benefit Cost
Service cost	7	6
Interest cost	12	12
Expected return on assets	-17	-16
Amortization of prior service cost	-1	-1
Amortization of actuarial loss	0	0
Settlement	0	0
Regulatory adjustment	0	0
Total net periodic benefit cost	1	1
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions to other postretirement benefit plans	1
Expected contributions to benefit plans	11
Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Net Periodic Benefit Cost
Service cost	2	2
Interest cost	2	2
Expected return on assets	-3	-3
Amortization of prior service cost	1	1
Amortization of actuarial loss	0	0
Regulatory adjustment	-2	-2
Total net periodic benefit cost	0	0
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions to other postretirement benefit plans	0
Expected contributions to benefit plans	8
Other Postretirement Benefits | Southern California Gas Company [Member]
Net Periodic Benefit Cost
Service cost	5	4
Interest cost	9	9
Expected return on assets	-14	-13
Amortization of prior service cost	-2	-2
Amortization of actuarial loss	0	0
Regulatory adjustment	2	2
Total net periodic benefit cost	0	0
Pension and Other Postretirement Benefit Contributions [Abstract]
Contributions to other postretirement benefit plans	0
Expected contributions to benefit plans	$0

OTHER_FINANCIAL_DATA_RABBI_TRU

OTHER FINANCIAL DATA - RABBI TRUST (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Rabbi Trust Disclosure [Abstract]
Rabbi Trust	$476	$512	[1]
[1]	Derived from audited financial statements.

OTHER_FINANCIAL_DATA_EARNINGS_

OTHER FINANCIAL DATA - EARNINGS PER SHARE (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Earnings Per Share Numerator [Abstract]
Earnings	$437	$247
Earnings Per Share Denominator [Abstract]
Weighted-average common shares outstanding for basic EPS	247,722,000	245,277,000
Dilutive effect of stock options, restricted stock awards and restricted stock units	3,484,000	4,392,000
Weighted-average common shares outstanding for diluted EPS	251,206,000	249,669,000
Earnings Per Share [Abstract]
Basic earnings per common share	$1.76	$1.01
Diluted earnings per common share	$1.74	$0.99
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares excluded from potential dilutive shares	1,285,193	1,142,023
Performance RSU minnimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	0.00%
Performance RSU max prior to 2014 [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	150.00%
Performance RSU max in 2014 and after [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	200.00%
Service RSU max [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Sharebased Compensation Arrangement By Sharebased Payment Award Award Vesting Rights Percentage	100.00%
Out Of The Money Stock Options [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	0	0
Employee Stock Option [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	0	0
Restricted Stock [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	0	0
Restricted Stock Units [Member]
Antidilutive Securities Excluded From Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from computation of earnings per share	614	0

OTHER_FINANCIAL_DATA_SHAREBASE

OTHER FINANCIAL DATA - SHARE-BASED COMPENSATION (Details) (USD $)	3 Months Ended
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based compensation expense, net of income taxes	$8	$7
IENova Plans [Member] [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	148,781
Service-Based [Member] | Sempra Energy Plans [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	127,753
Performance-Based, Total Shareholder Return [Member] | Sempra Energy Plans [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	300,719
Performance-Based, Earnings Per Share [Member] | Sempra Energy Plans [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	76,505

OTHER_FINANCIAL_DATA_CAPITALIZ

OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	$6	$6
AFUDC related to equity	27	25
Other capitalized financing costs	17	8
Total capitalized financing costs	50	39
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	3	4
AFUDC related to equity	8	11
Total capitalized financing costs	11	15
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	3	2
AFUDC related to equity	9	5
Total capitalized financing costs	$12	$7

OTHER_FINANCIAL_DATA_COMPREHEN

OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period	$12,100	[1]	$11,850
Comprehensive income (loss)	329		219
Share-based compensation expense	13		10
Common stock dividends declared	-173		-162
Issuance of common stock	30		11
Tax benefit related to share-based compensation	52		8
Repurchases of common stock	-65		-37
Noncontrolling Interest Increase			1
Distributions to noncontrolling interests	-5		-11
Equity, end of period	12,281		11,889
Ownership Interests Held By Others [Line Items]
Amount of ownership interests held by others	757			754
Ownership Interests Held By Others, Bay Gas Storage Company [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	9.10%			9.10%
Amount of ownership interests held by others	23			23
Ownership Interests Held By Others, Southern Gas Transmission [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	49.00%			49.00%
Amount of ownership interests held by others	1			1
Ownership Interests Held By Others, Liberty Gas Storage [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	25.00%			25.00%
Amount of ownership interests held by others	14			14
Ownership Interests Held By Others, Tecsur [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	9.80%			9.80%
Amount of ownership interests held by others	3			4
Ownership Interests Held By Others, Luz Del Sur [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	16.40%			16.40%
Amount of ownership interests held by others	174			177
Ownership Interests Held By Others, Chilquinta Energia [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others, minimum	23.50%	[2]		23.60%	[2]
Percent of ownership held by others, maximum	43.40%	[2]		43.40%	[2]
Amount of ownership interests held by others	23	[2]		23	[2]
Otay Mesa VIE [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	100.00%			100.00%
Amount of ownership interests held by others	59			60
Ownership Interests Held By Others IEnova [Member]
Ownership Interests Held By Others [Line Items]
Percent of ownership held by others	18.90%			18.90%
Amount of ownership interests held by others	460			452
San Diego Gas and Electric Company [Member]
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period	4,992		4,719
Comprehensive income (loss)	149		101
Distributions to noncontrolling interests	-3		-6
Equity, end of period	5,138		4,814
Southern California Gas Company [Member]
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period				2,781
Equity, end of period	2,995			2,781
Total Shareholders' Equity
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period	11,326		11,008
Comprehensive income (loss)	321		202
Share-based compensation expense	13		10
Common stock dividends declared	-173		-162
Issuance of common stock	30		11
Tax benefit related to share-based compensation	52		8
Repurchases of common stock	-65		-37
Noncontrolling Interest Increase			0
Distributions to noncontrolling interests	0		0
Equity, end of period	11,504		11,040
Total Shareholders' Equity | San Diego Gas and Electric Company [Member]
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period	4,932		4,628
Comprehensive income (loss)	147		99
Distributions to noncontrolling interests	0		0
Equity, end of period	5,079		4,727
Noncontrolling Interests [Member]
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period	774		842
Comprehensive income (loss)	8		17
Share-based compensation expense	0		0
Common stock dividends declared	0		0
Issuance of common stock	0		0
Tax benefit related to share-based compensation	0		0
Repurchases of common stock	0		0
Noncontrolling Interest Increase			1
Distributions to noncontrolling interests	-5		-11
Equity, end of period	777		849
Noncontrolling Interests [Member] | San Diego Gas and Electric Company [Member]
Comprehensive Income Disclosure [Line Items]
Equity, beginning of period	60		91
Comprehensive income (loss)	2		2
Distributions to noncontrolling interests	-3		-6
Equity, end of period	$59		$87
[1]	Derived from audited financial statements.
[2]	Chilquinta EnergC-a has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages amongst these subsidiaries.

OTHER_FINANCIAL_DATA_COMPREHEN1

OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY 2 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	($497)	[1],[2]	($228)	[1]
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	-116	[1]	-57	[1]
Amounts Reclassified From Accumulated Other Comprehensive Income	0	[1]	12	[1]
Net Other Comprehensive Income	-116	[1]	-45	[1]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	-613	[1]	-273	[1]
San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance					-12	[2]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	-12				-12	[2]
Southern California Gas Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance					-18	[2]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	-18				-18	[2]
Accumulated Translation Adjustment [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	-322	[1]	-129	[1]
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	-62	[1]	-43	[1]
Amounts Reclassified From Accumulated Other Comprehensive Income	0	[1]	0	[1]
Net Other Comprehensive Income	-62	[1]	-43	[1]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	-384	[1]	-172	[1]
Accumulated Defined Benefit Plans Adjustment Net Unamortized Gain Loss [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	-83	[1]	-73	[1]
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	0	[1]	0	[1]
Amounts Reclassified From Accumulated Other Comprehensive Income	1	[1]	3	[1]
Net Other Comprehensive Income	1	[1]	3	[1]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	-82	[1]	-70	[1]
Accumulated Defined Benefit Plans Adjustment Net Prior Service Cost Credit [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	-2	[1]	0	[1]
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	0	[1]	0	[1]
Amounts Reclassified From Accumulated Other Comprehensive Income	0	[1]	0	[1]
Net Other Comprehensive Income	0	[1]	0	[1]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	-2	[1]	0	[1]
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	-90	[1]	-26	[1]
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	-54	[1]	-14	[1]
Amounts Reclassified From Accumulated Other Comprehensive Income	-1	[1]	9	[1]
Net Other Comprehensive Income	-55	[1]	-5	[1]
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	($145)	[1]	($31)	[1]
[1]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
[2]	Derived from audited financial statements.

OTHER_FINANCIAL_DATA_COMPREHEN2

OTHER FINANCIAL DATA - COMPREHENSIVE INCOME AND EQUITY 3 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, net of income tax.	$15		$6
Interest expense	-134		-136
Equity Earnings (Losses) Recorded Before Tax	19		17
Revenues - energy related businesses	260		310
Total before income tax	606		387
Income tax (expense) benefit	-163		-127
Earnings attributable to noncontrolling interest	-21		-19
Grand total reclassifications for the period, net of tax	0		12
San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense	-52		-50
Total before income tax	239		184
Income tax (expense) benefit	-88		-83
Earnings attributable to noncontrolling interest	-4		-2
Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense	-19		-17
Total before income tax	309		116
Income tax (expense) benefit	-95		-38
Accumulated Defined Benefit Plans Adjustment [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Income tax (expense) benefit	-1		-2
Total reclassifications for the period, net of tax	1		3
Accumulated Defined Benefit Plans Adjustment [Member] | Amortization of Actuarial Loss [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	2	[1]	5	[1]
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Total before income tax	2		18
Income tax (expense) benefit	1		-6
Net of Income Tax	3		12
Earnings attributable to noncontrolling interest	-4		-3
Total reclassifications for the period, net of tax	-1		9
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest	-3		-3
Total reclassifications for the period, net of tax	0		0
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate And Foreign Exchange Instruments [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense	6		3
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Gain on sale of equity interests and assets	0		2
Equity Earnings (Losses) Recorded Before Tax	3		3
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense	3		3
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Revenues - energy related businesses	($7)		$10
[1]	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).

OTHER_FINANCIAL_DATA_TRANSACTI

OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details) (USD $)	3 Months Ended			12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014	Dec. 31, 2014
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	$200	[1]		$226	[1]
San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, current	41			1
Due to affiliate, current	2			21
Revenues from unconsolidated affiliates	3		3
Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, current	61			4
Due to affiliate, current	0			13
Revenues from unconsolidated affiliates	19		18
Due to/from Sempra Energy | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, current	40			0
Due to affiliate, current	0			17
Income taxes due from Sempra Energy	15	[2]		16	[2]
Due to/from Sempra Energy | Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, current	59			0
Income taxes due to Sempra Energy	-107	[2]
Income taxes due from Sempra Energy				9	[2]
Subsidiary Of Common Parent S D G E [Member] | Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, current	2			4
Subsdiary Of Common Parent So Cal Gas [Member] | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliate, current	2			4
Subsidiary Of Common Parent Other Affiliates [Member] | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, current	$1			$1
[1]	Amounts include principal balances plus accumulated interest outstanding.
[2]	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.

OTHER_FINANCIAL_DATA_TRANSACTI1

OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES 2 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	$200	[1]	$226	[1]
Joint venture with PEMEX [Member]
Transactions With Affiliates Disclosure [Line Items]
Interest rate on due from affiliate, noncurrent	4.67%
PEMEX Four year loan C [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	8	[1],[2]	8	[1],[2]
PEMEX Three year loan A [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	44	[1],[2]	44	[1],[2]
PEMEX Four year loan B [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	33	[1],[2]	33	[1],[2]
PEMEX Four year loan A [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	41	[1],[2]	40	[1],[2]
ESJ joint venture [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	23	[1],[3]	22	[1],[3]
Interest rate on due from affiliate, noncurrent	6.55%
Eletrans [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	46	[1],[4]	41	[1],[4]
Interest rate on due from affiliate, noncurrent	4.00%
Affiliate Of Investee [Member]
Transactions With Affiliates Disclosure [Line Items]
Due From Joint Ventures Noncurrent	$5	[1],[5]	$38	[1],[5]
[1]	Amounts include principal balances plus accumulated interest outstanding.
[2]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.67 percent at March 31, 2015), to finance the Los Ramones Norte pipeline project.
[3]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.55 percent at March 31, 2015), to finance the first phase of the EnergC-a Sierra JuC!rez wind project.
[4]	U.S. dollar-denominated loan, at a fixed interest rate with no stated maturity date, to provide project financing for the construction of transmission lines at Eletrans S.A., an affiliate of Chilquinta EnergC-a.
[5]	Amounts represent accounts receivable from various Sempra Renewables and Sempra Mexico joint venture investments.

OTHER_FINANCIAL_DATA_OTHER_INC

OTHER FINANCIAL DATA - OTHER INCOME (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity	$27		$25
Investment gains (losses)	9	[1]	8	[1]
Gains (losses) on interest rate and foreign exchange instruments, net	0		2
Regulatory Interest, net	1	[2]	1	[2]
Sundry, net	3		4
Foreign currency gain (losses)	-1		0
Total	39		40
San Diego Gas and Electric Company [Member]
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity	8		11
Regulatory Interest, net	1	[2]	1	[2]
Sundry, net	0		1
Total	9		13
Southern California Gas Company [Member]
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity	9		5
Sundry, net	-1		-1
Total	$8		$4
[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]	Interest on regulatory balancing accounts.

OTHER_FINANCIAL_DATA_INCOME_TA

OTHER FINANCIAL DATA - INCOME TAXES (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$163	$127
Effective income tax rate	27.00%	33.00%
Charge To Reduce Certain Tax Regulatory Assets Attributable To Nuclear Plant		17
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	88	83
Effective income tax rate	37.00%	45.00%
Charge To Reduce Certain Tax Regulatory Assets Attributable To Nuclear Plant		17
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$95	$38
Effective income tax rate	31.00%	33.00%

OTHER_FINANCIAL_DATA_INVENTORY

OTHER FINANCIAL DATA - INVENTORY (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	$111	$246
Energy Related Inventory, Liquefied Natural Gas	11	14
Energy Related Inventory, Materials And Supplies	133	136
Inventory, Total	255	396	[1]
S D G E Segment [Member]
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	6	8
Energy Related Inventory, Liquefied Natural Gas	0	0
Energy Related Inventory, Materials And Supplies	63	65
Inventory, Total	69	73
So Cal Gas Segment [Member]
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	83	155
Energy Related Inventory, Liquefied Natural Gas	0	0
Energy Related Inventory, Materials And Supplies	26	26
Inventory, Total	109	181
Sempra South American Utilities Segment [Member]
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	0	0
Energy Related Inventory, Liquefied Natural Gas	0	0
Energy Related Inventory, Materials And Supplies	32	33
Inventory, Total	32	33
Sempra Mexico Segment [Member]
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	0	0
Energy Related Inventory, Liquefied Natural Gas	7	9
Energy Related Inventory, Materials And Supplies	9	9
Inventory, Total	16	18
Sempra Natural Gas Segment [Member]
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	22	83
Energy Related Inventory, Liquefied Natural Gas	4	5
Energy Related Inventory, Materials And Supplies	1	1
Inventory, Total	27	89
Sempra Renewables Segment [Member]
Total Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	0	0
Energy Related Inventory, Liquefied Natural Gas	0	0
Energy Related Inventory, Materials And Supplies	2	2
Inventory, Total	$2	$2
[1]	Derived from audited financial statements.

DEBT_AND_CREDIT_FACILITIES_Det

DEBT AND CREDIT FACILITIES (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Line Of Credit Facility, Sempra Energy Consolidated [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$4,100
Committed lines of credit, remaining borrowing capacity	3,300
Weighted average interest rate on total short-term debt outstanding	0.72%	0.70%
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, outstanding borrowings	0
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	731
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, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	558
Outstanding commercial paper supported by committed lines of credit	100
Weighted average interest rate on total short-term debt outstanding		0.27%
Weighted Average Interest Rate On Commercial Paper, Noncurrent	0.40%
Line Of Credit Facility, So Cal Gas [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	658
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	658
Outstanding letters of credit	0
Weighted average interest rate on total short-term debt outstanding		0.25%
Line Of Credit Facility, California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	877
Committed lines of credit, capacity for issuance of letters of credit	300
Line Of Credit Facility, South American Utilities And Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	843
Committed lines of credit, remaining borrowing capacity	648
Line Of Credit Facility, IEnova Santander [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	200
Committed lines of credit, remaining borrowing capacity	150
Committed lines of credit, outstanding borrowings	50
Line Of Credit Facility, IEnova Sumitomo [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	100
Committed lines of credit, remaining borrowing capacity	75
Committed lines of credit, outstanding borrowings	$25

DEBT_AND_CREDIT_FACILITIES_2_D

DEBT AND CREDIT FACILITIES 2 (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Other Long Term Debt, Variable Rate Due 2017 [Member] | San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$140
Debt Instrument, Interest Rate At Period End	0.47%
Debt Instrument, Variable Base Rate	0.20%
Other Long Term Debt, Fixed Rate Due 2020 [Member] | Sempra Energy [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	500
Debt Instrument, Interest Rate, Stated Percentage	2.40%
Other Long Term Debt, Amortizing Fixed Rate Due 2022 [Member] | San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$250
Debt Instrument, Interest Rate, Stated Percentage	1.91%

DERIVATIVE_FINANCIAL_INSTRUMEN2

DERIVATIVE FINANCIAL INSTRUMENTS (Details)	Mar. 31, 2015		Dec. 31, 2014
S D G E Segment [Member]
Schedule Of Commodity Derivative Volumes [Line Items]
Commodity derivative volumes, natural gas (in millions of million British thermal units)	57	[1]	55	[1]
Commodity derivative volumes, congestion revenue rights (in millions of megawatt hours)	24	[2]	27	[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)	1	[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)	7	[1]	29	[1]
[1]	Million British thermal units
[2]	Megawatt hours

DERIVATIVE_FINANCIAL_INSTRUMEN3

DERIVATIVE FINANCIAL INSTRUMENTS 2 (Details) (USD $)	3 Months Ended		12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
Cash Flow Hedges
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Derivative Liability Notional Amount	396	[1]	399	[1]
Cash Flow Hedges | Maximum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	2028		2028
Cash Flow Hedges | Minimum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	2015		2015
Fair Value Hedges
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Derivative Liability Notional Amount	300		300
Fair Value Hedges | Maximum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	2016		2016
San Diego Gas and Electric Company [Member] | Cash Flow Hedges
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Derivative Liability Notional Amount	322	[1]	325	[1]
San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Maximum [Member]
Schedule Of Notional Amounts Of Interest Rate Derivatives [Line Items]
Maturities of interest rate derivatives	2019		2019
[1]	Amounts include Otay Mesa VIE. All of SDG&Ebs interest rate derivative activity relates to Otay Mesa VIE.

DERIVATIVE_FINANCIAL_INSTRUMEN4

DERIVATIVE FINANCIAL INSTRUMENTS 3 (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
OtherCurrentAssetsMember
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	$10,000,000	[1],[2]	$10,000,000	[1]
Commodity contracts not subject to rate recovery			25,000,000	[1]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments	11,000,000	[1]	8,000,000	[1]
Commodity contracts not subject to rate recovery	129,000,000	[1]	143,000,000	[1]
Associated offsetting commodity contracts not subject to rate recovery	-123,000,000	[1]	-129,000,000	[1]
Associated cash collateral commodity contracts not subject to rate recovery	0	[1]	-11,000,000	[1]
Commodity contracts subject to rate recovery	28,000,000	[1]	36,000,000	[1]
Associated cash collateral commodity contracts subject to rate recovery	0	[1]	0	[1]
Associated offsetting commodity contracts subject to rate recovery	-1,000,000	[1]	-3,000,000	[1]
Net amount presented on balance sheet	54,000,000	[1]	79,000,000	[1]
Additional margin posted for commodity contracts not subject to rate recovery	16,000,000	[1]
Additional margin posted for commodity contracts subject to rate recovery	19,000,000	[1]	14,000,000	[1]
Total	89,000,000	[1],[3]	93,000,000	[1],[3]
OtherCurrentAssetsMember | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	0	[2]	0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	0
Associated cash collateral commodity contracts not subject to rate recovery	0
Commodity contracts subject to rate recovery	26,000,000		32,000,000
Associated cash collateral commodity contracts subject to rate recovery	0		0
Associated offsetting commodity contracts subject to rate recovery			0
Net amount presented on balance sheet	26,000,000		32,000,000
Additional margin posted for commodity contracts not subject to rate recovery	1,000,000
Additional margin posted for commodity contracts subject to rate recovery	17,000,000		12,000,000
Total	44,000,000	[3]	44,000,000	[3]
OtherCurrentAssetsMember | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	0
Associated cash collateral commodity contracts not subject to rate recovery	0
Commodity contracts subject to rate recovery	2,000,000	[1]	4,000,000	[1]
Associated offsetting commodity contracts subject to rate recovery	-1,000,000	[1]	-3,000,000	[1]
Net amount presented on balance sheet	1,000,000	[1]	1,000,000	[1]
Additional margin posted for commodity contracts not subject to rate recovery	1,000,000	[1]
Additional margin posted for commodity contracts subject to rate recovery	2,000,000	[1]	2,000,000	[1]
Total	4,000,000	[1]	3,000,000	[1]
OtherNoncurrentAssetsMember
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	3,000,000	[2]	3,000,000
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	28,000,000		27,000,000
Commodity contracts not subject to rate recovery	25,000,000		32,000,000
Associated offsetting commodity contracts not subject to rate recovery	-21,000,000		-27,000,000
Associated cash collateral commodity contracts not subject to rate recovery	0		0
Commodity contracts subject to rate recovery	76,000,000		76,000,000
Associated cash collateral commodity contracts subject to rate recovery	0		0
Associated offsetting commodity contracts subject to rate recovery	0		-1,000,000
Net amount presented on balance sheet	111,000,000		110,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	111,000,000	[3]	110,000,000	[3]
OtherNoncurrentAssetsMember | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	0	[2]	0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	0
Associated cash collateral commodity contracts not subject to rate recovery	0
Commodity contracts subject to rate recovery	76,000,000		76,000,000
Associated cash collateral commodity contracts subject to rate recovery	0		0
Associated offsetting commodity contracts subject to rate recovery			-1,000,000
Net amount presented on balance sheet	76,000,000		75,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	76,000,000	[3]	75,000,000	[3]
OtherNoncurrentAssetsMember | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	0
Associated cash collateral commodity contracts not subject to rate recovery	0
Commodity contracts subject to rate recovery	0		0
Associated offsetting commodity contracts subject to rate recovery	0		0
Net amount presented on balance sheet	0		0
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	0		0
OtherCurrentLiabilitiesMember
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	-17,000,000	[2],[4]	-17,000,000	[4]
Commodity contracts not subject to rate recovery			0	[4]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments	-7,000,000	[4]	-7,000,000	[4]
Commodity contracts not subject to rate recovery	-137,000,000	[4]	-135,000,000	[4]
Associated offsetting commodity contracts not subject to rate recovery	123,000,000	[4]	129,000,000	[4]
Associated cash collateral commodity contracts not subject to rate recovery	10,000,000	[4]	0	[4]
Commodity contracts subject to rate recovery	-35,000,000	[4]	-36,000,000	[4]
Associated cash collateral commodity contracts subject to rate recovery	27,000,000	[4]	23,000,000	[4]
Associated offsetting commodity contracts subject to rate recovery	1,000,000	[4]	3,000,000	[4]
Net amount presented on balance sheet	-35,000,000	[4]	-40,000,000	[4]
Additional margin posted for commodity contracts not subject to rate recovery	0	[4]
Additional margin posted for commodity contracts subject to rate recovery	0	[4]	0	[4]
Total	-35,000,000	[3],[4]	-40,000,000	[3],[4]
OtherCurrentLiabilitiesMember | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	-16,000,000	[2]	-16,000,000
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	-1,000,000
Associated cash collateral commodity contracts not subject to rate recovery	1,000,000
Commodity contracts subject to rate recovery	-34,000,000		-32,000,000
Associated cash collateral commodity contracts subject to rate recovery	27,000,000		23,000,000
Associated offsetting commodity contracts subject to rate recovery			0
Net amount presented on balance sheet	-23,000,000		-25,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	-23,000,000	[3]	-25,000,000	[3]
OtherCurrentLiabilitiesMember | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	-2,000,000
Associated cash collateral commodity contracts not subject to rate recovery	2,000,000
Commodity contracts subject to rate recovery	-1,000,000	[4]	-4,000,000	[4]
Associated offsetting commodity contracts subject to rate recovery	1,000,000	[4]	3,000,000	[4]
Net amount presented on balance sheet	0	[4]	-1,000,000	[4]
Additional margin posted for commodity contracts not subject to rate recovery	0	[4]
Additional margin posted for commodity contracts subject to rate recovery	0	[4]	0	[4]
Total	0	[4]	-1,000,000	[4]
OtherNoncurrentLiabilitiesMember
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	-130,000,000	[2]	-109,000,000
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	-25,000,000		-22,000,000
Commodity contracts not subject to rate recovery	-22,000,000		-29,000,000
Associated offsetting commodity contracts not subject to rate recovery	21,000,000		27,000,000
Associated cash collateral commodity contracts not subject to rate recovery	1,000,000		0
Commodity contracts subject to rate recovery	-33,000,000		-20,000,000
Associated cash collateral commodity contracts subject to rate recovery	27,000,000		13,000,000
Associated offsetting commodity contracts subject to rate recovery	0		1,000,000
Net amount presented on balance sheet	-161,000,000		-139,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	-161,000,000	[3]	-139,000,000	[3]
OtherNoncurrentLiabilitiesMember | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	-32,000,000	[2]	-31,000,000
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	0
Associated cash collateral commodity contracts not subject to rate recovery	0
Commodity contracts subject to rate recovery	-33,000,000		-20,000,000
Associated cash collateral commodity contracts subject to rate recovery	27,000,000		13,000,000
Associated offsetting commodity contracts subject to rate recovery			1,000,000
Net amount presented on balance sheet	-38,000,000		-37,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	-38,000,000	[3]	-37,000,000	[3]
OtherNoncurrentLiabilitiesMember | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	0
Associated cash collateral commodity contracts not subject to rate recovery	0
Commodity contracts subject to rate recovery	0		0
Associated offsetting commodity contracts subject to rate recovery	0		0
Net amount presented on balance sheet	0		0
Additional margin posted for commodity contracts not subject to rate recovery	0
Additional margin posted for commodity contracts subject to rate recovery	0		0
Total	$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]	Normal purchase contracts previously measured at fair value are excluded.
[4]	Included in Current Liabilities: Other for SoCalGas.

DERIVATIVE_FINANCIAL_INSTRUMEN5

DERIVATIVE FINANCIAL INSTRUMENTS 4 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	($11)		$3
Cash Flow Hedge Ineffectiveness	0		0
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	1		2
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	-2	[1]	-18	[1]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	-97	[1]	-26	[1]
Cash Flow Hedges | Interest Expense | Interest Rate And Foreign Exchange Instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	-6	[2]	-3	[2]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	-18	[2]	-3	[2]
Cash Flow Hedges | Interest Expense | Interest Rate Instruments | San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	-3	[1],[2]	-3	[1],[2]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	-5	[1],[2]	-3	[1],[2]
Cash Flow Hedges | Equity Earnings Before Income Tax [Member] | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	-3		-3
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	-78		-15
Cash Flow Hedges | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	7		-10
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	-1		-6
Cash Flow Hedges | Gain on sale of equity interest [Member] | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	0		-2
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	0		-2
Fair Value Hedges | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	3	[3]	-1	[3]
Fair Value Hedges | Interest Expense | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	2		3
Fair Value Hedge Ineffectiveness	0		2
Fair Value Hedges | Other Income, Net | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	1		-4
Undesignated Derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	-17		7
Undesignated Derivatives | Equity Earnings Net Of Income Tax [Member] | Foregn Exchange Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	-1		-2
Undesignated Derivatives | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	3		-5
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	-20		12
Undesignated Derivatives | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	-20		12
Undesignated Derivatives | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	1		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	$1		$2
[1]	There was a negligible amount of ineffectiveness related to these hedges in 2015 and 2014.
[2]	Amounts include Otay Mesa VIE. All of SDG&Ebs interest rate derivative activity relates to Otay Mesa VIE.
[3]	There was no hedge ineffectiveness on these swaps in the three months ended March 31, 2015 and $2 million in the three months ended March 31, 2014. All other 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 and recorded in Other Income, Net.

DERIVATIVE_FINANCIAL_INSTRUMEN6

DERIVATIVE FINANCIAL INSTRUMENTS 5 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash Flow Hedge Disclosure [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$23
Maximum Length Time Hedged In Cash Flow Hedge	14 years
Joint Venture Maximum Length Of Time Hedged In Cash Flow Hedge	20 years
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	13
Cash Flow Hedge Ineffectiveness	0	0
San Diego Gas and Electric Company [Member]
Cash Flow Hedge Disclosure [Line Items]
Maximum Length Time Hedged In Cash Flow Hedge	4 years
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	12
Southern California Gas Company [Member]
Cash Flow Hedge Disclosure [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$0

DERIVATIVE_FINANCIAL_INSTRUMEN7

DERIVATIVE FINANCIAL INSTRUMENTS 6 (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified
Derivative Credit Risk Related Contingent Features [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$7	$9
Additional Collateral Aggregate Fair Value	7
San Diego Gas and Electric Company [Member]
Derivative Credit Risk Related Contingent Features [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	4	2
Additional Collateral Aggregate Fair Value	$4

FAIR_VALUE_MEASUREMENTS_2_Deta

FAIR VALUE MEASUREMENTS 2 (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	$666		$655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	111		109
Nuclear decomissioning trusts - Municipal debt securities	142		129
Nuclear decommissioning trusts - Other debt securities	212		207
Nuclear decommissioning trusts - Total debt securities	465		445
Total nuclear decommissioning trusts	1,131	[1]	1,100	[1]
Interest rate instruments, assets	52		48
Commodity contracts not subject to rate recovery, assets	26		33
Commodity contracts subject to rate recovery, assets	122		122
Total fair value of assets measured on a recurring basis	1,331		1,303
Interest rate instruments, liabilities	179		155
Commodity contracts not subject to rate recovery, liabilities	4		8
Commodity contracts subject to rate recovery, liabilities	13		16
Total fair value of liabilities measured on a recurring basis	196		179
San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	666		655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	111		109
Nuclear decomissioning trusts - Municipal debt securities	142		129
Nuclear decommissioning trusts - Other debt securities	212		207
Nuclear decommissioning trusts - Total debt securities	465		445
Total nuclear decommissioning trusts	1,131	[1]	1,100	[1]
Commodity contracts not subject to rate recovery, assets	1
Commodity contracts subject to rate recovery, assets	119		119
Total fair value of assets measured on a recurring basis	1,251		1,219
Interest rate instruments, liabilities	48		47
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	13		15
Total fair value of liabilities measured on a recurring basis	61		62
Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	1
Commodity contracts subject to rate recovery, assets	3		3
Total fair value of assets measured on a recurring basis	4		3
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities			1
Total fair value of liabilities measured on a recurring basis	0		1
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	666		655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	58		62
Nuclear decomissioning trusts - Municipal debt securities	0		0
Nuclear decommissioning trusts - Other debt securities	0		0
Nuclear decommissioning trusts - Total debt securities	58		62
Total nuclear decommissioning trusts	724	[1]	717	[1]
Interest rate instruments, assets	0		0
Commodity contracts not subject to rate recovery, assets	2		28
Commodity contracts subject to rate recovery, assets	0		0
Total fair value of assets measured on a recurring basis	726		745
Interest rate instruments, liabilities	0		0
Commodity contracts not subject to rate recovery, liabilities	6		3
Commodity contracts subject to rate recovery, liabilities	0		0
Total fair value of liabilities measured on a recurring basis	6		3
Level 1 | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	666		655
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	58		62
Nuclear decomissioning trusts - Municipal debt securities	0		0
Nuclear decommissioning trusts - Other debt securities	0		0
Nuclear decommissioning trusts - Total debt securities	58		62
Total nuclear decommissioning trusts	724	[1]	717	[1]
Commodity contracts not subject to rate recovery, assets	0
Commodity contracts subject to rate recovery, assets	0		0
Total fair value of assets measured on a recurring basis	724		717
Interest rate instruments, liabilities	0		0
Commodity contracts not subject to rate recovery, liabilities	1		1
Commodity contracts subject to rate recovery, liabilities	0		0
Total fair value of liabilities measured on a recurring basis	1		1
Level 1 | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	0
Commodity contracts subject to rate recovery, assets	0		0
Total fair value of assets measured on a recurring basis	0		0
Commodity contracts not subject to rate recovery, liabilities	2		2
Commodity contracts subject to rate recovery, liabilities			0
Total fair value of liabilities measured on a recurring basis	2		2
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	0		0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	53		47
Nuclear decomissioning trusts - Municipal debt securities	142		129
Nuclear decommissioning trusts - Other debt securities	212		207
Nuclear decommissioning trusts - Total debt securities	407		383
Total nuclear decommissioning trusts	407	[1]	383	[1]
Interest rate instruments, assets	52		48
Commodity contracts not subject to rate recovery, assets	8		16
Commodity contracts subject to rate recovery, assets	1		1
Total fair value of assets measured on a recurring basis	468		448
Interest rate instruments, liabilities	179		155
Commodity contracts not subject to rate recovery, liabilities	9		9
Commodity contracts subject to rate recovery, liabilities	67		52
Total fair value of liabilities measured on a recurring basis	255		216
Level 2 | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	0		0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	53		47
Nuclear decomissioning trusts - Municipal debt securities	142		129
Nuclear decommissioning trusts - Other debt securities	212		207
Nuclear decommissioning trusts - Total debt securities	407		383
Total nuclear decommissioning trusts	407	[1]	383	[1]
Commodity contracts not subject to rate recovery, assets	0
Commodity contracts subject to rate recovery, assets	0		0
Total fair value of assets measured on a recurring basis	407		383
Interest rate instruments, liabilities	48		47
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	67		51
Total fair value of liabilities measured on a recurring basis	115		98
Level 2 | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	0
Commodity contracts subject to rate recovery, assets	1		1
Total fair value of assets measured on a recurring basis	1		1
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities			1
Total fair value of liabilities measured on a recurring basis	0		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 not subject to rate recovery, assets	0		0
Commodity contracts subject to rate recovery, assets	102		107
Total fair value of assets measured on a recurring basis	102		107
Interest rate instruments, liabilities	0		0
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	0		0
Total fair value of liabilities measured on a recurring basis	0		0
Level 3 | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	0		0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	0		0
Nuclear decomissioning trusts - Municipal debt securities	0		0
Nuclear decommissioning trusts - Other debt securities	0		0
Nuclear decommissioning trusts - Total debt securities	0		0
Total nuclear decommissioning trusts	0	[1]	0	[1]
Commodity contracts not subject to rate recovery, assets	0
Commodity contracts subject to rate recovery, assets	102		107
Total fair value of assets measured on a recurring basis	102		107
Interest rate instruments, liabilities	0		0
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities	0		0
Total fair value of liabilities measured on a recurring basis	0		0
Level 3 | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	0
Commodity contracts subject to rate recovery, assets	0		0
Total fair value of assets measured on a recurring basis	0		0
Commodity contracts not subject to rate recovery, liabilities	0		0
Commodity contracts subject to rate recovery, liabilities			0
Total fair value of liabilities measured on a recurring basis	0		0
Collateral Netted [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]
Interest rate instruments, assets	0	[2]	0	[2]
Commodity contracts not subject to rate recovery, assets	16	[2]	-11	[2]
Commodity contracts subject to rate recovery, assets	19	[2]	14	[2]
Total fair value of assets measured on a recurring basis	35	[2]	3	[2]
Interest rate instruments, liabilities	0	[2]	0	[2]
Commodity contracts not subject to rate recovery, liabilities	-11	[2]	-4	[2]
Commodity contracts subject to rate recovery, liabilities	-54	[2]	-36	[2]
Total fair value of liabilities measured on a recurring basis	-65	[2]	-40	[2]
Collateral Netted [Member] | San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	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 not subject to rate recovery, assets	1	[2]
Commodity contracts subject to rate recovery, assets	17	[2]	12	[2]
Total fair value of assets measured on a recurring basis	18	[2]	12	[2]
Interest rate instruments, liabilities	0	[2]	0	[2]
Commodity contracts not subject to rate recovery, liabilities	-1	[2]	-1	[2]
Commodity contracts subject to rate recovery, liabilities	-54	[2]	-36	[2]
Total fair value of liabilities measured on a recurring basis	-55	[2]	-37	[2]
Collateral Netted [Member] | Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	1	[2]
Commodity contracts subject to rate recovery, assets	2	[2]	2	[2]
Total fair value of assets measured on a recurring basis	3	[2]	2	[2]
Commodity contracts not subject to rate recovery, liabilities	-2	[2]	-2	[2]
Commodity contracts subject to rate recovery, liabilities			0	[2]
Total fair value of liabilities measured on a recurring basis	($2)	[2]	($2)	[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_3_Deta

FAIR VALUE MEASUREMENTS 3 (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	$107	$99
Realized and unrealized gains (losses)	6	1
Allocated transmission instruments	0	1
Settlements	-11	-6
Balance at end of period	102	95
Change in unrealized gains (losses) relating to instruments still held at period end	1	0
CRR Auction Rate Per MWh, Minimum	-16	-6
CRR Auction Rate Per MWh, Maximum	$8	$12

FAIR_VALUE_MEASUREMENTS_4_Deta

FAIR VALUE MEASUREMENTS 4 (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	$13,176	[1],[2]	$12,347	[1],[2]
Preferred Stock Of Subsidiaries Fair Value Disclosure	20		20
Debt Instrument Unamortized Discount	23		21
Capital Lease Obligations	336		310
Debt Instrument Carrying Amount	322		325
Carrying Amount | San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	4,849	[1],[3]	4,461	[1],[3]
Debt Instrument Unamortized Discount	12		11
Capital Lease Obligations	232		234
Debt Instrument Carrying Amount	322		325
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	1,913	[4]	1,913	[4]
Preferred Stock Of Subsidiaries Fair Value Disclosure	22		22
Debt Instrument Unamortized Discount	7		8
Capital Lease Obligations			1
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	14,784	[1],[2]	13,699	[1],[2]
Preferred Stock Of Subsidiaries Fair Value Disclosure	23		23
Fair Value | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	0	[1],[2]	0	[1],[2]
Preferred Stock Of Subsidiaries Fair Value Disclosure	0		0
Fair Value | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	13,889	[1],[2]	12,782	[1],[2]
Preferred Stock Of Subsidiaries Fair Value Disclosure	23		23
Fair Value | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	895	[1],[2]	917	[1],[2]
Preferred Stock Of Subsidiaries Fair Value Disclosure	0		0
Fair Value | San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	5,483	[1],[3]	4,988	[1],[3]
Fair Value | San Diego Gas and Electric Company [Member] | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	0	[1],[3]	0	[1],[3]
Fair Value | San Diego Gas and Electric Company [Member] | Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	5,061	[1],[3]	4,563	[1],[3]
Fair Value | San Diego Gas and Electric Company [Member] | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	422	[1],[3]	425	[1],[3]
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	2,167	[4]	2,124	[4]
Preferred Stock Of Subsidiaries Fair Value Disclosure	25		25
Fair Value | Southern California Gas Company [Member] | Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	0	[4]	0	[4]
Preferred Stock Of Subsidiaries Fair Value Disclosure	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	2,167	[4]	2,124	[4]
Preferred Stock Of Subsidiaries Fair Value Disclosure	25		25
Fair Value | Southern California Gas Company [Member] | Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	0	[4]	0	[4]
Preferred Stock Of Subsidiaries Fair Value Disclosure	$0		$0
[1]	Level 3 instruments include $322 million and $325 million at March 31, 2015 and December 31, 2014, respectively, related to Otay Mesa VIE.
[2]	Before reductions for unamortized discount (net of premium) of $23 million and $21 million at March 31, 2015 and December 31, 2014, respectively, and excluding build-to-suit and capital leases of $336 million and $310 million at March 31, 2015 and December 31, 2014, respectively. We discuss our long-term debt in Note 6 above and in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report.
[3]	Before reductions for unamortized discount of $12 million and $11 million at March 31, 2015 and December 31, 2014, respectively, and excluding capital leases of $232 million and $234 million at March 31, 2015 and December 31, 2014, respectively.
[4]	Before reductions for unamortized discount of $7 million and $8 million at March 31, 2015 and December 31, 2014, respectively, and excluding capital leases of $1 million at December 31, 2014.

NUCLEAR_PLANT_1_Details

NUCLEAR PLANT 1 (Details) (USD $)	3 Months Ended				6 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014		Mar. 31, 2014	Jun. 30, 2013
Nuclear Plant [Line Items]
Nuclear decommissioning trusts	$1,150	$1,131	[1]
Nuclear Plant Investment [Line Items]
Plant closure (adjustment) loss	-21			-13
Loss (Adjustment) From Plant Closure, After Tax	-13	12		9
Loss from plant closure, after-tax (cumulative)	127				119
Charge To Reduce Certain Tax Regulatory Assets Attributable To Nuclear Plant				17
Regulatory Asset, Current, Nuclear Plant Closure	41
Regulatory Asset, Nuclear Plant Closure	294
Regulatory Asset, Noncurrent, Nuclear Plant Closure	253
Other Commitments [Line Items]
Five-year research funding commitment, annual amount	1
San Diego Gas and Electric Company [Member]
Nuclear Plant [Line Items]
Nuclear decommissioning trusts	1,150	1,131	[1]
Nuclear Plant Investment [Line Items]
Utility plant closure (adjustment) loss	-21			-13
Loss (Adjustment) From Plant Closure, After Tax	-13	12		9
Loss from plant closure, after-tax (cumulative)	127				119
Charge To Reduce Certain Tax Regulatory Assets Attributable To Nuclear Plant				17
Regulatory Asset, Current, Nuclear Plant Closure	41
Regulatory Asset, Nuclear Plant Closure	294
Regulatory Asset, Noncurrent, Nuclear Plant Closure	253
Other Commitments [Line Items]
Five-year research funding commitment, annual amount	$1
Nuclear Plant, SDGE [Member]
Nuclear Plant [Line Items]
Nuclear Plant, Ownership Percentage	20.00%
[1]	Derived from audited financial statements.

SONGS_NDT_1_Details

SONGS NDT 1 (Details) (USD $)	3 Months Ended				12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014
Schedule of Available-for-sale Securities [Line Items]
Cost	$685				$675
Gross Unrealized Gains	477				466
Gross Unrealized Loss	-12				-10
Estimated fair value	1,150				1,131
Proceeds from sales	94	[1]	195	[1]
Gross realized gains	2		4
Gross realized losses	-4		-4
Total Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Cost	448				430
Gross Unrealized Gains	25				21
Gross Unrealized Loss	-8				-6
Estimated fair value	465				445
Debt Securities Issued By The U.S. Treasury And Other U.S. Government Corporations And Agencies
Schedule of Available-for-sale Securities [Line Items]
Cost	103	[2]			103
Gross Unrealized Gains	8	[2]			6
Gross Unrealized Loss	0	[2]			0
Estimated fair value	111	[2]			109
Municipal Bonds
Schedule of Available-for-sale Securities [Line Items]
Cost	134	[3]			121
Gross Unrealized Gains	8	[3]			8
Gross Unrealized Loss	0	[3]			0
Estimated fair value	142	[3]			129
Other Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Cost	211	[4]			206
Gross Unrealized Gains	9	[4]			7
Gross Unrealized Loss	-8	[4]			-6
Estimated fair value	212	[4]			207
Equity Securities
Schedule of Available-for-sale Securities [Line Items]
Cost	218				215
Gross Unrealized Gains	452				444
Gross Unrealized Loss	-4				-4
Estimated fair value	666				655
Cash And Cash Equivalents
Schedule of Available-for-sale Securities [Line Items]
Cost	19				30
Gross Unrealized Gains	0				1
Gross Unrealized Loss	0				0
Estimated fair value	$19				$31
[1]	Excludes securities that are held to maturity.
[2]	Maturity dates are 2015-2060.
[3]	Maturity dates are 2015-2114.
[4]	Maturity dates are 2015-2111.

CALIFORNIA_UTILITIES_REGULATOR1

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 1 (Details) (Year 2016 [Member], USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
General Rate Case, Revenue Requirement, Revised Request	$1,905
General Rate Case, Revenue Requirement Increase, Original Request	133
General Rate Case, Revenue Requirement Increase, Revised Request	111			111
General Rate Case, Revenue Requirement Percentage Increase, Revised Request	6.00%
General Rate Case, Revised Request Decrease Compared To Original	6
General Rate Case, Proposed Revenue Requirement Increase (Decrease)		63	61	-62
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)		3.50%	3.50%	-3.50%
General Rate Case, Adjustment To Decrease Estimated Revenue Requirement	16
Southern California Gas Company [Member]
General Rate Case [Line Items]
General Rate Case, Revenue Requirement, Revised Request	2,342
General Rate Case, Revenue Requirement Increase, Original Request	256
General Rate Case, Revenue Requirement Increase, Revised Request	246			246
General Rate Case, Revenue Requirement Percentage Increase, Revised Request	12.00%
General Rate Case, Revised Request Decrease Compared To Original	10
General Rate Case, Proposed Revenue Requirement Increase (Decrease)		$78	$76	$70
General Rate Case, Proposed Revenue Requirement Percentage Increase (Decrease)		3.50%	3.50%	3.30%

CALIFORNIA_UTILITIES_REGULATOR2

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 2 (Details) (Southern California Gas Company [Member], Year 2014 [Member], USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified
Southern California Gas Company [Member] | Year 2014 [Member]
Utility Incentive Awards [Line Items]
Recognized Gas Cost Incentive Mechanism Award	$13,700

CALIFORNIA_UTILITIES_REGULATOR3

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF UTILITY PROJECTS (Details) (USD $)	12 Months Ended	3 Months Ended
	Dec. 31, 2014	Mar. 31, 2015	Jun. 11, 2014
Pipeline Safety Phase 1 [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Pipeline Safety Plan Regulatory Account		$4,000,000	$100,000
Pipeline Safety Phase 1 [Member] | Southern California Gas Company [Member]
Schedule Of Utility Projects [Line Items]
Pipeline Safety Plan Regulatory Account		104,000,000	46,000,000
Disallowed Costs Impact On Earnings After Tax	5,000,000
South Orange County Reliability Enhancement [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Lower Range		400,000,000
Estimated Project Cost, Upper Range		500,000,000
Cleveland National Forest Transmissions Projects [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Lower Range		400,000,000
Estimated Project Cost, Upper Range		450,000,000
Southern Gas System Member [Member] | Utility Subsidiaries [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Lower Range		800,000,000
Estimated Project Cost, Upper Range		850,000,000
Sycamore Penasquitos Transmission Project [Member] | San Diego Gas and Electric Company [Member]
Schedule Of Utility Projects [Line Items]
Estimated Project Cost, Lower Range		120,000,000
Estimated Project Cost, Upper Range		$150,000,000
Public Utilities Requested Basis Point Return On Equity Adder, Denied		100
Public Utilities Abandoned Plant Cost Recovery Approved, Percentage		100.00%

CALIFORNIA_UTILITIES_REGULATOR4

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF REGULATORY AMOUNTS 3 (Details) (Southern California Gas Company [Member], USD $)	3 Months Ended	9 Months Ended	12 Months Ended				36 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014
Impact Of 2010 Tax Act [Line Items]
Increase Due To Bonus Depreciation Extension, Net Of Tax	$1,400	$2,500					$11,300
Increase Due To Bonus Depreciation Extension, Before Tax			$6,600	$6,400	$6,300	$6,400
First Quarter [Member]
Seasonal Factors [Line Items]
Percentage Revenue Recognized Straight Line	25.00%
Percentage Revenue Recognized Seasonal	34.00%
Second Quarter [Member]
Seasonal Factors [Line Items]
Percentage Revenue Recognized Straight Line	25.00%
Percentage Revenue Recognized Seasonal	21.00%
Third Quarter [Member]
Seasonal Factors [Line Items]
Percentage Revenue Recognized Straight Line	25.00%
Percentage Revenue Recognized Seasonal	16.00%
Fourth Quarter [Member]
Seasonal Factors [Line Items]
Percentage Revenue Recognized Straight Line	25.00%
Percentage Revenue Recognized Seasonal	29.00%

COMMITMENTS_AND_CONTINGENCIES_1

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details)	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Mar. 31, 2015	Oct. 01, 2014	Mar. 31, 2015
	USD ($)	San Diego Gas and Electric Company [Member]	Southern California Gas Company [Member]	Loss from Catastrophes [Member]	Mobile Gas Litigation [Member]	Liberty Gas Storage Litigation [Member]	R B S [Member]	R B S [Member]	Rim Rock [Member]
		USD ($)	USD ($)	San Diego Gas and Electric Company [Member]		USD ($)	USD ($)	GBP (£)	San Diego Gas and Electric Company [Member]
				USD ($)					USD ($)
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value	$57,000,000	$39,000,000	$12,000,000
Payments for Legal Settlements in April 2010, CPUC Proceedings				14,750,000
Claims Payments By Insurers To All Claimants				1,600,000,000
Percentage of Total Claims to be Paid by Company				57.50%
Total Settled Claims				1,300,000,000
Total Remaining Settlement Demands				60,000,000
Loss Contingency Number Of Plaintiffs				6,500	350
Loss Contingency, Number Of Claims				19,000
Liability Insurance Coverage, Maximum				1,100,000,000
Litigation Settlement Amount, Gross, Recovered From Third Parties				824,000,000
Loss Contingency Monetary Damages Sought						56,700,000
Counterclaim For Damages On Contract Termination						215,000,000
Payments For Legal Settlements In Excess Of Recovered Amounts				493,000,000
Regulatory Assets Arising From Wildfire Litigation Costs				372,000,000
Potential After-Tax Charge for Nonrecovery of CPUC Regulatory Assets				217,000,000
Portion of Regulatory Assets Arising From Wildfire Litigation Related To CPUC Operations				367,000,000
Estimated Tax Equity Investment									285,000,000
VAT Tax Claim Paid Upon Appeal								86,000,000
Investment in RBS Sempra Commodities LLP							$71,000,000
Loss Contingency, Number Of Lawsuits					11

COMMITMENTS_AND_CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - NUCLEAR INSURANCE (Details) (San Diego Gas and Electric Company [Member], USD $)	Mar. 31, 2015
San Diego Gas and Electric Company [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 Insurance, Deductible Per Event	$2,500,000

COMMITMENTS_AND_CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS 2 (Details) (USD $)	Mar. 31, 2015
San Diego Gas and Electric Company [Member] | Purchased Power Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	($339,000,000)
Increase (Decrease) In Contractual Commitments, Payments Due, Current	-20,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Two Years	-16,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Three Years	-17,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Four Years	-18,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Five Years	-23,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Thereafter	-245,000,000
San Diego Gas and Electric Company [Member] | Construction and Development Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	-54,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, Current	-95,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Two Years	20,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Three Years	-4,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Four Years	1,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Five Years	24,000,000
Southern California Gas Company [Member] | Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	-43,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, Current	-41,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Thereafter	-2,000,000
Southern California Gas Company [Member] | Construction and Development Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	-62,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, Current	-72,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Two Years	7,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Three Years	3,000,000
Sempra Mexico [Member] | Construction and Development Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	12,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, Current	12,000,000
Sempra Natural Gas [Member] | Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	-69,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, Current	-54,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Two Years	1,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Five Years	-16,000,000
Sempra Natural Gas [Member] | Liquefied Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitments, Payments Due, Current	-138,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Two Years	-83,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Three Years	-93,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Four Years	-109,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Five Years	-109,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, In Thereafter	-937,000,000
Sempra Renewables [Member] | Construction and Development Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Contractual Commitment Amount	26,000,000
Increase (Decrease) In Contractual Commitments, Payments Due, Current	$26,000,000

COMMITMENTS_AND_CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS 4 (Details) (Pio Pico [Member], USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Pio Pico [Member]
Capital Leases [Line Items]
CapitalLeasesFutureMinimumPaymentsDueCurrent	$0
CapitalLeasesFutureMinimumPaymentsDueInTwoYears	0
CapitalLeasesFutureMinimumPaymentsDueInThreeYears	38
CapitalLeasesFutureMinimumPaymentsDueInFourYears	65
CapitalLeasesFutureMinimumPaymentsDueInFiveYears	65
CapitalLeasesFutureMinimumPaymentsDueThereafter	1,460
CapitalLeasesFutureMinimumPaymentsDue	1,628
CapitalLeasesFutureMinimumPaymentsExecutoryCosts	-392
CapitalLeasesFutureMinimumPaymentsInterestIncludedInPayments	-736
CapitalLeasesFutureMinimumPaymentsPresentValueOfNetMinimumPayments	$500

SEGMENT_INFORMATION_Details

SEGMENT INFORMATION (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	$2,682		$2,795
Segment reporting information, Percentage of Total Consolidated Revenues	100.00%		100.00%
Segment reporting information, Interest Expense	134		136
Segment reporting information, Interest Income	7		4
Segment reporting information, Depreciation and Amortization	303		286
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	100.00%		100.00%
Segment reporting information, Income Tax Expense (Benefit)	163		127
Equity Earnings (Losses) Recorded Before Tax	19		17
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax	15		6
Segment reporting information, Earnings (Losses)	437		247
Segment reporting information, Percentage of Consolidated Earnings (Losses)	100.00%		100.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	780		801
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	100.00%		100.00%
Segment reporting information, Assets	39,551				39,732	[1]
Segment reporting information, Percentage of Consolidated Assets	100.00%				100.00%
Segment Reporting Information Investments In Equity Method Investees	2,772				2,848
S D G E Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	966		987
Segment reporting information, Percentage of Total Consolidated Revenues	36.00%		35.00%
Segment reporting information, Interest Expense	52		50
Segment reporting information, Depreciation	145		130
Segment reporting information, Percentage of Consolidated Depreciation	48.00%		45.00%
Segment reporting information, Income Tax Expense (Benefit)	88		83
Segment reporting information, Earnings (Losses)	147		99
Segment reporting information, Percentage of Consolidated Earnings (Losses)	34.00%		40.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	355		294
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	46.00%		37.00%
Segment reporting information, Assets	16,485				16,296
Segment reporting information, Percentage of Consolidated Assets	42.00%				41.00%
Segment Reporting Information, Intersegment Revenues	2		3
So Cal Gas Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	1,048		1,085
Segment reporting information, Percentage of Total Consolidated Revenues	39.00%		39.00%
Segment reporting information, Interest Expense	19		17
Segment reporting information, Depreciation	113		105
Segment reporting information, Percentage of Consolidated Depreciation	37.00%		37.00%
Segment reporting information, Income Tax Expense (Benefit)	95		38
Segment reporting information, Earnings (Losses)	214	[2]	78	[2]
Segment reporting information, Percentage of Consolidated Earnings (Losses)	49.00%		32.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	315		260
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	40.00%		33.00%
Segment reporting information, Assets	10,563				10,461
Segment reporting information, Percentage of Consolidated Assets	27.00%				26.00%
Segment Reporting Information, Intersegment Revenues	19		18
Sempra South American Utilities Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	389		378
Segment reporting information, Percentage of Total Consolidated Revenues	15.00%		14.00%
Segment reporting information, Interest Expense	5		8
Segment reporting information, Interest Income	4		3
Segment reporting information, Depreciation and Amortization	13		14
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	4.00%		5.00%
Segment reporting information, Income Tax Expense (Benefit)	16		15
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax	-1		-2
Segment reporting information, Earnings (Losses)	41		35
Segment reporting information, Percentage of Consolidated Earnings (Losses)	9.00%		14.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	31		32
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	4.00%		4.00%
Segment reporting information, Assets	3,350				3,379
Segment reporting information, Percentage of Consolidated Assets	8.00%				9.00%
Segment Reporting Information Investments In Equity Method Investees	-8				-8
Sempra Mexico Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	163		201
Segment reporting information, Percentage of Total Consolidated Revenues	6.00%		7.00%
Segment reporting information, Interest Expense	5		4
Segment reporting information, Interest Income	2		0
Segment reporting information, Depreciation and Amortization	17		16
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	6.00%		6.00%
Segment reporting information, Income Tax Expense (Benefit)	8		12
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax	16		8
Segment reporting information, Earnings (Losses)	47		42
Segment reporting information, Percentage of Consolidated Earnings (Losses)	11.00%		17.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	55		75
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	7.00%		9.00%
Segment reporting information, Assets	3,502				3,488
Segment reporting information, Percentage of Consolidated Assets	9.00%				9.00%
Segment Reporting Information Investments In Equity Method Investees	439				434
Segment Reporting Information, Intersegment Revenues	25		22
Sempra Renewables Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	8		6
Segment reporting information, Percentage of Total Consolidated Revenues	0.00%		0.00%
Segment reporting information, Interest Expense	1		0
Segment reporting information, Depreciation and Amortization	2		1
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	1.00%		0.00%
Segment reporting information, Income Tax Expense (Benefit)	-17		-6
Equity Earnings (Losses) Recorded Before Tax	2		2
Segment reporting information, Earnings (Losses)	13		28
Segment reporting information, Percentage of Consolidated Earnings (Losses)	3.00%		11.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	3		99
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	1.00%		12.00%
Segment reporting information, Assets	1,277				1,338
Segment reporting information, Percentage of Consolidated Assets	3.00%				3.00%
Segment Reporting Information Investments In Equity Method Investees	859				911
Sempra Natural Gas Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	197		260
Segment reporting information, Percentage of Total Consolidated Revenues	7.00%		9.00%
Segment reporting information, Interest Expense	21		32
Segment reporting information, Interest Income	19		31
Segment reporting information, Depreciation and Amortization	12		17
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	4.00%		6.00%
Segment reporting information, Income Tax Expense (Benefit)	2		6
Equity Earnings (Losses) Recorded Before Tax	17		15
Segment reporting information, Earnings (Losses)	2		9
Segment reporting information, Percentage of Consolidated Earnings (Losses)	0.00%		4.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	10		40
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	1.00%		5.00%
Segment reporting information, Assets	6,032				6,436
Segment reporting information, Percentage of Consolidated Assets	15.00%				16.00%
Segment Reporting Information Investments In Equity Method Investees	1,319				1,347
Segment Reporting Information, Intersegment Revenues	43		79
Intercompany Eliminations Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Interest Expense	-32		-33
Segment reporting information, Interest Income	-18		-30
Intersegment Revenues Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	-89	[3]	-122	[3]
Segment reporting information, Percentage of Total Consolidated Revenues	-3.00%		-4.00%
Intersegment Receivables Segment [Member]
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Assets	-2,618				-2,561
Segment reporting information, Percentage of Consolidated Assets	-6.00%				-6.00%
All Other Segments [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Interest Expense	63		58
Segment reporting information, Depreciation and Amortization	1		3
Segment reporting information, Percentage of Consolidated Depreciation and Amortization	0.00%		1.00%
Segment reporting information, Income Tax Expense (Benefit)	-29		-21
Segment reporting information, Earnings (Losses)	-27		-44
Segment reporting information, Percentage of Consolidated Earnings (Losses)	-6.00%		-18.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment	11		1
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment	1.00%		0.00%
Segment reporting information, Assets	960				895
Segment reporting information, Percentage of Consolidated Assets	2.00%				2.00%
Segment Reporting Information Investments In Equity Method Investees	$163				$164
[1]	Derived from audited financial statements.
[2]	After preferred dividends.
[3]	Revenues for reportable segments include intersegment revenues of $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 and $3 million, $18 million, $22 million and $79 million for the three months ended March 31, 2014 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.