Southern California Gas Company PFD 6% (SOCGM) 10-Q 4 May 16 2016 Q1 Quarterly report Financial data

DOCUMENT AND ENTITY INFORMATION

DOCUMENT AND ENTITY INFORMATION - shares	3 Months Ended
	Mar. 31, 2016	Apr. 28, 2016
Document And Entity Information [Abstract]
Entity Registrant Name	Sempra Energy
Document Type	10-Q
Document Period End Date	Mar. 31, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Shares Outstanding		249,496,738
Entity Central Index Key	1,032,208
Trading Symbol	SRE

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)		Mar. 31, 2016	Dec. 31, 2015	[1]
Current assets:
Cash and cash equivalents		$ 376,000,000	$ 403,000,000
Restricted cash		23,000,000	27,000,000
Trade accounts receivable		1,100,000,000	1,283,000,000
Other accounts and notes receivable		177,000,000	190,000,000
Due from unconsolidated affiliates		7,000,000	6,000,000
Income taxes receivable		49,000,000	30,000,000
Inventories		231,000,000	298,000,000
Regulatory balancing accounts, undercollected		256,000,000	307,000,000
Fixed-price contracts and other derivatives, current assets		88,000,000	80,000,000
Assets held for sale, power plant		303,000,000	0
Other current assets		273,000,000	267,000,000
Total current assets		2,883,000,000	2,891,000,000
Other assets:
Restricted cash, noncurrent		20,000,000	20,000,000
Due from unconsolidated affiliate		186,000,000	186,000,000
Other regulatory assets		3,336,000,000	3,273,000,000
Nuclear decommissioning trusts		1,082,000,000	1,063,000,000
Other investments		2,727,000,000	2,905,000,000
Goodwill		849,000,000	819,000,000
Other intangible assets		402,000,000	404,000,000
Dedicated assets in support of certain benefit plans		432,000,000	464,000,000
Insurance receivable for Aliso Canyon costs		660,000,000	325,000,000
Sundry		825,000,000	761,000,000
Total other assets		10,519,000,000	10,220,000,000
Property, plant and equipment:
Property, plant and equipment		38,541,000,000	38,200,000,000
Less accumulated depreciation and amortization		(10,108,000,000)	(10,161,000,000)
Property, plant and equipment, net		28,433,000,000	28,039,000,000
Total assets		41,835,000,000	41,150,000,000
Current liabilities:
Short-term debt		1,177,000,000	622,000,000
Accounts payable - trade		1,028,000,000	1,133,000,000
Accounts payable - other		129,000,000	142,000,000
Due to unconsolidated affiliates		13,000,000	14,000,000
Dividends and interest payable		360,000,000	303,000,000
Accrued compensation and benefits		259,000,000	423,000,000
Regulatory balancing accounts, overcollected		45,000,000	34,000,000
Current portion of long-term debt		1,066,000,000	907,000,000
Fixed-price contracts and other derivatives, current liabilities		57,000,000	56,000,000
Customer deposits		147,000,000	153,000,000
Reserve for Aliso Canyon costs		302,000,000	274,000,000
Other current liabilities		549,000,000	551,000,000
Total current liabilities		5,132,000,000	4,612,000,000
Long-term debt		12,975,000,000	13,134,000,000
Deferred Credits And Other Liabilities [Abstract]
Customer advances for construction		148,000,000	149,000,000
Pension and other postretirement benefit obligations, net of plan assets		1,165,000,000	1,152,000,000
Deferred income taxes, net noncurrent liabilities		3,222,000,000	3,157,000,000
Deferred investment tax credits		32,000,000	32,000,000
Regulatory liabilities arising from removal obligations		2,850,000,000	2,793,000,000
Asset retirement obligations		2,151,000,000	2,126,000,000
Fixed-price contracts and other derivatives, noncurrent liabilities		248,000,000	240,000,000
Deferred credits and other		1,188,000,000	1,176,000,000
Total deferred credits and other liabilities		11,004,000,000	10,825,000,000
Equity:
Preferred stock		0	0
Common stock		2,642,000,000	2,621,000,000
Retained earnings		10,125,000,000	9,994,000,000
Accumulated other comprehensive income (loss)	[2]	(821,000,000)	(806,000,000)
Total shareholders' equity		11,946,000,000	11,809,000,000
Preferred stock of subsidiaries		20,000,000	20,000,000
Other noncontrolling interests		758,000,000	750,000,000
Total equity		12,724,000,000	12,579,000,000
Total liabilities and equity		41,835,000,000	41,150,000,000
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents		36,000,000	20,000,000
Restricted cash		21,000,000	23,000,000
Trade accounts receivable		300,000,000	331,000,000
Other accounts and notes receivable		18,000,000	17,000,000
Due from unconsolidated affiliates		1,000,000	1,000,000
Inventories		72,000,000	75,000,000
Regulatory balancing accounts, undercollected		256,000,000	307,000,000
Other regulatory assets		119,000,000	107,000,000
Fixed-price contracts and other derivatives, current assets		50,000,000	53,000,000
Other current assets		64,000,000	70,000,000
Total current assets		937,000,000	1,004,000,000
Other assets:
Restricted cash, noncurrent		2,000,000	0
Deferred taxes recoverable in rates		921,000,000	914,000,000
Other regulatory assets		968,000,000	977,000,000
Nuclear decommissioning trusts		1,082,000,000	1,063,000,000
Sundry		331,000,000	301,000,000
Total other assets		3,304,000,000	3,255,000,000
Property, plant and equipment:
Property, plant and equipment		16,668,000,000	16,458,000,000
Less accumulated depreciation and amortization		(4,284,000,000)	(4,202,000,000)
Property, plant and equipment, net		12,384,000,000	12,256,000,000
Total assets		16,625,000,000	16,515,000,000
Current liabilities:
Short-term debt		166,000,000	168,000,000
Accounts payable - trade		295,000,000	377,000,000
Due to unconsolidated affiliates		49,000,000	55,000,000
Income taxes payable		59,000,000	0
Accrued compensation and benefits		67,000,000	129,000,000
Accrued Franchise Fees		46,000,000	66,000,000
Current portion of long-term debt		191,000,000	50,000,000
Fixed-price contracts and other derivatives, current liabilities		53,000,000	51,000,000
Customer deposits		71,000,000	72,000,000
Interest payable		39,000,000	39,000,000
Asset Retirement Obligation Current		63,000,000	99,000,000
Other current liabilities		130,000,000	101,000,000
Total current liabilities		1,229,000,000	1,207,000,000
Long-term debt		4,294,000,000	4,455,000,000
Deferred Credits And Other Liabilities [Abstract]
Customer advances for construction		44,000,000	46,000,000
Pension and other postretirement benefit obligations, net of plan assets		216,000,000	212,000,000
Deferred income taxes, net noncurrent liabilities		2,497,000,000	2,472,000,000
Deferred investment tax credits		20,000,000	19,000,000
Regulatory liabilities arising from removal obligations		1,692,000,000	1,629,000,000
Asset retirement obligations		745,000,000	729,000,000
Fixed-price contracts and other derivatives, noncurrent liabilities		107,000,000	106,000,000
Deferred credits and other		378,000,000	364,000,000
Total deferred credits and other liabilities		5,699,000,000	5,577,000,000
Equity:
Common stock		1,338,000,000	1,338,000,000
Retained earnings		4,022,000,000	3,893,000,000
Accumulated other comprehensive income (loss)		(8,000,000)	(8,000,000)
Total shareholders' equity		5,352,000,000	5,223,000,000
Other noncontrolling interests		51,000,000	53,000,000
Total equity		5,403,000,000	5,276,000,000
Total liabilities and equity		16,625,000,000	16,515,000,000
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents		14,000,000	58,000,000
Trade accounts receivable		445,000,000	635,000,000
Other accounts and notes receivable		99,000,000	99,000,000
Due from unconsolidated affiliates		8,000,000	48,000,000
Inventories		33,000,000	79,000,000
Other regulatory assets		8,000,000	7,000,000
Other current assets		44,000,000	40,000,000
Total current assets		651,000,000	966,000,000
Other assets:
Regulatory assets arising from pension and other postretirement benefit obligations		715,000,000	699,000,000
Other regulatory assets		686,000,000	636,000,000
Insurance receivable for Aliso Canyon costs		660,000,000	325,000,000
Sundry		252,000,000	207,000,000
Total other assets		2,313,000,000	1,867,000,000
Property, plant and equipment:
Property, plant and equipment		14,359,000,000	14,171,000,000
Less accumulated depreciation and amortization		(4,896,000,000)	(4,900,000,000)
Property, plant and equipment, net		9,463,000,000	9,271,000,000
Total assets		12,427,000,000	12,104,000,000
Current liabilities:
Short-term debt		5,000,000	0
Accounts payable - trade		351,000,000	422,000,000
Accounts payable - other		77,000,000	76,000,000
Due to unconsolidated affiliates		34,000,000	0
Income taxes payable		27,000,000	3,000,000
Accrued compensation and benefits		110,000,000	160,000,000
Regulatory balancing accounts, overcollected		45,000,000	34,000,000
Current portion of long-term debt		9,000,000	9,000,000
Customer deposits		70,000,000	76,000,000
Reserve for Aliso Canyon costs		302,000,000	274,000,000
Other current liabilities		193,000,000	184,000,000
Total current liabilities		1,223,000,000	1,238,000,000
Long-term debt		2,481,000,000	2,481,000,000
Deferred Credits And Other Liabilities [Abstract]
Customer advances for construction		104,000,000	103,000,000
Pension and other postretirement benefit obligations, net of plan assets		733,000,000	716,000,000
Deferred income taxes, net noncurrent liabilities		1,643,000,000	1,532,000,000
Deferred investment tax credits		13,000,000	14,000,000
Regulatory liabilities arising from removal obligations		1,139,000,000	1,145,000,000
Asset retirement obligations		1,367,000,000	1,354,000,000
Deferred credits and other		380,000,000	372,000,000
Total deferred credits and other liabilities		5,379,000,000	5,236,000,000
Equity:
Preferred stock		22,000,000	22,000,000
Common stock		866,000,000	866,000,000
Retained earnings		2,475,000,000	2,280,000,000
Accumulated other comprehensive income (loss)		(19,000,000)	(19,000,000)
Total shareholders' equity		3,344,000,000	3,149,000,000
Total equity		3,344,000,000	3,149,000,000
Total liabilities and equity		$ 12,427,000,000	$ 12,104,000,000
[1]	Derived from audited financial statements.
[2]	All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.

CONDENSED CONSOLIDATED BALANCE3

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) shares in Millions, $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Property, plant and equipment, net	$ 28,433	$ 28,039	[1]
Long-term debt	$ 12,975	$ 13,134	[1]
Shareholders' equity:
Preferred stock, shares authorized	50	50
Preferred stock, shares issued	0	0
Common stock, shares authorized	750	750
Common stock, shares outstanding	249	248
Otay Mesa VIE [Member]
Property, plant and equipment, net	$ 376	$ 383
Long-term debt	300	303
San Diego Gas and Electric Company [Member]
Property, plant and equipment, net	12,384	12,256	[1]
Long-term debt	$ 4,294	$ 4,455	[1]
Shareholders' equity:
Common stock, shares authorized	255	255
Common stock, shares outstanding	117	117
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Property, plant and equipment, net	$ 376	$ 383
Long-term debt	300	303
Southern California Gas Company [Member]
Property, plant and equipment, net	9,463	9,271	[1]
Long-term debt	$ 2,481	$ 2,481	[1]
Shareholders' equity:
Common stock, shares authorized	100	100
Common stock, shares outstanding	91	91
[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
REVENUES
Utilities		$ 2,442	$ 2,422
Energy-related businesses		180	260
Total revenues		2,622	2,682
Utilities [Abstract]
Cost of natural gas		(311)	(346)
Cost of electric fuel and purchased power		(515)	(481)
Energy-related businesses [Abstract]
Cost of natural gas, electric fuel and purchased power		(56)	(98)
Other cost of sales		(35)	(35)
Operation and maintenance		(701)	(658)
Depreciation and amortization		(328)	(303)
Plant closure adjustment (loss)		0	21
Franchise fees and other taxes		(111)	(107)
Equity Earnings Losses Before Income Tax [Abstract]
Equity (losses) earnings, before income tax		(22)	19
Other income (expense), net		49	39
Interest income		6	7
Interest expense		(143)	(134)
Income (loss) before income taxes and equity earnings of certain unconsolidated subsidiaries		455	606
Income tax (expense) benefit		(142)	(163)
Equity earnings, net of income tax		17	15
Net income (loss)		330	458
Losses (earnings) attributable to noncontrolling interests		(11)	(21)
Earnings (losses)		$ 319	$ 437
Basic earnings per common share:
Basic earnings per common share		$ 1.28	$ 1.76
Basic earnings per common share, weighted-average number of shares outstanding (thousands)	[1]	249,734	247,722
Diluted earnings per common share:
Diluted earnings per common share		$ 1.27	$ 1.74
Diluted earnings per common share, weighted-average number of shares outstanding (thousands)		251,412	251,206
Dividends declared per share of common stock		$ 0.76	$ 0.7
San Diego Gas and Electric Company [Member]
Utility operating revenues
Electric		$ 843	$ 805
Natural gas		148	161
Total utility operating revenues		991	966
Utility operating expenses
Utility cost of electric fuel and purchased power		248	228
Utility cost of natural gas		39	54
Utility operation and maintenance		246	217
Utility depreciation and amortization		159	145
Utility franchise fees and other taxes		63	61
Utility plant closure (adjustment) loss		0	(21)
Total utility operating expenses		755	684
Utility operating income (loss)		236	282
Equity Earnings Losses Before Income Tax [Abstract]
Other income (expense), net		14	9
Interest expense		(48)	(52)
Income (loss) before income taxes and equity earnings of certain unconsolidated subsidiaries		202	239
Income tax (expense) benefit		(72)	(88)
Net income (loss)		130	151
Losses (earnings) attributable to noncontrolling interests		(1)	(4)
Earnings (losses)		129	147
Southern California Gas Company [Member]
Utility operating revenues
Total utility operating revenues		1,033	1,048
Utility operating expenses
Utility cost of natural gas		253	267
Utility operation and maintenance		327	314
Utility depreciation and amortization		122	113
Utility franchise fees and other taxes		37	34
Total utility operating expenses		739	728
Utility operating income (loss)		294	320
Equity Earnings Losses Before Income Tax [Abstract]
Other income (expense), net		10	8
Interest expense		(22)	(19)
Income (loss) before income taxes and equity earnings of certain unconsolidated subsidiaries		282	309
Income tax (expense) benefit		(87)	(95)
Net income (loss)		195	214
Earnings (losses)		$ 195	$ 214
[1]	Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

CONDENSED CONSOLIDATED STATEME5

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Net income	$ 330,000,000	$ 458,000,000
Before-Tax Amount [Member]
Net income	461,000,000	600,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	68,000,000	(62,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	2,000,000	2,000,000
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(159,000,000)	(89,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(89,000,000)	(149,000,000)
Total Comprehensive Income	372,000,000	451,000,000
Income Tax (Expense) Benefit [Member]
Net income	(142,000,000)	(163,000,000)
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	(1,000,000)	(1,000,000)
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	75,000,000	34,000,000
Other Comprehensive Income (Loss), Net of Tax, Total	74,000,000	33,000,000
Total Comprehensive Income	(68,000,000)	(130,000,000)
Net-of-Tax Amount [Member]
Net income	319,000,000	437,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	68,000,000	(62,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1,000,000	1,000,000
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(84,000,000)	(55,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(15,000,000)	(116,000,000)
Total Comprehensive Income	304,000,000	321,000,000
Noncontrolling Interests [Member]
Net income	11,000,000	21,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	5,000,000	(8,000,000)
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	(5,000,000)	(5,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	0	(13,000,000)
Total Comprehensive Income	11,000,000	8,000,000
Total Equity [Member]
Net income	330,000,000	458,000,000
Comprehensive income, net of income tax
Foreign currency translation adjustments	73,000,000	(70,000,000)
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net of Tax	1,000,000	1,000,000
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(89,000,000)	(60,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(15,000,000)	(129,000,000)
Total Comprehensive Income	315,000,000	329,000,000
San Diego Gas and Electric Company [Member]
Net income	130,000,000	151,000,000
San Diego Gas and Electric Company [Member] | Before-Tax Amount [Member]
Net income	201,000,000	235,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Total Comprehensive Income	201,000,000	235,000,000
San Diego Gas and Electric Company [Member] | Income Tax (Expense) Benefit [Member]
Net income	(72,000,000)	(88,000,000)
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Total Comprehensive Income	(72,000,000)	(88,000,000)
San Diego Gas and Electric Company [Member] | Net-of-Tax Amount [Member]
Net income	129,000,000	147,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	0	0
Other Comprehensive Income (Loss), Net of Tax, Total	0	0
Total Comprehensive Income	129,000,000	147,000,000
San Diego Gas and Electric Company [Member] | Noncontrolling Interests [Member]
Net income	1,000,000	4,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(2,000,000)	(2,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(2,000,000)	(2,000,000)
Total Comprehensive Income	(1,000,000)	2,000,000
San Diego Gas and Electric Company [Member] | Total Equity [Member]
Net income	130,000,000	151,000,000
Comprehensive income, net of income tax
Other Comprehensive Income (Loss), Derivatives Qualifying As Hedges, Net of Tax	(2,000,000)	(2,000,000)
Other Comprehensive Income (Loss), Net of Tax, Total	(2,000,000)	(2,000,000)
Total Comprehensive Income	128,000,000	149,000,000
Southern California Gas Company [Member]
Net income	195,000,000	214,000,000
Southern California Gas Company [Member] | Before-Tax Amount [Member]
Net income	282,000,000	309,000,000
Comprehensive income, net of income tax
Total Comprehensive Income	282,000,000	309,000,000
Southern California Gas Company [Member] | Income Tax (Expense) Benefit [Member]
Net income	(87,000,000)	(95,000,000)
Comprehensive income, net of income tax
Total Comprehensive Income	(87,000,000)	(95,000,000)
Southern California Gas Company [Member] | Net-of-Tax Amount [Member]
Net income	195,000,000	214,000,000
Comprehensive income, net of income tax
Total Comprehensive Income	$ 195,000,000	$ 214,000,000

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016		Mar. 31, 2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 330		$ 458
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	328		303
Deferred income taxes and investment tax credits	112		131
Plant closure (adjustment) loss	0		(21)
Equity earnings	5		(34)
Fixed-price contracts and other derivatives	4		11
Other	2		(27)
Net change in other working capital components	165		19
Insurance Receivable For Aliso Canyon Costs	(335)		0
Changes in other assets	(29)		(42)
Changes in other liabilities	10		13
Net cash provided by operating activities	592		811
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(971)		(780)
Expenditures for investments	(30)		(34)
Distributions from investments	9		1
Purchases of nuclear decommissioning and other trust assets	(94)		(95)
Proceeds from sales by nuclear decommissioning and other trusts	93		94
Decrease in restricted cash	20		25
Increase in restricted cash	(16)		(18)
Advances to unconsolidated affiliates	(6)		(5)
Proceeds From Payments For Long Term Loans For Related Parties	9		33
Other cash flows from investing activities	(3)		9
Net cash used in investing activities	(989)		(770)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(161)		(149)
Proceeds from issuances of common stock	15		17
Repurchases of common stock	(54)		(65)
Issuances of long-term debt	55		938
Payments on long-term debt	(54)		(654)
Increase (decrease) in short-term debt, net	531		(363)
Excess Tax Benefit From Share Based Compensation Financing Activities	34		52
Other cash flows from financing activities	(2)		(7)
Net cash provided by (used in) financing activities	364		(231)
Effect of exchange rate changes on cash and cash equivalents	6		(3)
Increase (decrease) in cash and cash equivalents	(27)		(193)
Cash and cash equivalents, beginning of period	403	[1]	570
Cash and cash equivalents, end of period	376		377
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	97		83
Income tax payments, net of refunds	41		42
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	423		272
Financing of build-to-suit property	0		27
Common dividends issued in stock	13		13
Dividends declared but not paid	197		181
Acquisition Of Business [Abstract]
Assets acquired	0		10
Liabilities Assumed	0		(2)
Accrued purchase price	0		(6)
Cash paid	0		2
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	130		151
Adjustments to reconcile net income to net cash provided by operating activities:
Utility depreciation and amortization	159		145
Deferred income taxes and investment tax credits	20		56
Utility plant closure (adjustment) loss	0		(21)
Fixed-price contracts and other derivatives	(1)		(1)
Other	(9)		(1)
Net change in other working capital components	103		7
Changes in other assets	(34)		(48)
Changes in other liabilities	1		11
Net cash provided by operating activities	369		299
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(329)		(355)
Purchases of nuclear decommissioning trust assets	(93)		(94)
Proceeds from sales by nuclear decommissioning trusts	93		94
Decrease in restricted cash	10		10
Increase in restricted cash	(10)		(10)
Other cash flows from investing activities	(1)		0
Increase (Decrease) in loans to affiliates, net	0		(66)
Net cash used in investing activities	(330)		(421)
CASH FLOWS FROM FINANCING ACTIVITIES
Issuances of long-term debt	0		388
Payments on long-term debt	(20)		(3)
Increase (decrease) in short-term debt, net	(2)		(246)
Distributions to noncontrolling interests	(1)		(2)
Net cash provided by (used in) financing activities	(23)		137
Increase (decrease) in cash and cash equivalents	16		15
Cash and cash equivalents, beginning of period	20	[1]	8
Cash and cash equivalents, end of period	36		23
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	46		39
Income tax payments, net of refunds	(8)		31
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	104		103
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	195		214
Adjustments to reconcile net income to net cash provided by operating activities:
Utility depreciation and amortization	122		113
Deferred income taxes and investment tax credits	59		(9)
Other	(7)		(6)
Net change in other working capital components	243		85
Insurance Receivable For Aliso Canyon Costs	(335)		0
Changes in other assets	(37)		(19)
Changes in other liabilities	1		(3)
Net cash provided by operating activities	241		375
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(340)		(315)
Increase (Decrease) in loans to affiliates, net	50		(74)
Net cash used in investing activities	(290)		(389)
CASH FLOWS FROM FINANCING ACTIVITIES
Increase (decrease) in short-term debt, net	5		(50)
Net cash provided by (used in) financing activities	5		(50)
Increase (decrease) in cash and cash equivalents	(44)		(64)
Cash and cash equivalents, beginning of period	58	[1]	85
Cash and cash equivalents, end of period	14		21
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	17		17
Income tax payments, net of refunds	3		(3)
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	$ 148		$ 129
[1]	Derived from audited financial statements.

GENERAL

GENERAL	3 Months Ended
	Mar. 31, 2016
Organization Consolidation And Presentation Of Financial Statements [Abstract]
General	SEMPRA ENERGY AND SUBSIDIARIES NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS NOTE 1. GENERAL 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 Southern California Gas Company ( SoCalGas ) , wh ich 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 segme nts. 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 Glo bal 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 r efer 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 activit y. 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, 2015 (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 Notes 3, 4 and 10 of 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 N ote 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 minimi s 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 perio ds are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after March 31, 2016 through the date the financial statements were issued and , in the opinion of management, the accompanying statements r eflect all adjustments necessary for a fair presentation. These adjustments are only of a normal, recurring nature. All December 31, 2015 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2015 C onsolidated 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 p rovisions 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 reportin g purposes. 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, Chilquinta E nerg í a S.A. ( Chilquinta Energ í a ) in Chile and Luz del Sur S.A.A. (Luz del Sur) in Peru, and their subsidiaries. Sempra Natural Gas owns Mobile Gas Service Corporation (Mobile Gas) in southwest Alabama and Willmut Gas Company ( Willmut Gas) in Mississippi, an d Sempra Mexico owns Ecogas México, S. de R.L. de C.V. ( Ecogas ) in northern Mexico, all natural gas distribution utilities. The California Utilities, Mobile Gas, Willmut Gas, and Ecogas prepare their financial statements in accordance with U.S. GAAP provis ions governing rate-regulated operations, as we discuss in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report . Pipeline projects currently under constructi on by IEnova that are both regulated by the Comisión Reguladora de Energí a (or CRE, the Energy Regulatory Commission ) and meet the regulatory accounting requirements of U.S. GAAP record the impact of allowance for funds used during construction (AFUDC) related to equity. We discuss AFUDC in Note 5 below and in Note 1 of the Not es to Consolidated Financial Statements in the Annual Report.

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	3 Months Ended
	Mar. 31, 2016
Significant Accounting Policies
New Accounting Standards	N OTE 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 2015-14, “Revenue from Contracts with Customers: Deferral of the Effective Date,” ASU 2016-08, “Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” and ASU 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Lice nsing”: ASU 2014-09 provides accounting guidance for revenue 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 recogn ition 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 m odified retrospective approach. Amending ASU 2014-09, ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations and ASU 2016-10 clarifies the determination of whether a good or service is separately identifiable from other promises and revenue recognition related to licenses of intellectual property. ASU 2015-14 defers the effective date of ASU 2014-09 by one year for all entities and permits early adoption on a limited basis. For public entities, ASU 2014-09 is effective fo r fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We are currently evaluating the effect of the standards on our ongoing financial reporting and have not yet selected the year in which we will adopt the standards or our transition method . ASU 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities”: In addition to the presentation and dis closure requirements for financial instruments, ASU 2016-01 requires entities to measure equity investments not accounted for under the equity method at fair value and recognize changes in fair value in net income. Entities will no longer be able to use th e cost method of accounting for equity securities. However, for equity investments without readily determinable fair values, entities may elect a measurement alternative that will allow those investments to be recorded at cost, less impairment, and adjuste d for subsequent observable price changes. Upon adoption, entities must record a cumulative-effect adjustment to the balance sheet as of the beginning of the first reporting period in which the standard is adopted. The guidance on equity securities without readily determinable fair value will be applied prospectively to all equity investments that exist as of the date of adoption of the standard. For public entities, ASU 2016-01 is effective for fiscal years beginning after December 15, 2017. We will adopt ASU 2016-01 on January 1, 2018 as required and do not expect it to materially affect our financial condition, results of operations or cash flows. We will make the required changes to our disclosures upon adoption. ASU 2016-02, “Leases”: ASU 2016-02 requi res entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to exclude from the balance sheet those leases with a maximum possible term o f less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP , other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public e ntities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes optional practical expedients that may be elected, which would allow entities to continue to account for leases that commen ce before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting, and have not yet selected the year in which we will adopt the standard . ASU 2016-05, “Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships”: ASU 2016-05 provides clarification that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge ac counting criteria continue to be met. ASU 2016-05 may be adopted prospectively or using a modified retrospective approach. We prospectively adopted ASU 2016-05 on January 1, 2016 and it did not affect our financial condition, results of operations or cash flows. ASU 2016-09 , “ Improvements to Employee Share-Based Payment Accounting” : ASU 2016-09 is intended to simplify several aspects of the accounting for employee share-based payment transactions . Under ASU 2016-09, excess tax benefits and tax deficiencies are required to be recorded in earnings, and the requirement to reclassify excess tax benefits from operating to financing activities on the statement of cash flows has been eliminated. ASU 2016-09 also allows entities to withhold taxes up to the maximum i ndividual statutory tax rate without resulting in liability classification of the award and clarifies that cash payments made to taxi ng authorities in connection with withheld shares should be classified as financing activities in the statement of cash flo ws. Additionally, the standard provides for an accounting policy election to either continue to estimate forfeitures or account for them as they occur. For public entities, ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, with e arly adoption permitted, and is effective for interim periods in the year of adoption. We are currently evaluating the full effect of the standard on our ongoing financial reporting, and have not yet concluded as to whether we will elect an early adoption. If we early adopt in 2016, we will recognize a $34 million tax benefit in earnings, which is currently recorded in Shareholders’ Equity, related to the three months ended March 31, 2016, and a benefit to retained earnings as of January 1, 2016 of approximately $10 7 million, both associated with the provision in ASU 2016-09 to recognize all excess tax benefits related to share-based compensation.

RECENT INVESTMENT ACTIVITY

RECENT INVESTMENT ACTIVITY	3 Months Ended
	Mar. 31, 2016
Investments [Abstract]
Recent Investment Activity	NOTE 3. ACQUISITION AND DIVESTITURE ACTIVITY We consolidate assets and liabilities acquired as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date. Acquisition Sempra Renewables In March 2015, Sempra Renewables invested $8 million to acquire a 100-percent interest in the Black Oak Getty Wind project, a 78-megawatt (MW) wind farm under development in Stearns County, Minnesota. The wind farm has a 20-year power purchase agreement with Minnesota Mu nicipal Power Agency that will commence upon commercial operation in late 2016. POTENTIAL ACQUISITION Sempra Mexico IEnova and Petróleos Mexicanos (or PEMEX, the Mexican state-owned oil company) are 50-50 partners in the joint venture Gasoductos de Chihua hua ( GdC ). GdC develops and operates energy infrastructure in Mexico. On July 31, 2015, IEnova entered into an agreement to purchase PEMEX’s 50-percent interest for $1.325 billion (excluding the assumption of approximately $170 million of net debt), which upon closing would increase its interest from 50 percent to 100 percent. The assets involved in the acquisition included three natural gas pipelines, an ethane pipeline, and a liquid petroleum gas pipeline and associated storage terminal. The transaction e xcluded the Los Ramones Norte pipeline that is owned under a separate joint venture with GdC , PEMEX, BlackRock and First Reserve, keeping IEnova’s interest in the pipeline at the current 25 percent. In December 2015, Mexico’s Comisión Federal de Competenc ia Económica (COFECE or Mexican Competition Commission) objected to the transaction based upon previous antitrust rulings on PEMEX’s indirect ownership of two of the assets, the TDF S. de R.L. de C.V. liquid petroleum gas pipeline and the San Fernando natu ral gas pipeline, included in the acquisition as proposed. COFECE specified that these assets must be offered by PEMEX in a competitive bidding process as a prerequisite for approval of any transaction involving these two assets. COFECE’s decision did not object to IEnova’s acquisition of the assets on a market concentration basis. The parties are in the process of restructuring the transaction so that PEMEX can proceed with a bidding process on these two assets in accordance with the COFECE ruling. IEnova will have the right to approve the winning bidder as a new partner. Any restructured transaction will require negotiation of satisfactory terms for the revised transaction, and will also be subject to IEnova and PEMEX board approvals and satisfactory compl etion of the Mexican antitrust review, and may require further approvals from Mexican authorities. ASSETS HELD FOR SALE, POWER PLANT Sempra Mexico ASSETS HELD FOR SALE, POWER PLANT (Dollars in millions) March 31, 2016 Cash and cash equivalents $ 1 Inventories 8 Other current assets 29 Other assets 15 Property, plant and equipment, net 250 Total assets held for sale $ 303 Accounts payable $ 1 Other current liabilities 7 Deferred income taxes 16 Asset retirement obligations 4 Other liabilities 15 Total liabilities held for sale(1) $ 43 (1) Included in Other Current Liabilities on the Sempra Energy Condensed Consolidated Balance Sheet. We considered the estimated fair value of the p lant, less costs to sell, and determined that no adjustment to carrying value was required. In estimating fair value, we used both a market approach and discounted cash flow valuation techniques. In the event that the estimated sales price, less transaction costs, is less than the carrying value, or updated market information indicates fair value may be less than carrying value, we would recognize a loss in our results of operations at that time. We expect to c omplete the sale in the second half of 2016. PENDING DIVESTITURE Sempra Natural Gas On March 29, 2016, Sempra Natural Gas entered into an agreement to sell its 25-percent interest in Rockies Express Pipeline LLC (Rockies Express) to a subsidiary of Tallg rass Development, LP for cash consideration of approximately $440 million, subject to adjustment at closing. The transaction is subject to customary closing conditions. Sempra Natural Gas expects the transaction to close in the second quarter of 2016. At t he date of the agreement, the carrying value of Sempra Natural Gas’ investment in Rockies Express was $484 million. Sempra Natural Gas measured the fair value of its equity method investment at $440 million, and recognized a $44 million ($27 million after- tax) impairment in Equity (Losses) Earnings, Before Income Tax, on the Sempra Energy Condensed Consolidated Statement of Operations for the three months ended March 31, 2016. We discuss non-recurring fair value measures and the associated accounting impact on our investment in Rockies Express in Note 8.

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	3 Months Ended
	Mar. 31, 2016
Investments [Abstract]
Investments in Unconsolidated Entities	NOTE 4. INVESTMENTS IN UNCONSOLIDATED ENTITIES We provide additional information concerning our equity method investments above in Note 3 above and in Notes 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. SEMPRA RENEWABLES Sempra Renewables invested cash of $15 million and $17 million in its joint ventures during the three months ended March 31, 2016 and 2015, respectively. SEMPRA NATURAL GAS Sempra Natural Gas capitalized $12 million of interest during both the three months ended March 31, 2016 and 2015 and invested cash of $3 million during the three months ended March 31, 2015 at Cameron LNG Holdings, LLC (Cameron LNG JV). In March 2016, Sempra Natural Gas entered into an agreement to sell its 25-percent interest in Rockies Exp ress, which we discuss in Note 3. GUARANTEES We discuss guarantees that we have provided, which have a maximum aggregate amount of $4.5 billion, in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. These guarantees have an aggr egate carrying value of $67 million at March 31, 2016.

OTHER FINANCIAL DATA

OTHER FINANCIAL DATA	3 Months Ended
	Mar. 31, 2016
Disclosure Text Block [Abstract]
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 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 SDG&E $ 3 $ 6 $ ― $ ― $ 69 $ 69 $ 72 $ 75 SoCalGas(1) ― 49 ― ― 33 30 33 79 Sempra South American Utilities ― ― ― ― 37 30 37 30 Sempra Mexico ― ― 6 3 2 10 8 13 Sempra Renewables ― ― ― ― 3 3 3 3 Sempra Natural Gas 74 94 3 3 1 1 78 98 Sempra Energy Consolidated $ 77 $ 149 $ 9 $ 6 $ 145 $ 143 $ 231 $ 298 (1) At both March 31, 2016 and December 31, 2015, SoCalGas' natural gas inventory for core customers is net of the estimated inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11. GOODWILL We discuss goodwill in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. The increase in goodwill from $819 million at December 31, 2015 to $849 million at March 31, 2016 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 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 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. Tolling Agreements SDG&E has agreements under which it purchases power generated by facilities for which it sup plies 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 thes e 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 faci lity for a substantial portion of the facility’s useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which we co nsider 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 beneficiar y, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE. 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 OMEC 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 e xercise 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 porti on 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 $51 million at March 31, 2016 and $53 million at December 31, 2015 is included on the Condensed Co nsolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E. OMEC LLC has a loan outstanding of $312 million at March 31, 2016, the proceeds of which were used for the construction of OMEC. The lo an 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 20 19 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 . 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 captions in the table be low 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, 2016 2015 Operating expenses Cost of electric fuel and purchased power $ (17) $ (18) Operation and maintenance 4 4 Depreciation and amortization 7 6 Total operating expenses (6) (8) Operating income 6 8 Interest expense (5) (4) Income before income taxes/Net income 1 4 Earnings attributable to noncontrolling interest (1) (4) Earnings attributable to common shares $ ― $ ― 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, 2016. 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 substanti al, 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 consolid ation 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 s uch variability would be recovered in rates. We provide additional information about power purchase agreements with peaker plant facilities that are VIEs of which SDG&E is not the primary beneficiary in Note 15 of the Notes to Consolidated Financial Statem ents in the Annual Report. We provide additional information regarding Otay Mesa VIE in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Sempra Natural Gas Sempra Energy’s equity method investment in Cameron LNG JV is consider ed 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, including amounts recognized in Accumulated Other Comprehensive Income (Loss) (AOCI), was $872 mill ion at March 31, 2016 and $983 million at December 31, 2015. Our maximum exposure to loss includes the carrying value of our investment and the guarantees discussed above in Note 4 and in Note 4 of the Notes to Consolidated Financial Statem ents in the Annu al Report. Other Variable Interest Entities 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 analys es described above. Certain of these entities are service companies that are VIEs. As the primary beneficiary of these service companies, we consolidate them; however, their financial statements are not material to the financial statements of Sempra Energy . 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. 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, 2016 2015 2016 2015 Service cost $ 28 $ 30 $ 5 $ 7 Interest cost 40 39 11 12 Expected return on assets (42) (44) (17) (17) Amortization of: Prior service cost (credit) 3 3 ― (1) Actuarial loss 6 8 ― ― Regulatory adjustment (28) (29) 2 ― Total net periodic benefit cost $ 7 $ 7 $ 1 $ 1 NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension benefits Other postretirement benefits Three months ended March 31, 2016 2015 2016 2015 Service cost $ 7 $ 8 $ 1 $ 2 Interest cost 10 10 2 2 Expected return on assets (12) (14) (3) (3) Amortization of: Prior service cost ― ― 1 1 Actuarial loss 3 2 ― ― Regulatory adjustment (7) (5) (1) (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, 2016 2015 2016 2015 Service cost $ 17 $ 19 $ 4 $ 5 Interest cost 25 25 8 9 Expected return on assets (25) (27) (14) (14) Amortization of: Prior service cost (credit) 2 2 (1) (2) Actuarial loss 3 5 ― ― Regulatory adjustment (21) (24) 3 2 Total net periodic benefit cost $ 1 $ ― $ ― $ ― Benefit Plan Contributions The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts w e expect to contribute in 20 16 : BENEFIT PLAN CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Contributions through March 31, 2016: Pension plans $ 15 $ 2 $ ― Other postretirement benefit plans 1 ― ― Total expected contributions in 2016: Pension plans $ 123 $ 4 $ 77 Other postretirement benefit plans 6 2 1 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 $432 million and $464 million at March 31, 2016 and December 31, 2015, respectively. EARNINGS PER SHARE The following table provides earnings per share (EPS) computations for the three months ended March 31, 2016 and 2015. Basic 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, 2016 2015 Numerator: Earnings/Income attributable to common shares $ 319 $ 437 Denominator: Weighted-average common shares outstanding for basic EPS(1) 249,734 247,722 Dilutive effect of stock options, restricted stock awards and restricted stock units 1,678 3,484 Weighted-average common shares outstanding for diluted EPS 251,412 251,206 Earnings per share: Basic $ 1.28 $ 1.76 Diluted $ 1.27 $ 1.74 (1) Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued. The dilution from common stock options is based on the treasury stock method. Under this method, proceeds based on the exercise price plus unearned compensation and windfall tax benefits recognized , minus tax shortfalls recognized , are assumed to be used to repurchase shares on the open market at the average market price for the period. The windfall tax benefits are tax deductions we would receive upon the assumed exercise of stock options in excess of the deferred income taxes we recorded related to the c ompensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation of dilutive common stock equivalents excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). For the three months ended March 31, 2016 and 2015, we had no such antidilutive stock options outstanding. For the three months ended March 31 , 201 6 and 2015, we had no stock options outstanding that were antidilutive because of the unearned compensation and windfall tax benefits included in the assumed proceeds u nder the treasury stock method. The dilution from unvested restricted stock awards (RSAs) and restricted stoc k 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 re lated to the compensation expense on such awards and units. There were no antidilutive RSAs or antidilutive RSUs from the application of unearned compensation in the treasury stock method for the three months ended March 31, 2016. There were no such antidi lutive RSAs and 614 antidilutive RSUs for the three months ended March 31, 2015. Our performance-based RSUs include awards that vest at the end of three-year (for awards granted during or after 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. We primarily use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies to develop our EPS RSU targ ets. 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 Sempr a 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 o n 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. We discuss performance-based RSU awards further in Note 8 of the Notes to Conso lidated Financial Statements in our Annual Report. Our RSAs , which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above . We include RSAs and these RSUs in potential dilutive shares at 100 percent , subject to the application of the treasury stock method. We includ e our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of bo th Sempra Energy stock and the comparative indices , dilutive TSR RSU shares may vary widely from period-to-period. If it were assumed that performance goals for all performance-based RSUs were met at maximum levels and if the treasury stock method were not applied to any of our RSAs or RSUs, the incremental potential dilutive shares would be 2,616,084 and 1,285,193 for the three months ended March 31, 2016 and 2015, 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 $7 million and $8 million for the three months ended March 31, 2016 and 2015, respectively. Pursuant to our Sempra Energy share-based compensation plans, Sempra Energy’s compensation committee granted 372,270 TSR RSUs, 94,550 EPS RSUs and 93,256 service-base d RSUs during the three months ended March 31, 2016, primarily in January. During the three months ended March 31, 2016, IEnova issued 183,970 RSUs from the IEnova 2013 Long-Term Incentive Plan, under which awards are cash settled at vesting based on the p rice of IEnova common stock. CAPITALIZED FINANCING COSTS Capitalized financing costs include capitalized interest costs and AFUDC related to both debt and equity financing of construction projects. We capitalize interest costs incurred to finance capital projects and interest on equity method investments that have not commenced planned principal operations. The following table shows capitalized financing costs for the three months ended March 31, 2016 and 2015. CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended March 31, 2016 2015 Sempra Energy Consolidated: AFUDC related to debt $ 7 $ 6 AFUDC related to equity 27 27 Other capitalized interest 18 17 Total Sempra Energy Consolidated $ 52 $ 50 SDG&E: AFUDC related to debt $ 4 $ 3 AFUDC related to equity 11 8 Total SDG&E $ 15 $ 11 SoCalGas: AFUDC related to debt $ 3 $ 3 AFUDC related to equity 10 9 Total SoCalGas $ 13 $ 12 COMPREHENSIVE INCOME The following tables present the changes in 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) Three months ended March 31, 2016 and 2015 Foreign Total currency Pension and other accumulated other translation Financial postretirement comprehensive adjustments instruments benefits income (loss) 2016: Balance as of December 31, 2015 $ (582) $ (137) $ (87) $ (806) Other comprehensive income (loss) before reclassifications 68 (82) ― (14) Amounts reclassified from accumulated other comprehensive income ― (2) 1 (1) Net other comprehensive income (loss) 68 (84) 1 (15) Balance as of March 31, 2016 $ (514) $ (221) $ (86) $ (821) 2015: Balance as of December 31, 2014 $ (322) $ (90) $ (85) $ (497) Other comprehensive loss before reclassifications (62) (54) ― (116) Amounts reclassified from accumulated other comprehensive income ― (1) 1 ― Net other comprehensive (loss) income (62) (55) 1 (116) Balance as of March 31, 2015 $ (384) $ (145) $ (84) $ (613) (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) Amounts reclassified Details about accumulated from accumulated other Affected line item on Condensed other comprehensive income (loss) components comprehensive income (loss) Consolidated Statements of Operations Three months ended March 31, 2016 2015 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments $ 4 $ 6 Interest Expense Interest rate instruments 3 3 Equity (Losses) Earnings, Before Income Tax Interest rate and foreign exchange instruments 1 ― Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery (7) (7) Revenues: Energy-Related Businesses Total before income tax 1 2 ― 1 Income Tax Expense Net of income tax 1 3 (3) (4) Earnings Attributable to Noncontrolling Interests $ (2) $ (1) Pension and other postretirement benefits: Amortization of actuarial loss $ 2 $ 2 See note (1) below (1) (1) Income Tax Expense Net of income tax $ 1 $ 1 Total reclassifications for the period, net of tax $ (1) $ ― SDG&E: Financial instruments: Interest rate instruments $ 3 $ 3 Interest Expense (3) (3) Earnings Attributable to Noncontrolling Interest Total reclassifications for the period $ ― $ ― (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, 2016 and 2015, Other Comprehensive Income (Loss) (OCI), excluding amounts attributable to noncontrolling interests, at SDG&E and SoCalGas was negligible, and reclassifications out of AOCI to Net Income were also negligible for SoCalGas . SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS The following 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, 2016 and 2015. The only change in SoCalGas ’ equity for the three months ended March 31, 2016 and 2015 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(1) equity Balance at December 31, 2015 $ 11,809 $ 770 $ 12,579 Comprehensive income 304 11 315 Share-based compensation expense 13 ― 13 Common stock dividends declared (188) ― (188) Issuances of common stock 28 ― 28 Repurchases of common stock (54) ― (54) Tax benefit related to share-based compensation 34 ― 34 Distributions to noncontrolling interests ― (3) (3) Balance at March 31, 2016 $ 11,946 $ 778 $ 12,724 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) Issuances of common stock 30 ― 30 Repurchases 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 (1) Noncontrolling interests include the preferred stock of SoCalGas and other noncontrolling interests as listed in the table below under "Other Noncontrolling Interests." 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, 2015 $ 5,223 $ 53 $ 5,276 Comprehensive income (loss) 129 (1) 128 Distributions to noncontrolling interest ― (1) (1) Balance at March 31, 2016 $ 5,352 $ 51 $ 5,403 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 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 compre hensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income (Loss). Preferred Stock At Sempra Energy, the preferred stock of SoCalGas is presented as a noncontro lling 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. Oth er Noncontrolling Interests At March 31, 2016 and December 31, 2015, we reported the following noncontrolling ownership interests held by others (not including preferred shareholders) recorded in Other Noncontrolling Interests in Total Equity on Sempra Ene rgy’s Condensed Consolidated Balance Sheets: OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by others March 31, December 31, March 31, December 31, 2016 2015 2016 2015 SDG&E: Otay Mesa VIE 100 % 100 % $ 51 $ 53 Sempra South American Utilities: Chilquinta Energía subsidiaries(1) 23.5 – 43.4 23.5 – 43.4 22 21 Luz del Sur 16.4 16.4 171 164 Tecsur 9.8 9.8 4 4 Sempra Mexico: IEnova 18.9 18.9 470 468 Sempra Natural Gas: Bay Gas Storage Company, Ltd. 9.1 9.1 25 25 Liberty Gas Storage, LLC 23.2 23.2 14 14 Southern Gas Transmission Company 49.0 49.0 1 1 Total Sempra Energy $ 758 $ 750 (1) Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries. TRANSACTIONS WITH AFFILIATES Amounts due from and to unconsolidated affiliates at Sempra Energy Consolidated, SDG&E and SoCalGas are as follows: AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) March 31, 2016 December 31, 2015 Sempra Energy Consolidated: Total due from various unconsolidated affiliates - current $ 7 $ 6 Sempra South American Utilities(1): Eletrans S.A. and Eletrans II S.A.: 4% Note(2) $ 76 $ 72 Other related party receivables 1 ― Sempra Mexico(1): Affiliate of joint venture with PEMEX: Note due November 13, 2017(3) 3 3 Note due November 14, 2018(3) 42 42 Note due November 14, 2018(3) 34 34 Note due November 14, 2018(3) 8 8 Energía Sierra Juárez: Note due June 15, 2018(4) 17 24 Sempra Natural Gas: Cameron LNG JV 5 3 Total due from unconsolidated affiliates - noncurrent $ 186 $ 186 Total due to various unconsolidated affiliates - current $ (13) $ (14) SDG&E: Total due from various unconsolidated affiliates - current $ 1 $ 1 Sempra Energy $ (35) $ (34) SoCalGas (8) (13) Affiliate (6) (8) Total due to unconsolidated affiliates - current $ (49) $ (55) Income taxes due (to) from Sempra Energy(5) $ (32) $ 28 SoCalGas: Sempra Energy(6) $ ― $ 35 SDG&E 8 13 Total due from unconsolidated affiliates - current $ 8 $ 48 Sempra Energy $ (34) $ ― Total due to unconsolidated affiliate - current $ (34) $ ― Income taxes due (to) from Sempra Energy(5) $ (23) $ 1 (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. and Eletrans II S.A., both of which are joint ventures at Chilquinta Energía. (3) U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.94 percent at March 31, 2016), 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 (6.81 percent at March 31, 2016), to finance the first phase of the Energía Sierra Juárez wind project. (5) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return. (6) At December 31, 2015, net receivable included outstanding advances to Sempra Energy of $50 million at an interest rate of 0.11 percent. Revenues and cost of sales fr om unconsolidated affiliates are as follows: REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended March 31, 2016 2015 REVENUES Sempra Energy Consolidated $ 5 $ 8 SDG&E 3 3 SoCalGas 17 19 COST OF SALES Sempra Energy Consolidated $ 30 $ 19 SDG&E 14 5 Guarantees Sempra Energy has provided guarantees to certain of its solar and wind farm joint ventures and entered into completion guarantees related to the financing of the Cameron LNG JV project, as we discuss above in Note 4 and in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. OTHER INCOME, NET (Dollars in millions) Three months ended March 31, 2016 2015 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 27 $ 27 Investment gains(1) 10 9 Electrical infrastructure relocation income(2) 1 ― Gains on interest rate and foreign exchange instruments, net 3 ― Sale of other investments 1 ― Foreign currency transaction losses (2) (1) Regulatory interest, net(3) 2 1 Sundry, net 7 3 Total $ 49 $ 39 SDG&E: Allowance for equity funds used during construction $ 11 $ 8 Regulatory interest, net(3) 2 1 Sundry, net 1 ― Total $ 14 $ 9 SoCalGas: Allowance for equity funds used during construction $ 10 $ 9 Sundry, net ― (1) Total $ 10 $ 8 (1) Represents investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans. (2) Income at Luz del Sur associated with the relocation of electrical infrastructure. (3) Interest on regulatory balancing accounts. 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, 2016 2015 Sempra Energy Consolidated $ 142 31 % $ 163 27 % SDG&E 72 36 88 37 SoCalGas 87 31 95 31 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 is f actored into the forecasted effective tax rate , and the impact is recognized proportionately over the year. Items that cannot be reliably forecasted (e.g., resolution of prior years’ income tax items, remeasurement of deferred tax asset valuation allowances, Mexi can 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 variabili ty in income tax expense. Sempra Energy’s income tax expense in the three months ended March 31, 2016 includes deferred income tax expense related to Sempra Mexico’s power plant held for sale, as we discuss in Note 3. For SDG&E and SoCalGas , the California Public Utilities Commiss ion (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

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	3 Months Ended
	Mar. 31, 2016
Debt Disclosure [Abstract]
Debt and Credit Facilities	NOTE 6. DEBT AND CREDIT FACILITIES LINES OF CREDIT At March 31, 2016, Sempra Energy Consolidated had an aggregate of $4.2 billion in three primary committed lines of credit for Sempra Energy, Sempra Global and the California Utilities to provide liquidity and to support commercial paper, the major components of which we detail below. Available unused credit on these lines at March 31, 2016 was approximately $3.1 billion. Our foreign operations have additional general purpose credit facilities aggregating $1.1 billion at March 31, 2016. Available unused credit on these lines totaled $876 million at March 31, 2016. Sempra Energ y Sempra Energy has a $1 billion, five-year syndicated revolving credit agreement expiring in October 2020. Citibank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. Borrowings b ear interest at benchmark rates plus a margin that varies with 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, 2016, 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 $400 million of letters of credit on behalf of Sempra Energ y with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. At March 31, 2016, Sempra Energy had no outstanding borrowings or letters of credit supported by the facility. Sempra Global Semp ra Global has a $2.21 billion, five-year syndicated revolving credit agreement expiring in October 2020. Citibank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. Sempra Energy guarantees Sempra Global’s obligations under the credit facility. Borrowings bear interest at benchmark rates plus a margin that varies with Sempra Energy’s credit ratings. The facility requires Sempra Energy to maintain a ratio of total indebtedness to to tal capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At March 31, 2016, Sempra Energy was in compliance with this and all other financial covenants under the credit facility. At March 31, 2016, Sempra Glob al had $879 million of commercial paper outstanding supported by the facility and $1.33 billion of available unused credit on the line. California Utilities SDG&E and SoCalGas have a combined $1 billion, five-year syndicated revolving credit agreement expi ring in October 2020. JPMorgan Chase Bank, N.A. serves as administrative agent for the syndicate of 20 lenders, and no single lender has greater than a 7-percent share. The agreement permits each utility to individually borrow up to $750 million, subject t o a combined limit of $1 billion for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credit commitment of $250 million for both utilities. The amount of borrowings otherwise a vailable under the facility is reduced by the amount of outstanding letters of credit. Borrowings bear interest at benchmark rates plus a margin that varies with the borrowing utility’s credit rating. The agreement requires each utility to maintain a ratio of total indebtedness to total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At March 31, 2016, 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 ut ility. At March 31, 2016, SDG&E and SoCalGas had $166 million and $5 million, respectively, of commercial paper outstanding, supported by the facility. Available unused credit on the line at March 31, 2016 was $584 million and $745 million at SDG&E and SoC alGas , respectively, subject to the $1 billion maximum combined credit limit. Sempra South American Utilities Sempra South American Utilities has Peruvian Sol- and Chilean Peso-denominated credit facilities aggregating $547 million U.S. dollar equivalent, expiring between 2016 and 2018 . The credit facilities were entered into to finance working capital and for general corporate purposes. The Peruvian facilities require a debt to equity ratio of no more than 170 percent. At March 31, 2016, Sempra South Ameri can Utilities was in compliance with this financial covenant under the credit facilities. At March 31, 2016, Sempra South American Utilities had outstanding borrowings of $165 million and bank guarantees of $15 million against the Peruvian facilities, and $255 million of available unused credit. There were no outstanding borrowings at March 31, 2016 under the $112 million Chilean facility. Sempra Mexico IEnova has a $600 million, five-year revolving credit agreement expiring in August 2020. The lenders are Banco Santander (México), S.A., Institución de Banca Múltiple , Grupo Financiero Santander México, The Bank of Tokyo - Mitsubishi UFJ, LTD., The Bank of Nova Scotia and Sumitomo Mitsui Banking Corporation. At March 31, 2016, IEnova had $91 million of outst anding borrowings supported by the facility, and available unused credit on the line was $509 million. WEIGHTED AVERAGE INTEREST RATES The weighted average interest rates on the total short-term debt at Sempra Energy Consolidated were 1.12 percent and 1.09 percent at March 31, 2016 and December 31, 2015, respectively. At March 31, 2016, the weighted average interest rate s on total s hort-term debt at SDG&E and SoCalGas were 1.02 percent and 0.40 percent, respectively. The weighted average interest rate on total s hort-term debt at SDG&E was 1.01 percent at December 31, 2015. LONG-TERM DEBT SDG&E In Ap ril 2016, SDG&E notified bondholders that it intends to redeem, prior to maturity, certain outstanding long-term debt instruments with a total principal amou nt of $105 million. At March 31, 2016, the debt remains classified as long-term on Sempra Energy’s and SDG&E’s Condensed Consolidated Balance Sheets. These instruments have a coupon rate of 5 per cent and a maturity date of December 2027 . SDG&E expects to repay the debt in the second quarter of 2016. INTEREST RATE SWAPS We discuss our fair value interest rate swaps and interest rate swap s to hedge cash flows in Note 7 .

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	3 Months Ended
	Mar. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [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, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines i n anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated reven ues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Condensed Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) u ndesignated. 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 offse t 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 Conde nsed Consolid ated Statements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge 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 the future cash flows of a given revenue or expense item may vary, and other criteria. We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest rate to a variable rate. The co mbination 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 inst rument 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, as follows: The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed price natural gas and electricity positions, options, and basis risk instruments, which are either exchang e-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative a ctivities 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 Powe r 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 loss es do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power 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 S empra 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 derivati ves, 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, incl uding 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, 2016 and December 31, 2015 as follows: NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) March 31, December 31, Segment and Commodity Unit of measure 2016 2015 California Utilities: SDG&E: Natural gas MMBtu(1) 60 70 Electricity MWh(2) ― 1 Congestion revenue rights MWh 33 36 SoCalGas – natural gas MMBtu ― 1 Energy-Related Businesses: Sempra Natural Gas – natural gas MMBtu 39 43 (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 phy sical locations of contractual obligation s and assets , such as natural gas purchases and sales . INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We 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. Interest rate derivati ves are generally accounted for as hedges, and although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate deriva tives may not be recovered from customers as timely as described above with regard to energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate ch anges. At March 31, 2016 and December 31, 2015, the net notional amounts of our interest rate derivatives, excluding the cross-currency swaps discussed below, were: INTEREST RATE DERIVATIVES (Dollars in millions) March 31, 2016 December 31, 2015 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges(1) $ 381 2016-2028 $ 384 2016-2028 Fair value hedges 300 2016 300 2016 SDG&E: Cash flow hedge(1) 312 2016-2019 315 2016-2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and joint ventures. These cash flow hedges exchange our Mexican-peso denominated principal and interest payments into the U.S. dollar and swap Mexican variable interest rates for U.S. fixed interest rates. We are also exposed to exchange rate movements at our Mexican subsidiaries and joint ventures, which have U.S. dollar denominated cash balances, receivables, payables and debt (monetary asset s and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We utilize foreign currency derivatives as a means to manage the risk of ex posure to significant fluctuations in our income tax expense and equity earnings from these impacts. In January 2016, we entered into foreign currency derivatives with a notional amount totaling $550 million. At March 31, 2016 and December 31, 2015, the n et notional amounts of our foreign currency derivatives were: FOREIGN CURRENCY DERIVATIVES (Dollars in millions) March 31, 2016 December 31, 2015 Notional debt Maturities Notional debt Maturities Sempra Mexico: Cross-currency swaps $ 408 2018-2023 $ 408 2018-2023 Other foreign currency derivatives 550 2016 ― ― In addition, Sempra South American Utilities use 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 w ith 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, 2016 and December 31, 2015, including the amount of cash collate ral 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) March 31, 2016 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Fixed-price Fixed-price contracts 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) $ 5 $ ― $ (15) $ (166) Derivatives not designated as hedging instruments: Interest rate and foreign exchange instruments 3 ― ― ― Commodity contracts not subject to rate recovery 144 20 (144) (9) Associated offsetting commodity contracts (135) (9) 135 9 Associated offsetting cash collateral ― ― 7 ― Commodity contracts subject to rate recovery 23 51 (68) (61) Associated offsetting commodity contracts (4) (1) 4 1 Associated offsetting cash collateral ― ― 31 24 Net amounts presented on the balance sheet 36 61 (50) (202) Additional cash collateral for commodity contracts not subject to rate recovery 20 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 32 ― ― ― Total(4) $ 88 $ 61 $ (50) $ (202) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (14) $ (25) 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 20 51 (65) (61) Associated offsetting commodity contracts (2) (1) 2 1 Associated offsetting cash collateral ― ― 31 24 Net amounts presented on the balance sheet 18 50 (46) (61) Additional cash collateral for commodity contracts not subject to rate recovery 2 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 30 ― ― ― Total(4) $ 50 $ 50 $ (46) $ (61) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery $ ― $ ― $ (1) $ ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 3 ― (3) ― Associated offsetting commodity contracts (2) ― 2 ― Net amounts presented on the balance sheet 1 ― (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) $ ― (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) December 31, 2015 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Fixed-price Fixed-price contracts Other contracts contracts and other assets: and other and other derivatives(1) Sundry derivatives(2) derivatives Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 4 $ 1 $ (15) $ (156) Commodity contracts not subject to rate recovery 13 ― ― ― Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 245 32 (239) (21) Associated offsetting commodity contracts (232) (20) 232 20 Associated offsetting cash collateral (6) ― 4 ― Commodity contracts subject to rate recovery 28 49 (61) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 50 60 (49) (193) Additional cash collateral for commodity contracts not subject to rate recovery 2 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 28 ― ― ― Total(4) $ 80 $ 60 $ (49) $ (193) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (14) $ (23) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery ― ― (1) ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 27 49 (60) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 25 47 (44) (59) Additional cash collateral for commodity contracts not subject to rate recovery 1 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 27 ― ― ― Total(4) $ 53 $ 47 $ (44) $ (59) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery $ ― $ ― $ (1) $ ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 1 ― (1) ― Net amounts presented on the balance sheet 1 ― (1) ― Additional cash collateral for commodity contracts subject to rate recovery 1 ― ― ― Total $ 2 $ ― $ (1) $ ― (1) Included in Current Assets: Other for SoCalGas. (2) Included in Current Liabilities: Other for SoCalGas. (3) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (4) Normal purchase contracts previously measured at fair value are excluded. The effects of derivative instruments designated as hedges on the Condensed Consolidated Statement s of Operations and in OCI and AOCI for the three months ended March 31 were FAIR VALUE HEDGE IMPACTS (Dollars in millions) Pretax gain on derivatives recognized in earnings Three months ended March 31, Location 2016 2015 Sempra Energy Consolidated: Interest rate instruments Interest Expense $ 2 $ 2 Interest rate instruments Other Income, Net ― 1 Total(1) $ 2 $ 3 (1) There was no hedge ineffectiveness in either the three months ended March 31, 2016 or 2015. 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 IMPACTS (Dollars in millions) Pretax (loss) gain Pretax (loss) gain reclassified recognized in OCI from AOCI into earnings (effective portion) (effective portion) Three months ended March 31, Three months ended March 31, 2016 2015 Location 2016 2015 Sempra Energy Consolidated: Interest rate and foreign exchange instruments(1) $ (11) $ (18) Interest Expense $ (4) $ (6) Equity (Losses) Earnings, Interest rate instruments (137) (78) Before Income Tax (3) (3) Interest rate and foreign Equity Earnings, exchange instruments (18) ― Net of Income Tax (1) ― Commodity contracts not Revenues: Energy-Related subject to rate recovery 1 (1) Businesses 7 7 Total(2) $ (165) $ (97) $ (1) $ (2) SDG&E: Interest rate instruments(1)(2) $ (5) $ (5) 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) Amounts include negligible hedge ineffectiveness in the three months ended March 31, 2016 and 2015. For Sempra Energy Consolidated, we expect that losses of $21 million, which are net of income tax benefit, that are currently recorded in AOCI (including $12 million in noncontrolling interests, substantially all of which is related to Otay Mesa VIE at SDG&E) related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivativ e contracts that are currently outstanding mature. SoCalGas expects that negligible losses, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve mont hs as the hedged items affect earnings. For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at March 31, 2016 is approximately 13 years and 3 years for Sempra Energy Consolidated a nd SDG&E, respectively. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 19 years. The effects of derivative instruments not designated as hedging instruments on the Condensed Consolidate d Statements of Operations for the three months ended March 31 were UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Three months ended March 31, Location 2016 2015 Sempra Energy Consolidated: Foreign exchange instruments Other Income, Net $ 3 $ ― Foreign exchange instruments Equity Earnings, Net of Income Tax 2 (1) Commodity contracts not subject Revenues: Energy-Related to rate recovery Businesses (1) 3 Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power (12) (20) Commodity contracts subject to rate recovery Cost of Natural Gas (1) 1 Total $ (9) $ (17) SDG&E: Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power $ (12) $ (20) SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (1) $ 1 CONTINGENT FEATURES For Sempra Energy Consolidated and SDG&E, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing fu ll collateralization. For Sempra Energy Consolidated, the total fair value of this group of derivative instruments in a net liability position is $6 million at both March 31, 2016 and December 31, 2015 . At March 31, 2016, if the cr edit 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 is $5 million at both March 31, 2016 and December 31, 2015. At March 31, 2016, if the credit ratings of SDG&E were reduced below invest ment grade, $6 millio n 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 performa nce 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, 2016
Fair Value Disclosures [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 t he fair value hierarchy in Note 1 of the Notes to Consolida ted Financial Statements in the Annual Report. We have not changed the valuation techniques or types of inputs we use to me asure fair value during the three months ended March 31, 2016 . 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, 2016 and December 31, 2015. 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 affec t 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 un der “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, 2016 and December 31, 2015 in the tables below include the following: Nuclear decom missioning 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). For commodity contracts, interest rate derivatives and foreign exchange instrument s, 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 obse rvable, 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). Level 3 recurring items rel ate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.” Rabbi Trust investments include marketable securities that we value using a market approach based on closing prices reported in the act ive market in which the identical security is traded (Level 1). These i nvestments in marketable securities were negligible at both March 31, 2016 and December 31, 2015. There were no transfers into or out of Level 1, Level 2 or Level 3 for Sempra Energy Consoli dated , SDG&E or SoCalGas during the periods presented . RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at March 31, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 623 $ ― $ ― $ ― $ 623 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 43 ― ― 105 Municipal bonds ― 156 ― ― 156 Other securities ― 190 ― ― 190 Total debt securities 62 389 ― ― 451 Total nuclear decommissioning trusts(2) 685 389 ― ― 1,074 Interest rate and foreign exchange instruments ― 8 ― ― 8 Commodity contracts not subject to rate recovery 1 19 ― 20 40 Commodity contracts subject to rate recovery ― 1 68 32 101 Total $ 686 $ 417 $ 68 $ 52 $ 1,223 Liabilities: Interest rate and foreign exchange instruments $ ― $ 181 $ ― $ ― $ 181 Commodity contracts not subject to rate recovery 3 6 ― (7) 2 Commodity contracts subject to rate recovery ― 67 57 (55) 69 Total $ 3 $ 254 $ 57 $ (62) $ 252 Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Interest rate and foreign exchange instruments ― 5 ― ― 5 Commodity contracts not subject to rate recovery 22 16 ― (4) 34 Commodity contracts subject to rate recovery ― 1 72 28 101 Total $ 688 $ 404 $ 72 $ 24 $ 1,188 Liabilities: Interest rate and foreign exchange instruments $ ― $ 171 $ ― $ ― $ 171 Commodity contracts not subject to rate recovery 5 3 ― (4) 4 Commodity contracts subject to rate recovery ― 68 53 (54) 67 Total $ 5 $ 242 $ 53 $ (58) $ 242 (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, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 623 $ ― $ ― $ ― $ 623 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 43 ― ― 105 Municipal bonds ― 156 ― ― 156 Other securities ― 190 ― ― 190 Total debt securities 62 389 ― ― 451 Total nuclear decommissioning trusts(2) 685 389 ― ― 1,074 Commodity contracts not subject to rate recovery ― ― ― 2 2 Commodity contracts subject to rate recovery ― ― 68 30 98 Total $ 685 $ 389 $ 68 $ 32 $ 1,174 Liabilities: Interest rate instruments $ ― $ 39 $ ― $ ― $ 39 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 66 57 (55) 68 Total $ 1 $ 105 $ 57 $ (56) $ 107 Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Commodity contracts not subject to rate recovery ― ― ― 1 1 Commodity contracts subject to rate recovery ― ― 72 27 99 Total $ 666 $ 382 $ 72 $ 28 $ 1,148 Liabilities: Interest rate instruments $ ― $ 37 $ ― $ ― $ 37 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 67 53 (54) 66 Total $ 1 $ 104 $ 53 $ (55) $ 103 (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, 2016 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 $ 1 $ ― $ ― $ (1) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 1 $ 1 $ ― $ (1) $ 1 Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Commodity contracts subject to rate recovery $ ― $ 1 $ ― $ 1 $ 2 Total $ ― $ 1 $ ― $ 1 $ 2 Liabilities: Commodity contracts not subject to rate recovery $ 1 $ ― $ ― $ (1) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 1 $ 1 $ ― $ (1) $ 1 (1) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. Level 3 Information The following table sets forth reconciliations of changes in the fair value of congestion revenue r ights (CRRs) and long-term, fixed-price electricity positions classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated and SDG&E: LEVEL 3 RECONCILIATIONS (Dollars in millions) Three months ended March 31, 2016 2015 Balance as of January 1 $ 19 $ 107 Realized and unrealized (losses) gains (1) 6 Settlements (7) (11) Balance as of March 31 $ 11 $ 102 Change in unrealized (losses) gains relating to instruments still held at March 31 $ (1) $ 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 and long-term, fixed-price electricity positions on an ongoing basis. Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to these instruments to be recoverable throug h 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 year. The impact associated with discounting is negligible. Because auction prices are a less observa ble input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. From January 1, 2016 to December 31, 2016, the auction prices range from $(24) per MWh to $10 per M Wh at a given location, and from January 1, 2015 to December 31, 2015, the auction prices ranged from $(16) per MWh to $8 per MWh at a given location. Positive values between two locations represent expected future reductions in congestion costs, whereas n egative 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 (lowe r) fair value measurement. We summarize CRR volumes in Note 7. Long-term, fixed-price electricity p ositions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. At March 31, 2016, these electricit y forward prices range from $15.85 per MWh to $57.43 per MWh. A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. We summarize long-term, fixed-price electricity position volumes in Note 7. Realized gains and losses associated with CRRs and long-term electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the 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, current amounts due to/from unconsolidated affiliates, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferre d Compensation Plans are c arried 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 that are not recorded at fair value on the Condensed Consolidated Balance Sheets at March 31, 2016 and December 31, 2015: FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) March 31, 2016 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 173 $ ― $ 92 $ 72 $ 164 Total long-term debt (2)(3) 13,761 ― 14,363 652 15,015 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,285 $ ― $ 4,517 $ 312 $ 4,829 SoCalGas: Total long-term debt (5) $ 2,513 $ ― $ 2,731 $ ― $ 2,731 Preferred stock 22 ― 25 ― 25 December 31, 2015 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 175 $ ― $ 97 $ 69 $ 166 Total long-term debt (2)(3) 13,761 ― 13,985 648 14,633 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,304 $ ― $ 4,355 $ 315 $ 4,670 SoCalGas: Total long-term debt (5) $ 2,513 $ ― $ 2,621 $ ― $ 2,621 Preferred stock 22 ― 25 ― 25 (1) Excluding accumulated interest outstanding of $13 million and $11 million at March 31, 2016 and December 31, 2015, respectively. (2) Before reductions for unamortized discount (net of premium) and debt issuance costs of $106 million and $107 million at March 31, 2016 and December 31, 2015, respectively, and excluding build-to-suit and capital lease obligations of $386 million and $387 million at March 31, 2016 and December 31, 2015, 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) Level 3 instruments include $312 million and $315 million at March 31, 2016 and December 31, 2015, respectively, related to Otay Mesa VIE. (4) Before reductions for unamortized discount and debt issuance costs of $43 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $243 million and $244 million at March 31, 2016 and December 31, 2015, respectively. (5) Before reductions for unamortized discount and debt issuance costs of $24 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $1 million at March 31, 2016 and December 31, 2015. We base the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other noncurrent amounts due from unconsolidated affiliates of Sempra South American Utilities using a perpetuity approach based on the obligation’s fixed interest rate, the absence of a stated maturity date and a discount rate reflecting local borrowing c osts (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3). We provide the fair values for the securities held in the nucle ar decommissioning trust funds related to the San Onofre Nuclear Generating Station (SONGS) in Note 9 below. Non-Recurring Fair Value Measures – Sempra Energy Consolidated Sempra Natural Gas – Rockies Express In March 2016, Sempra Natural Gas agreed to sell its 25-percent interest in Rockies Express to a subsidiary of Tallgrass Development, LP for cash consideration of $440 million, subject to adjustment at closing. We consider the sale price for our equity interest in Rockies Express to be a market participants’ view of the total value of Rockies Express and have measured the fair value of our investment based on the equity sale price. In March 2016, we recorded a nonca sh impairment of our investment in Rockies Express of $44 million ($27 million after-tax), which is included in Equity Earnings, Before Income Tax, on the Condensed Consolidated Statement of Operations for the three months ended March 31, 2016. Use of this market participant input as the indicator of fair value is a Level 2 measurement in the fair value hierarchy. The following table summarizes significant inputs impacting non-recurring fair value measures related to our investment in Rockies Express: NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Estimated Fair % of Inputs used to fair value fair value develop Range of value Valuation technique hierarchy measurement measurement inputs Investment in Rockies Express $ 440 (1) Market approach Level 2 100% Equity sale price 100% (1) At measurement date of March 29, 2016. At March 31, 2016, our investment in Rockies Express had a carrying value of $436 million, reflecting subsequent equity method activity to record a distribution.

CALIFORNIA UTILITIES' REGULATOR

CALIFORNIA UTILITIES' REGULATORY MATTERS	3 Months Ended
	Mar. 31, 2016
Regulated Operations [Abstract]
Sempra Utilities' Regulatory Matters	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, after an extended outage beginning in 2012, 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 Commi ssion (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 Steam Generator Replacement Project 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. Th ese issues with the steam generators ultimately resulted in Edison’s decision to permanently retire SONGS . The replacement steam generators were designed and provided by Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsub ishi 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 b inding arbitration proceedings against MHI seeking damages as well. SDG&E is participating in the arbitration as a claimant and respondent. We discuss these proceedings in Note 11. Settlement Agreement to Resolve the CPUC’s Order Instituting Investigation (OII) into the SONGS Outage (SONGS OII) In November 2012, in response to the outage, the CPUC issued the SONGS OII, which was intended to determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of this outag e, including purchased replacement power costs, which are typically recovered through the Energy Resource Recovery Account (ERRA). In April 2014, SDG&E filed with the CPUC a Se ttlement Agreement, along with Edison, The Utility Reform Network ( TURN), the C PUC Office of Ratepayer Advocates ( ORA) and two other intervenors who joined the Settlement Agreement to the SONGS OII proceeding (collectively, the Settling Parties). In September 2014, the Settling Parties executed an Amended and Restated Settlement Agr eement (Amended Settlement Agreement), which amended the Settlement Agreement, and in November 2014, the CPUC issued a final decision approving the Amended Settlement Agreement. The Amended Settlement Agreement does not affect on-going or future proceeding s before the NRC, or litigation or arbitration related to potential future recoveries from third parties (except for the allocation to ratepayers of a ny recoveries as described below ) or proceedings addressing decommissioning activities and costs. We discu ss the terms of the Amended Settlement Agreement and related filings in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report . 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, asking the CPUC to set aside its decision approving the Amended Settlement Agreement and reop en the SONGS OII proceeding . In June 2015, TURN , a party to the Amended Settlement Agreement , filed a response supporting the A4NR petition. TURN does not question the merits of the Amended Settlement Agreement , but is concerned that certain allegations re garding Edison raised by A4NR have undermined the public’s confidence in the regulatory process. SDG&E has responded that TURN’s concerns regarding public perception do not impact the reasonableness of the Amended Settlement Agreement and are insufficient to overturn it. SDG&E is unable to determine what actions the CPUC will take , if any, in response to the A4NR PFM. In A ugust 2015 , ORA, also a party to the Amended Settlement Agreement, filed a PFM with the CPUC, withdrawing its support for the Amended Set tlement Agreement and asking the CPUC to reopen the SONGS OII proceeding. The ORA does not question the merits of the Amended Settlement Agreement, but is concerned with the CPUC’s approach toward recent disclosures concerning Edison ex parte communication s with the CPUC. SDG&E responded that the ORA’s PFM is insufficient to overturn the Amended Settlement Agreement , because the ORA fails to make a case that the Amended Settlement Agreement is no longer in the public interest. SDG&E is unable to determine w hat actions the CPUC will take, if any, in response to the ORA PFM. Accounting and Financial Impacts Through December 31, 2015 and March 31, 2016, the cumulative after-tax loss from plant closure recorded by Sempra Energy and SDG&E is $125 million, includi ng a reduction in the after-tax loss of $13 million 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. The regulatory asset for the expected recovery of SONGS costs, consistent with the Amended Settlement Agreement, is $243 million ($43 million current and $200 million long-term) at March 31, 2016 and is recorded on the Condensed Consolidated Balance Sheets in Other Current Assets and Regulator y Assets Noncurrent, respectively, at Sempra Energy, and in Regulatory Assets Current and Other Regulatory Assets Noncurrent, respectively, at SDG&E . The amortization period prescribed for the regulatory asset is 10 years, which began on February 1, 2012. However, since the CPUC’s final decision approving the Amended Settlement Agreement was not issued until November 2014, amortization did not commence until January 2015 . Settlement with Nuclear Electric Insurance Limited (NEIL) NEIL insures domestic and i nternational nuclear utilities for the costs associated with interruptions, damages, decontaminations and related nuclear risks. In October 2015, the SONGS co-owners (Edison, SDG&E and the City of Riverside) reached an agreement with NEIL to resolve all of SONGS’ insurance claims arising out of the failures of the replacement steam generators for a total payment by NEIL of $400 million, SDG&E’s share of which is $80 million. Pursuant to the terms of the SONGS OII Amended Settlement Agreement, after reimburs ement of legal fees and a 5-percent allocation to shareholders, the net proceeds of $75 million were allocated to ratepayers through ERRA. We discuss NEIL further in Note 11. Nuclear Decommissioning and Funding As a result of Edison’s decision to permanent ly retire SONGS Units 2 and 3, Edison has begun the decommissioning phase of the plant. We discuss the process of decommissioning SONGS and oversight by the NRC in Note 13 of the Notes to Consolidated Financial Statements in the Annual Report. In accordan ce 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 1 992, is largely complete. The remaining work will be done when Units 2 and 3 are decommissioned. At March 31, 2016, the fair value of SDG&E’s NDT assets was $1.1 billion. Except for the use of funds for the planning of decommissioning activities or NDT adm inistrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In July 2015, the CPUC authorized SDG&E’s request to access trust funds for up to $55 million in decommissioning costs in curred in 2013, including $18 million that is expected to be withdrawn pending satisfactory clarification by the Internal Revenue Service (IRS) that certain spent fuel costs and other costs are eligible decommissioning costs, payable from qualified nuclear decommissioning trusts. We are uncertain as to when such clarification will be provided. In November 2015, the CPUC authorized SDG&E’s request to access trust funds for $3 6 million for SONGS Units 2 and 3 de commiss ioning costs incurred in 2014, including $13 million that also will be withdrawn pending satisfactory clarification by the IRS . SDG&E expects to request and receive approval in the second quarter of 2016 to access trust funds for Units 2 and 3 decom missioning costs incurred in 2015 . In April 2016, the CPUC adopted a decision approving a total decommissioning cost estimate for SONGS Units 2 and 3 of $4.411 billion, of which SDG&E’s share is $89 9 million. The decision also approves an annual advice letter request process for SDG&E to request trust fund disbursements for decommissioning costs based on a forecast for 2016 and thereafter. Disbursements from the trust will then be made up to this annu al forecast amount as decommissioning expenses are incurred. All disbursements will be subject to future refund until a reasonableness review of the actual decommissioning costs is conducted, which would be no less frequently than every three years . 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 presented 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 l osses for the securities held in the NDT . We provide additional fair value disclosures for the NDT in Note 8 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Gross Gross Estimated unrealized unrealized fair Cost gains losses value At March 31, 2016: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1) $ 101 $ 4 $ ― $ 105 Municipal bonds(2) 146 10 ― 156 Other securities(2) 192 6 (8) 190 Total debt securities 439 20 (8) 451 Equity securities 214 413 (4) 623 Cash and cash equivalents 9 ― (1) 8 Total $ 662 $ 433 $ (13) $ 1,082 At December 31, 2015: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 89 $ 2 $ ― $ 91 Municipal bonds 148 8 ― 156 Other securities 194 1 (13) 182 Total debt securities 431 11 (13) 429 Equity securities 214 412 (7) 619 Cash and cash equivalents 15 ― ― 15 Total $ 660 $ 423 $ (20) $ 1,063 (1) Maturity dates are 2016-2065. (2) Maturity dates are 2016-2115. 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, 2016 2015 Proceeds from sales(1) $ 93 $ 94 Gross realized gains 3 2 Gross realized losses (8) (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 . 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 set sufficient rates to allow the California Utilities to recover their reasonable cost of operations and maintenance and to provide the opportunity to realize their authorized rates of return on their investment . 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 , respe ctively, over t heir 2015 revenue requirements. In September 2015, the California Utilities filed settlement agreements with the CPUC that resolve all material matters related to the proceeding, except for the revenue requirement implications of certain in come tax benefits associated with flow-through repair allowance tax deductions, discussed below. The settlement agreements are with eight of eleven intervening parties. For SoCalGas , the settlement proposes a total revenue requirement in 2016 of $2.219 bil lion, which is $133 million less than its original request. The proposed settlement represents an increase of $122 million , or 6 percent , over the 2015 total revenue requirement. For SDG&E, the settlement proposes a total revenue requirement in 2016 of $1. 811 billion, which is $100 million less than its original request (as revised). The proposed settlement represents an increase of $17 million, or one percent , over the 2015 total revenue requirement. This increase reflects a $16 million adjustment to the 2 015 estimated revenue requirement since the November 2014 filings. The filed settlement agreements also call for attrition adjustments of 3.5 percent for both 2017 and 2018. Because the 2016 settlement has not been finalized, the California Utilities will collect rates identical to 2015 authorized amounts until a 2016 decision is approved . The California Utilities also filed a separate agreement, reached with ORA, proposing that a fourth year (2019) be added to the GRC period, with a revenue requirement i ncrease of 4.3 percent over 2018. On April 29, 2016, the CPUC issued a proposed decision in a separate proceeding denying the potential of four-year GRC cycles citing that an extension to the GRC period would delay the implementation of the risk-based decis ion making framework. The settlement agreements described above exclude a proposal, for both SDG&E and SoCalGas , regarding certain intra-rate case income tax benefits. The proposal recommends that the CPUC adjust SoCalGas ’ rate base by $92 million and SDG& E’s rate base by $93 million, and additionally reduce both utilities’ revenue requirements by amounts tracked in tax memorandum accounts for the year 2015, which total $ 74 million for SoCalGas and $39 million for SDG&E. We believe the proposed treatment wo uld violate and contradict long standing rate making and income tax policy, and would represent a material departure from historical practice. If this proposal is adopted, the outcome would reduce the revenue requirement amounts agreed to in the respective settlement agreements described above. SDG&E and SoCalGas do not expect that the prospective reduction to rate base described above would result in an immediate earnings impact if this proposal is adopted. However, if this proposal is adopted, SDG&E and S oCalGas may record a material charge against earnings for amounts in the tax memorandum accounts when the proposed decision is received . We anticipate all matters to be resolved in the CPUC’s final decision on the 2016 GRC proceeding. We expect the CPUC to issue a final decision in the proceeding in the second quarter of 2016 . Natural Gas Pipeline Operations Safety Assessments In June 2014, the CPUC issued a final decision addressing SDG&E’s and SoCalGas ’ Pipeline Safety Enhancement Plan (PSEP) . Specifically, the decision determined the following for Phase 1 of the program : approved the utilities’ model for implementing PSEP; approved a process, including a reasonableness review, to determine the amount that the utilities will be authorized to recover from ratepayers for the interim costs incurred through the date of the fina l decision to implemen t PSEP, which is recorded in regulatory accounts authorized by the CPUC; approved balancing account treatment, subject to a reasonableness review, for incremental costs yet to be incurred to implement PSEP; and established the criteri a 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 ha s 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 ch arge of $5 million in 2014 for costs incurred in prior periods that were no longer subject to recovery. After taking the amounts disallowed for recovery into consideration, as of March 31, 201 6 , SDG&E and SoCalGas have recorded PSEP costs of $ 12 million an d $ 177 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 Triennial Co st Allocation Proceeding ( TCAP ) decision, SDG&E and SoCalGas are authorized to file an application wit h 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 ended December 31, 2015. SoCalGas and SDG&E currently expect to file such applica tions no later than the second 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 a s of December 31, 2015 would be expected by mid-2017) . In October 2014, SDG&E and SoCalGas filed a PFM with the CPUC requesting authority to begin to recover PSEP costs from customers in the year in which the costs are incurred, subj ect 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 mil lion, respectively, in costs recorded in the regulatory account through June 11, 2014. In June 2015, SDG&E and SoCalGas agreed to remove certain projects from the filing and defer their review to future proceedings and, as a result, are now requesting reco very of $0.1 million and $26.8 million, respectively. The ORA, TURN, and the Southern California Generation Coalition (SCGC) have recommended disallowances related to completed projects, as well as facilities build-out costs, de-scoped projects, and projec t management and consulting costs. We expect a decision on this application in the second quarter of 2016 . In July 2014, the ORA and TURN filed a joint application for rehearing of the CPUC’s June 2014 final decision. In March 2015, the CPUC issued a decision denying the ORA’s and TURN’s second request for rehearing, but keeping the record open to admit additional evidence on the limited issue of pressure testing or replacing pipelines installed between January 1, 1956 and July 1, 1961. The ORA and TURN allege 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 December 2015, the CPUC issued a final decision finding that ratepayers should not bear the costs associated with pressure testing subject pipelines, or, if replaced, ratepayers should bear neither the average cost of pressure testing nor the undepreciated balance o f abandoned pipelines. Through March 31, 201 6, the after- tax disallowed costs for SoCalGas and SDG&E are $ 2.6 million and $0.5 million, respectively. In January 2016, SoCalGas and SDG&E joint ly filed a request with the CPUC seeking rehearing of its December 2015 decision. A CPUC decision on the rehearing request is expected in 2016 . SDG&E MATTERS SONGS We discuss regulatory and other matters related to SONGS in Note 9. Wildfire Claims Cost Recovery In September 2015, SDG&E filed an application with the CPUC requesting rate recovery of an estimated $379 million in costs related to the October 2007 wildfires that have been recorded to the Wildfire Expense Memorandum Account (WEMA). These costs represent a portion of the estimated total of $2.4 billion in costs and legal fees that SDG&E has incurred to resolve third-party damage claims arising from the October 2007 wildfires. The requested amount of $379 million is the net estimated cost incurred by SDG&E after deductions for insurance reimbursement ($1.1 billion), third party settlement recoveries ($824 million) and allocations to Federal Energy Regulatory Commission (FERC) -jurisdictional rates ($80 million), and reflects a voluntary 10 percent shareholder contribution applied to the net WEMA balance ($42 million). SDG&E requested a CPUC decision by the end of 2016 and is proposing to recover the costs in rates over a six- to ten-year period. In April 2016, a ruling was issued establishing the scope and sche dule for the proceeding, which will be managed in two phases. Phase 1 will address SDG&E’s operational and management prudence surrounding the 2007 wildfires. Phase 2 will address whether SDG&E’s actions and decision-making in connection with settling lega l claims in relation to the wildfires were reasonable. Evidentiary hearings in Phase 1 are scheduled to be held in January 2017 , with a final decision scheduled to be issued in the second half of 2017. The procedural schedule for Phase 2 will be determined after Phase 1 is concluded . In September 2015, the presiding judge assigned by the FERC to SDG&E’s annual Electric Transmission Formula Rate filing (TO4 Formula Cycle 2) issued an initial decision and an order on summary judgment that authorized SDG&E to recover all of the costs incurred and allocated to SDG&E’s FERC-regulated operations, including $23.1 million of costs associated with the 2007 wildfires. In October 2015, the CPUC filed a request for rehearing of the FERC’s September 2015 order, which req uested abeyance of SDG&E’s request to recover 2007 wildfire damage expenses. On April 21, 2016, the FERC affirmed its findings in the September 2015 order and denied the CPUC’s request for rehearing. The FERC decision finalizes SDG&E’s base transmission re venue requirement and the $23.1 million of wildfire damage expenses. We provide additional information about wildfire litigation costs and their recovery in Note 11. SOCALGAS MATTERS Aliso Canyon Natural Gas Storage Facility We discuss various regulatory matters regarding the Aliso Canyon natural gas storage facility and leak in Note 1 1 . CALIFORNIA UTILITIES — MAJOR PROJECTS We discuss the California Utilities’ major projects in detail in Note 14 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and details in the tables below. MAJOR PROJECTS – UPDATES Joint Utilities Projects Southern Gas System Reliability Project § In April 2016, the CPUC issued a proposed decision finding that there is a need for enhanced system reliability for the southern portion of the SoCalGas and SDG&E gas system, but concluding that the utilities have failed to demonstrate that there is a need for their proposed pipeline project. Instead, the proposed decision determines that certain non-physical alternatives will provide enhanced supply reliability, without the need to construct pipeline facilities. § At March 31, 2016, SoCalGas has approximately $23 million of development costs invested in the project, classified as Property, Plant and Equipment on Sempra Energy's and SoCalGas' Condensed Consolidated Balance Sheets. Some or all of these assets could become impaired if the project and potential alternative uses for these assets were ultimately rejected by the CPUC. SoCalGas and SDG&E filed comments with the CPUC in April 2016. Pipeline Safety & Reliability Project § SDG&E and SoCalGas filed an amended application with the CPUC in March 2016 providing detailed analysis and testimony supporting the proposed project. The revised request also presents additional information on the costs and benefits of project alternatives, safety evaluation and compliance analysis, and statutory and procedural requirements. SDG&E and SoCalGas seek approval to construct the proposed project, estimated at a cost of $633 million, and authority to recover the associated revenue requirement in rates. SDG&E Projects Cleveland National Forest (CNF) Transmission Projects § In March 2016, the U.S. Forest Service issued a final decision authorizing issuance of the CNF Master Special Use Permit renewing SDG&E's land rights and authorizing the construction, operation and maintenance of facilities located on national forest lands for the next 50 years, as well as approving the majority of the fire-hardening activities proposed by SDG&E. § Proposed decision issued by the CPUC in April 2016, which granted SDG&E a permit to construct. Final CPUC decision expected in the second quarter of 2016. Sycamore-Peñasquitos Transmission Project § March 2016 final environmental impact report (EIR) recommended an alternative that undergrounds more of the project than originally proposed, and is viewed as environmentally superior. The CPUC may consider this alternative. § CPUC's recommended alternative has an estimated cost of $250 million to $300 million, compared to the original project cost estimate of $120 million to $150 million, and would also delay the project schedule by approximately 10 months. § CPUC decision expected in the second half of 2016. South Orange County Reliability Enhancement § CPUC issued its final EIR for the project in April 2016. The EIR concluded that an alternative project is considered environmentally superior to SDG&E's proposal. The final EIR states that the CPUC is not required to adopt the environmentally superior alternative if there are overriding considerations in favor of another alternative. The CPUC will consider the findings in determining whether to approve SDG&E's proposed project or an alternative to it. § Final CPUC decision expected in the second half of 2016.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	3 Months Ended
	Mar. 31, 2016
Commitments and Contingencies Disclosure [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 material ly adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued. At March 31, 2016, Sempra Energy’s ac crued liabilities for legal proceedings, including associated legal fees and costs of litigation, on a consolidated basis, were $37 million. At March 31, 2016, accrued liabilities for legal proceedings for SDG&E and SoCalGas were $29 million and $6 million , respectively, excluding amounts for matters related to the Aliso Canyon natural gas leak , which we discuss below. SDG&E 2007 Wildfire Litigation In October 2007, San Diego County experienced several catastrophic wildfires. Reports issued by the California Department of Forestry and Fire Protection (Cal Fire) concluded that two of these fires (the Witch and Rice fires) were SDG&E “power line caused” and that a third fire (the Guejito fire) occurred when a wire securing a Cox Communications’ (Cox) fiber optic cable came into contact with an SDG&E power line “causing an arc and starting the fire.” A September 2008 staff report issued by the CPUC’s Consumer Protection and Safety Division, now known as the Safety and Enforcement Division, reached substantially the same conclusions as the Cal Fire reports, but also contended that the power lines involved in the Witch and Rice fire s and the lashing wire involved in the Guejito fire were not properly designed, constructed and maintained. Numerous parties sued SDG&E and Sempra Energy in San Diego County Superior Court seeking recovery of unspecified amounts of damages, including punit ive damages, from the three fires. They asserted various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without reg ard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines. SDG&E has resolved almost all of these lawsuits. One case remains subject to a damages-only trial, where the value of any compensatory damages resul ting from the fires will be determined. Two appeals are pending after judgment in the trial court. SDG&E does not expect additional plaintiffs to file lawsuits given the applicable statutes of limitation, but could receive additional settlement demands and damage estimates from the remaining plaintiff until the case is resolved. SDG&E establishes reserves for the wildfire litigation as information becomes available and amounts are estimable. SDG&E has concluded that it is probable that it will be 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, at March 31, 2016, Sempra Energy and SDG&E have recorded ass ets of $363 million in Other Regulatory Assets (long-term) on their Condensed Consolidated Balance Sheets, including $360 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. On September 25, 2015, SDG&E filed an application with the CPUC seeking authority to recove r these costs, as we discuss in Note 10. 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 r elated to CPUC-regulated operations was no longer probable or was less than currently estimated at March 31, 2016, the resulting after-tax charge against earnings would have been up to approximately $213 million. A failure to obtain substantial or full rec overy of these costs from customers, or any negative assessment of the likelihood of recovery, would likely have a material adverse effect on Sempra Energy’s and SDG&E’s results of operations and cash flows. We provide additional information about excess wildfire claims cost recovery and related CPUC actions in Note 14 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. Smart Meters Patent Infringement Lawsuit In October 2011, SDG&E was sued by a Texas design and manufacturing company in Federal District Court, Southern District of California, and later transferred to the Federal District Court, Western District of Oklahoma as part of Multi-District Litigation (MDL) proceedings, alleging that SDG&E’s recently installed smart meters infringed certain patents. The meters were purchased from a third party vendor that has agreed to defend and indemnify SDG&E. The lawsuit seeks injunctive relief and recovery of unspecified amounts of damages . The MDL court has finished ruling on pre-trial matters, and SDG&E expects that it will return the case to the Southern District of California. Lawsuit Against Mitsubishi Heavy Industries, Ltd. On July 18, 2013, SDG&E filed a lawsuit in the Superior Court of California in the County of San Diego against Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). The lawsuit seeks to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators MHI provided to the SONGS nuclear power plant. The lawsuit asserts a number of causes of action, including fraud, based on the repr esentations MHI made about its qualifications and ability to design generators free from defects of the kind that resulted in the permanent shutdown of the plant and further seeks to set aside the contractual limitation of damages that MHI has asserted. On July 24, 2013, MHI removed the lawsuit to the United States District Court for the Southern District of California and on August 8, 2013, MHI moved to stay the proceeding pending resolution of the dispute resolution process involving MHI and Edison arisin g from their contract for the purchase and sale of the steam generators. On October 16, 2013, Edison initiated an arbitration proceeding against MHI seeking damages stemming from the failure of the replacement steam generators. In late December 2013, MHI a nswered and filed a counterclaim against Edison. On March 14, 2014, MHI’s motion to stay the United States District Court proceeding was granted with instructions that require the parties to allow SDG&E to participate in the ongoing Edison/MHI arbitration. As a result, SDG&E participated in the arbitration as a claimant and respondent . The arbitration hearing concluded at the end of April 2016, and a decision could come as early as this year. Investment in Wind Farm In 2011, the CPUC and FERC approved SDG&E’s estimated $285 million tax equity investment in a wind farm project and its purchase of renewable energy credits from that project. SDG&E’s contractual obligations to both invest in the Rim Rock wind farm and to purchase renewable energy credits from the wind farm under the power purchase agreement are subject to the satisfaction of certain conditions which, if not achieved, would allow SDG&E to terminate the power purchase agreement and not make the investment. In December 2013, SDG&E received a closing notice from the project developer indicating that all such conditions had been met. SDG&E responded to the closing notice asserting that the contractual conditions had not been satisfied. On December 19, 2013, SDG&E filed a complaint against the project developer in San Diego Superior Court, asking that the court determine that SDG&E is entitled to terminate both the investment contract and the power purchase agreement due to the project de veloper’s failure to satisfy certain conditions. The project developer filed a separate complaint against SDG&E in Montana state court asking that court to determine that SDG&E breached the investment contract and the power purchase agreement, and asking f or several categories of relief, including requiring SDG&E to invest in the project, requiring SDG&E to continue performing under the power purchase agreement, and payment of damages. On January 27, 2014, the Montana court ordered SDG&E to continue making payments under the power purchase agreement pending a hearing on the project developer’s preliminary injunction motion. On March 14, 2014, SDG&E notified the project developer that the investment agreement expired by its own terms because a closing had no t occurred by that date. The project developer disputed SDG&E’s position. On March 28, 2014, SDG&E filed an amended complaint against the project developer in San Diego seeking damages and declaratory relief that SDG&E was entitled to terminate the pow er purchase agreement and to permit the investment agreement to expire. On April 25, 2014, the Montana court granted the project developer’s preliminary injunction motion to prevent SDG&E from terminating the power purchase agreement on the grounds that th e project developer would be irreparably harmed if the payments were not made while the parties’ respective rights were being determined in the litigation. The court did not rule on the merits of the parties’ claims. On July 18, 2014, the Montana Supreme C ourt determined that the parties’ contractual agreement to resolve any disputes in San Diego was mandatory, and ordered that the Montana action be dismissed. The San Diego court has scheduled a trial in May 2016. On February 11, 2016, SDG&E, the project de veloper and several of the project developer’s parent and affiliated entities entered into a conditional settlement agreement. Under the conditional settlement agreement, among other things, the parties agreed to terminate the tax equity investment arrange ment, continue the power purchase agreement for the wind farm generation, and release all claims against each other. The conditional settlement agreement will not result in rate increases to SDG&E customers or a material impact on Sempra Energy’s or SDG&E’ s financial condition, results of operations or cash flows. On February 16, 2016, SDG&E and the project developer filed a petition for approval of the settlement agreement with the CPUC. The conditional settlement agreement is not fully effective until app roved by the CPUC; SDG&E expects a decision in 2016. The May 2016 trial date set in the San Diego court has been stayed until the settlement is addressed by the CPUC. SoCalGas Aliso Canyon Natural Gas Storage Facility Gas Leak In October 2015, SoCalGas discovered a leak at one of its injection and withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility, located in the northern part of the San Fernando Valley in Los Angeles County. The Aliso Canyon facility has been operated by SoCalGas since 1972. SS25 is more than one mile away from and 1,200 feet above the closest homes. It is one of more than 100 injection and withdrawal wells at the storage facility. Stopping the Leak, and Local Community Mitigation Efforts . SoCalGas worked closely with several of the world’s leading experts to stop the leak, including planning and obtaining all necessary approvals for drilling relief wells. On February 18, 2016, the California Department of Conservation’s Division of Oil, Gas, and Geothermal Resourc es (DOGGR) confirmed that the well was permanently sealed. On December 24, 2015, by stipulation and court order, SoCalGas agreed to implement a formal plan for assisting residents in the nearby community to temporarily relocate, as well as to pay for addit ional overtime and costs associated with extra Los Angeles Police Department security patrols, among other things. SoCalGas has been providing temporary relocation support to residents in the nearby community who requested it before the well was permanentl y sealed. In addition, SoCalGas provided air filtration and purification systems to those residents in the nearby community requesting them. As a result of receiving the confirmation from DOGGR that SS25 was permanently sealed, SoCalGas started winding do wn its temporary relocation support in accordance with the terms of the formal relocation plan. Subject to certain exceptions, the period for temporary relocation support to residents who temporarily relocated to short-term housing, such as hotels, was sch eduled to end on February 25, 2016. This deadline was challenged by the County of Los Angeles (County), who expressed concern about potential lingering health effects and stated that they intended to perform indoor air testing. The California Superior Cour t issued an order extending such period for an additional 22 days for certain residents. On March 18, 2016, the County sought a further extension through the end of the litigation, which was denied, but the Superior Court stayed its order pending a potenti al appeal to the California Court of Appeal. Following an appeal by the County, on April 13, 2016, the Court of Appeal remanded the matter back to the California Superior Court for further consideration of the record and extended the relocation support ter m to at least April 27, 2016. The Superior Court set the matter for hearing on April 27, 2016, and gave the parties an opportunity to file supplemental briefing and evidence. On April 27, 2016, the Superior Court heard oral argument on the matter and ultim ately entered an order further extending the relocation support term pending the completion of the County’s indoor testing. The Superior Court set a case management conference on June 7, 2016, for further consideration of the relocation program, and instru cted the County and SoCalGas to file a joint update with the Court on May 31, 2016 regarding the status of the relocation support. To put the relocation dispute in perspective, on January 31, 2016, the Los Angeles County Department of Public Health (LA Cou nty DPH) stated, “The average levels of benzene and other trace chemicals that have been measured in the community are currently at or below levels seen elsewhere in the county, and do not pose an increase in the risk of short ‐ term or long ‐ term health effe cts.” Following the sealing of the well, included in its April 9, 2016 update to its Aliso Canyon webpage, the LA County DPH affirmed that “levels of chemicals of concern are now consistent with expected background levels for the Los Angeles air basin.” In seeking the extension of the relocation support term, the County has contended that indoor testing is required in order to determine whether it is safe for residents to return home. On March 24, 2016, the County released its indoor sampling work plan to t est approximately 100 houses for a broad range of chemicals, including volatile organic compounds, semi-volatile organic compounds, metals, and sulfur compounds in the air and on surfaces. These substances are commonly found in households at varying levels . We were informed that this testing was completed on April 8, 2016, and that the County is currently analyzing the results. The County has reported that it anticipates completing its analysis and releasing a final report by late May 2016. In mid-March 201 6, a third party engaged by SoCalGas conducted screening of indoor air for methane and mercaptans (odorants added to natural gas) in 71 houses in the Porter Ranch community near the Aliso Canyon storage facility. Based on this screening, no mercaptans were detected, and concentrations of methane were well below levels of concern as established by the California Environmental Protection Agency’s Department of Toxic Substances Control. The total costs incurred to remediate and stop the leak and to mitigate l ocal community impacts will be significant, and to the extent not covered by insurance, or if there were to be significant delays in receiving insurance recoveries, such costs could have a material adverse effect on SoCalGas ’ and Sempra Energy’s cash flows , financial condition and results of operations. Cost Estimates and Accounting Impact. At March 31, 2016, SoCalGas recorded estimated costs of $665 million related to the leak. Of this amount, approximately 70 percent is for the temporary relocation progra m and approximately 15 percent is for attempts to control the well, stop the leak, stop or reduce the emissions, and the estimated cost of the root cause analysis being conducted to determine the cause of the leak. The remaining amount includes estimated l egal costs necessary to defend litigation, the value of lost gas, the costs to mitigate the actual natural gas released, and other costs. SoCalGas made a commitment in December 2015 to mitigate the actual natural gas released and has been working on a plan to accomplish the mitigation. The $665 million represents management’s best estimate of these costs related to the leak. Of these costs, certain amounts have been paid and $302 million is recorded as Reserve for Aliso Canyon Costs at March 31, 2016 on SoC alGas ’ and Sempra Energy’s Condensed Consolidated Balance Sheets for amounts expected to be paid after March 31, 2016. We will refine these estimates as further information becomes available. SoCalGas ’ estimate of temporary relocation costs was primarily d etermined considering the current experience of temporary relocations through the hearing date of April 27, 2016 discussed above. The remainder of the reserve was estimated primarily based on work plans, the rate of cost accumulation and estimated duration of the various activities, or other estimates. Any differences in actual costs incurred will impact these estimates. Based on the order of the Superior Court on April 27, 2016, which scheduled the next hearing on June 7, 2016, for purposes of th is estimate we assume the period for temporary relocation support to residents who temporarily relocated has been extended to June 7, 2016. While such support period could end before June 7, 2016, due to the fact that temporary relocation support has been extended several times, there can be no assurance that future extensions will not be granted. The cost of the temporary relocation support is significant, and the costs of any further extensions of the relocation support term, which are not included in our estimate, could result in a material increase in our cost estimate. At March 31, 2016, we recorded the expected recovery of the costs described in the immediately preceding paragraph related to the leak (less insurance retentions) of $660 million as Insur ance Receivable for Aliso Canyon Costs on SoCalGas ’ and Sempra Energy’s Condensed Consolidated Balance Sheets. If we were to conclude that this receivable or a portion of it was no longer probable of recovery from insurers, some or all of this receivable w ould be charged against earnings. The above amounts do not include any damage awards, restitution, or any civil or criminal fines, costs or other penalties that may be imposed, as it is not possible to predict the outcome of any criminal or civil proceedin g or any administrative action in which such damage awards, restitution or civil or criminal fines, costs or other penalties could be imposed, and any such amounts, if awarded or imposed, cannot be estimated at this time. In addition, the above amounts do not include other potential costs that we currently do not anticipate incurring or we cannot reasonably estimate. On March 17, 2016, the CPUC issued a decision directing SoCalGas to establish a memorandum account to prospectively track its authorized reven ue requirement and all revenues that it receives for its normal, business-as-usual costs to own and operate the Aliso Canyon gas storage field. The CPUC will determine at a later time whether, and to what extent, the tracked revenues may be refunded to rat epayers. Pursuant to the CPUC’s decision, on March 24, 2016, SoCalGas filed an advice letter requesting to establish a memorandum account to track all business-as-usual costs to own and operate the Aliso Canyon storage field, which has been protested by TU RN and SCGC. On April 22, 2016, the CPUC’s Energy Division issued a suspension notice for SoCalGas ’ advice letter citing the need for additional time for staff review. This suspension period could last up to 120 days. Insurance. We have at least four kind s of insurance policies that provide in excess of $1 billion in insurance coverage. We cannot predict all of the potential categories of costs or the total amount of costs that we may incur as a result of the leak. In reviewing each of our policies, and su bject to various policy limits, exclusions and conditions, based upon what we know as of the filing date of this report, we believe that our insurance policies collectively should cover the following categories of costs: the costs incurred for temporary re location, costs to address the leak and stop or reduce emissions, the root cause analysis being conducted to determine the cause of the leak, the value of lost natural gas and estimated costs to mitigate the actual natural gas released, the costs associate d with litigation and claims by nearby residents and businesses, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have been communicating with our insurance carriers and intend to pursue the full extent of our insurance coverage. There can be no assurance that we will be successful in obtaining insurance coverage for these costs under the applicable policies, and to the extent we are not successful, it could result in a material charge against the earnin gs of SoCalGas and Sempra Energy. Our estimate at March 31, 2016 of $665 million of certain costs in connection with the Aliso Canyon storage facility leak may rise significantly as more information becomes available, and to the extent not covered by insur ance, or if there were to be significant delays in receiving insurance recoveries, such costs could have a material adverse effect on Sempra Energy’s and SoCalGas ’ cash flows, financial condition and results of operations. In addition, the costs not includ ed in the $665 million estimate could be material, and to the extent not covered by insurance, could have a material adverse effect on Sempra Energy’s and SoCalGas ’ cash flows, financial condition and results of operations. Governmental Investigations and Civil and Criminal Litigation. Various governmental agencies, including the DOGGR, LA County DPH, South Coast Air Quality Management District (SCAQMD), California Air Resources Board (CARB), California Division of Occupational Safety and Health (DOSH), CPU C, Pipeline and Hazardous Materials Safety Administration (PHMSA), U.S. Environmental Protection Agency (EPA), Los Angeles District Attorney’s Office and California Attorney General’s Office, are investigating this incident. On January 25, 2016, the DOGGR and CPUC selected Blade Energy Partners to conduct an independent analysis under their supervision and to be funded by SoCalGas to investigate the technical root cause of the Aliso Canyon gas leak. We expect the root cause analysis to be completed in late 2016 or early 2017, but the timing is dependent on the DOGGR and the CPUC. As of April 28, 2016, 138 lawsuits have been filed (134 in Los Angeles County Superior Court, 2 in San Diego County Superior Court, and 2 in the United States District Court for the Southern District of California) against SoCalGas , some of which have also named Sempra Energy, and, in derivative and securities law claims on behalf of Sempra Energy and/or SoCalGas , certain officers and directors of Sempra Energy and/or SoCalGas . These various lawsuits assert causes of action for negligence, strict liability, property damage, fraud, nuisance, trespass, breach of fiduciary duties, and violation of federal securities laws, among other things, and additional litigation may be filed against us in the future related to this incident. Many of these complaints seek class action status, compensatory and punitive damages, injunctive relief, and attorneys’ fees. The Los Angeles City Attorney and Los Angeles County Counsel have also filed a complai nt on behalf of the people of the State of California against SoCalGas for public nuisance and violation of the California Unfair Competition Law. The California Attorney General , acting in her independent capacity and on behalf of the people of the State of California and the CARB, joined this lawsuit. The complaint, which as amended includes the California Attorney General, adds allegations of violations of California Health and Safety Code sections 41700, prohibiting discharge of air contaminants that ca use annoyance to the public, and 25510, requiring reporting of the release of hazardous material, as well as California Government Code section 12607 for equitable relief for the protection of natural resources. The complaint seeks an order for injunctive relief, to abate the public nuisance, and to impose civil penalties. The SCAQMD also filed a complaint against SoCalGas seeking civil penalties for alleged violations of several nuisance-related statutory provisions arising from the leak and delays in stop ping the leak. That suit seeks up to $250,000 in civil penalties for each day the violations occurred. On February 2, 2016, the Los Angeles District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas seeking penalties and other reme dies for alleged failure to provide timely notice of the leak pursuant to California Health and Safety Code section 25510(a), Los Angeles County Code section 12.56.030, and Title 19 California Code of Regulations section 2703(a), and for violating Californ ia Health and Safety Code section 41700 prohibiting discharge of air contaminants that cause annoyance to the public. The costs of defending against these civil and criminal lawsuits and cooperating with these investigations, and any damages, restitution, and civil and criminal fines, costs and other penalties, if awarded or imposed, could be significant and to the extent not covered by insurance, or if there were to be significant delays in receiving insurance recoveries, could have a material adverse effe ct on SoCalGas ’ and Sempra Energy’s cash flows, financial condition and results of operations. Governmental Orders, Additional Regulation and Reliability . On January 6, 2016, the Governor of the State of California issued the Governor’s Order proclaiming a state of emergency to exist in Los Angeles County due to the natural gas leak at the Aliso Canyon facility. The Governor’s Order implemented orders to stop the leak and implements various other orders with respect to: Protecting Public Health and Safety : State agencies will: continue the prohibition against SoCalGas injecting any gas into the Aliso Canyon storage facility until a comprehensive review, utilizing independent experts, of the safety of the storage wells and the air quality of the surrounding c ommunity is completed; expand real-time monitoring of emissions in the surrounding community; convene an independent panel of scientific and medical experts to review public health concerns stemming from the natural gas leak and evaluate whether additional measures are needed to protect public health; and take all actions necessary to ensure the continued reliability of natural gas and electricity supplies in the coming months during the moratorium on gas injections into the Aliso Canyon storage facility. E nsuring Accountability : The CPUC will ensure that SoCalGas covers costs related to the natural gas leak and its response, while protecting ratepayers; and CARB will develop a program to fully mitigate the leak’s emissions of methane by March 31, 2016, with such program to be funded by SoCalGas . Strengthening Over sight : The DOGGR will promulgate emergency regulations for gas storage facility operators throughout the state, requiring: at least daily inspection of gas storage well heads using gas leak detection technology such as infrared imaging; ongoing verificatio n of the mechanical integrity of all gas storage wells; ongoing measurement of annular gas pressure or annular gas flow within wells; regular testing of all safety valves used in wells; minimum and maximum pressure limits for each gas storage facility in t he state; and a comprehensive risk management plan for each facility that evaluates and prepares for risks, including corrosion potential of pipes and equipment. Additionally, the DOGGR, the CPUC, the CARB and the California Energy Commission will submit t o the Governor’s Office a report that assesses the long-term viability of natural gas storage facilities in California. SoCalGas made a commitment in December 2015 to mitigate the actual natural gas released and has been working on a plan to accomplish the mitigation. On March 31, 2016, pursuant to the Governor’s Order, the CARB issued its Aliso Canyon Methane Leak Climate Impacts Mitigation Program, which sets forth its recommended approach to achieve full mitigation of the emissions from the Aliso Canyon natural gas leak. The CARB program preliminarily assumes that the leak released approximately 100,000 metric tons of methane. It states that full mitigation requires that the program generate reductions in short-lived climate pollutants and other greenhous e gases at least equivalent to that amount and that the appropriate global warming potential to be used in deriving the amount of reductions required is a 20-year term rather than the 100-year term the CARB and other state and federal agencies use in regul ating emissions, resulting in a target of approximately 8,000,000 metric tons of carbon dioxide equivalent. CARB’s program also requires all of the mitigation to occur in California over the next five to ten years without the use of allowances or offsets. We have not agreed to this proposed formulation and continue to work with CARB on the mitigation plan. On January 23, 2016, the Hearing Board of the SCAQMD ordered SoCalGas to, among other things: stop all injections of natural gas except as directed by th e CPUC, withdraw the maximum amount of natural gas feasible in a contained and safe manner, subject to orders of the CPUC, and permanently seal the well once the leak has ceased; continuously monitor the well site with infrared cameras until 30 days after the leak has ceased; provide the public with daily air monitoring data collected by SoCalGas ; provide the SCAQMD with certain natural gas injection, withdrawal and emissions data from the Aliso Canyon facility; prepare and submit to the SCAQMD for its appr oval an enhanced leak detection and reporting well inspection program for the Aliso Canyon facility; provide the SCAQMD with funding to develop a continuous air monitoring plan for the Aliso Canyon facility and the nearby schools and community; prepare and submit to the SCAQMD for its approval an air quality notification plan to provide notice to SCAQMD, other public agencies and the nearby community in the event of a future reportable release; and provide the SCAQMD with funding to conduct an independent h ealth study on the potential impacts of exposure on the constituents of the natural gas released from the facility, as well as any odor suppressants used to mitigate odors from the leaking well. On April 1, 2016, the Secretary of the U.S. Department of Energy (DOE) and PHMSA jointly announced the formation of an Interagency Task Force on Natural Gas Storage Safety in response to the leak at Aliso Canyon to assess and make recommendations on best pra ctices, response plans and safe operation of gas storage facilities. PHMSA has indicated plans to initiate additional regulatory actions on natural gas storage nationally. Each of the DOGGR, SCAQMD, EPA and CARB has commenced separate rulemaking proceeding s to adopt further regulations covering natural gas storage facilities and injection we

SEGMENT INFORMATION

SEGMENT INFORMATION	3 Months Ended
	Mar. 31, 2016
Segment [Abstract]
Segment Information	NO TE 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 develops, owns and operates, or holds interests in, electric transmission, distribution and gen eration infrastructure in Chile and Peru. Sempra Mexico develops, owns and operates, or holds interests in, natural gas transmission pipelines and propane and ethane systems, a natural gas distribution utility, electric generation facilities (including win d), a terminal for the import of LNG, and marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. In February 2016, management approved a plan to market and sell the Termoeléctrica de Mexicali natural gas-fired powe r plant located in Mexicali, Baja California , as discussed in Note 3 . 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 se rve wholesale electricity markets in the United States. Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities, natural gas distribution utilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. Sempra Natural Gas also owned and operated the Mesquite Power plant, a natural gas-fired electric generation asset, the remaining 625-MW block of which was sold in April 2015. Sempra South American U tilities 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 r eported 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 a nd 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, d epending 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 Conden sed 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, 2016 2015 REVENUES SDG&E $ 991 38 % $ 966 36 % SoCalGas 1,033 40 1,048 39 Sempra South American Utilities 400 15 389 15 Sempra Mexico 138 5 163 6 Sempra Renewables 7 ― 8 ― Sempra Natural Gas 130 5 197 7 Intersegment revenues(1) (77) (3) (89) (3) Total $ 2,622 100 % $ 2,682 100 % INTEREST EXPENSE SDG&E $ 48 $ 52 SoCalGas 22 19 Sempra South American Utilities 9 5 Sempra Mexico 4 5 Sempra Renewables ― 1 Sempra Natural Gas 12 21 All other 72 63 Intercompany eliminations (24) (32) Total $ 143 $ 134 INTEREST INCOME Sempra South American Utilities $ 5 $ 4 Sempra Mexico 2 2 Sempra Renewables 1 ― Sempra Natural Gas 16 19 Intercompany eliminations (18) (18) Total $ 6 $ 7 DEPRECIATION AND AMORTIZATION SDG&E $ 159 49 % $ 145 48 % SoCalGas 122 37 113 37 Sempra South American Utilities 13 4 13 4 Sempra Mexico 17 5 17 6 Sempra Renewables 1 ― 2 1 Sempra Natural Gas 13 4 12 4 All other 3 1 1 ― Total $ 328 100 % $ 303 100 % INCOME TAX EXPENSE (BENEFIT) SDG&E $ 72 $ 88 SoCalGas 87 95 Sempra South American Utilities 14 16 Sempra Mexico 41 8 Sempra Renewables (12) (17) Sempra Natural Gas (25) 2 All other (35) (29) Total $ 142 $ 163 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended March 31, 2016 2015 EQUITY EARNINGS (LOSSES) Earnings (losses) recorded before tax: Sempra Renewables $ 7 $ 2 Sempra Natural Gas (29) 17 Total $ (22) $ 19 Earnings (losses) recorded net of tax: Sempra South American Utilities $ 2 $ (1) Sempra Mexico 15 16 Total $ 17 $ 15 EARNINGS (LOSSES) SDG&E $ 129 40 % $ 147 34 % SoCalGas(2) 195 61 214 49 Sempra South American Utilities 38 12 41 9 Sempra Mexico 17 5 47 11 Sempra Renewables 13 4 13 3 Sempra Natural Gas (36) (11) 2 ― All other (37) (11) (27) (6) Total $ 319 100 % $ 437 100 % EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 329 34 % $ 355 46 % SoCalGas 340 35 315 40 Sempra South American Utilities 43 4 31 4 Sempra Mexico 40 4 55 7 Sempra Renewables 181 19 3 1 Sempra Natural Gas 35 4 10 1 All other 3 ― 11 1 Total $ 971 100 % $ 780 100 % March 31, 2016 December 31, 2015 ASSETS SDG&E $ 16,625 40 % $ 16,515 40 % SoCalGas 12,427 30 12,104 29 Sempra South American Utilities 3,434 8 3,235 8 Sempra Mexico 3,843 9 3,783 9 Sempra Renewables 1,454 3 1,441 4 Sempra Natural Gas 5,395 13 5,566 13 All other 741 2 734 2 Intersegment receivables (2,084) (5) (2,228) (5) Total $ 41,835 100 % $ 41,150 100 % EQUITY METHOD AND OTHER INVESTMENTS Sempra South American Utilities $ (2) $ (4) Sempra Mexico 522 519 Sempra Renewables 823 855 Sempra Natural Gas 1,308 1,460 All other 76 75 Total $ 2,727 $ 2,905 (1) Revenues for reportable segments include intersegment revenues of $3 million, $17 million, $27 million and $30 million for the three months ended March 31, 2016 and $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively. (2) After preferred dividends.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	3 Months Ended
	Mar. 31, 2016
Subsequent Events (Abstract)
Subsequent Events	NOTE 13. SUBSEQUENT EVENT SEMPRA NATURAL GAS In April 2016, Sempra Natural Gas signed a definitive agreement to sell the parent company of Mobile Gas and Willmut Gas. We expect to receive cash proceeds of approximately $323 million, subject to normal adjustments at closing, and the buyer will assume existing debt of approximately $67 million. In April 2016, we reclassified the assets and liabilities of Mobile Gas and Willmut Gas to held for sale. The transaction is subject to customary regulatory approvals, and we expect the sale to close in 2016.

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES (Policies)	3 Months Ended
	Mar. 31, 2016
Significant Accounting Policies
New Accounting Standards Policy	N OTE 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 2015-14, “Revenue from Contracts with Customers: Deferral of the Effective Date,” ASU 2016-08, “Revenue from Contracts with Customers: Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” and ASU 2016-10, “Revenue from Contracts with Customers: Identifying Performance Obligations and Lice nsing”: ASU 2014-09 provides accounting guidance for revenue 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 recogn ition 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 m odified retrospective approach. Amending ASU 2014-09, ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations and ASU 2016-10 clarifies the determination of whether a good or service is separately identifiable from other promises and revenue recognition related to licenses of intellectual property. ASU 2015-14 defers the effective date of ASU 2014-09 by one year for all entities and permits early adoption on a limited basis. For public entities, ASU 2014-09 is effective fo r fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We are currently evaluating the effect of the standards on our ongoing financial reporting and have not yet selected the year in which we will adopt the standards or our transition method . ASU 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities”: In addition to the presentation and dis closure requirements for financial instruments, ASU 2016-01 requires entities to measure equity investments not accounted for under the equity method at fair value and recognize changes in fair value in net income. Entities will no longer be able to use th e cost method of accounting for equity securities. However, for equity investments without readily determinable fair values, entities may elect a measurement alternative that will allow those investments to be recorded at cost, less impairment, and adjuste d for subsequent observable price changes. Upon adoption, entities must record a cumulative-effect adjustment to the balance sheet as of the beginning of the first reporting period in which the standard is adopted. The guidance on equity securities without readily determinable fair value will be applied prospectively to all equity investments that exist as of the date of adoption of the standard. For public entities, ASU 2016-01 is effective for fiscal years beginning after December 15, 2017. We will adopt ASU 2016-01 on January 1, 2018 as required and do not expect it to materially affect our financial condition, results of operations or cash flows. We will make the required changes to our disclosures upon adoption. ASU 2016-02, “Leases”: ASU 2016-02 requi res entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to exclude from the balance sheet those leases with a maximum possible term o f less than 12 months. For lessees, a lease is classified as finance or operating and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP , other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public e ntities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes optional practical expedients that may be elected, which would allow entities to continue to account for leases that commen ce before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases at the reporting date. We are currently evaluating the effect of the standard on our ongoing financial reporting, and have not yet selected the year in which we will adopt the standard . ASU 2016-05, “Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships”: ASU 2016-05 provides clarification that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge ac counting criteria continue to be met. ASU 2016-05 may be adopted prospectively or using a modified retrospective approach. We prospectively adopted ASU 2016-05 on January 1, 2016 and it did not affect our financial condition, results of operations or cash flows. ASU 2016-09 , “ Improvements to Employee Share-Based Payment Accounting” : ASU 2016-09 is intended to simplify several aspects of the accounting for employee share-based payment transactions . Under ASU 2016-09, excess tax benefits and tax deficiencies are required to be recorded in earnings, and the requirement to reclassify excess tax benefits from operating to financing activities on the statement of cash flows has been eliminated. ASU 2016-09 also allows entities to withhold taxes up to the maximum i ndividual statutory tax rate without resulting in liability classification of the award and clarifies that cash payments made to taxi ng authorities in connection with withheld shares should be classified as financing activities in the statement of cash flo ws. Additionally, the standard provides for an accounting policy election to either continue to estimate forfeitures or account for them as they occur. For public entities, ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, with e arly adoption permitted, and is effective for interim periods in the year of adoption. We are currently evaluating the full effect of the standard on our ongoing financial reporting, and have not yet concluded as to whether we will elect an early adoption. If we early adopt in 2016, we will recognize a $34 million tax benefit in earnings, which is currently recorded in Shareholders’ Equity, related to the three months ended March 31, 2016, and a benefit to retained earnings as of January 1, 2016 of approximately $10 7 million, both associated with the provision in ASU 2016-09 to recognize all excess tax benefits related to share-based compensation.
Consolidation Variable Interest Entity Policy	VARIABLE INTEREST ENTITIES 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 compre hensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income (Loss).
Earnings Per Share Policy	Basic 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 c ompensation expense on the stock options. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. The calculation of dilutive common stock equivalents excludes options for which the exercise price on common stock was greater than the average market price during the period (out-of-the-money options). The dilution from unvested restricted stock awards (RSAs) and restricted stoc k 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 re lated 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 during or after 2015) or four-year performance periods based on Sempra Energy’s total return to shareholders relative to that of specified market indices (Total Shareholder Return or TSR RSUs) or based on the compound annual growth rate of Sempra Energy’s EPS (EPS RSUs). The comparative market indices for the TSR RSUs are the Standard & Poor’s (S&P) 500 Utilities Index and the S&P 500 Index. We primarily use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies to develop our EPS RSU targ ets. 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 Sempr a 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 o n shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate. Our RSAs , which are solely service-based, and those RSUs that are service-based or issued in connection with certain other performance goals represent the right to receive up to 1.0 share if the service requirements or certain other vesting conditions are met. These RSAs and RSUs have the same dividend equivalent rights as the performance-based RSUs described above . We include RSAs and these RSUs in potential dilutive shares at 100 percent , subject to the application of the treasury stock method. We includ e our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method.
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 is f actored into the forecasted effective tax rate , and the impact is recognized proportionately over the year. Items that cannot be reliably forecasted (e.g., resolution of prior years’ income tax items, remeasurement of deferred tax asset valuation allowances, Mexi can 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 variabili ty in income tax expense. Sempra Energy’s income tax expense in the three months ended March 31, 2016 includes deferred income tax expense related to Sempra Mexico’s power plant held for sale, as we discuss in Note 3. For SDG&E and SoCalGas , the California Public Utilities Commiss ion (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 treatm ent: 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 pl ant assets state income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico has similar flow-through treatment.
Fair Value Measurement Policy	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 affec t 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 un der “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, 2016 and December 31, 2015 in the tables below include the following: Nuclear decom missioning 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). For commodity contracts, interest rate derivatives and foreign exchange instrument s, 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 obse rvable, 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). Level 3 recurring items rel ate to CRRs and long-term, fixed-price electricity positions at SDG&E, as we discuss below under “Level 3 Information.” Rabbi Trust investments include marketable securities that we value using a market approach based on closing prices reported in the act ive market in which the identical security is traded (Level 1). These i nvestments in marketable securities were negligible at both March 31, 2016 and December 31, 2015. 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 and long-term, fixed-price electricity positions on an ongoing basis. Inputs used to determine the fair value of CRRs and fixed-price electricity positions are reviewed and compared with market conditions to determine reasonableness. SDG&E expects all costs related to these instruments to be recoverable throug h 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 year. The impact associated with discounting is negligible. Because auction prices are a less observa ble input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. From January 1, 2016 to December 31, 2016, the auction prices range from $(24) per MWh to $10 per M Wh at a given location, and from January 1, 2015 to December 31, 2015, the auction prices ranged from $(16) per MWh to $8 per MWh at a given location. Positive values between two locations represent expected future reductions in congestion costs, whereas n egative 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 (lowe r) fair value measurement. We summarize CRR volumes in Note 7. Long-term, fixed-price electricity p ositions that are valued using significant unobservable data are classified as Level 3 because the contract terms relate to a delivery location or tenor for which observable market rate information is not available. The fair value of the net electricity positions classified as Level 3 is derived from a discounted cash flow model using market electricity forward price inputs. At March 31, 2016, these electricit y forward prices range from $15.85 per MWh to $57.43 per MWh. A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. We summarize long-term, fixed-price electricity position volumes in Note 7. Realized gains and losses associated with CRRs and long-term electricity positions, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the 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, current amounts due to/from unconsolidated affiliates, dividends and accounts payable, short-term debt and customer deposits) approximate their carrying amounts because of the short-term nature of these instruments. Investments in life insurance contracts that we hold in support of our Supplemental Executive Retirement, Cash Balance Restoration and Deferre d Compensation Plans are c arried at cash surrender values, which represent the amount of cash that could be realized under the contracts. We base the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock on a market approach using quoted market prices for identical or similar securities in thinly-traded markets (Level 2). We value other noncurrent amounts due from unconsolidated affiliates of Sempra South American Utilities using a perpetuity approach based on the obligation’s fixed interest rate, the absence of a stated maturity date and a discount rate reflecting local borrowing c osts (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3).
Derivatives Policy	We use derivative instruments primarily to manage exposures arising in the normal course of business. Our principal exposures are commodity market risk, benchmark interest rate risk and foreign exchange rate exposures. Our use of derivatives for these risks is integrated into the economic management of our anticipated revenues, anticipated expenses, assets and liabilities. Derivatives may be effective in mitigating these risks (1) that could lead to declines i n anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated reven ues, expenses, assets or liabilities that are not included in the tables below. In certain cases, we apply the normal purchase or sale exception to derivative instruments and have other commodity contracts that are not derivatives. These contracts are not recorded at fair value and are therefore excluded from the disclosures below. In all other cases, we record derivatives at fair value on the Condensed Consolidated Balance Sheets. We designate each derivative as (1) a cash flow hedge, (2) a fair value hedge, or (3) u ndesignated. 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 offse t 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 Conde nsed Consolid ated Statements of Cash Flows. HEDGE ACCOUNTING We may designate a derivative as a cash flow hedging instrument if it effectively converts anticipated cash flows associated with revenues or expenses to a fixed dollar amount. We may utilize cash flow hedge 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 the future cash flows of a given revenue or expense item may vary, and other criteria. We may designate an interest rate derivative as a fair value hedging instrument if it effectively converts our own debt from a fixed interest rate to a variable rate. The co mbination 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 inst rument 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, as follows: The California Utilities use energy derivatives, both natural gas and electricity, for the benefit of customers, with the objective of managing price risk and basis risks, and stabilizing and lowering natural gas and electricity costs. These derivatives include fixed price natural gas and electricity positions, options, and basis risk instruments, which are either exchang e-traded or over-the-counter financial instruments, or bilateral physical transactions. This activity is governed by risk management and transacting activity plans that have been filed with and approved by the CPUC. Natural gas and electricity derivative a ctivities 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 Powe r 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 loss es do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power 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 S empra 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 derivati ves, 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, incl uding 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 phy sical locations of contractual obligation s and assets , such as natural gas purchases and sales . INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We 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. Interest rate derivati ves are generally accounted for as hedges, and although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate deriva tives may not be recovered from customers as timely as described above with regard to energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate ch anges. FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and joint ventures. These cash flow hedges exchange our Mexican-peso denominated principal and interest payments into the U.S. dollar and swap Mexican variable interest rates for U.S. fixed interest rates. We are also exposed to exchange rate movements at our Mexican subsidiaries and joint ventures, which have U.S. dollar denominated cash balances, receivables, payables and debt (monetary asset s and liabilities) that give rise to Mexican currency exchange rate movements for Mexican income tax purposes. They also have deferred income tax assets and liabilities denominated in the Mexican peso, which must be translated to U.S. dollars for financial reporting purposes. In addition, monetary assets and liabilities and certain nonmonetary assets and liabilities are adjusted for Mexican inflation for Mexican income tax purposes. We utilize foreign currency derivatives as a means to manage the risk of ex posure to significant fluctuations in our income tax expense and equity earnings from these impacts. In January 2016, we entered into foreign currency derivatives with a notional amount totaling $550 million.
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, d epending 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, 2016
Investments [Abstract]
Assets Held for Sale Table	ASSETS HELD FOR SALE, POWER PLANT (Dollars in millions) March 31, 2016 Cash and cash equivalents $ 1 Inventories 8 Other current assets 29 Other assets 15 Property, plant and equipment, net 250 Total assets held for sale $ 303 Accounts payable $ 1 Other current liabilities 7 Deferred income taxes 16 Asset retirement obligations 4 Other liabilities 15 Total liabilities held for sale(1) $ 43 (1) Included in Other Current Liabilities on the Sempra Energy Condensed Consolidated Balance Sheet.

OTHER FINANCIAL DATA (Tables)

OTHER FINANCIAL DATA (Tables)	3 Months Ended
	Mar. 31, 2016
Disclosure Text Block [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, 2016 2015 2016 2015 Service cost $ 28 $ 30 $ 5 $ 7 Interest cost 40 39 11 12 Expected return on assets (42) (44) (17) (17) Amortization of: Prior service cost (credit) 3 3 ― (1) Actuarial loss 6 8 ― ― Regulatory adjustment (28) (29) 2 ― Total net periodic benefit cost $ 7 $ 7 $ 1 $ 1 NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension benefits Other postretirement benefits Three months ended March 31, 2016 2015 2016 2015 Service cost $ 7 $ 8 $ 1 $ 2 Interest cost 10 10 2 2 Expected return on assets (12) (14) (3) (3) Amortization of: Prior service cost ― ― 1 1 Actuarial loss 3 2 ― ― Regulatory adjustment (7) (5) (1) (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, 2016 2015 2016 2015 Service cost $ 17 $ 19 $ 4 $ 5 Interest cost 25 25 8 9 Expected return on assets (25) (27) (14) (14) Amortization of: Prior service cost (credit) 2 2 (1) (2) Actuarial loss 3 5 ― ― Regulatory adjustment (21) (24) 3 2 Total net periodic benefit cost $ 1 $ ― $ ― $ ―
Contributions to Benefit Plans Table	BENEFIT PLAN CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Contributions through March 31, 2016: Pension plans $ 15 $ 2 $ ― Other postretirement benefit plans 1 ― ― Total expected contributions in 2016: Pension plans $ 123 $ 4 $ 77 Other postretirement benefit plans 6 2 1
Earnings Per Share Computations Table	EARNINGS PER SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Three months ended March 31, 2016 2015 Numerator: Earnings/Income attributable to common shares $ 319 $ 437 Denominator: Weighted-average common shares outstanding for basic EPS(1) 249,734 247,722 Dilutive effect of stock options, restricted stock awards and restricted stock units 1,678 3,484 Weighted-average common shares outstanding for diluted EPS 251,412 251,206 Earnings per share: Basic $ 1.28 $ 1.76 Diluted $ 1.27 $ 1.74 (1) Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.
Capitalized Financing Costs Table	CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended March 31, 2016 2015 Sempra Energy Consolidated: AFUDC related to debt $ 7 $ 6 AFUDC related to equity 27 27 Other capitalized interest 18 17 Total Sempra Energy Consolidated $ 52 $ 50 SDG&E: AFUDC related to debt $ 4 $ 3 AFUDC related to equity 11 8 Total SDG&E $ 15 $ 11 SoCalGas: AFUDC related to debt $ 3 $ 3 AFUDC related to equity 10 9 Total SoCalGas $ 13 $ 12
Changes in Components of Accumulated Comprehensive Income Table	CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Three months ended March 31, 2016 and 2015 Foreign Total currency Pension and other accumulated other translation Financial postretirement comprehensive adjustments instruments benefits income (loss) 2016: Balance as of December 31, 2015 $ (582) $ (137) $ (87) $ (806) Other comprehensive income (loss) before reclassifications 68 (82) ― (14) Amounts reclassified from accumulated other comprehensive income ― (2) 1 (1) Net other comprehensive income (loss) 68 (84) 1 (15) Balance as of March 31, 2016 $ (514) $ (221) $ (86) $ (821) 2015: Balance as of December 31, 2014 $ (322) $ (90) $ (85) $ (497) Other comprehensive loss before reclassifications (62) (54) ― (116) Amounts reclassified from accumulated other comprehensive income ― (1) 1 ― Net other comprehensive (loss) income (62) (55) 1 (116) Balance as of March 31, 2015 $ (384) $ (145) $ (84) $ (613) (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) Amounts reclassified Details about accumulated from accumulated other Affected line item on Condensed other comprehensive income (loss) components comprehensive income (loss) Consolidated Statements of Operations Three months ended March 31, 2016 2015 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments $ 4 $ 6 Interest Expense Interest rate instruments 3 3 Equity (Losses) Earnings, Before Income Tax Interest rate and foreign exchange instruments 1 ― Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery (7) (7) Revenues: Energy-Related Businesses Total before income tax 1 2 ― 1 Income Tax Expense Net of income tax 1 3 (3) (4) Earnings Attributable to Noncontrolling Interests $ (2) $ (1) Pension and other postretirement benefits: Amortization of actuarial loss $ 2 $ 2 See note (1) below (1) (1) Income Tax Expense Net of income tax $ 1 $ 1 Total reclassifications for the period, net of tax $ (1) $ ― SDG&E: Financial instruments: Interest rate instruments $ 3 $ 3 Interest Expense (3) (3) Earnings Attributable to Noncontrolling Interest Total reclassifications for the period $ ― $ ― (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(1) equity Balance at December 31, 2015 $ 11,809 $ 770 $ 12,579 Comprehensive income 304 11 315 Share-based compensation expense 13 ― 13 Common stock dividends declared (188) ― (188) Issuances of common stock 28 ― 28 Repurchases of common stock (54) ― (54) Tax benefit related to share-based compensation 34 ― 34 Distributions to noncontrolling interests ― (3) (3) Balance at March 31, 2016 $ 11,946 $ 778 $ 12,724 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) Issuances of common stock 30 ― 30 Repurchases 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 (1) Noncontrolling interests include the preferred stock of SoCalGas and other noncontrolling interests as listed in the table below under "Other Noncontrolling Interests." 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, 2015 $ 5,223 $ 53 $ 5,276 Comprehensive income (loss) 129 (1) 128 Distributions to noncontrolling interest ― (1) (1) Balance at March 31, 2016 $ 5,352 $ 51 $ 5,403 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
Amounts Due To and From Affiliates at SDG&E and SoCalGas Table	AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) March 31, 2016 December 31, 2015 Sempra Energy Consolidated: Total due from various unconsolidated affiliates - current $ 7 $ 6 Sempra South American Utilities(1): Eletrans S.A. and Eletrans II S.A.: 4% Note(2) $ 76 $ 72 Other related party receivables 1 ― Sempra Mexico(1): Affiliate of joint venture with PEMEX: Note due November 13, 2017(3) 3 3 Note due November 14, 2018(3) 42 42 Note due November 14, 2018(3) 34 34 Note due November 14, 2018(3) 8 8 Energía Sierra Juárez: Note due June 15, 2018(4) 17 24 Sempra Natural Gas: Cameron LNG JV 5 3 Total due from unconsolidated affiliates - noncurrent $ 186 $ 186 Total due to various unconsolidated affiliates - current $ (13) $ (14) SDG&E: Total due from various unconsolidated affiliates - current $ 1 $ 1 Sempra Energy $ (35) $ (34) SoCalGas (8) (13) Affiliate (6) (8) Total due to unconsolidated affiliates - current $ (49) $ (55) Income taxes due (to) from Sempra Energy(5) $ (32) $ 28 SoCalGas: Sempra Energy(6) $ ― $ 35 SDG&E 8 13 Total due from unconsolidated affiliates - current $ 8 $ 48 Sempra Energy $ (34) $ ― Total due to unconsolidated affiliate - current $ (34) $ ― Income taxes due (to) from Sempra Energy(5) $ (23) $ 1 (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. and Eletrans II S.A., both of which are joint ventures at Chilquinta Energía. (3) U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.94 percent at March 31, 2016), 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 (6.81 percent at March 31, 2016), to finance the first phase of the Energía Sierra Juárez wind project. (5) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and are allocated income tax expense from Sempra Energy in an amount equal to that which would result from each company having always filed a separate return. (6) At December 31, 2015, net receivable included outstanding advances to Sempra Energy of $50 million at an interest rate of 0.11 percent.
Revenues From Unconsolidated Affiliates at SDG&E and SoCalGas Table	REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended March 31, 2016 2015 REVENUES Sempra Energy Consolidated $ 5 $ 8 SDG&E 3 3 SoCalGas 17 19 COST OF SALES Sempra Energy Consolidated $ 30 $ 19 SDG&E 14 5
Other Income and Expense Table	OTHER INCOME, NET (Dollars in millions) Three months ended March 31, 2016 2015 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 27 $ 27 Investment gains(1) 10 9 Electrical infrastructure relocation income(2) 1 ― Gains on interest rate and foreign exchange instruments, net 3 ― Sale of other investments 1 ― Foreign currency transaction losses (2) (1) Regulatory interest, net(3) 2 1 Sundry, net 7 3 Total $ 49 $ 39 SDG&E: Allowance for equity funds used during construction $ 11 $ 8 Regulatory interest, net(3) 2 1 Sundry, net 1 ― Total $ 14 $ 9 SoCalGas: Allowance for equity funds used during construction $ 10 $ 9 Sundry, net ― (1) Total $ 10 $ 8 (1) Represents investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans. (2) Income at Luz del Sur associated with the relocation of electrical infrastructure. (3) Interest on regulatory balancing accounts.
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, 2016 2015 Sempra Energy Consolidated $ 142 31 % $ 163 27 % SDG&E 72 36 88 37 SoCalGas 87 31 95 31
Variable Interest Entity Table	AMOUNTS ASSOCIATED WITH OTAY MESA VIE (Dollars in millions) Three months ended March 31, 2016 2015 Operating expenses Cost of electric fuel and purchased power $ (17) $ (18) Operation and maintenance 4 4 Depreciation and amortization 7 6 Total operating expenses (6) (8) Operating income 6 8 Interest expense (5) (4) Income before income taxes/Net income 1 4 Earnings attributable to noncontrolling interest (1) (4) 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, 2016 2015 2016 2015 SDG&E: Otay Mesa VIE 100 % 100 % $ 51 $ 53 Sempra South American Utilities: Chilquinta Energía subsidiaries(1) 23.5 – 43.4 23.5 – 43.4 22 21 Luz del Sur 16.4 16.4 171 164 Tecsur 9.8 9.8 4 4 Sempra Mexico: IEnova 18.9 18.9 470 468 Sempra Natural Gas: Bay Gas Storage Company, Ltd. 9.1 9.1 25 25 Liberty Gas Storage, LLC 23.2 23.2 14 14 Southern Gas Transmission Company 49.0 49.0 1 1 Total Sempra Energy $ 758 $ 750 (1) Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.
Inventory Table	INVENTORY BALANCES (Dollars in millions) Natural gas Liquefied natural gas Materials and supplies Total March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 SDG&E $ 3 $ 6 $ ― $ ― $ 69 $ 69 $ 72 $ 75 SoCalGas(1) ― 49 ― ― 33 30 33 79 Sempra South American Utilities ― ― ― ― 37 30 37 30 Sempra Mexico ― ― 6 3 2 10 8 13 Sempra Renewables ― ― ― ― 3 3 3 3 Sempra Natural Gas 74 94 3 3 1 1 78 98 Sempra Energy Consolidated $ 77 $ 149 $ 9 $ 6 $ 145 $ 143 $ 231 $ 298 (1) At both March 31, 2016 and December 31, 2015, SoCalGas' natural gas inventory for core customers is net of the estimated inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11.

DERIVATIVE FINANCIAL INSTRUME22

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	3 Months Ended
	Mar. 31, 2016
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity Derivative Volumes Table	NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) March 31, December 31, Segment and Commodity Unit of measure 2016 2015 California Utilities: SDG&E: Natural gas MMBtu(1) 60 70 Electricity MWh(2) ― 1 Congestion revenue rights MWh 33 36 SoCalGas – natural gas MMBtu ― 1 Energy-Related Businesses: Sempra Natural Gas – natural gas MMBtu 39 43 (1) Million British thermal units (2) Megawatt hours
Notional Amounts of Interest Rate Derivatives Table	INTEREST RATE DERIVATIVES (Dollars in millions) March 31, 2016 December 31, 2015 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges(1) $ 381 2016-2028 $ 384 2016-2028 Fair value hedges 300 2016 300 2016 SDG&E: Cash flow hedge(1) 312 2016-2019 315 2016-2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) March 31, 2016 December 31, 2015 Notional debt Maturities Notional debt Maturities Sempra Mexico: Cross-currency swaps $ 408 2018-2023 $ 408 2018-2023 Other foreign currency derivatives 550 2016 ― ―
Derivative Instruments on the Condensed Consolidated Balance Sheets Table	DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) March 31, 2016 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Fixed-price Fixed-price contracts 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) $ 5 $ ― $ (15) $ (166) Derivatives not designated as hedging instruments: Interest rate and foreign exchange instruments 3 ― ― ― Commodity contracts not subject to rate recovery 144 20 (144) (9) Associated offsetting commodity contracts (135) (9) 135 9 Associated offsetting cash collateral ― ― 7 ― Commodity contracts subject to rate recovery 23 51 (68) (61) Associated offsetting commodity contracts (4) (1) 4 1 Associated offsetting cash collateral ― ― 31 24 Net amounts presented on the balance sheet 36 61 (50) (202) Additional cash collateral for commodity contracts not subject to rate recovery 20 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 32 ― ― ― Total(4) $ 88 $ 61 $ (50) $ (202) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (14) $ (25) 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 20 51 (65) (61) Associated offsetting commodity contracts (2) (1) 2 1 Associated offsetting cash collateral ― ― 31 24 Net amounts presented on the balance sheet 18 50 (46) (61) Additional cash collateral for commodity contracts not subject to rate recovery 2 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 30 ― ― ― Total(4) $ 50 $ 50 $ (46) $ (61) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery $ ― $ ― $ (1) $ ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 3 ― (3) ― Associated offsetting commodity contracts (2) ― 2 ― Net amounts presented on the balance sheet 1 ― (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) $ ― (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) December 31, 2015 Deferred credits Current Current and other assets: liabilities: liabilities: Fixed-price Fixed-price Fixed-price contracts Other contracts contracts and other assets: and other and other derivatives(1) Sundry derivatives(2) derivatives Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 4 $ 1 $ (15) $ (156) Commodity contracts not subject to rate recovery 13 ― ― ― Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 245 32 (239) (21) Associated offsetting commodity contracts (232) (20) 232 20 Associated offsetting cash collateral (6) ― 4 ― Commodity contracts subject to rate recovery 28 49 (61) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 50 60 (49) (193) Additional cash collateral for commodity contracts not subject to rate recovery 2 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 28 ― ― ― Total(4) $ 80 $ 60 $ (49) $ (193) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ ― $ ― $ (14) $ (23) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery ― ― (1) ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 27 49 (60) (64) Associated offsetting commodity contracts (2) (2) 2 2 Associated offsetting cash collateral ― ― 28 26 Net amounts presented on the balance sheet 25 47 (44) (59) Additional cash collateral for commodity contracts not subject to rate recovery 1 ― ― ― Additional cash collateral for commodity contracts subject to rate recovery 27 ― ― ― Total(4) $ 53 $ 47 $ (44) $ (59) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery $ ― $ ― $ (1) $ ― Associated offsetting cash collateral ― ― 1 ― Commodity contracts subject to rate recovery 1 ― (1) ― Net amounts presented on the balance sheet 1 ― (1) ― Additional cash collateral for commodity contracts subject to rate recovery 1 ― ― ― Total $ 2 $ ― $ (1) $ ― (1) Included in Current Assets: Other for SoCalGas. (2) Included in Current Liabilities: Other for SoCalGas. (3) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (4) Normal purchase contracts previously measured at fair value are excluded.
Fair Value Hedge Impact on the Condensed Consolidated Statements of Operations Table	FAIR VALUE HEDGE IMPACTS (Dollars in millions) Pretax gain on derivatives recognized in earnings Three months ended March 31, Location 2016 2015 Sempra Energy Consolidated: Interest rate instruments Interest Expense $ 2 $ 2 Interest rate instruments Other Income, Net ― 1 Total(1) $ 2 $ 3 (1) There was no hedge ineffectiveness in either the three months ended March 31, 2016 or 2015. 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 IMPACTS (Dollars in millions) Pretax (loss) gain Pretax (loss) gain reclassified recognized in OCI from AOCI into earnings (effective portion) (effective portion) Three months ended March 31, Three months ended March 31, 2016 2015 Location 2016 2015 Sempra Energy Consolidated: Interest rate and foreign exchange instruments(1) $ (11) $ (18) Interest Expense $ (4) $ (6) Equity (Losses) Earnings, Interest rate instruments (137) (78) Before Income Tax (3) (3) Interest rate and foreign Equity Earnings, exchange instruments (18) ― Net of Income Tax (1) ― Commodity contracts not Revenues: Energy-Related subject to rate recovery 1 (1) Businesses 7 7 Total(2) $ (165) $ (97) $ (1) $ (2) SDG&E: Interest rate instruments(1)(2) $ (5) $ (5) 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) Amounts include negligible hedge ineffectiveness in the three months ended March 31, 2016 and 2015.
Undesignated Derivative Impact on the Condensed Consolidated Statements of Operations Table	UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Three months ended March 31, Location 2016 2015 Sempra Energy Consolidated: Foreign exchange instruments Other Income, Net $ 3 $ ― Foreign exchange instruments Equity Earnings, Net of Income Tax 2 (1) Commodity contracts not subject Revenues: Energy-Related to rate recovery Businesses (1) 3 Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power (12) (20) Commodity contracts subject to rate recovery Cost of Natural Gas (1) 1 Total $ (9) $ (17) SDG&E: Commodity contracts subject Cost of Electric Fuel to rate recovery and Purchased Power $ (12) $ (20) SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (1) $ 1

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	3 Months Ended
	Mar. 31, 2016
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at March 31, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 623 $ ― $ ― $ ― $ 623 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 43 ― ― 105 Municipal bonds ― 156 ― ― 156 Other securities ― 190 ― ― 190 Total debt securities 62 389 ― ― 451 Total nuclear decommissioning trusts(2) 685 389 ― ― 1,074 Interest rate and foreign exchange instruments ― 8 ― ― 8 Commodity contracts not subject to rate recovery 1 19 ― 20 40 Commodity contracts subject to rate recovery ― 1 68 32 101 Total $ 686 $ 417 $ 68 $ 52 $ 1,223 Liabilities: Interest rate and foreign exchange instruments $ ― $ 181 $ ― $ ― $ 181 Commodity contracts not subject to rate recovery 3 6 ― (7) 2 Commodity contracts subject to rate recovery ― 67 57 (55) 69 Total $ 3 $ 254 $ 57 $ (62) $ 252 Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Interest rate and foreign exchange instruments ― 5 ― ― 5 Commodity contracts not subject to rate recovery 22 16 ― (4) 34 Commodity contracts subject to rate recovery ― 1 72 28 101 Total $ 688 $ 404 $ 72 $ 24 $ 1,188 Liabilities: Interest rate and foreign exchange instruments $ ― $ 171 $ ― $ ― $ 171 Commodity contracts not subject to rate recovery 5 3 ― (4) 4 Commodity contracts subject to rate recovery ― 68 53 (54) 67 Total $ 5 $ 242 $ 53 $ (58) $ 242 (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, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 623 $ ― $ ― $ ― $ 623 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 62 43 ― ― 105 Municipal bonds ― 156 ― ― 156 Other securities ― 190 ― ― 190 Total debt securities 62 389 ― ― 451 Total nuclear decommissioning trusts(2) 685 389 ― ― 1,074 Commodity contracts not subject to rate recovery ― ― ― 2 2 Commodity contracts subject to rate recovery ― ― 68 30 98 Total $ 685 $ 389 $ 68 $ 32 $ 1,174 Liabilities: Interest rate instruments $ ― $ 39 $ ― $ ― $ 39 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 66 57 (55) 68 Total $ 1 $ 105 $ 57 $ (56) $ 107 Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 619 $ ― $ ― $ ― $ 619 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 47 44 ― ― 91 Municipal bonds ― 156 ― ― 156 Other securities ― 182 ― ― 182 Total debt securities 47 382 ― ― 429 Total nuclear decommissioning trusts(2) 666 382 ― ― 1,048 Commodity contracts not subject to rate recovery ― ― ― 1 1 Commodity contracts subject to rate recovery ― ― 72 27 99 Total $ 666 $ 382 $ 72 $ 28 $ 1,148 Liabilities: Interest rate instruments $ ― $ 37 $ ― $ ― $ 37 Commodity contracts not subject to rate recovery 1 ― ― (1) ― Commodity contracts subject to rate recovery ― 67 53 (54) 66 Total $ 1 $ 104 $ 53 $ (55) $ 103 (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, 2016 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 $ 1 $ ― $ ― $ (1) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 1 $ 1 $ ― $ (1) $ 1 Fair value at December 31, 2015 Level 1 Level 2 Level 3 Netting(1) Total Assets: Commodity contracts subject to rate recovery $ ― $ 1 $ ― $ 1 $ 2 Total $ ― $ 1 $ ― $ 1 $ 2 Liabilities: Commodity contracts not subject to rate recovery $ 1 $ ― $ ― $ (1) $ ― Commodity contracts subject to rate recovery ― 1 ― ― 1 Total $ 1 $ 1 $ ― $ (1) $ 1 (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, 2016 2015 Balance as of January 1 $ 19 $ 107 Realized and unrealized (losses) gains (1) 6 Settlements (7) (11) Balance as of March 31 $ 11 $ 102 Change in unrealized (losses) gains relating to instruments still held at March 31 $ (1) $ 1
Fair Value of Financial Instruments Table	FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) March 31, 2016 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 173 $ ― $ 92 $ 72 $ 164 Total long-term debt (2)(3) 13,761 ― 14,363 652 15,015 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,285 $ ― $ 4,517 $ 312 $ 4,829 SoCalGas: Total long-term debt (5) $ 2,513 $ ― $ 2,731 $ ― $ 2,731 Preferred stock 22 ― 25 ― 25 December 31, 2015 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Noncurrent due from unconsolidated affiliates (1) $ 175 $ ― $ 97 $ 69 $ 166 Total long-term debt (2)(3) 13,761 ― 13,985 648 14,633 Preferred stock of subsidiary 20 ― 23 ― 23 SDG&E: Total long-term debt (3)(4) $ 4,304 $ ― $ 4,355 $ 315 $ 4,670 SoCalGas: Total long-term debt (5) $ 2,513 $ ― $ 2,621 $ ― $ 2,621 Preferred stock 22 ― 25 ― 25 (1) Excluding accumulated interest outstanding of $13 million and $11 million at March 31, 2016 and December 31, 2015, respectively. (2) Before reductions for unamortized discount (net of premium) and debt issuance costs of $106 million and $107 million at March 31, 2016 and December 31, 2015, respectively, and excluding build-to-suit and capital lease obligations of $386 million and $387 million at March 31, 2016 and December 31, 2015, 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) Level 3 instruments include $312 million and $315 million at March 31, 2016 and December 31, 2015, respectively, related to Otay Mesa VIE. (4) Before reductions for unamortized discount and debt issuance costs of $43 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $243 million and $244 million at March 31, 2016 and December 31, 2015, respectively. (5) Before reductions for unamortized discount and debt issuance costs of $24 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $1 million at March 31, 2016 and December 31, 2015.
Fair Value Measurements, Nonrecurring Table	NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Estimated Fair % of Inputs used to fair value fair value develop Range of value Valuation technique hierarchy measurement measurement inputs Investment in Rockies Express $ 440 (1) Market approach Level 2 100% Equity sale price 100% (1) At measurement date of March 29, 2016. At March 31, 2016, our investment in Rockies Express had a carrying value of $436 million, reflecting subsequent equity method activity to record a distribution.

NUCLEAR PLANT (Tables)

NUCLEAR PLANT (Tables)	3 Months Ended
	Mar. 31, 2016
Public Utilities General Disclosures [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, 2016: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1) $ 101 $ 4 $ ― $ 105 Municipal bonds(2) 146 10 ― 156 Other securities(2) 192 6 (8) 190 Total debt securities 439 20 (8) 451 Equity securities 214 413 (4) 623 Cash and cash equivalents 9 ― (1) 8 Total $ 662 $ 433 $ (13) $ 1,082 At December 31, 2015: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 89 $ 2 $ ― $ 91 Municipal bonds 148 8 ― 156 Other securities 194 1 (13) 182 Total debt securities 431 11 (13) 429 Equity securities 214 412 (7) 619 Cash and cash equivalents 15 ― ― 15 Total $ 660 $ 423 $ (20) $ 1,063 (1) Maturity dates are 2016-2065. (2) Maturity dates are 2016-2115.
Schedule of Sales of Securities By Nuclear Decommissioning Trusts	SALES OF SECURITIES (Dollars in millions) Three months ended March 31, 2016 2015 Proceeds from sales(1) $ 93 $ 94 Gross realized gains 3 2 Gross realized losses (8) (4) (1) Excludes securities that are held to maturity.

CALIFORNIA UTILITIES' REGULAT25

CALIFORNIA UTILITIES' REGULATORY MATTERS (Tables)	3 Months Ended
	Mar. 31, 2016
Public Utilities General Disclosures [Abstract]
Schedule Of California Utilities Major Projects	MAJOR PROJECTS – UPDATES Joint Utilities Projects Southern Gas System Reliability Project § In April 2016, the CPUC issued a proposed decision finding that there is a need for enhanced system reliability for the southern portion of the SoCalGas and SDG&E gas system, but concluding that the utilities have failed to demonstrate that there is a need for their proposed pipeline project. Instead, the proposed decision determines that certain non-physical alternatives will provide enhanced supply reliability, without the need to construct pipeline facilities. § At March 31, 2016, SoCalGas has approximately $23 million of development costs invested in the project, classified as Property, Plant and Equipment on Sempra Energy's and SoCalGas' Condensed Consolidated Balance Sheets. Some or all of these assets could become impaired if the project and potential alternative uses for these assets were ultimately rejected by the CPUC. SoCalGas and SDG&E filed comments with the CPUC in April 2016. Pipeline Safety & Reliability Project § SDG&E and SoCalGas filed an amended application with the CPUC in March 2016 providing detailed analysis and testimony supporting the proposed project. The revised request also presents additional information on the costs and benefits of project alternatives, safety evaluation and compliance analysis, and statutory and procedural requirements. SDG&E and SoCalGas seek approval to construct the proposed project, estimated at a cost of $633 million, and authority to recover the associated revenue requirement in rates. SDG&E Projects Cleveland National Forest (CNF) Transmission Projects § In March 2016, the U.S. Forest Service issued a final decision authorizing issuance of the CNF Master Special Use Permit renewing SDG&E's land rights and authorizing the construction, operation and maintenance of facilities located on national forest lands for the next 50 years, as well as approving the majority of the fire-hardening activities proposed by SDG&E. § Proposed decision issued by the CPUC in April 2016, which granted SDG&E a permit to construct. Final CPUC decision expected in the second quarter of 2016. Sycamore-Peñasquitos Transmission Project § March 2016 final environmental impact report (EIR) recommended an alternative that undergrounds more of the project than originally proposed, and is viewed as environmentally superior. The CPUC may consider this alternative. § CPUC's recommended alternative has an estimated cost of $250 million to $300 million, compared to the original project cost estimate of $120 million to $150 million, and would also delay the project schedule by approximately 10 months. § CPUC decision expected in the second half of 2016. South Orange County Reliability Enhancement § CPUC issued its final EIR for the project in April 2016. The EIR concluded that an alternative project is considered environmentally superior to SDG&E's proposal. The final EIR states that the CPUC is not required to adopt the environmentally superior alternative if there are overriding considerations in favor of another alternative. The CPUC will consider the findings in determining whether to approve SDG&E's proposed project or an alternative to it. § Final CPUC decision expected in the second half of 2016.

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	3 Months Ended
	Mar. 31, 2016
Segment [Abstract]
Segment Information Table	SEGMENT INFORMATION (Dollars in millions) Three months ended March 31, 2016 2015 REVENUES SDG&E $ 991 38 % $ 966 36 % SoCalGas 1,033 40 1,048 39 Sempra South American Utilities 400 15 389 15 Sempra Mexico 138 5 163 6 Sempra Renewables 7 ― 8 ― Sempra Natural Gas 130 5 197 7 Intersegment revenues(1) (77) (3) (89) (3) Total $ 2,622 100 % $ 2,682 100 % INTEREST EXPENSE SDG&E $ 48 $ 52 SoCalGas 22 19 Sempra South American Utilities 9 5 Sempra Mexico 4 5 Sempra Renewables ― 1 Sempra Natural Gas 12 21 All other 72 63 Intercompany eliminations (24) (32) Total $ 143 $ 134 INTEREST INCOME Sempra South American Utilities $ 5 $ 4 Sempra Mexico 2 2 Sempra Renewables 1 ― Sempra Natural Gas 16 19 Intercompany eliminations (18) (18) Total $ 6 $ 7 DEPRECIATION AND AMORTIZATION SDG&E $ 159 49 % $ 145 48 % SoCalGas 122 37 113 37 Sempra South American Utilities 13 4 13 4 Sempra Mexico 17 5 17 6 Sempra Renewables 1 ― 2 1 Sempra Natural Gas 13 4 12 4 All other 3 1 1 ― Total $ 328 100 % $ 303 100 % INCOME TAX EXPENSE (BENEFIT) SDG&E $ 72 $ 88 SoCalGas 87 95 Sempra South American Utilities 14 16 Sempra Mexico 41 8 Sempra Renewables (12) (17) Sempra Natural Gas (25) 2 All other (35) (29) Total $ 142 $ 163 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended March 31, 2016 2015 EQUITY EARNINGS (LOSSES) Earnings (losses) recorded before tax: Sempra Renewables $ 7 $ 2 Sempra Natural Gas (29) 17 Total $ (22) $ 19 Earnings (losses) recorded net of tax: Sempra South American Utilities $ 2 $ (1) Sempra Mexico 15 16 Total $ 17 $ 15 EARNINGS (LOSSES) SDG&E $ 129 40 % $ 147 34 % SoCalGas(2) 195 61 214 49 Sempra South American Utilities 38 12 41 9 Sempra Mexico 17 5 47 11 Sempra Renewables 13 4 13 3 Sempra Natural Gas (36) (11) 2 ― All other (37) (11) (27) (6) Total $ 319 100 % $ 437 100 % EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 329 34 % $ 355 46 % SoCalGas 340 35 315 40 Sempra South American Utilities 43 4 31 4 Sempra Mexico 40 4 55 7 Sempra Renewables 181 19 3 1 Sempra Natural Gas 35 4 10 1 All other 3 ― 11 1 Total $ 971 100 % $ 780 100 % March 31, 2016 December 31, 2015 ASSETS SDG&E $ 16,625 40 % $ 16,515 40 % SoCalGas 12,427 30 12,104 29 Sempra South American Utilities 3,434 8 3,235 8 Sempra Mexico 3,843 9 3,783 9 Sempra Renewables 1,454 3 1,441 4 Sempra Natural Gas 5,395 13 5,566 13 All other 741 2 734 2 Intersegment receivables (2,084) (5) (2,228) (5) Total $ 41,835 100 % $ 41,150 100 % EQUITY METHOD AND OTHER INVESTMENTS Sempra South American Utilities $ (2) $ (4) Sempra Mexico 522 519 Sempra Renewables 823 855 Sempra Natural Gas 1,308 1,460 All other 76 75 Total $ 2,727 $ 2,905 (1) Revenues for reportable segments include intersegment revenues of $3 million, $17 million, $27 million and $30 million for the three months ended March 31, 2016 and $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively. (2) After preferred dividends.

NEW ACCOUNTING POLICY (details)

NEW ACCOUNTING POLICY (details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
New Accounting Policies
Tax benefit related to share-based compensation	$ 34	$ 52
Cumulative Effect On Retained Earnings Tax1	$ 107

RECENT BUSINESS ACQUISITIONS (D

RECENT BUSINESS ACQUISITIONS (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2015	Mar. 31, 2015	Jul. 31, 2015
Black Oak Getty Wind [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)		$ 8
Equity Method Investment Ownership Percentage		100.00%
PEMEX [Member]
Business Acquisition [Line Items]
Ownership Percentage in consolidated entity	50.00%
IEnova [Member]
Business Acquisition [Line Items]
Ownership percentage before acquisition			50.00%
Acquired percentage interest in joint venture			100.00%
Net Debt Not Assumed By Investee	$ 170
Business Acquisition Purchase Price Allocation Equity Method Investment	$ 1,325
Ownership Percentage in consolidated entity	25.00%
Equity Method Investment Ownership Percentage			50.00%

ASSETS HELD FOR SALE (Details)

ASSETS HELD FOR SALE (Details) - Termoelectrica de Mexicali [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)
Assets Held for Sale, Assets [Abstract]
Assets Held for Sale, Cash and Cash Equivalent	$ 1
Assets Held for Sale, Inventories	8
Assets Held for Sale, Other Current Assets	29
Assets Held for Sale, Other Assets	15
Assets Held for Sale, Property, Plant and Equipment, Net	250
Total Assets Held for Sale	303
Assets Held for Sale, Liabilities [Abstract]
Assets Held for Sale, Accounts Payable	1
Assets Held for Sale, Other Current Liabilities	7
Assets Held for Sale, Deferred Income Taxes	16
Assets Held for Sale, Asset Retirement Obligations	4
Assets Held for Sale, Other Liabilities	15
Total Liabilities Held for Sale	43
Disposal Group Including Discontinued Operation Additional Disclosures [Abstract]
Deferred Tax Expense From The Outside Basis Difference	29
Deferred Tax Expense From The Outside Basis Difference After NoncontrollingInterest	$ 24

DIVESTITURES (Details)

DIVESTITURES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 29, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	$ 2,727		$ 2,905
Rockies Express [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment Ownership Percentage		25.00%
Equity Method Investment, Other than Temporary Impairment	44
Equity Method Investment Other Than Temporary Impairment Net Of Tax Benefit	27
Equity Method Investments	436	$ 484
Proceeds From Sale Of Equity Method Investments	$ 440

INVESTMENTS IN UNCONSOLIDATED31

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity Method Investments in Joint Ventures, capitalized interest	$ 18	$ 17
Guarantee Obligations Maximum Exposure	4,500
Guarantee Obligations Current Carrying Value	67
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Payments To Acquire Equity Method Investments	15	17
Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investments in Joint Ventures, capitalized interest	12	$ 12
Payments To Acquire Equity Method Investments	$ 3

OTHER FINANCIAL DATA - VARIABLE

OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Variable Interest Entities [Line Items]
Cost Of Electric Fuel And Purchased Power From Utilities	$ 515	$ 481
Other operation and maintenance	701	658
Depreciation and amortization	328	303
Other income (expense), net	49	39
Interest expense	(143)	(134)
Net income	330	458
Earnings attributable to noncontrolling interest	(11)	(21)
Earnings attributable to common shares	319	437
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	2,727		$ 2,905
Otay Mesa VIE [Member]
Variable Interest Entities [Line Items]
Cost Of Electric Fuel And Purchased Power From Utilities	(17)	(18)
Other operation and maintenance	4	4
Depreciation and amortization	7	6
Operating Expenses	(6)	(8)
Utility operating income	6	8
Interest expense	(5)	(4)
Net income	1	4
Earnings attributable to noncontrolling interest	(1)	(4)
Earnings attributable to common shares	0	$ 0
Equity of variable interest entity	51		53
Secured debt of variable interest entity	312
Cameron LNG Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	$ 872		$ 983

OTHER FINANCIAL DATA - GOODWILL

OTHER FINANCIAL DATA - GOODWILL (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill	$ 849	$ 819	[1]
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - PENSION

OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 28	$ 30
Interest cost	40	39
Expected return on assets	(42)	(44)
Amortization of prior service cost	3	3
Amortization of actuarial loss	6	8
Regulatory adjustment	(28)	(29)
Total net periodic benefit cost	7	7
Defined benefit plan, contributions by employer	15
Defined benefit plan, expected contributions in current fiscal year	123
Pension Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	7	8
Interest cost	10	10
Expected return on assets	(12)	(14)
Amortization of prior service cost	0	0
Amortization of actuarial loss	3	2
Regulatory adjustment	(7)	(5)
Total net periodic benefit cost	1	1
Defined benefit plan, contributions by employer	2
Defined benefit plan, expected contributions in current fiscal year	4
Pension Benefits | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	17	19
Interest cost	25	25
Expected return on assets	(25)	(27)
Amortization of prior service cost	2	2
Amortization of actuarial loss	3	5
Regulatory adjustment	(21)	(24)
Total net periodic benefit cost	1	0
Defined benefit plan, contributions by employer	0
Defined benefit plan, expected contributions in current fiscal year	77
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	7
Interest cost	11	12
Expected return on assets	(17)	(17)
Amortization of prior service cost	0	(1)
Amortization of actuarial loss	0	0
Regulatory adjustment	2	0
Total net periodic benefit cost	1	1
Defined benefit plan, contributions by employer	1
Defined benefit plan, expected contributions in current fiscal year	6
Other Postretirement Benefits | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	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	(1)	(2)
Total net periodic benefit cost	0	0
Defined benefit plan, contributions by employer	0
Defined benefit plan, expected contributions in current fiscal year	2
Other Postretirement Benefits | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	5
Interest cost	8	9
Expected return on assets	(14)	(14)
Amortization of prior service cost	(1)	(2)
Amortization of actuarial loss	0	0
Regulatory adjustment	3	2
Total net periodic benefit cost	0	$ 0
Defined benefit plan, contributions by employer	0
Defined benefit plan, expected contributions in current fiscal year	$ 1

OTHER FINANCIAL DATA - RABBI TR

OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Assets Noncurrent [Abstract]
Rabbi Trust	$ 432	$ 464	[1]
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - EARNINGS

OTHER FINANCIAL DATA - EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Earnings Per Share [Abstract]
Basic earnings per common share		$ 1.28	$ 1.76
Weighted-average common shares outstanding for basic EPS	[1]	249,734,000	247,722,000
Diluted earnings per common share		$ 1.27	$ 1.74
Weighted-average common shares outstanding for diluted EPS		251,412,000	251,206,000
Vested RSUs included in basic WASO		555,000	452,000
Dilutive effect of stock options, restricted stock awards and restricted stock units		1,678,000	3,484,000
Shares excluded from potential dilutive shares		2,616,084	1,285,193
Earnings		$ 319	$ 437
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		0	614
[1]	Includes 555 and 452 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended March 31, 2016 and 2015, respectively. These fully vested restricted stock units are included in weighted-average common shares outstanding for basic EPS because there are no conditions under which the corresponding shares will not be issued.

OTHER FINANCIAL DATA - EARNIN37

OTHER FINANCIAL DATA - EARNINGS PER SHARE - SHARE BASED COMPENSATION (Details)	3 Months Ended
	Mar. 31, 2016
Performance RSU minimum [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 and Other Awards 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%

OTHER FINANCIAL DATA - SHARE-BA

OTHER FINANCIAL DATA - SHARE-BASED COMPENSATION (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Allocated Share Based Compensation Expense Net Of Tax	$ 7	$ 8
IENova Plans [Member] [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	183,970
Service-Based [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	93,256
Performance-Based, Total Shareholder Return [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	372,270
Performance-Based, Earnings Per Share [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Restricted stock units granted	94,550

OTHER FINANCIAL DATA - CAPITALI

OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	$ 7	$ 6
AFUDC related to equity	27	27
Other capitalized financing costs	18	17
Total capitalized financing costs	52	50
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	4	3
AFUDC related to equity	11	8
Total capitalized financing costs	15	11
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
AFUDC related to debt	3	3
AFUDC related to equity	10	9
Total capitalized financing costs	$ 13	$ 12

OTHER FINANCIAL DATA - SHAREHOL

OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016		Mar. 31, 2015
Equity, beginning of period		$ 12,579	[1]	$ 12,100
Comprehensive income (loss)		315		329
Share-based compensation expense		13		13
Common stock dividends declared		(188)		(173)
Issuance of common stock		28		30
Repurchases of common stock		(54)		(65)
Tax benefit related to share-based compensation		34		52
Distributions to noncontrolling interests		(3)		(5)
Equity, end of period		12,724		12,281
San Diego Gas and Electric Company [Member]
Equity, beginning of period		5,276	[1]	4,992
Comprehensive income (loss)		128		149
Distributions to noncontrolling interests		(1)		(3)
Equity, end of period		5,403		5,138
Southern California Gas Company [Member]
Equity, beginning of period	[1]	3,149
Equity, end of period		3,344
Total Shareholders' Equity [Member]
Equity, beginning of period		11,809		11,326
Comprehensive income (loss)		304		321
Share-based compensation expense		13		13
Common stock dividends declared		(188)		(173)
Issuance of common stock		28		30
Repurchases of common stock		(54)		(65)
Tax benefit related to share-based compensation		34		52
Distributions to noncontrolling interests		0		0
Equity, end of period		11,946		11,504
Total Shareholders' Equity [Member] | San Diego Gas and Electric Company [Member]
Equity, beginning of period		5,223		4,932
Comprehensive income (loss)		129		147
Distributions to noncontrolling interests		0		0
Equity, end of period		5,352		5,079
Noncontrolling Interests [Member]
Equity, beginning of period	[2]	770		774
Comprehensive income (loss)	[2]	11		8
Share-based compensation expense	[2]	0		0
Common stock dividends declared	[2]	0		0
Issuance of common stock	[2]	0		0
Repurchases of common stock	[2]	0		0
Tax benefit related to share-based compensation	[2]	0		0
Distributions to noncontrolling interests	[2]	(3)		(5)
Equity, end of period	[2]	778		777
Noncontrolling Interests [Member] | San Diego Gas and Electric Company [Member]
Equity, beginning of period		53		60
Comprehensive income (loss)		(1)		2
Distributions to noncontrolling interests		(1)		(3)
Equity, end of period		$ 51		$ 59
[1]	Derived from audited financial statements.
[2]	Noncontrolling interests include the preferred stock of SoCalGas and other noncontrolling interests as listed in the table below under "Other Noncontrolling Interests."

OTHER FINANCIAL DATA - CHANGES

OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016		Mar. 31, 2015
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	$ (806)	[2]	$ (497)
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	[1]	(14)		(116)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	(1)		0
Net Other Comprehensive Income	[1]	(15)		(116)
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(821)		(613)
San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[2]	(8)
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance		(8)
Southern California Gas Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[2]	(19)
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance		(19)
Accumulated Translation Adjustment [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(582)		(322)
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	[1]	68		(62)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	0		0
Net Other Comprehensive Income	[1]	68		(62)
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(514)		(384)
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(137)		(90)
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	[1]	(82)		(54)
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	(2)		(1)
Net Other Comprehensive Income	[1]	(84)		(55)
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	(221)		(145)
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax, beginning balance	[1]	(87)		(85)
Other Comprehensive Income Loss Before Reclassifications Net Of Tax	[1]	0		0
Amounts Reclassified From Accumulated Other Comprehensive Income	[1]	1		1
Net Other Comprehensive Income	[1]	1		1
Accumulated Other Comprehensive Income (Loss), Net of Tax, ending balance	[1]	$ (86)		$ (84)
[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 - RECLASSI

OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, net of income tax.		$ 17	$ 15
Interest expense		(143)	(134)
Equity Earnings (Losses) Recorded Before Tax		(22)	19
Revenues - energy related businesses		180	260
Total before income tax		455	606
Income tax (expense) benefit		(142)	(163)
Earnings attributable to noncontrolling interest		(11)	(21)
Grand total reclassifications for the period, net of tax		(1)	0
San Diego Gas and Electric Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		(48)	(52)
Total before income tax		202	239
Income tax (expense) benefit		(72)	(88)
Earnings attributable to noncontrolling interest		(1)	(4)
Southern California Gas Company [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Interest expense		(22)	(19)
Total before income tax		282	309
Income tax (expense) benefit		(87)	(95)
Accumulated Defined Benefit Plans Adjustment [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Income tax (expense) benefit		(1)	(1)
Total reclassifications for the period, net of tax		1	1
Accumulated Defined Benefit Plans Adjustment [Member] | Amortization of Actuarial Loss [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Pension and other postretirement benefit expense	[1]	2	2
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		1	2
Income tax (expense) benefit		0	1
Net of Income Tax		1	3
Earnings attributable to noncontrolling interest		(3)	(4)
Total reclassifications for the period, net of tax		(2)	(1)
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]
Equity earnings, net of income tax.		1	0
Interest expense		4	6
Accumulated Net Gain Loss From Designated Or Qualifying Cash Flow Hedges [Member] | Interest Rate Instruments [Member]
Reclassification Adjustment Out Of Accumulated Other Comprehensive Income [Line Items]
Equity Earnings (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)	$ (7)
[1]	Amounts are included in the computation of net periodic benefit cost (see "Pension and Other Postretirement Benefits" above).

OTHER FINANCIAL DATA - OTHER NO

OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Noncontrolling Interest [Line Items]
Noncontrolling interests		$ 758	$ 750	[1]
Ownership Interests Held By Others, Bay Gas Storage Company [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		9.10%	9.10%
Other Noncontrolling Interests		$ 25	$ 25
Ownership Interests Held By Others, Southern Gas Transmission [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		49.00%	49.00%
Other Noncontrolling Interests		$ 1	$ 1
Ownership Interests Held By Others, Liberty Gas Storage [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		23.20%	23.20%
Other Noncontrolling Interests		$ 14	$ 14
Ownership Interests Held By Others, Tecsur [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		9.80%	9.80%
Other Noncontrolling Interests		$ 4	$ 4
Ownership Interests Held By Others, Luz Del Sur [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		16.40%	16.40%
Other Noncontrolling Interests		$ 171	$ 164
Ownership Interests Held By Others, Chilquinta Energia [Member]
Noncontrolling Interest [Line Items]
Percent Of Ownership Held By Others Minimum	[2]	23.50%	23.50%
Percent Of Ownership Held By Others Maximum	[2]	43.40%	43.40%
Other Noncontrolling Interests	[2]	$ 22	$ 21
Ownership Interests Held By Others, Otay Mesa VIE [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		100.00%	100.00%
Other Noncontrolling Interests		$ 51	$ 53
Ownership Interests Held By Others IEnova [Member]
Noncontrolling Interest [Line Items]
Minority Interest Ownership Percentage By Noncontrolling Owners		18.90%	18.90%
Other Noncontrolling Interests		$ 470	$ 468
[1]	Derived from audited financial statements.
[2]	Chilquinta Energía has four subsidiaries with noncontrolling interests held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

OTHER FINANCIAL DATA - DUE TO D

OTHER FINANCIAL DATA - DUE TO DUE FROM AFFILIATES (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Mar. 31, 2016	Dec. 31, 2015
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		$ 7	$ 6	[1]
Due to affiliaties, current		(13)	(14)	[1]
Due from affiliate, noncurrent		186	186	[1]
San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		1	1	[1]
Due to affiliaties, current		(49)	(55)	[1]
Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		8	48	[1]
Due to affiliaties, current		(34)	0	[1]
Due to/from Sempra Energy | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliaties, current		(35)	(34)
Income taxes due to Sempra Energy	[2]	(32)
Income taxes due from Sempra Energy	[2]		28
Due to/from Sempra Energy | Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		0	35	[3]
Due to affiliaties, current		(34)	0
Income taxes due to Sempra Energy	[2]	(23)
Income taxes due from Sempra Energy	[2]		$ 1
Interest rate on due from affiliate, noncurrent			0.11%
Loan to unconsolidated affiliate, principal			$ 50
Due to/from SDG&E | Southern California Gas Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliates, current		8	13
Due to/from SoCalGas | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliaties, current		$ (8)	(13)
Joint venture with PEMEX [Member]
Transactions With Affiliates Disclosure [Line Items]
Interest rate on due from affiliate, noncurrent		4.94%
PEMEX Four year loan C [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	[4],[5]	$ 8	8
PEMEX Three year loan A [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	[4],[5]	3	3
PEMEX Four year loan B [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	[4],[5]	34	34
PEMEX Four year loan A [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	[4],[5]	42	42
ESJ joint venture [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	[4],[6]	$ 17	24
Interest rate on due from affiliate, noncurrent		6.81%
Eletrans [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent	[4],[7]	$ 76	72
Interest rate on due from affiliate, noncurrent		4.00%
Sempra South American Utilities [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent		$ 1	0
Sempra Natural Gas Segment [Member]
Transactions With Affiliates Disclosure [Line Items]
Due from affiliate, noncurrent		5	3
Affiliate Of Investee [Member] | San Diego Gas and Electric Company [Member]
Transactions With Affiliates Disclosure [Line Items]
Due to affiliaties, current		$ (6)	$ (8)
[1]	Derived from audited financial statements.
[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 each company having always filed a separate return.
[3]	At December 31, 2015, net receivable included outstanding advances to Sempra Energy of $50 million at an interest rate of 0.11 percent.
[4]	Amounts include principal balances plus accumulated interest outstanding.
[5]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points (4.94 percent at March 31, 2016), to finance the Los Ramones Norte pipeline project.
[6]	U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 637.5 basis points (6.81 percent at March 31, 2016), to finance the first phase of the Energía Sierra Juárez wind project.
[7]	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. and Eletrans II S.A., both of which are joint ventures at Chilquinta Energía.

OTHER FINANCIAL DATA - AFFILIAT

OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Transactions With Affiliates Disclosure [Line Items]
Revenue from related parties	$ 5	$ 8
Costs and Expenses Related Party	30	19
S D G E Segment [Member]
Transactions With Affiliates Disclosure [Line Items]
Revenue from related parties	3	3
Costs and Expenses Related Party	14	5
So Cal Gas Segment [Member]
Transactions With Affiliates Disclosure [Line Items]
Revenue from related parties	$ 17	$ 19

OTHER FINANCIAL DATA - OTHER IN

OTHER FINANCIAL DATA - OTHER INCOME (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity		$ 27	$ 27
Investment gains (losses)	[1]	10	9
Electrical infrastructure relocation income	[2]	1	0
Gains (losses) on interest rate and foreign exchange instruments, net		3	0
Sale of other investments		1	0
Foreign currency gain (losses)		(2)	(1)
Regulatory Interest, net	[3]	2	1
Sundry, net		7	3
Total		49	39
San Diego Gas and Electric Company [Member]
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity		11	8
Regulatory Interest, net	[3]	2	1
Sundry, net		1	0
Total		14	9
Southern California Gas Company [Member]
Component of Other Income, Nonoperating [Line Items]
AFUDC related to equity		10	9
Sundry, net		0	(1)
Total		$ 10	$ 8
[1]	Represents investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans.
[2]	Income at Luz del Sur associated with the relocation of electrical infrastructure.
[3]	Interest on regulatory balancing accounts.

OTHER FINANCIAL DATA - INCOME T

OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 142	$ 163
Effective income tax rate	31.00%	27.00%
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 72	$ 88
Effective income tax rate	36.00%	37.00%
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit)	$ 87	$ 95
Effective income tax rate	31.00%	31.00%

OTHER FINANCIAL DATA - INVENTOR

OTHER FINANCIAL DATA - INVENTORY (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage		$ 77	$ 149
Energy Related Inventory, Liquefied Natural Gas		9	6
Energy Related Inventory, Materials And Supplies		145	143
Inventory, Total		231	298	[1]
S D G E Segment [Member]
Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage		3	6
Energy Related Inventory, Liquefied Natural Gas		0	0
Energy Related Inventory, Materials And Supplies		69	69
Inventory, Total		72	75
So Cal Gas Segment [Member]
Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage	[2]	0	49
Energy Related Inventory, Liquefied Natural Gas	[2]	0	0
Energy Related Inventory, Materials And Supplies	[2]	33	30
Inventory, Total	[2]	33	79
Sempra South American Utilities Segment [Member]
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		37	30
Inventory, Total		37	30
Sempra Mexico Segment [Member]
Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage		0	0
Energy Related Inventory, Liquefied Natural Gas		6	3
Energy Related Inventory, Materials And Supplies		2	10
Inventory, Total		8	13
Sempra Natural Gas Segment [Member]
Inventory [Line Items]
Energy Related Inventory, Natural Gas in Storage		74	94
Energy Related Inventory, Liquefied Natural Gas		3	3
Energy Related Inventory, Materials And Supplies		1	1
Inventory, Total		78	98
Sempra Renewables Segment [Member]
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		3	3
Inventory, Total		$ 3	$ 3
[1]	Derived from audited financial statements.
[2]	At both March 31, 2016 and December 31, 2015, SoCalGas' natural gas inventory for core customers is net of the estimated inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11.

DEBT AND CREDIT FACILITIES - LI

DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Line Of Credit Facility, Sempra Energy Consolidated [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 4,200
Committed lines of credit, remaining borrowing capacity	$ 3,100
Weighted average interest rate on total short-term debt outstanding	1.12%	1.09%
Line Of Credit Facility, Sempra Energy [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 1,000
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, capacity for issuance of letters of credit	$ 400
Committed lines of credit, outstanding borrowings	0
Line Of Credit Facility, Sempra Global [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 2,210
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 1,330
Outstanding commercial paper supported by committed lines of credit	879
Line Of Credit Facility, S D G E [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 750
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 584
Outstanding commercial paper supported by committed lines of credit	$ 166
Weighted average interest rate on total short-term debt outstanding	1.02%	1.01%
Line Of Credit Facility, So Cal Gas [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 750
Committed lines of credit, maximum ratio of indebtedness to total capitalization	65.00%
Committed lines of credit, remaining borrowing capacity	$ 745
Outstanding commercial paper supported by committed lines of credit	$ 5
Weighted average interest rate on total short-term debt outstanding	0.40%
Line Of Credit Facility, California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 1,000
Committed lines of credit, capacity for issuance of letters of credit	250
Line Of Credit Facility, South American Utilities And Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	1,100
Committed lines of credit, remaining borrowing capacity	876
Line Of Credit Facility Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	600
Committed lines of credit, remaining borrowing capacity	509
Committed lines of credit, outstanding borrowings	91
Line Of Credit Facility, Peruvian Facility [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, remaining borrowing capacity	255
Committed lines of credit, outstanding borrowings	165
Bank Guarantee	15
Line Of Credit Facility, Chilean Facility [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, remaining borrowing capacity	112
Committed lines of credit, outstanding borrowings	0
Line Of Credit Facility Sempra South America [Member]
Line of Credit Facility [Line Items]
Committed lines of credit, maximum borrowing capacity	$ 547
Committed lines of credit, maximum ratio of debt to equity	170.00%

DEBT AND CREDIT FACILITIES - LO

DEBT AND CREDIT FACILITIES - LONG TERM DEBT (Details) - Other Long Term Debt, Variable Rate Due 2027 [Member] - San Diego Gas and Electric Company [Member] $ in Millions	Mar. 31, 2016USD ($)
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.00%
Planned Early Redemption Of Long Term Debt Instruments	$ 105

DERIVATIVE COMMODITY VOLUMES (D

DERIVATIVE COMMODITY VOLUMES (Details)		Mar. 31, 2016	Dec. 31, 2015
S D G E Segment [Member]
Derivatives, Fair Value [Line Items]
Commodity Derivative Volumes Natural Gas	[1]	60	70
Commodity Derivative Volumes Congestion Revenue Rights	[2]	33	36
Commodity Derivative Volumes Electric Power	[2]	0	1
So Cal Gas Segment [Member]
Derivatives, Fair Value [Line Items]
Commodity Derivative Volumes Natural Gas	[1]	0	1
Sempra Natural Gas Segment [Member]
Derivatives, Fair Value [Line Items]
Commodity Derivative Volumes Natural Gas	[1]	39	43
[1]	Million British thermal units
[2]	Megawatt hours

DERIVATIVE NOTIONALS (Details)

DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Mar. 31, 2016	Dec. 31, 2015
Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Derivative Liability Notional Amount	[1]	$ 381	$ 384
Cash Flow Hedges | Cross Currency Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability Notional Amount		$ 408	$ 408
Cash Flow Hedges | Minimum [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,016	2,016
Cash Flow Hedges | Minimum [Member] | Cross Currency Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,018	2,018
Cash Flow Hedges | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,028	2,028
Cash Flow Hedges | Maximum [Member] | Cross Currency Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,023	2,023
Fair Value Hedges
Derivatives, Fair Value [Line Items]
Derivative Liability Notional Amount		$ 300	$ 300
Fair Value Hedges | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,016	2,016
Undesignated Derivatives | Foreign Exchange Instrument
Derivatives, Fair Value [Line Items]
Derivative Liability Notional Amount		$ 550	$ 0
Undesignated Derivatives | Maximum [Member] | Foreign Exchange Instrument
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,016	0
San Diego Gas and Electric Company [Member] | Cash Flow Hedges
Derivatives, Fair Value [Line Items]
Derivative Liability Notional Amount	[1]	$ 312	$ 315
San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Minimum [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,016	2,016
San Diego Gas and Electric Company [Member] | Cash Flow Hedges | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturities of interest rate derivatives		2,019	2,019
[1]	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

DERIVATIVE INSTRUMENTS ON THE C

DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Other Current Assets [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[1],[2]	$ 5	$ 4
Commodity contracts not subject to rate recovery	[1]		13
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments	[1]	3
Commodity contracts not subject to rate recovery	[1]	144	245
Associated offsetting commodity contracts not subject to rate recovery	[1]	(135)	(232)
Associated cash collateral commodity contracts not subject to rate recovery	[1]	0	(6)
Commodity contracts subject to rate recovery	[1]	23	28
Associated cash collateral commodity contracts subject to rate recovery	[1]	0	0
Associated offsetting commodity contracts subject to rate recovery	[1]	(4)	(2)
Net amount presented on balance sheet	[1]	36	50
Additional margin posted for commodity contracts not subject to rate recovery	[1]	20	2
Additional margin posted for commodity contracts subject to rate recovery	[1]	32	28
Total	[1],[3]	88	80
Other Current Assets [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[1],[2]	0	0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[1]	0	0
Associated cash collateral commodity contracts not subject to rate recovery	[1]	0	0
Commodity contracts subject to rate recovery	[1]	20	27
Associated cash collateral commodity contracts subject to rate recovery	[1]	0	0
Associated offsetting commodity contracts subject to rate recovery	[1]	(2)	(2)
Net amount presented on balance sheet	[1]	18	25
Additional margin posted for commodity contracts not subject to rate recovery	[1]	2	1
Additional margin posted for commodity contracts subject to rate recovery	[1]	30	27
Total	[1],[3]	50	53
Other Current Assets [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[1]	0	0
Associated cash collateral commodity contracts not subject to rate recovery	[1]	0	0
Commodity contracts subject to rate recovery	[1]	3	1
Associated offsetting commodity contracts subject to rate recovery	[1]	(2)
Net amount presented on balance sheet	[1]	1	1
Additional margin posted for commodity contracts not subject to rate recovery	[1]	1
Additional margin posted for commodity contracts subject to rate recovery	[1]	2	1
Total	[1]	4	2
Other Noncurrent Assets [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	0	1
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		0
Commodity contracts not subject to rate recovery		20	32
Associated offsetting commodity contracts not subject to rate recovery		(9)	(20)
Associated cash collateral commodity contracts not subject to rate recovery		0	0
Commodity contracts subject to rate recovery		51	49
Associated cash collateral commodity contracts subject to rate recovery		0	0
Associated offsetting commodity contracts subject to rate recovery		(1)	(2)
Net amount presented on balance sheet		61	60
Additional margin posted for commodity contracts not subject to rate recovery		0	0
Additional margin posted for commodity contracts subject to rate recovery		0	0
Total	[3]	61	60
Other Noncurrent Assets [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	0	0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0	0
Associated cash collateral commodity contracts not subject to rate recovery		0	0
Commodity contracts subject to rate recovery		51	49
Associated cash collateral commodity contracts subject to rate recovery		0	0
Associated offsetting commodity contracts subject to rate recovery		(1)	(2)
Net amount presented on balance sheet		50	47
Additional margin posted for commodity contracts not subject to rate recovery		0	0
Additional margin posted for commodity contracts subject to rate recovery		0	0
Total	[3]	50	47
Other Noncurrent Assets [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0	0
Associated cash collateral commodity contracts not subject to rate recovery		0	0
Commodity contracts subject to rate recovery		0	0
Associated offsetting commodity contracts subject to rate recovery		0
Net amount presented on balance sheet		0	0
Additional margin posted for commodity contracts not subject to rate recovery		0
Additional margin posted for commodity contracts subject to rate recovery		0	0
Total		0	0
Other Current Liabilities [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2],[4]	(15)	(15)
Commodity contracts not subject to rate recovery	[4]		0
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Interest rate and foreign exchange instruments	[4]	0
Commodity contracts not subject to rate recovery	[4]	(144)	(239)
Associated offsetting commodity contracts not subject to rate recovery	[4]	135	232
Associated cash collateral commodity contracts not subject to rate recovery	[4]	7	4
Commodity contracts subject to rate recovery	[4]	(68)	(61)
Associated cash collateral commodity contracts subject to rate recovery	[4]	31	28
Associated offsetting commodity contracts subject to rate recovery	[4]	4	2
Net amount presented on balance sheet	[4]	(50)	(49)
Additional margin posted for commodity contracts not subject to rate recovery	[4]	0	0
Additional margin posted for commodity contracts subject to rate recovery	[4]	0	0
Total	[3],[4]	(50)	(49)
Other Current Liabilities [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2],[4]	(14)	(14)
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[4]	(1)	(1)
Associated cash collateral commodity contracts not subject to rate recovery	[4]	1	1
Commodity contracts subject to rate recovery	[4]	(65)	(60)
Associated cash collateral commodity contracts subject to rate recovery	[4]	31	28
Associated offsetting commodity contracts subject to rate recovery	[4]	2	2
Net amount presented on balance sheet	[4]	(46)	(44)
Additional margin posted for commodity contracts not subject to rate recovery	[4]	0	0
Additional margin posted for commodity contracts subject to rate recovery	[4]	0	0
Total	[3],[4]	(46)	(44)
Other Current Liabilities [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery	[4]	(1)	(1)
Associated cash collateral commodity contracts not subject to rate recovery	[4]	1	1
Commodity contracts subject to rate recovery	[4]	(3)	(1)
Associated offsetting commodity contracts subject to rate recovery	[4]	2
Net amount presented on balance sheet	[4]	(1)	(1)
Additional margin posted for commodity contracts not subject to rate recovery	[4]	0
Additional margin posted for commodity contracts subject to rate recovery	[4]	0	0
Total	[4]	(1)	(1)
Other Noncurrent Liabilities [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	(166)	(156)
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		0
Commodity contracts not subject to rate recovery		(9)	(21)
Associated offsetting commodity contracts not subject to rate recovery		9	20
Associated cash collateral commodity contracts not subject to rate recovery		0	0
Commodity contracts subject to rate recovery		(61)	(64)
Associated cash collateral commodity contracts subject to rate recovery		24	26
Associated offsetting commodity contracts subject to rate recovery		1	2
Net amount presented on balance sheet		(202)	(193)
Additional margin posted for commodity contracts not subject to rate recovery		0	0
Additional margin posted for commodity contracts subject to rate recovery		0	0
Total	[3]	(202)	(193)
Other Noncurrent Liabilities [Member] | San Diego Gas and Electric Company [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	[2]	(25)	(23)
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0	0
Associated cash collateral commodity contracts not subject to rate recovery		0	0
Commodity contracts subject to rate recovery		(61)	(64)
Associated cash collateral commodity contracts subject to rate recovery		24	26
Associated offsetting commodity contracts subject to rate recovery		1	2
Net amount presented on balance sheet		(61)	(59)
Additional margin posted for commodity contracts not subject to rate recovery		0	0
Additional margin posted for commodity contracts subject to rate recovery		0	0
Total	[3]	(61)	(59)
Other Noncurrent Liabilities [Member] | Southern California Gas Company [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net, Total [Abstract]
Commodity contracts not subject to rate recovery		0	0
Associated cash collateral commodity contracts not subject to rate recovery		0	0
Commodity contracts subject to rate recovery		0	0
Associated offsetting commodity contracts subject to rate recovery		0
Net amount presented on balance sheet		0	0
Additional margin posted for commodity contracts 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&E’s amounts relate to Otay Mesa VIE.
[3]	Normal purchase contracts previously measured at fair value are excluded.
[4]	Included in Current Liabilities: Other for SoCalGas.

DERIVATIVE IMPACT ON THE INCOME

DERIVATIVE IMPACT ON THE INCOME STATEMENT (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		$ (4)	$ (11)
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		1	1
Cash Flow Hedges
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)	[1]	(1)	(2)
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[1]	(165)	(97)
Cash Flow Hedge Ineffectiveness		0	0
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)	[1]	(3)	(3)	[2]
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[1],[2]	(5)	(5)
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)	[2]	(4)	(6)
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)	[2]	(11)	(18)
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)		(137)	(78)
Cash Flow Hedges | Equity Earnings Net Of Income Tax [Member] | Interest Rate And Foreign Exchange Instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)		(1)	0
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)		(18)	0
Cash Flow Hedges | Revenues: Energy-Related Business [Member] | Commodity Contracts Not Subject To Rate Recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) reclassified from AOCI into earnings (effective portion)		7	7
Amount of pretax gain (loss) on derivative recognized in OCI (effective portion)		1	(1)
Fair Value Hedges | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	[3]	2	3
Fair Value Hedges | Interest Expense | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		2	2
Fair Value Hedge Ineffectiveness		0	0
Fair Value Hedges | Other Income, Net | Interest Rate Instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		0	1
Undesignated Derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(9)	(17)
Undesignated Derivatives | Other Income, Net | Foreign Exchange Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		3	0
Undesignated Derivatives | Equity Earnings Net Of Income Tax [Member] | Foreign Exchange Instrument
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		2	(1)
Undesignated Derivatives | Revenues: Energy-Related Business [Member] | Commodity Contracts Not Subject To Rate Recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings		(1)	3
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		(12)	(20)
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		(12)	(20)
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)	1
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)	$ 1
[1]	Amounts include negligible hedge ineffectiveness in the three months ended March 31, 2016 and 2015.
[2]	Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
[3]	There was no hedge ineffectiveness in either the three months ended March 31, 2016 or 2015. 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 INSTRUMENTS - CASH F

DERIVATIVE INSTRUMENTS - CASH FLOW HEDGES (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 21
Maximum Length Of Time Hedged In Interest Rate Cash Flow Hedge 1	13 years
Joint Venture Maximum Length Of Time Hedged In Cash Flow Hedge	19 years
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	$ 12
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum Length Of Time Hedged In Interest Rate Cash Flow Hedge 1	3 years
Cash Flow Hedge Gain (Loss) To Be Reclassified Within Twelve Months For Noncontrolling Interest	$ 12
Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Cash Flow Hedge Gain (Loss) to be Reclassified within Twelve Months	$ 0

DERIVATIVE INSTRUMENTS WITH CON

DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 6	$ 6
Additional Collateral Aggregate Fair Value	7
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	5	$ 5
Additional Collateral Aggregate Fair Value	$ 6

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($) $ in Millions		Mar. 31, 2016	Dec. 31, 2015
Nuclear Decommisioning Trusts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		$ 623	$ 619
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		105	91
Nuclear decommissioning trusts - Municipal bonds		156	156
Nuclear decommissioning trusts - Other securities		190	182
Nuclear decommissioning trusts - Total debt securities		451	429
Total nuclear decommissioning trusts	[1]	1,074	1,048
Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		8	5
Commodity contracts not subject to rate recovery, assets		40	34
Commodity contracts subject to rate recovery, assets		101	101
Total		1,223	1,188
Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		181	171
Commodity contracts not subject to rate recovery, liabilities		2	4
Commodity contracts subject to rate recovery, liabilities		69	67
Total		252	242
San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		623	619
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		105	91
Nuclear decommissioning trusts - Municipal bonds		156	156
Nuclear decommissioning trusts - Other securities		190	182
Nuclear decommissioning trusts - Total debt securities		451	429
Total nuclear decommissioning trusts	[1]	1,074	1,048
San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets		2	1
Commodity contracts subject to rate recovery, assets		98	99
Total		1,174	1,148
San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate instruments		39	37
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		68	66
Total		107	103
Southern California Gas Company [Member] | Derivative Financial Instruments Assets [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	2
Total		4	2
Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		1	1
Total		1	1
Level 1 | Nuclear Decommisioning Trusts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		623	619
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		62	47
Nuclear decommissioning trusts - Municipal bonds		0	0
Nuclear decommissioning trusts - Other securities		0	0
Nuclear decommissioning trusts - Total debt securities		62	47
Total nuclear decommissioning trusts	[1]	685	666
Level 1 | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		0	0
Commodity contracts not subject to rate recovery, assets		1	22
Commodity contracts subject to rate recovery, assets		0	0
Total		686	688
Level 1 | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		0	0
Commodity contracts not subject to rate recovery, liabilities		3	5
Commodity contracts subject to rate recovery, liabilities		0	0
Total		3	5
Level 1 | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities		623	619
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies		62	47
Nuclear decommissioning trusts - Municipal bonds		0	0
Nuclear decommissioning trusts - Other securities		0	0
Nuclear decommissioning trusts - Total debt securities		62	47
Total nuclear decommissioning trusts	[1]	685	666
Level 1 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets		0	0
Commodity contracts subject to rate recovery, assets		0	0
Total		685	666
Level 1 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate instruments		0	0
Commodity contracts not subject to rate recovery, liabilities		1	1
Commodity contracts subject to rate recovery, liabilities		0	0
Total		1	1
Level 1 | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [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		0	0
Level 1 | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, liabilities		1	1
Commodity contracts subject to rate recovery, liabilities		0	0
Total		1	1
Level 2 | Nuclear Decommisioning Trusts [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		43	44
Nuclear decommissioning trusts - Municipal bonds		156	156
Nuclear decommissioning trusts - Other securities		190	182
Nuclear decommissioning trusts - Total debt securities		389	382
Total nuclear decommissioning trusts	[1]	389	382
Level 2 | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		8	5
Commodity contracts not subject to rate recovery, assets		19	16
Commodity contracts subject to rate recovery, assets		1	1
Total		417	404
Level 2 | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		181	171
Commodity contracts not subject to rate recovery, liabilities		6	3
Commodity contracts subject to rate recovery, liabilities		67	68
Total		254	242
Level 2 | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [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		43	44
Nuclear decommissioning trusts - Municipal bonds		156	156
Nuclear decommissioning trusts - Other securities		190	182
Nuclear decommissioning trusts - Total debt securities		389	382
Total nuclear decommissioning trusts	[1]	389	382
Level 2 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets		0	0
Commodity contracts subject to rate recovery, assets		0	0
Total		389	382
Level 2 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate instruments		39	37
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		66	67
Total		105	104
Level 2 | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [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		1	1
Level 2 | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		1	1
Total		1	1
Level 3 | Nuclear Decommisioning Trusts [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 decommissioning trusts - Municipal bonds		0	0
Nuclear decommissioning trusts - Other securities		0	0
Nuclear decommissioning trusts - Total debt securities		0	0
Total nuclear decommissioning trusts	[1]	0	0
Level 3 | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		0	0
Commodity contracts not subject to rate recovery, assets		0	0
Commodity contracts subject to rate recovery, assets		68	72
Total		68	72
Level 3 | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments		0	0
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		57	53
Total		57	53
Level 3 | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [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 decommissioning trusts - Municipal bonds		0	0
Nuclear decommissioning trusts - Other securities		0	0
Nuclear decommissioning trusts - Total debt securities		0	0
Total nuclear decommissioning trusts	[1]	0	0
Level 3 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets		0	0
Commodity contracts subject to rate recovery, assets		68	72
Total		68	72
Level 3 | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate instruments		0	0
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		57	53
Total		57	53
Level 3 | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [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		0	0
Level 3 | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, liabilities		0	0
Commodity contracts subject to rate recovery, liabilities		0	0
Total		0	0
Netting | Nuclear Decommisioning Trusts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	[2]	0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	[2]	0	0
Nuclear decommissioning trusts - Municipal bonds	[2]	0	0
Nuclear decommissioning trusts - Other securities	[2]	0	0
Nuclear decommissioning trusts - Total debt securities	[2]	0	0
Total nuclear decommissioning trusts	[1],[2]	0	0
Netting | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments	[2]	0	0
Commodity contracts not subject to rate recovery, assets	[2]	20	(4)
Commodity contracts subject to rate recovery, assets	[2]	32	28
Total	[2]	52	24
Netting | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate and foreign exchange instruments	[2]	0	0
Commodity contracts not subject to rate recovery, liabilities	[2]	(7)	(4)
Commodity contracts subject to rate recovery, liabilities	[2]	(55)	(54)
Total	[2]	(62)	(58)
Netting | San Diego Gas and Electric Company [Member] | Nuclear Decommisioning Trusts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	[2]	0	0
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	[2]	0	0
Nuclear decommissioning trusts - Municipal bonds	[2]	0	0
Nuclear decommissioning trusts - Other securities	[2]	0	0
Nuclear decommissioning trusts - Total debt securities	[2]	0	0
Total nuclear decommissioning trusts	[1],[2]	0	0
Netting | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	[2]	2	1
Commodity contracts subject to rate recovery, assets	[2]	30	27
Total	[2]	32	28
Netting | San Diego Gas and Electric Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Interest rate instruments	[2]	0	0
Commodity contracts not subject to rate recovery, liabilities	[2]	(1)	(1)
Commodity contracts subject to rate recovery, liabilities	[2]	(55)	(54)
Total	[2]	(56)	(55)
Netting | Southern California Gas Company [Member] | Derivative Financial Instruments Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, assets	[2]	1
Commodity contracts subject to rate recovery, assets	[2]	2	1
Total	[2]	3	1
Netting | Southern California Gas Company [Member] | Derivative Financial Instruments Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity contracts not subject to rate recovery, liabilities	[2]	(1)	(1)
Commodity contracts subject to rate recovery, liabilities	[2]	0	0
Total	[2]	$ (1)	$ (1)
[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 - RECON

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) - USD ($)	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Balance at beginning of period	$ 19,000,000	$ 107,000,000
Realized and unrealized gains (losses)	(1,000,000)	6,000,000
Settlements	(7,000,000)	(11,000,000)
Balance at end of period	11,000,000	102,000,000
Change in unrealized gains relating to instruments still held at the end of the period	(1,000,000)	$ 1,000,000
Maximum [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Congestion Revenue Rights			$ 10	$ 8
Market Electricity Forward Price Inputs	57.43
Minimum [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Congestion Revenue Rights			$ (24)	$ (16)
Market Electricity Forward Price Inputs	$ 15.85

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions		3 Months Ended	12 Months Ended
		Mar. 31, 2016	Dec. 31, 2015
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[1],[2]	$ 13,761	$ 13,761
Preferred Stock Of Subsidiaries Fair Value Disclosure		20	20
Due from affiliate, noncurrent, Fair Value Disclosure	[3]	173	175
Debt Instrument Increase Accrued Interest		13	11
Unamortized Discount and Debt Issuance Costs		106	107
Build-To-Suit and Capital Lease Obligations		386	387
Carrying Amount | Otay Mesa Energy Center Loan Payable Currently Through April 2019 Member [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Debt Instrument Carrying Amount		312	315
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	[2],[4]	4,285	4,304
Capital Lease Obligations		243	244
Unamortized Discount and Debt Issuance Costs		43	43
Carrying Amount | Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	2,513	2,513
Preferred Stock Of Subsidiaries Fair Value Disclosure		22	22
Capital Lease Obligations		1	1
Unamortized Discount and Debt Issuance Costs		24	24
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[1],[2]	15,015	14,633
Preferred Stock Of Subsidiaries Fair Value Disclosure		23	23
Due from affiliate, noncurrent, Fair Value Disclosure	[3]	164	166
Fair Value | Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[1],[2]	0	0
Preferred Stock Of Subsidiaries Fair Value Disclosure		0	0
Due from affiliate, noncurrent, Fair Value Disclosure	[3]	0	0
Fair Value | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[1],[2]	14,363	13,985
Preferred Stock Of Subsidiaries Fair Value Disclosure		23	23
Due from affiliate, noncurrent, Fair Value Disclosure	[3]	92	97
Fair Value | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[1],[2]	652	648
Preferred Stock Of Subsidiaries Fair Value Disclosure		0	0
Due from affiliate, noncurrent, Fair Value Disclosure	[3]	72	69
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	[2],[4]	4,829	4,670
Fair Value | San Diego Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[4]	0	0
Fair Value | San Diego Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[4]	4,517	4,355
Fair Value | San Diego Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[2],[4]	312	315
Fair Value | Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	2,731	2,621
Preferred Stock Of Subsidiaries Fair Value Disclosure		25	25
Fair Value | Southern California Gas Company [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	0	0
Preferred Stock Of Subsidiaries Fair Value Disclosure		0	0
Fair Value | Southern California Gas Company [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	2,731	2,621
Preferred Stock Of Subsidiaries Fair Value Disclosure		25	25
Fair Value | Southern California Gas Company [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of financial instruments, Total long-term debt	[5]	0	0
Preferred Stock Of Subsidiaries Fair Value Disclosure		$ 0	$ 0
[1]	Before reductions for unamortized discount (net of premium) and debt issuance costs of $106 million and $107 million at March 31, 2016 and December 31, 2015, respectively, and excluding build-to-suit and capital lease obligations of $386 million and $387 million at March 31, 2016 and December 31, 2015, 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 $312 million and $315 million at March 31, 2016 and December 31, 2015, respectively, related to Otay Mesa VIE.
[3]	Excluding accumulated interest outstanding of $13 million and $11 million at March 31, 2016 and December 31, 2015, respectively.
[4]	Before reductions for unamortized discount and debt issuance costs of $43 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $243 million and $244 million at March 31, 2016 and December 31, 2015, respectively.
[5]	Before reductions for unamortized discount and debt issuance costs of $24 million at March 31, 2016 and December 31, 2015, and excluding capital lease obligations of $1 million at March 31, 2016 and December 31, 2015.

FAIR VALUE MEASUREMENTS - NONRE

FAIR VALUE MEASUREMENTS - NONRECURRING INPUTS (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 29, 2016	Dec. 31, 2015
Fair Value Inputs Assets Quantitative Information [Line Items]
Equity Method Investments		$ 2,727		$ 2,905
Rockies Express [Member]
Fair Value Inputs Assets Quantitative Information [Line Items]
Equity Method Investment Ownership Percentage			25.00%
Proceeds From Sale Of Equity Method Investments		440
Equity Method Investment, Other than Temporary Impairment		44
Equity Method Investment Other Than Temporary Impairment Net Of Tax Benefit		27
Equity Method Investments		$ 436	$ 484
Market Approach Valuation Technique [Member] | Fair Value, Inputs, Level 2 [Member] | One Hundred Percent [Member] | Rockies Express [Member]
Fair Value Inputs Assets Quantitative Information [Line Items]
Investments In Affiliates Subsidiaries Associates And Joint Ventures Fair Value Disclosure	[1]		$ 440
[1]	At measurement date of March 29, 2016. At March 31, 2016, our investment in Rockies Express had a carrying value of $436 million, reflecting subsequent equity method activity to record a distribution.

NUCLEAR PLANT - INVESTMENT (Det

NUCLEAR PLANT - INVESTMENT (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Nuclear Plant Investment [Line Items]
Loss From Plant Closure, Pretax	$ 0	$ (21)
Loss (Adjustment) From Plant Closure, After Tax		(13)
Loss from plant closure, after-tax (cumulative)	$ 125
Nuclear Plant, Ownership Percentage	20.00%
San Diego Gas and Electric Company [Member]
Nuclear Plant Investment [Line Items]
Utility plant closure (adjustment) loss	$ 0	(21)
Loss (Adjustment) From Plant Closure, After Tax		$ (13)
Loss from plant closure, after-tax (cumulative)	$ 125
Nuclear Plant, Ownership Percentage	20.00%

NUCLEAR PLANT - DECOMMISSIONING

NUCLEAR PLANT - DECOMMISSIONING AND FUNDING (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2015		Sep. 30, 2015	Mar. 31, 2016
Nuclear Plant Decommissioning And Funding [Line Items]
Nuclear decommissioning trusts	$ 1,063	[1]		$ 1,082
San Diego Gas and Electric Company [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Nuclear decommissioning trusts	1,063	[1]		$ 1,082
Year 2013 [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding			$ 55
Amount Pending IRS Clarification			18
Year 2013 [Member] | San Diego Gas and Electric Company [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding			55
Amount Pending IRS Clarification			$ 18
Year 2014 [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding	36
Amount Pending IRS Clarification	13
Year 2014 [Member] | San Diego Gas and Electric Company [Member]
Nuclear Plant Decommissioning And Funding [Line Items]
Authorized Annuial Recovery Amount, Nuclear Decommissioning Trust Funding	36
Amount Pending IRS Clarification	$ 13
[1]	Derived from audited financial statements.

NUCLEAR PLANT - REGULATORY ASSE

NUCLEAR PLANT - REGULATORY ASSET (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	[1]
Regulatory Asset [Line Items]
Regulatory Assets, Noncurrent	$ 3,336	$ 3,273
San Diego Gas and Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets Current	119	107
Regulatory Assets, Noncurrent	968	977
Southern California Gas Company [Member]
Regulatory Asset [Line Items]
Regulatory Assets Current	8	7
Regulatory Assets, Noncurrent	686	$ 636
Nuclear Plant Closure [Member]
Regulatory Asset [Line Items]
Regulatory Asset, Nuclear Plant Closure	243
Regulatory Assets Current	43
Regulatory Assets, Noncurrent	200
Nuclear Plant Closure [Member] | San Diego Gas and Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory Asset, Nuclear Plant Closure	243
Regulatory Assets Current	43
Regulatory Assets, Noncurrent	$ 200
[1]	Derived from audited financial statements.

NUCLEAR PLANT - COST STUDY (Det

NUCLEAR PLANT - COST STUDY (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)
SDG&E Ownership [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	$ 899
SDG&E Ownership [Member] | San Diego Gas and Electric Company [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	899
Total Ownership [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	4,411
Total Ownership [Member] | San Diego Gas and Electric Company [Member]
Environmental Exit Cost [Line Items]
Total Estimated Nuclear Decommissioning Costs, Latest Cost Study	$ 4,411

NUCLEAR PLANT - SETTLEMENT (Det

NUCLEAR PLANT - SETTLEMENT (Details) $ in Millions	3 Months Ended
	Dec. 31, 2015USD ($)
To SDGE [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 80
Nuclear Plant Insurance Recovery Allocation Percentage	5.00%
To SDGE [Member] | San Diego Gas and Electric Company [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 80
Nuclear Plant Insurance Recovery Allocation Percentage	5.00%
Total Ownership [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 400
Total Ownership [Member] | San Diego Gas and Electric Company [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	400
To Ratepayers [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	75
To Ratepayers [Member] | San Diego Gas and Electric Company [Member]
Nuclear Plant Insurance Settlement [Line Items]
Nuclear Plant Insurance Recoveries	$ 75

SONGS NDT 1 (Details)

SONGS NDT 1 (Details) - USD ($) $ in Millions		3 Months Ended			12 Months Ended
		Mar. 31, 2016		Mar. 31, 2015	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Cost		$ 662			$ 660
Gross Unrealized Gains		433			423
Gross Unrealized Loss		(13)			(20)
Estimated fair value		1,082			1,063
Proceeds from sales	[1]	93		$ 94
Gross realized gains		3		2
Gross realized losses		(8)		$ (4)
Total Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Cost		439			431
Gross Unrealized Gains		20			11
Gross Unrealized Loss		(8)			(13)
Estimated fair value		451			429
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		101	[2]		89
Gross Unrealized Gains		4	[2]		2
Gross Unrealized Loss		0	[2]		0
Estimated fair value		105	[2]		91
Municipal Bonds
Schedule of Available-for-sale Securities [Line Items]
Cost		146	[3]		148
Gross Unrealized Gains		10	[3]		8
Gross Unrealized Loss		0	[3]		0
Estimated fair value		156	[3]		156
Other Debt Securities
Schedule of Available-for-sale Securities [Line Items]
Cost		192	[3]		194
Gross Unrealized Gains		6	[3]		1
Gross Unrealized Loss		(8)	[3]		(13)
Estimated fair value		190	[3]		182
Equity Securities
Schedule of Available-for-sale Securities [Line Items]
Cost		214			214
Gross Unrealized Gains		413			412
Gross Unrealized Loss		(4)			(7)
Estimated fair value		623			619
Cash And Cash Equivalents
Schedule of Available-for-sale Securities [Line Items]
Cost		9			15
Gross Unrealized Gains		0			0
Gross Unrealized Loss		(1)			0
Estimated fair value		$ 8			$ 15
[1]	Excludes securities that are held to maturity.
[2]	Maturity dates are 2016-2065.
[3]	Maturity dates are 2016-2115.

CALIFORNIA UTILITIES' REGULAT67

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE (Details) - Year 2016 [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Mar. 31, 2016
San Diego Gas and Electric Company [Member]
Public Utilities General Disclosures [Line Items]
General Rate Case, Revenue Requirement, Revised Request				$ 1,811
General Rate Case, Revenue Requirement Increase, Original Request				133
General Rate Case, Revenue Requirement Increase, Revised Request				$ 17
General Rate Case, Revenue Requirement Percentage Increase, Revised Request	4.30%	3.50%	3.50%	1.00%
General Rate Case, Revised Request Decrease Compared To Original				$ (100)
General Rate Case, Adjustment To Decrease Estimated Revenue Requirement				16
General Rate Case, Proposed Rate Base Adjustment				93
General Rate Case, Tax Memorandum Accounts Balance					$ 39
Southern California Gas Company [Member]
Public Utilities General Disclosures [Line Items]
General Rate Case, Revenue Requirement, Revised Request				2,219
General Rate Case, Revenue Requirement Increase, Original Request				256
General Rate Case, Revenue Requirement Increase, Revised Request				$ 122
General Rate Case, Revenue Requirement Percentage Increase, Revised Request	4.30%	3.50%	3.50%	6.00%
General Rate Case, Revised Request Decrease Compared To Original				$ (133)
General Rate Case, Proposed Rate Base Adjustment				$ 92
General Rate Case, Tax Memorandum Accounts Balance					$ 74

CALIFORNIA UTILITIES' REGULAT68

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF UTILITY PROJECTS (Details) - USD ($) $ in Thousands	3 Months Ended	12 Months Ended
	Mar. 31, 2016	Dec. 31, 2014	Jun. 11, 2014
Southern Gas System Member [Member] | Total Estimated Cost [Member]
Schedule of Utility Projects [Line Items]
Development In Process	$ 23,000
Pipeline Safety And Reliability Project [Member] | Total Estimated Cost [Member]
Schedule of Utility Projects [Line Items]
Revised Estimated Project Cost	633,000
San Diego Gas and Electric Company [Member] | Pipeline Safety Enhancement Plan [Member]
Schedule of Utility Projects [Line Items]
Pipeline Safety Plan Regulatory Account	12,000
Recovery Requested, PSEP Costs	100		$ 100
San Diego Gas and Electric Company [Member] | Sycamore Penasquitos Transmission Project [Member] | Minimum Range [Member]
Schedule of Utility Projects [Line Items]
Estimated Project Cost	120,000
Revised Estimated Project Cost	250,000
San Diego Gas and Electric Company [Member] | Sycamore Penasquitos Transmission Project [Member] | Maximum Range [Member]
Schedule of Utility Projects [Line Items]
Estimated Project Cost	150,000
Revised Estimated Project Cost	300,000
San Diego Gas and Electric Company [Member] | Pipeline Testing/Replacing 1956 to 1961 [Member]
Schedule of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax	500
Southern California Gas Company [Member] | Pipeline Safety Enhancement Plan [Member]
Schedule of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax		$ 5,000
Pipeline Safety Plan Regulatory Account	177,000
Recovery Requested, PSEP Costs	26,800		$ 46,000
Southern California Gas Company [Member] | Pipeline Testing/Replacing 1956 to 1961 [Member]
Schedule of Utility Projects [Line Items]
Disallowed Costs Impact On Earnings After Tax	$ 2,600

CALIFORNIA UTILITIES' REGULAT69

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF WILDFIRE COST RECOVERY (Details) - San Diego Gas and Electric Company [Member]	3 Months Ended
	Sep. 30, 2015USD ($)
Public Utilities General Disclosures [Line Items]
Incurred Costs	$ 2,400,000,000
Requested Recovery	379,000,000
Insurance Reimbursement	1,100,000,000
Third Party Settlement Recoveries	824,000,000
FERC Jurisdictional Rates	$ 80,000,000
Voluntary Shareholder Contribution, Percentage	10.00%
WEMA Balance	$ 42,000,000
FERC-Approved Wildfire Damage Expenses	$ 23,100,000

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) $ in Thousands	Apr. 28, 2016	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	[1]
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value		$ 37,000
Reserve for Aliso Canyon costs		302,000	$ 274,000
Insurance receivable for Aliso Canyon costs		660,000	325,000
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value		29,000
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value		6,000
Reserve for Aliso Canyon costs		302,000	274,000
Insurance receivable for Aliso Canyon costs		660,000	$ 325,000
Wildfire [Member] | San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Regulatory Assets Arising From Wildfire Litigation Costs		363,000
Potential After-Tax Charge for Nonrecovery of CPUC Regulatory Assets		213,000
Portion of Regulatory Assets Arising From Wildfire Litigation Related To CPUC Operations		360,000
Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Loss Contingency Accrual, at Carrying Value		665,000
Liability Insurance Coverage, Maximum		1,000,000
Loss Contingency, Number Of Lawsuits	138
Number Of Lawsuits Filed In Los Angeles County	134
Number Of Lawsuits Filed In San Diego County	2
Number Of Lawsuits Filed In US District Court Of Southern District Of California	2
Maximum Occupational Safety And Health Penalties		280
Civil Penalties Per Day		$ 250
Proportion Of Total Gas Storage Capacity, Percentage		63.00%
Net Book Value Of Aliso Canyon Facility		$ 415,000
Construction Work In Progress Of New Compressor Station		$ 180,000
Estimated Costs Related To Temporary Relocation Percentage		70.00%
Estimated Costs Related To Controlling Well And Stopping Leak And Emissions Percentage		15.00%
[1]	Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIES71

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)	Oct. 01, 2015GBP (£)	Oct. 01, 2014GBP (£)
Wind Farm [Member] | San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Estimated Tax Equity Investment	$ 285
So Cal Gas PCB Litigation [Member] | Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number Of Lawsuits	7
Number of Lawsuits Settled	6
Mobile Gas Litigation [Member]
Loss Contingencies [Line Items]
Loss Contingency, Number Of Lawsuits	14
Number of Lawsuits Settled	11
Loss Contingency Number Of Plaintiffs	250
HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT Tax Claim Paid Upon Appeal | £		£ 156	£ 86
Investment in RBS Sempra Commodities LLP	$ 67

COMMITMENTS AND CONTINGENCIES72

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - Sempra Natural Gas [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)
Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Increase (Decrease) In Commitment Amount	$ (46)
Increase (Decrease) In Commitment Amount, Payments Due, Current	(60)
Increase (Decrease) In Commitment Amount, Payments Due, In Two Years	10
Increase (Decrease) In Commitment Amount, Payments Due, In Three Years	$ 4
Liquefied Natural Gas Contracts [Member]
Payments Under Contractual Commitments [Line Items]
Escalation Percentage Beyond Year 2028	1.00%
Increase (Decrease) In Commitment Amount, Payments Due, Current	$ (146)
Increase (Decrease) In Commitment Amount, Payments Due, In Two Years	(3)
Increase (Decrease) In Commitment Amount, Payments Due, In Three Years	(7)
Increase (Decrease) In Commitment Amount, Payments Due, In Four Years	(18)
Increase (Decrease) In Commitment Amount, Payments Due, In Five Years	(30)
Increase (Decrease) In Commitment Amount, Payments Due, In Thereafter	$ 20

COMMITMENTS AND CONTINGENCIES73

COMMITMENTS AND CONTINGENCIES - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Thousands	Mar. 31, 2016USD ($)
Schedule Of Nuclear Insurance [Line Items]
Nuclear Liability Insurance Coverage, Maximum	$ 375,000
Secondary Financial Protection, Maximum	13,200,000
Secondary Financial Protection, Company Contribution, Maximum	50,930
Secondary Financial Protection, Company Contribution, Annual Maximum	7,600
Nuclear Property Insurance Coverage, Maximum	2,750,000
Nuclear Property Damage Insurance, Premium Assessment	9,700
Nuclear Property Insurance Terrorism Coverage, Maximum	3,240,000
Nuclear Property Insurance, Deductible Per Event	$ 2,500

COMMITMENTS AND CONTINGENCIES74

COMMITMENTS AND CONTINGENCIES - NUCLEAR FUEL DISPOSAL (Details) - San Diego Gas and Electric Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2013USD ($)
SDG&E Ownership [Member]
Jointly Owned Utility Plant Interests [Line Items]
Spent Nuclear Fuel Damages Awarded, Value	$ 32
Total Ownership [Member]
Jointly Owned Utility Plant Interests [Line Items]
Spent Nuclear Fuel Damages Awarded, Value	$ 162

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) - USD ($)		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 2,622,000,000	$ 2,682,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		100.00%	100.00%
Segment reporting information, Interest Expense		$ 143,000,000	$ 134,000,000
Segment reporting information, Interest Income		6,000,000	7,000,000
Segment reporting information, Depreciation and Amortization		$ 328,000,000	$ 303,000,000
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		100.00%	100.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 142,000,000	$ 163,000,000
Equity Earnings (Losses) Recorded Before Tax		(22,000,000)	19,000,000
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax		17,000,000	15,000,000
Segment reporting information, Earnings (Losses)		$ 319,000,000	$ 437,000,000
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		$ 971,000,000	$ 780,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		100.00%	100.00%
Segment reporting information, Assets		$ 41,835,000,000		$ 41,150,000,000	[1]
Segment reporting information, Percentage of Consolidated Assets		100.00%		100.00%
Equity investments In Joint Ventures		$ 2,727,000,000		$ 2,905,000,000
S D G E Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 991,000,000	$ 966,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		38.00%	36.00%
Segment reporting information, Interest Expense		$ 48,000,000	$ 52,000,000
Segment reporting information, Depreciation		$ 159,000,000	$ 145,000,000
Segment reporting information, Percentage of Consolidated Depreciation		49.00%	48.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 72,000,000	$ 88,000,000
Segment reporting information, Earnings (Losses)		$ 129,000,000	$ 147,000,000
Segment reporting information, Percentage of Consolidated Earnings (Losses)		40.00%	34.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 329,000,000	$ 355,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		34.00%	46.00%
Segment reporting information, Assets		$ 16,625,000,000		$ 16,515,000,000
Segment reporting information, Percentage of Consolidated Assets		40.00%		40.00%
Segment Reporting Information, Intersegment Revenues		$ 3,000,000	$ 2,000,000
So Cal Gas Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 1,033,000,000	$ 1,048,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		40.00%	39.00%
Segment reporting information, Interest Expense		$ 22,000,000	$ 19,000,000
Segment reporting information, Depreciation		$ 122,000,000	$ 113,000,000
Segment reporting information, Percentage of Consolidated Depreciation		37.00%	37.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 87,000,000	$ 95,000,000
Segment reporting information, Earnings (Losses)	[2]	$ 195,000,000	$ 214,000,000
Segment reporting information, Percentage of Consolidated Earnings (Losses)		61.00%	49.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 340,000,000	$ 315,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		35.00%	40.00%
Segment reporting information, Assets		$ 12,427,000,000		$ 12,104,000,000
Segment reporting information, Percentage of Consolidated Assets		30.00%		29.00%
Segment Reporting Information, Intersegment Revenues		$ 17,000,000	$ 19,000,000
Sempra South American Utilities Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 400,000,000	$ 389,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		15.00%	15.00%
Segment reporting information, Interest Expense		$ 9,000,000	$ 5,000,000
Segment reporting information, Interest Income		5,000,000	4,000,000
Segment reporting information, Depreciation and Amortization		$ 13,000,000	$ 13,000,000
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		4.00%	4.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 14,000,000	$ 16,000,000
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax		2,000,000	(1,000,000)
Segment reporting information, Earnings (Losses)		$ 38,000,000	$ 41,000,000
Segment reporting information, Percentage of Consolidated Earnings (Losses)		12.00%	9.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 43,000,000	$ 31,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		4.00%	4.00%
Segment reporting information, Assets		$ 3,434,000,000		$ 3,235,000,000
Segment reporting information, Percentage of Consolidated Assets		8.00%		8.00%
Equity investments In Joint Ventures		$ (2,000,000)		$ (4,000,000)
Sempra Mexico Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 138,000,000	$ 163,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		5.00%	6.00%
Segment reporting information, Interest Expense		$ 4,000,000	$ 5,000,000
Segment reporting information, Interest Income		2,000,000	2,000,000
Segment reporting information, Depreciation and Amortization		$ 17,000,000	$ 17,000,000
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		5.00%	6.00%
Segment reporting information, Income Tax Expense (Benefit)		$ 41,000,000	$ 8,000,000
Segment reporting information, Equity Earnings (Losses) Recorded Net of Tax		15,000,000	16,000,000
Segment reporting information, Earnings (Losses)		$ 17,000,000	$ 47,000,000
Segment reporting information, Percentage of Consolidated Earnings (Losses)		5.00%	11.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 40,000,000	$ 55,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		4.00%	7.00%
Segment reporting information, Assets		$ 3,843,000,000		$ 3,783,000,000
Segment reporting information, Percentage of Consolidated Assets		9.00%		9.00%
Equity investments In Joint Ventures		$ 522,000,000		$ 519,000,000
Segment Reporting Information, Intersegment Revenues		27,000,000	$ 25,000,000
Sempra Renewables Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 7,000,000	$ 8,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		0.00%	0.00%
Segment reporting information, Interest Expense		$ 0	$ 1,000,000
Segment reporting information, Interest Income		1,000,000	0
Segment reporting information, Depreciation and Amortization		$ 1,000,000	$ 2,000,000
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		0.00%	1.00%
Segment reporting information, Income Tax Expense (Benefit)		$ (12,000,000)	$ (17,000,000)
Equity Earnings (Losses) Recorded Before Tax		7,000,000	2,000,000
Segment reporting information, Earnings (Losses)		$ 13,000,000	$ 13,000,000
Segment reporting information, Percentage of Consolidated Earnings (Losses)		4.00%	3.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 181,000,000	$ 3,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		19.00%	1.00%
Segment reporting information, Assets		$ 1,454,000,000		$ 1,441,000,000
Segment reporting information, Percentage of Consolidated Assets		3.00%		4.00%
Equity investments In Joint Ventures		$ 823,000,000		$ 855,000,000
Sempra Natural Gas Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue		$ 130,000,000	$ 197,000,000
Segment reporting information, Percentage of Total Consolidated Revenues		5.00%	7.00%
Segment reporting information, Interest Expense		$ 12,000,000	$ 21,000,000
Segment reporting information, Interest Income		16,000,000	19,000,000
Segment reporting information, Depreciation and Amortization		$ 13,000,000	$ 12,000,000
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		4.00%	4.00%
Segment reporting information, Income Tax Expense (Benefit)		$ (25,000,000)	$ 2,000,000
Equity Earnings (Losses) Recorded Before Tax		(29,000,000)	17,000,000
Segment reporting information, Earnings (Losses)		$ (36,000,000)	$ 2,000,000
Segment reporting information, Percentage of Consolidated Earnings (Losses)		(11.00%)	0.00%
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 35,000,000	$ 10,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		4.00%	1.00%
Segment reporting information, Assets		$ 5,395,000,000		$ 5,566,000,000
Segment reporting information, Percentage of Consolidated Assets		13.00%		13.00%
Equity investments In Joint Ventures		$ 1,308,000,000		$ 1,460,000,000
Segment Reporting Information, Intersegment Revenues		30,000,000	$ 43,000,000
Intercompany Eliminations Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Interest Expense		(24,000,000)	(32,000,000)
Segment reporting information, Interest Income		(18,000,000)	(18,000,000)
Intersegment Revenues Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue	[3]	$ (77,000,000)	$ (89,000,000)
Segment reporting information, Percentage of Total Consolidated Revenues		(3.00%)	(3.00%)
Intersegment Receivables Segment [Member]
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Assets		$ (2,084,000,000)		$ (2,228,000,000)
Segment reporting information, Percentage of Consolidated Assets		(5.00%)		(5.00%)
All Other Segments [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Interest Expense		$ 72,000,000	$ 63,000,000
Segment reporting information, Depreciation and Amortization		$ 3,000,000	$ 1,000,000
Segment reporting information, Percentage of Consolidated Depreciation and Amortization		1.00%	0.00%
Segment reporting information, Income Tax Expense (Benefit)		$ (35,000,000)	$ (29,000,000)
Segment reporting information, Earnings (Losses)		$ (37,000,000)	$ (27,000,000)
Segment reporting information, Percentage of Consolidated Earnings (Losses)		(11.00%)	(6.00%)
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Expenditures for property plant and equipment		$ 3,000,000	$ 11,000,000
Segment reporting information, Percentage of Consolidated Expenditures for Property, Plant & Equipment		0.00%	1.00%
Segment reporting information, Assets		$ 741,000,000		$ 734,000,000
Segment reporting information, Percentage of Consolidated Assets		2.00%		2.00%
Equity investments In Joint Ventures		$ 76,000,000		$ 75,000,000
[1]	Derived from audited financial statements.
[2]	After preferred dividends.
[3]	Revenues for reportable segments include intersegment revenues of $3 million, $17 million, $27 million and $30 million for the three months ended March 31, 2016 and $2 million, $19 million, $25 million and $43 million for the three months ended March 31, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively.

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - USD ($) $ in Millions	Apr. 24, 2016	Mar. 31, 2016	Mar. 31, 2015
Assets Held for Sale [Line Items]
Expected Cash Proceeds on Sale	$ 323
Liabilities Assumed	$ 67	$ 0	$ (2)