Southern California Gas Company PFD 6% (SOCGM) 10-Q 2 Nov 16 2016 Q3 Quarterly report Financial data

DOCUMENT AND ENTITY INFORMATION

DOCUMENT AND ENTITY INFORMATION - shares	9 Months Ended
	Sep. 30, 2016	Oct. 27, 2016
Document And Entity Information [Abstract]
Entity Registrant Name	Sempra Energy
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Shares Outstanding		250,060,973
Entity Central Index Key	1,032,208
Trading Symbol	SRE

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
REVENUES
Utilities	$ 2,264	$ 2,213	$ 6,700	$ 6,768
Energy-related businesses	271	268	613	762
Total revenues	2,535	2,481	7,313	7,530
Utilities:
Cost of natural gas	(208)	(201)	(702)	(786)
Cost of electric fuel and purchased power	(604)	(666)	(1,680)	(1,645)
Energy-related businesses:
Cost of natural gas, electric fuel and purchased power	(95)	(91)	(213)	(262)
Other cost of sales	(32)	(34)	(293)	(111)
Operation and maintenance	(703)	(701)	(2,109)	(2,072)
Depreciation and amortization	(328)	(315)	(970)	(925)
Franchise fees and other taxes	(108)	(111)	(315)	(314)
Impairment losses	(132)	0	(154)	0
Plant closure adjustment	0	0	0	21
Gain on sale of assets	131	0	131	62
Equity earnings, before income tax	12	33	4	79
Remeasurement of equity method investment	617	0	617	0
Operating expenses
Impairment losses	132	0	154	0
Other income, net	26	12	98	88
Interest income	7	6	19	23
Interest expense	(136)	(143)	(421)	(416)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	982	270	1,325	1,272
Income tax expense	(282)	(15)	(284)	(276)
Equity earnings, net of income tax	19	27	69	64
Net (loss) income	719	282	1,110	1,060
(Earnings) losses attributable to noncontrolling interest	(97)	(34)	(118)	(79)
Preferred dividends of subsidiary	0	0	(1)	(1)
Earnings	$ 622	$ 248	$ 991	$ 980
Basic earnings per common share (in dollars per share)	$ 2.48	$ 1	$ 3.96	$ 3.95
Weighted-average number of shares outstanding, basic	250,386	248,432	250,073	248,090
Diluted earnings per common share (in dollars per share)	$ 2.46	$ 0.99	$ 3.93	$ 3.91
Weighted-average number of shares outstanding, diluted	252,405	251,024	251,976	250,665
Dividends declared per share of common stock (in dollars per share)	$ 0.76	$ 0.70	$ 2.27	$ 2.10
San Diego Gas and Electric Company [Member]
Operating revenues
Electric	$ 1,111	$ 1,140	$ 2,851	$ 2,819
Natural gas	98	90	341	349
Total operating revenues	1,209	1,230	3,192	3,168
Operating expenses
Cost of electric fuel and purchased power	364	427	926	906
Cost of natural gas	25	27	89	112
Operation and maintenance	268	251	780	723
Depreciation and amortization	161	152	478	446
Franchise fees and other taxes	68	73	190	193
Plant closure adjustment	0	0	0	(21)
Total operating expenses	886	930	2,463	2,359
Operating income	323	300	729	809
Other income, net	11	8	38	26
Interest expense	(49)	(51)	(145)	(155)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	285	257	622	680
Income tax expense	(91)	(75)	(204)	(217)
Net (loss) income	194	182	418	463
(Earnings) losses attributable to noncontrolling interest	(11)	(12)	1	(20)
(Losses) earnings attributable to common shares	183	170	419	443
Southern California Gas Company [Member]
Operating revenues
Total operating revenues	686	620	2,336	2,448
Energy-related businesses:
Impairment losses	(1)	0	(23)	0
Operating expenses
Cost of natural gas	171	163	571	626
Operation and maintenance	322	325	966	985
Depreciation and amortization	121	116	355	342
Franchise fees and other taxes	33	29	100	94
Impairment losses	1	0	23	0
Total operating expenses	648	633	2,015	2,047
Operating income	38	(13)	321	401
Other income, net	8	8	24	25
Interest income	0	0	0	3
Interest expense	(25)	(23)	(71)	(61)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	21	(28)	274	368
Income tax expense	(21)	20	(75)	(91)
Net (loss) income	0	(8)	199	277
Preferred dividend requirements	0	0	(1)	(1)
(Losses) earnings attributable to common shares	$ 0	$ (8)	$ 198	$ 276

CONDENSED CONSOLIDATED STATEME3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Net income (loss)	$ 719	$ 282	$ 1,110	$ 1,060
Other comprehensive income (loss):
Total other comprehensive loss	(13)	(165)	(59)	(264)
Comprehensive income			1,050	773
Preferred dividends of subsidiary	0	0	(1)	(1)
Pretax amount [Member]
Net income (loss)	904	263	1,276	1,257
Other comprehensive income (loss):
Foreign currency translation adjustments	(28)	(92)	51	(197)
Financial instruments	23	(128)	(214)	(122)
Pension and other postretirement benefits	4	7	8	11
Total other comprehensive loss	(1)	(213)	(155)	(308)
Comprehensive income	903	50	1,121	949
Preferred dividends of subsidiary			(1)	(1)
Comprehensive income, after preferred dividends of subsidiary			1,120	948
Income tax (expense) benefit [Member]
Net income (loss)	(282)	(15)	(284)	(276)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0	0
Financial instruments	(10)	50	100	48
Pension and other postretirement benefits	(2)	(2)	(4)	(4)
Total other comprehensive loss	(12)	48	96	44
Comprehensive income	(294)	33	(188)	(232)
Preferred dividends of subsidiary			0	0
Comprehensive income, after preferred dividends of subsidiary			(188)	(232)
Net-of-tax amount [Member]
Net income (loss)	622	248	992	981
Other comprehensive income (loss):
Foreign currency translation adjustments	(28)	(92)	51	(197)
Financial instruments	13	(78)	(114)	(74)
Pension and other postretirement benefits	2	5	4	7
Total other comprehensive loss	(13)	(165)	(59)	(264)
Comprehensive income	609	83	933	717
Preferred dividends of subsidiary			(1)	(1)
Comprehensive income, after preferred dividends of subsidiary			932	716
Noncontrolling Interests (after-tax) [Member]
Net income (loss)	97	34	118	79
Other comprehensive income (loss):
Foreign currency translation adjustments	(7)	(8)	(2)	(21)
Financial instruments	5	(3)	1	(2)
Pension and other postretirement benefits	0	0	0	0
Total other comprehensive loss	(2)	(11)	(1)	(23)
Comprehensive income	95	23	117	56
Preferred dividends of subsidiary			0	0
Comprehensive income, after preferred dividends of subsidiary			117	56
Total [Member]
Net income (loss)	719	282	1,110	1,060
Other comprehensive income (loss):
Foreign currency translation adjustments	(35)	(100)	49	(218)
Financial instruments	18	(81)	(113)	(76)
Pension and other postretirement benefits	2	5	4	7
Total other comprehensive loss	(15)	(176)	(60)	(287)
Comprehensive income	704	106	1,050	773
Preferred dividends of subsidiary			(1)	(1)
Comprehensive income, after preferred dividends of subsidiary			1,049	772
San Diego Gas and Electric Company [Member]
Net income (loss)	194	182	418	463
Other comprehensive income (loss):
Comprehensive income			422	463
San Diego Gas and Electric Company [Member] | Pretax amount [Member]
Net income (loss)	274	245	623	660
Other comprehensive income (loss):
Financial instruments	0	0	0
Total other comprehensive loss	0	0	0
Comprehensive income	274	245	623	660
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit [Member]
Net income (loss)	(91)	(75)	(204)	(217)
Other comprehensive income (loss):
Financial instruments	0	0	0
Total other comprehensive loss	0	0	0
Comprehensive income	(91)	(75)	(204)	(217)
San Diego Gas and Electric Company [Member] | Net-of-tax amount [Member]
Net income (loss)	183	170	419	443
Other comprehensive income (loss):
Financial instruments	0	0	0
Total other comprehensive loss	0	0	0
Comprehensive income	183	170	419	443
San Diego Gas and Electric Company [Member] | Noncontrolling Interests (after-tax) [Member]
Net income (loss)	11	12	(1)	20
Other comprehensive income (loss):
Financial instruments	5	(1)	4
Total other comprehensive loss	5	(1)	4
Comprehensive income	16	11	3	20
San Diego Gas and Electric Company [Member] | Total [Member]
Net income (loss)	194	182	418	463
Other comprehensive income (loss):
Financial instruments	5	(1)	4
Total other comprehensive loss	5	(1)	4
Comprehensive income	199	181	422	463
Southern California Gas Company [Member]
Net income (loss)	0	(8)	199	277
Other comprehensive income (loss):
Total other comprehensive loss	1		1
Comprehensive income			200	277
Southern California Gas Company [Member] | Pretax amount [Member]
Net income (loss)	21	(28)	274	368
Other comprehensive income (loss):
Financial instruments	1		1
Total other comprehensive loss	1		1
Comprehensive income	22	(28)	275	368
Southern California Gas Company [Member] | Income tax (expense) benefit [Member]
Net income (loss)	(21)	20	(75)	(91)
Other comprehensive income (loss):
Financial instruments	0		0
Total other comprehensive loss	0		0
Comprehensive income	(21)	20	(75)	(91)
Southern California Gas Company [Member] | Net-of-tax amount [Member]
Net income (loss)	0	(8)	199	277
Other comprehensive income (loss):
Financial instruments	1		1
Total other comprehensive loss	1		1
Comprehensive income	$ 1	$ (8)	$ 200	$ 277

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 518,000,000	$ 403,000,000	[1]
Restricted cash	14,000,000	27,000,000	[1]
Accounts receivable – trade, net	1,062,000,000	1,283,000,000	[1]
Accounts receivable – other	171,000,000	190,000,000	[1]
Due from unconsolidated affiliates	8,000,000	6,000,000	[1]
Income taxes receivable	28,000,000	30,000,000	[1]
Inventories	302,000,000	298,000,000	[1]
Regulatory balancing accounts – undercollected	248,000,000	307,000,000	[1]
Fixed-price contracts and other derivatives	53,000,000	80,000,000	[1]
Assets held for sale	181,000,000	0	[1]
Other	339,000,000	267,000,000	[1]
Total current assets	2,924,000,000	2,891,000,000	[1]
Other assets:
Restricted cash	12,000,000	20,000,000	[1]
Due from unconsolidated affiliates	195,000,000	186,000,000	[1]
Regulatory assets	3,424,000,000	3,273,000,000	[1]
Nuclear decommissioning trusts	1,068,000,000	1,063,000,000	[1]
Investments	1,840,000,000	2,905,000,000	[1]
Goodwill	2,150,000,000	819,000,000	[1]
Other intangible assets	397,000,000	404,000,000	[1]
Dedicated assets in support of certain benefit plans	439,000,000	464,000,000	[1]
Insurance receivable for Aliso Canyon costs	664,000,000	325,000,000	[1]
Deferred income taxes	211,000,000	120,000,000	[1]
Sundry	715,000,000	641,000,000	[1]
Total other assets	11,115,000,000	10,220,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	41,938,000,000	38,200,000,000	[1]
Less accumulated depreciation and amortization	(10,451,000,000)	(10,161,000,000)	[1]
Property, plant and equipment, net	31,487,000,000	28,039,000,000	[1]
Total assets	45,526,000,000	41,150,000,000	[1]
Current liabilities:
Short-term debt	2,869,000,000	622,000,000	[1]
Accounts payable – trade	1,173,000,000	1,133,000,000	[1]
Accounts payable – other	125,000,000	142,000,000	[1]
Due to unconsolidated affiliates	9,000,000	14,000,000	[1]
Dividends and interest payable	357,000,000	303,000,000	[1]
Accrued compensation and benefits	298,000,000	423,000,000	[1]
Regulatory balancing accounts – overcollected	146,000,000	34,000,000	[1]
Current portion of long-term debt	904,000,000	907,000,000	[1]
Fixed-price contracts and other derivatives	94,000,000	56,000,000	[1]
Customer deposits	153,000,000	153,000,000	[1]
Reserve for Aliso Canyon costs	73,000,000	274,000,000	[1]
Liabilities held for sale	35,000,000	0	[1]
Other	558,000,000	551,000,000	[1]
Total current liabilities	6,794,000,000	4,612,000,000	[1]
Long-term debt	13,522,000,000	13,134,000,000	[1]
Deferred credits and other liabilities:
Customer advances for construction	153,000,000	149,000,000	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	1,199,000,000	1,152,000,000	[1]
Deferred income taxes	3,326,000,000	3,157,000,000	[1]
Deferred investment tax credits	34,000,000	32,000,000	[1]
Regulatory liabilities arising from removal obligations	2,878,000,000	2,793,000,000	[1]
Asset retirement obligations	2,508,000,000	2,126,000,000	[1]
Fixed-price contracts and other derivatives	413,000,000	240,000,000	[1]
Deferred credits and other	1,508,000,000	1,176,000,000	[1]
Total deferred credits and other liabilities	12,019,000,000	10,825,000,000	[1]
Commitments and contingencies (Note 11)
Equity:
Preferred stock	0	0	[1]
Common stock	2,684,000,000	2,621,000,000	[1]
Retained earnings	10,527,000,000	9,994,000,000	[1]
Accumulated other comprehensive income (loss)	(865,000,000)	(806,000,000)	[1]
Total shareholders’ equity	12,346,000,000	11,809,000,000	[1]
Preferred stock of subsidiary	20,000,000	20,000,000	[1]
Other noncontrolling interests	825,000,000	750,000,000	[1]
Total equity	13,191,000,000	12,579,000,000	[1]
Total liabilities and equity	45,526,000,000	41,150,000,000	[1]
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	23,000,000	20,000,000	[1]
Restricted cash	10,000,000	23,000,000	[1]
Accounts receivable – trade, net	358,000,000	331,000,000	[1]
Accounts receivable – other	17,000,000	17,000,000	[1]
Due from unconsolidated affiliates	88,000,000	1,000,000	[1]
Income taxes receivable	84,000,000	1,000,000	[1]
Inventories	73,000,000	75,000,000	[1]
Regulatory balancing accounts – undercollected	248,000,000	307,000,000	[1]
Regulatory assets	124,000,000	107,000,000	[1]
Fixed-price contracts and other derivatives	23,000,000	53,000,000	[1]
Other	98,000,000	69,000,000	[1]
Total current assets	1,146,000,000	1,004,000,000	[1]
Other assets:
Deferred taxes recoverable in rates	971,000,000	914,000,000	[1]
Regulatory assets	1,036,000,000	977,000,000	[1]
Nuclear decommissioning trusts	1,068,000,000	1,063,000,000	[1]
Sundry	373,000,000	301,000,000	[1]
Total other assets	3,448,000,000	3,255,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	17,344,000,000	16,458,000,000	[1]
Less accumulated depreciation and amortization	(4,492,000,000)	(4,202,000,000)	[1]
Property, plant and equipment, net	12,852,000,000	12,256,000,000	[1]
Total assets	17,446,000,000	16,515,000,000	[1]
Current liabilities:
Short-term debt	54,000,000	168,000,000	[1]
Accounts payable – trade	422,000,000	377,000,000	[1]
Due to unconsolidated affiliates	10,000,000	55,000,000	[1]
Interest payable	47,000,000	39,000,000	[1]
Accrued compensation and benefits	87,000,000	129,000,000	[1]
Accrued franchise fees	39,000,000	66,000,000	[1]
Current portion of long-term debt	191,000,000	50,000,000	[1]
Asset retirement obligations	72,000,000	99,000,000	[1]
Fixed-price contracts and other derivatives	59,000,000	51,000,000	[1]
Customer deposits	71,000,000	72,000,000	[1]
Other	116,000,000	101,000,000	[1]
Total current liabilities	1,168,000,000	1,207,000,000	[1]
Long-term debt	4,660,000,000	4,455,000,000	[1]
Deferred credits and other liabilities:
Customer advances for construction	53,000,000	46,000,000	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	226,000,000	212,000,000	[1]
Deferred income taxes	2,628,000,000	2,472,000,000	[1]
Deferred investment tax credits	21,000,000	19,000,000	[1]
Regulatory liabilities arising from removal obligations	1,742,000,000	1,629,000,000	[1]
Asset retirement obligations	760,000,000	729,000,000	[1]
Fixed-price contracts and other derivatives	207,000,000	106,000,000	[1]
Deferred credits and other	441,000,000	364,000,000	[1]
Total deferred credits and other liabilities	6,078,000,000	5,577,000,000	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Common stock	1,338,000,000	1,338,000,000	[1]
Retained earnings	4,160,000,000	3,893,000,000	[1]
Accumulated other comprehensive income (loss)	(8,000,000)	(8,000,000)	[1]
Total shareholders’ equity	5,490,000,000	5,223,000,000	[1]
Other noncontrolling interests	50,000,000	53,000,000	[1]
Total equity	5,540,000,000	5,276,000,000	[1]
Total liabilities and equity	17,446,000,000	16,515,000,000	[1]
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	8,000,000	58,000,000	[1]
Accounts receivable – trade, net	344,000,000	635,000,000	[1]
Accounts receivable – other	81,000,000	99,000,000	[1]
Due from unconsolidated affiliates	35,000,000	48,000,000	[1]
Income taxes receivable	12,000,000	0	[1]
Inventories	77,000,000	79,000,000	[1]
Regulatory assets	8,000,000	7,000,000	[1]
Other	70,000,000	40,000,000	[1]
Total current assets	635,000,000	966,000,000	[1]
Other assets:
Regulatory assets arising from pension obligations	747,000,000	699,000,000	[1]
Regulatory assets	637,000,000	636,000,000	[1]
Insurance receivable for Aliso Canyon costs	664,000,000	325,000,000	[1]
Sundry	276,000,000	207,000,000	[1]
Total other assets	2,324,000,000	1,867,000,000	[1]
Property, plant and equipment:
Property, plant and equipment	15,186,000,000	14,171,000,000	[1]
Less accumulated depreciation and amortization	(4,997,000,000)	(4,900,000,000)	[1]
Property, plant and equipment, net	10,189,000,000	9,271,000,000	[1]
Total assets	13,148,000,000	12,104,000,000	[1]
Current liabilities:
Accounts payable – trade	330,000,000	422,000,000	[1]
Accounts payable – other	72,000,000	76,000,000	[1]
Income taxes payable	0	3,000,000	[1]
Accrued compensation and benefits	119,000,000	160,000,000	[1]
Regulatory balancing accounts – overcollected	146,000,000	34,000,000	[1]
Current portion of long-term debt	1,000,000	9,000,000	[1]
Customer deposits	76,000,000	76,000,000	[1]
Reserve for Aliso Canyon costs	73,000,000	274,000,000	[1]
Other	182,000,000	184,000,000	[1]
Total current liabilities	999,000,000	1,238,000,000	[1]
Long-term debt	2,982,000,000	2,481,000,000	[1]
Deferred credits and other liabilities:
Customer advances for construction	101,000,000	103,000,000	[1]
Pension obligation, net of plan assets	765,000,000	716,000,000	[1]
Deferred income taxes	1,643,000,000	1,532,000,000	[1]
Deferred investment tax credits	12,000,000	14,000,000	[1]
Regulatory liabilities arising from removal obligations	1,136,000,000	1,145,000,000	[1]
Asset retirement obligations	1,714,000,000	1,354,000,000	[1]
Deferred credits and other	433,000,000	372,000,000	[1]
Total deferred credits and other liabilities	5,804,000,000	5,236,000,000	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Preferred stock	22,000,000	22,000,000	[1]
Common stock	866,000,000	866,000,000	[1]
Retained earnings	2,493,000,000	2,280,000,000	[1]
Accumulated other comprehensive income (loss)	(18,000,000)	(19,000,000)	[1]
Total shareholders’ equity	3,363,000,000	3,149,000,000	[1]
Total liabilities and equity	$ 13,148,000,000	$ 12,104,000,000	[1]
[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED BALANCE5

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Property, plant and equipment, net related to VIE	$ 31,487	$ 28,039	[1]
Long term debt related to VIE	$ 13,522	$ 13,134	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized	50,000,000	50,000,000	[1]
Preferred stock, shares issued	0	0	[1]
Common stock, shares authorized	750,000,000	750,000,000	[1]
Common stock, shares outstanding	250,000,000	248,000,000	[1]
Common stock, No par value (in dollars per share)	$ 0	$ 0	[1]
Otay Mesa VIE [Member]
Property, plant and equipment, net related to VIE	$ 365	$ 383	[1]
Long term debt related to VIE	296	303	[1]
San Diego Gas and Electric Company [Member]
Property, plant and equipment, net related to VIE	12,852	12,256	[1]
Long term debt related to VIE	$ 4,660	$ 4,455	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Common stock, shares authorized	255,000,000	255,000,000
Common stock, shares outstanding	117,000,000	117,000,000
Common stock, No par value (in dollars per share)	$ 0	$ 0
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Property, plant and equipment, net related to VIE	$ 365	$ 383
Long term debt related to VIE	296	303
Southern California Gas Company [Member]
Property, plant and equipment, net related to VIE	10,189	9,271	[1]
Long term debt related to VIE	$ 2,982	$ 2,481	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Common stock, shares authorized	100,000,000	100,000,000
Common stock, shares outstanding	91,000,000	91,000,000
Common stock, No par value (in dollars per share)	$ 0	$ 0
[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED STATEME6

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016		Sep. 30, 2015
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 1,110		$ 1,060
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	970		925
Deferred income taxes and investment tax credits	170		179
Impairment losses	154		0
Plant closure adjustment	0		(21)
Gain on sale of assets	(131)		(62)
Equity earnings	(73)		(143)
Remeasurement of equity method investment	(617)		0
Fixed-price contracts and other derivatives	39		(20)
Other	50		28
Net change in other working capital components	224		260
Insurance receivable for Aliso Canyon costs	(339)		0
Changes in other assets	(4)		(112)
Changes in other liabilities	138		(5)
Net cash provided by operating activities	1,691		2,089
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,087)		(2,227)
Expenditures for investments and acquisition of businesses, net of cash and cash equivalents acquired	(1,212)		(183)
Proceeds from sale of assets, net of cash sold	761		347
Distributions from investments	23		14
Purchases of nuclear decommissioning and other trust assets	(418)		(407)
Proceeds from sales by nuclear decommissioning and other trusts	486		431
Increases in restricted cash	(53)		(81)
Decreases in restricted cash	71		68
Advances to unconsolidated affiliates	(12)		(24)
Repayments of advances to unconsolidated affiliates	11		74
Other	(2)		9
Net cash used in investing activities	(3,432)		(1,979)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(510)		(468)
Preferred dividends paid by subsidiary	(1)		(1)
Issuances of common stock	40		41
Repurchases of common stock	(55)		(74)
Issuances of debt (maturities greater than 90 days)	2,013		2,058
Payments on debt (maturities greater than 90 days)	(1,298)		(1,316)
Increase (decrease) in short-term debt, net	1,636		(201)
Deposit for sale of noncontrolling interest	78		0
Net distributions to noncontrolling interests	(43)		(57)
Tax benefit related to share-based compensation	0		56
Other	(12)		(9)
Net cash provided by financing activities	1,848		29
Effect of exchange rate changes on cash and cash equivalents	8		(12)
Increase (decrease) in cash and cash equivalents	115		127
Cash and cash equivalents, January 1	403	[1]	570
Cash and cash equivalents, September 30	518		697
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	367		355
Income tax payments, net of refunds	103		37
Supplemental disclosure of noncash investing and financing activities:
Assets acquired, net of cash and cash equivalents	(2,692)		(10)
Fair value of equity method investment immediately prior to acquisition	(1,144)		0
Liabilities assumed	(448)		(2)
Accrued purchase price	(4)		(5)
Cash paid, net of cash and cash equivalents acquired	1,096		3
Accrued capital expenditures	483		459
Financing of build-to-suit property	0		61
Redemption of industrial development bonds	0		79
Common dividends issued in stock	40		41
Dividends declared but not paid	195		179
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	418		463
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	478		446
Deferred income taxes and investment tax credits	98		170
Plant closure adjustment	0		(21)
Fixed-price contracts and other derivatives	(2)		(3)
Other	(29)		(14)
Net change in other working capital components	14		136
Changes in other assets	(47)		(93)
Changes in other liabilities	3		10
Net cash provided by operating activities	933		1,094
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(959)		(835)
Purchases of nuclear decommissioning trust assets	(415)		(404)
Proceeds from sales by nuclear decommissioning trusts	486		431
Increases in restricted cash	(30)		(29)
Decreases in restricted cash	43		27
Increase in loans to affiliate, net	(107)		0
Net cash used in investing activities	(982)		(810)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(175)		(150)
Issuances of debt (maturities greater than 90 days)	498		388
Payments on debt (maturities greater than 90 days)	(148)		(294)
Increase (decrease) in short-term debt, net	(114)		(202)
Net distributions to noncontrolling interests	(6)		(14)
Other	(3)		0
Net cash provided by financing activities	52		(272)
Increase (decrease) in cash and cash equivalents	3		12
Cash and cash equivalents, January 1	20	[1]	8
Cash and cash equivalents, September 30	23		20
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	132		141
Income tax payments, net of refunds	165		62
Supplemental disclosure of noncash investing and financing activities:
Accrued capital expenditures	139		142
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	199		277
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	355		342
Deferred income taxes and investment tax credits	52		98
Impairment losses	23		0
Other	(22)		(18)
Net change in other working capital components	135		48
Insurance receivable for Aliso Canyon costs	(339)		0
Changes in other assets	2		(57)
Changes in other liabilities	4		0
Net cash provided by operating activities	409		690
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(949)		(946)
Increase in loans to affiliate, net	(1)		(250)
Net cash used in investing activities	(950)		(1,196)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid	(1)		(1)
Issuances of debt (maturities greater than 90 days)	499		599
Payments on debt (maturities greater than 90 days)	(3)		0
Increase (decrease) in short-term debt, net	0		(50)
Other	(4)		(4)
Net cash provided by financing activities	491		544
Increase (decrease) in cash and cash equivalents	(50)		38
Cash and cash equivalents, January 1	58	[1]	85
Cash and cash equivalents, September 30	8		123
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	60		53
Income tax payments, net of refunds	35		11
Supplemental disclosure of noncash investing and financing activities:
Accrued capital expenditures	150		172
Dividends declared but not paid	$ 0		$ 50
[1]	Derived from audited financial statements.

GENERAL

GENERAL	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General	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), which are separate, reportable segments; ▪ Sempra International, which includes our Sempra South American Utilities and Sempra Mexico reportable segments; and ▪ Sempra U.S. Gas & Power, which includes our Sempra Renewables and Sempra Natural Gas reportable segments. We provide descriptions of each of our segments in Note 12. We refer to SDG&E and SoCalGas collectively as the California Utilities, which do not include the utilities in our Sempra International and Sempra U.S. Gas & Power operating units. As we discuss below and in Note 3, Sempra U.S. Gas & Power sold its natural gas distribution utilities in September 2016. Sempra Global is the holding company for most of our subsidiaries that are not subject to California utility regulation. All references in these Notes to “Sempra International,” “Sempra U.S. Gas & Power” and their respective reportable segments are not intended to refer to any legal entity with the same or similar name. Our Sempra Mexico segment includes the operating companies of our subsidiary, Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), as well as certain holding companies and risk management activity. We discuss IEnova further in Note 1 of the Notes to Consolidated Financial Statements in our Annual Report on Form 10-K for the year ended December 31, 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 Note 5 under “Variable Interest Entities.” SDG&E’s common stock is wholly owned by Enova Corporation, which is a wholly owned subsidiary of Sempra Energy. SoCalGas SoCalGas’ 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. Throughout this report, we refer to the following as Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements when discussed together or collectively: ▪ the Condensed Consolidated Financial Statements and related Notes of Sempra Energy and its subsidiaries and VIEs, ▪ the Condensed Consolidated Financial Statements and related Notes of SDG&E and its VIE, and ▪ the Condensed Financial Statements and related Notes of SoCalGas. We have prepared the Condensed Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after September 30, 2016 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. These adjustments are only of a normal, recurring nature. All December 31, 2015 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2015 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim-period-reporting provisions of U.S. GAAP and the Securities and Exchange Commission. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We follow the same accounting policies for interim reporting purposes. 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 Energía S.A. (Chilquinta Energía) in Chile and Luz del Sur S.A.A. (Luz del Sur) in Peru, and their subsidiaries. Sempra Mexico owns Ecogas México, S. de R.L. de C.V. (Ecogas), a natural gas distribution utility in northern Mexico. The California Utilities and Ecogas prepare their financial statements in accordance with U.S. GAAP provisions governing rate-regulated operations, as we discuss in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Sempra Natural Gas owned Mobile Gas Service Corporation (Mobile Gas) in southwest Alabama and Willmut Gas Company (Willmut Gas) in Mississippi until they were sold in September 2016, as we discuss in Note 3. Mobile Gas and Willmut Gas also prepared their financial statements in accordance with U.S. GAAP provisions governing rate-regulated operations. Certain business activities at IEnova are regulated by the Comisión Reguladora de Energía (or CRE, the Energy Regulatory Commission) and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently under construction by IEnova that 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 Notes to Consolidated Financial Statements in the Annual Report.

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
New Accounting Standards	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, “Deferral of the Effective Date,” ASU 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” ASU 2016-10, “Identifying Performance Obligations and Licensing,” and ASU 2016-12, “Narrow-Scope Improvements and Practical Expedients”: ASU 2014-09 provides accounting guidance for the recognition of 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 recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach. Amending ASU 2014-09, ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations, 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, and ASU 2016-12 provides guidance on transition, collectability, noncash consideration, and the presentation of sales and other similar taxes. 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 for fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We plan to adopt ASU 2014-09 on January 1, 2018 and are currently evaluating the transition method and the effect on our ongoing financial reporting. As part of our evaluation, we continue to actively monitor outstanding issues currently being addressed by the American Institute of Certified Public Accountants’ Revenue Recognition Working Group and the Financial Accounting Standards Board’s Transition Resource Group, since conclusions reached by these groups may impact our application of these ASU’s. ASU 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities”: In addition to the presentation and disclosure 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 the 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 adjusted 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 values 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 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to exclude from the balance sheet those leases with a maximum possible term of less than 12 months . For lessees, a lease is classified as finance or operating, and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP, other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and 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 commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases on the balance sheet 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 accounting 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 individual statutory tax rate without resulting in liability classification of the award and clarifies that cash payments made to taxing authorities in connection with withheld shares should be classified as financing activities in the statement of cash flows. 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 early adoption permitted, and is effective for interim periods in the year of adoption. We early adopted the provisions of ASU 2016-09 during the three months ended September 30, 2016, with an effective date of January 1, 2016. Upon adoption: ▪ Sempra Energy, SDG&E and SoCalGas recognized a cumulative-effect adjustment to retained earnings and a deferred tax asset as of January 1, 2016 of $107 million , $23 million and $15 million , respectively, for previously unrecognized excess tax benefits from share-based compensation. ▪ Sempra Energy, SDG&E and SoCalGas recognized earnings consisting of excess tax benefits on the Condensed Consolidated Statements of Operations of $34 million , $7 million and $4 million , respectively, in the nine months ended September 30, 2016, all of which related to the three months ended March 31, 2016. The $34 million was previously recorded in Sempra Energy Shareholders’ Equity in Common Stock prior to adoption of ASU 2016-09. ▪ The $34 million of excess tax benefits from share-based compensation for Sempra Energy related to the three months ended March 31, 2016 was previously classified as a financing activity on Sempra Energy’s Condensed Consolidated Statement of Cash Flows. As now required, the $34 million of excess tax benefits for Sempra Energy, as well as the $7 million for SDG&E and $4 million for SoCalGas, are included in Cash Flows From Operating Activities on the Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2016. This amendment was adopted prospectively, and therefore, we have not adjusted the Condensed Consolidated Statements of Cash Flows for the prior period presented. ▪ As a result of the provision to recognize excess tax benefits in earnings, these benefits are no longer included in the calculation of diluted earnings per share (EPS) effective January 1, 2016. The weighted-average number of common shares outstanding for diluted EPS increased by 75 thousand shares for the three months ended March 31, 2016 and 98 thousand shares and 89 thousand shares for the three months and six months ended June 30, 2016, respectively. We discuss the impact further in Note 5 under “Earnings Per Share.” Upon adoption of ASU 2016-09, we elected to continue estimating the number of awards expected to be forfeited and adjusting our estimate on an ongoing basis. All other provisions of ASU 2016-09 did not impact our financial condition, results of operations or cash flows. ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13 changes how entities will measure credit losses for most financial assets and certain other instruments. The standard introduces an “expected credit loss” impairment model that requires immediate recognition of estimated credit losses expected to occur over the remaining life of most financial assets measured at amortized cost, including trade and other receivables, loan commitments and financial guarantees. ASU 2016-13 also requires use of an allowance to record estimated credit losses on available-for-sale debt securities and expands disclosure requirements regarding an entity’s assumptions, models and methods for estimating the credit losses. For public entities, ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, with early adoption permitted for fiscal years beginning after December 15, 2018. We are currently evaluating the year in which we will adopt the standard and its effect on our ongoing financial reporting. ASU 2016-15, “Classification of Certain Cash Receipts and Cash Payments”: ASU 2016-15 provides guidance on how certain cash receipts and cash payments are to be presented and classified in the statement of cash flows in order to reduce diversity in practice. For public entities, ASU 2016-15 is effective for fiscal years beginning after December 15, 2017, with early adoption permitted, and is effective for interim periods in the year of adoption. An entity that elects early adoption must adopt all of the amendments in the same period. Entities must apply the guidance retrospectively to all periods presented, but may apply it prospectively if retrospective application would be impracticable. We are currently evaluating the year in which we will adopt the standard and its effect on our ongoing financial reporting.

ACQUISITION AND DIVESTITURE ACT

ACQUISITION AND DIVESTITURE ACTIVITY	9 Months Ended
	Sep. 30, 2016
Business Combinations [Abstract]
ACQUISITION AND DIVESTITURE ACTIVITY	ACQUISITION AND DIVESTITURE ACTIVITY We consolidate assets acquired and liabilities assumed as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date. ACQUISITIONS Sempra Mexico Gasoductos de Chihuahua S. de R.L. de C.V. (GdC) Background and Financing. In July 2015, IEnova entered into an agreement to purchase Petróleos Mexicanos’ (or PEMEX, the Mexican state-owned oil company) 50 -percent interest in GdC. GdC develops and operates energy infrastructure in Mexico. On September 21, 2016, IEnova received approval for the acquisition from Mexico’s Comisión Federal de Competencia Económica (COFECE or Mexican Competition Commission). On September 26, 2016, IEnova completed the acquisition of PEMEX’s 50 -percent interest in GdC for a purchase price of $1.144 billion (exclusive of $66 million of cash and cash equivalents acquired), plus the assumption of $364 million of long-term debt, increasing IEnova’s ownership interest in GdC to 100 percent . GdC became a consolidated subsidiary of IEnova on this date. Prior to the acquisition date, IEnova owned 50 percent of GdC and accounted for its interest as an equity method investment. The assets involved in the acquisition include three natural gas pipelines, an ethane pipeline, and a liquid petroleum gas pipeline and associated storage terminal. The transaction excludes the Los Ramones Norte pipeline, in which IEnova will continue holding an indirect 25 -percent ownership interest through GdC’s interest in Ductos y Energéticos del Norte, S. de R.L. de C.V. (DEN). As of the acquisition date, IEnova continues to hold a 50-percent interest in DEN through GdC and accounts for it as an equity method investment. PEMEX continues to hold its 50 -percent interest in DEN, which enables us to have an ongoing relationship with PEMEX for joint development of new projects in the future. We paid $1.078 billion in cash ( $1.144 billion purchase price less $66 million of cash and cash equivalents acquired), which was funded using interim financing provided by Sempra Global through a $1.150 billion bridge loan to IEnova. Sempra Global funded the transaction using commercial paper borrowings. On October 19, 2016, IEnova completed a private follow-on offering of its common stock in the U.S. and outside of Mexico and a concurrent public common stock offering in Mexico, which generated net proceeds of approximately $1.57 billion or 29.86 billion Mexican pesos (based on an exchange rate of 18.96 pesos to 1.00 U.S. dollar as of October 13, 2016). IEnova used a portion of the proceeds from the offerings to fully repay the Sempra Global bridge loan in October 2016. We discuss the offerings in Note 13. Purchase Price Allocation. We accounted for this business combination using the acquisition method of accounting whereby the total fair value of the business acquired is allocated to identifiable assets acquired and liabilities assumed based on respective fair values, with any excess recognized as goodwill at the Sempra Mexico reportable segment. We expect the GdC acquisition to have strategic benefits, including opportunities for asset optimization and expansion into areas such as the transportation and storage of refined products; and a larger platform and presence in Mexico to participate in energy sector reform, reflecting the value of goodwill recognized. None of the goodwill is expected to be deductible in Mexico or the United States for income tax purposes. The following table summarizes the total fair value of the business combination and the values of the assets acquired and liabilities assumed at the date of acquisition: PURCHASE PRICE ALLOCATION – GdC (Dollars in millions) September 26, 2016 Fair value of business combination: Cash consideration (fair value of total consideration) $ 1,144 Fair value of equity interest in GdC immediately prior to acquisition 1,144 Total fair value of business combination $ 2,288 Recognized amounts of identifiable assets acquired and liabilities assumed: Cash and cash equivalents $ 66 Accounts receivable(1) 39 Other current assets 6 Property, plant and equipment 1,248 Other noncurrent assets 1 Accounts payable (11 ) Due to unconsolidated affiliates (3 ) Current portion of long-term debt (49 ) Fixed-price contracts and other derivatives, current (6 ) Other current liabilities (20 ) Long-term debt (315 ) Asset retirement obligations (5 ) Deferred income taxes (8 ) Fixed-price contracts and other derivatives, noncurrent (19 ) Other noncurrent liabilities (11 ) Total identifiable net assets 913 Goodwill 1,375 Total fair value of business combination $ 2,288 (1) We expect acquired accounts receivable to be substantially realizable in cash. Accounts receivable are net of negligible collection allowances. Gain on Remeasurement of Equity Method Investment. Our results in the three months and nine months ended September 30, 2016, include a pretax gain of $617 million ( $432 million after-tax) for the excess of the acquisition-date fair value of Sempra Mexico’s previously held equity interest in GdC over the carrying value of that interest, included as Remeasurement of Equity Method Investment on the Sempra Energy Condensed Consolidated Statements of Operations. We used a market approach to measure the acquisition-date fair value of IEnova’s equity interest in GdC immediately prior to the business acquisition. We discuss non-recurring fair value measures and the associated accounting impact of the GdC acquisition in Note 8. Valuation of GdC’s Assets and Liabilities. Based on the nature of the Mexico regulatory environment and the oversight surrounding the establishment and maintenance of rates that GdC charges for services on its assets, GdC applies the guidance under the provisions of U.S. GAAP governing rate-regulated operations. Therefore, when determining the fair value of the acquired assets and liabilities assumed, we considered the effect of regulation on a market participant’s view of the highest and best use of the assets, in particular for the fair value of GdC’s property, plant and equipment (PP&E). Under U.S. GAAP, regulation is viewed as being a characteristic (restriction) of a regulated entity’s PP&E, and the impact of regulation is considered a fundamental input to measuring the fair value of PP&E in a business combination involving a regulated business. As a regulated business will generally earn a return of its costs and a reasonable return on its invested capital, but nothing more, the value of a regulated business is the value of its invested capital. Under this premise, the fair value of the PP&E of a regulated business is generally assumed to be equivalent to carrying value for financial reporting purposes. Management has concluded that the carrying value of GdC’s PP&E is representative of fair value. We applied an income approach, specifically the discounted cash flow method, to measure the fair value of debt and derivatives. We valued debt by discounting future debt payments by a market yield and we valued derivatives by discounting the future interest payments under the fixed and floating rates using current market data. For substantially all other assets and liabilities, our analysis indicates that historical carrying value approximates fair value due to their short-term nature. Impact on Operating Results. We incurred acquisition costs of $2 million in the three months and nine months ended September 30, 2016, and $1 million in the three months and nine months ended September 30, 2015. These costs are included in Operation and Maintenance Expense on the Sempra Energy Condensed Consolidated Statements of Operations. For the three months and nine months ended September 30, 2016, the Sempra Energy Condensed Consolidated Statements of Operations include $3 million of revenues and $1 million of losses (after noncontrolling interest) from GdC since the September 26, 2016 date of acquisition. The following table presents the pro forma results for the three months and nine months ended September 30, 2016 and 2015. The pro forma financial information combines the historical results of operations of Sempra Energy and GdC as though the acquisition occurred on January 1, 2015. The pro forma information is not necessarily indicative of results that would have been achieved had the business been combined during the periods presented or the results that we will experience going forward. PRO FORMA INFORMATION – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 Revenues $ 2,608 $ 2,545 $ 7,529 $ 7,708 Net income 308 308 744 1,550 Earnings 299 255 685 1,280 The pro forma information above assumes: ▪ the related IEnova equity offerings, discussed above and in Note 13, occurred on January 1, 2015, which results in a change in Sempra Energy’s noncontrolling interest in IEnova from 18.9 percent to 33.6 percent for all periods presented; ▪ the proceeds from the IEnova equity offerings were used to fund the acquisition, instead of the bridge loan that was provided by Sempra Global to IEnova, therefore interest expense on the commercial paper borrowings supporting the bridge loan is excluded for all periods presented; ▪ equity earnings, net of income tax, from GdC that were previously included in Sempra Energy’s results have been excluded for all periods presented; ▪ the gain related to the remeasurement of our previously held equity interest in GdC has been included in the nine months ended September 30, 2015, and accordingly, the three months and nine months ended September 30, 2016 were adjusted to exclude the gain; and ▪ acquisition-related transaction costs have been included in the nine months ended September 30, 2015, and accordingly, the three months and nine months ended September 30, 2016 were adjusted to exclude them. Most of Sempra Mexico’s operations, including GdC, use the U.S. dollar as their functional currency. Sempra Renewables In July 2016, Sempra Renewables acquired a 100 -percent interest in the Apple Blossom Wind project, a 100 -megawatt (MW) wind farm currently under construction in Huron County, Michigan, for a total purchase price of $22 million . Sempra Renewables paid $18 million in cash on the July 1, 2016 acquisition date and anticipates paying the remaining $4 million on achievement of certain construction milestones in the fourth quarter of 2016. The wind farm has a 15 -year power purchase agreement with Consumers Energy that will commence upon commercial operation, expected in late 2017. In March 2015, Sempra Renewables invested $8 million to acquire a 100 -percent interest in the Black Oak Getty Wind project, a 78 -MW wind farm currently under construction in Stearns County, Minnesota. The wind farm has a 20 -year power purchase agreement with Minnesota Municipal Power Agency that will commence upon commercial operation, expected in late 2016. PENDING ACQUISITION Sempra Mexico On September 5, 2016, IEnova entered into an agreement to acquire 100 percent of the equity interests in the Ventika I and Ventika II (collectively, Ventika) wind power generation facilities for an estimated purchase price of $852 million , which includes the assumption of approximately $477 million of existing debt, subject to normal adjustments at closing. Ventika is a 252 -MW wind farm located in Nuevo Leon, Mexico, which began commercial operations in April 2016. All of Ventika’s generation capacity is contracted under 20 -year, U.S. dollar-denominated power purchase agreements with five private off-takers. We expect the acquisition to be completed in the fourth quarter of 2016, subject to the satisfaction of customary closing conditions, including receipt of approval from the COFECE. The acquisition will be partially funded through debt financing at IEnova and a portion of the proceeds from the IEnova equity offerings that we discuss in Note 13. ASSETS HELD FOR SALE We classify assets as held for sale when management approves and commits to a formal plan to actively market an asset for sale and we expect the sale to close within the next 12 months . Upon classifying an asset as held for sale, we record the asset at the lower of its carrying value or its estimated fair value reduced for selling costs. Sempra Mexico In February 2016, management approved a plan to market and sell Sempra Mexico’s Termoeléctrica de Mexicali (TdM), a 625 -MW natural gas-fired power plant located in Mexicali, Baja California, Mexico. As a result, we stopped depreciating the plant and classified it as held for sale. In connection with the sales process, in September 2016, Sempra Mexico obtained market information indicating that the fair value of TdM may be less than its carrying value. After performing an analysis of the information, Sempra Mexico reduced the carrying value of TdM by recognizing a noncash impairment charge of $131 million ( $111 million after-tax) in the three months and nine months ended September 30, 2016 in Impairment Losses on Sempra Energy’s Condensed Consolidated Statements of Operations. We discuss non-recurring fair value measures and the associated accounting impact on TdM in Note 8. In connection with classifying TdM as held for sale, we recognized $32 million in income tax expense in the first half of 2016 for a deferred Mexican income tax liability related to the excess of carrying value over the tax basis. As a result of reducing the carrying value of TdM in the third quarter of 2016, we reduced the deferred Mexican income tax liability by $31 million . As the Mexican income tax on this basis difference is based on current carrying value, foreign exchange rates and inflation, such amount could change in future periods until the date of sale. We expect to complete the sale in the first half of 2017. At September 30, 2016 , the carrying amounts of the major classes of assets and related liabilities held for sale associated with TdM are as follows: ASSETS HELD FOR SALE AT SEPTEMBER 30, 2016 (Dollars in millions) Termoeléctrica de Mexicali Cash and cash equivalents $ 1 Inventories 8 Other current assets 25 Deferred income taxes 5 Other assets 22 Property, plant and equipment, net 120 Total assets held for sale $ 181 Accounts payable $ 1 Other current liabilities 7 Asset retirement obligations 4 Other liabilities 23 Total liabilities held for sale $ 35 DIVESTITURES Sempra Natural Gas EnergySouth Inc. In April 2016, Sempra Natural Gas signed a definitive agreement to sell 100 percent of the outstanding equity of EnergySouth Inc. (EnergySouth), the parent company of Mobile Gas and Willmut Gas, to Spire Inc., formerly The Laclede Group, Inc. On September 12, 2016, Sempra Natural Gas completed the sale for cash proceeds of $318 million , net of $2 million cash sold, with the buyer assuming debt of $67 million . We recognized a pretax gain on the sale of $ 130 million ($ 78 million after-tax) in the three months and nine months ended September 30, 2016, in Gain on Sale of Assets on Sempra Energy’s Condensed Consolidated Statements of Operations. As we discuss in Note 11, litigation and any associated liabilities and insurance receivable at Mobile Gas were retained by Mobile Gas at the close of the transaction. On September 12, 2016, Sempra Natural Gas deconsolidated EnergySouth. The following table summarizes the deconsolidation: DECONSOLIDATION OF SUBSIDIARY (Dollars in millions) EnergySouth Inc. Proceeds from sale, net of transaction costs $ 304 Cash (2 ) Inventory (3 ) Other current assets (14 ) Regulatory assets (12 ) Goodwill (72 ) Other assets (53 ) Property, plant and equipment, net (199 ) Accounts payable 12 Other current liabilities 13 Long-term debt 67 Deferred income taxes 36 Regulatory liabilities 23 Asset retirement obligations 12 Other liabilities 18 Gain on sale of business(1) $ 130 (1) Included in Gain on Sale of Assets on Sempra Energy’s Condensed Consolidated Statements of Operations. Investment in Rockies Express Pipeline LLC In March 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 Tallgrass Development, LP for cash consideration of $440 million , subject to adjustment at closing. The transaction closed in May 2016 for total cash proceeds of $443 million . At the date of the agreement, the carrying value of Sempra Natural Gas’ investment in Rockies Express was $484 million . Following the execution of the agreement, 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 Earnings, Before Income Tax, on the Sempra Energy Condensed Consolidated Statement of Operations in the first quarter of 2016. We discuss non-recurring fair value measures and the associated accounting impact on our investment in Rockies Express in Note 8. In the second quarter of 2016, Sempra Natural Gas permanently released pipeline capacity that it held with Rockies Express and others, as we discuss in Note 11. Mesquite Power Plant In April 2015, Sempra Natural Gas sold the remaining 625 -MW block of the Mesquite Power plant, together with a related power sales contract, for net cash proceeds of $347 million . We recognized a pretax gain on the sale of $61 million ( $36 million after-tax), included in Gain on Sale of Assets on the Sempra Energy Condensed Consolidated Statements of Operations for the nine months ended September 30, 2015 .

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	9 Months Ended
	Sep. 30, 2016
Investments [Abstract]
Investments in Unconsolidated Entities	INVESTMENTS IN UNCONSOLIDATED ENTITIES We provide additional information concerning our equity method investments in Note 3 above and in Notes 3 and 4 of the Notes to Consolidated Financial Statements in the Annual Report. SEMPRA MEXICO As we discuss in Note 3, on September 26, 2016, IEnova completed the acquisition of the remaining 50 -percent interest in GdC and GdC became a consolidated subsidiary. Prior to the acquisition date, IEnova owned 50 percent of GdC and accounted for its interest as an equity method investment. As of the acquisition date, IEnova accounts for GdC’s 50 -percent interest in DEN as an equity method investment. In June 2016, Infraestructura Marina del Golfo (IMG), a joint venture between IEnova and a subsidiary of TransCanada Corporation (TransCanada), was awarded the right to build, own and operate the Sur de Texas – Tuxpan natural gas pipeline by the Federal Electricity Commission (Comisión Federal de Electricidad, or CFE). IEnova has a 40 -percent interest in the project and TransCanada owns the remaining 60 -percent interest. The project is expected to be completed in late 2018 and is fully contracted under a 25 -year natural gas transportation service contract with the CFE. During the nine months ended September 30, 2016 , Sempra Mexico invested cash of $56 million in the joint venture. SEMPRA RENEWABLES Sempra Renewables invested cash of $18 million in its joint ventures during both the nine months ended September 30, 2016 and 2015 . SEMPRA NATURAL GAS Sempra Natural Gas capitalized $36 million of interest during both the nine months ended September 30, 2016 and 2015 related to its investment in Cameron LNG Holdings, LLC (Cameron LNG JV), which has not commenced planned principal operations. In addition, during the nine months ended September 30, 2015 , Sempra Natural Gas invested cash of $10 million in the joint venture. In May 2016, Sempra Natural Gas sold its 25 -percent interest in Rockies Express, as we discuss in Note 3. In April 2015, Sempra Natural Gas invested $113 million of cash in Rockies Express to repay project debt that matured in early 2015. GUARANTEES We discuss guarantees that we have provided in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report. These guarantees have a maximum aggregate amount of $4.5 billion and an aggregate carrying value of $58 million at September 30, 2016 .

OTHER FINANCIAL DATA

OTHER FINANCIAL DATA	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Other Financial Data	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 September 30, 2016 December 31, 2015 September 30, 2016 December 31, 2015 September 30, 2016 December 31, 2015 September 30, 2016 December 31, 2015 SDG&E $ 1 $ 6 $ — $ — $ 72 $ 69 $ 73 $ 75 SoCalGas(1) 24 49 — — 53 30 77 79 Sempra South American Utilities — — — — 46 30 46 30 Sempra Mexico — — 4 3 2 10 6 13 Sempra Renewables — — — — 3 3 3 3 Sempra Natural Gas 94 94 3 3 — 1 97 98 Sempra Energy Consolidated $ 119 $ 149 $ 7 $ 6 $ 176 $ 143 $ 302 $ 298 (1) At both September 30, 2016 and December 31, 2015 , SoCalGas’ natural gas inventory for core customers is net of an inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11. Temporary LIFO Liquidation The California Utilities value natural gas inventory using the last-in first-out (LIFO) method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. These differences are generally temporary, but may become permanent. For interim periods, temporary LIFO liquidation represents the difference between the carrying value of natural gas inventory withdrawn from storage during the period for delivery to customers and the projected cost of the replacement of that inventory by year end. At September 30, 2016, temporary LIFO liquidation of $8 million is recorded in Other Assets on the Sempra Energy and SoCalGas Condensed Consolidated Balance Sheets. SoCalGas estimates that by December 31, 2016, temporary LIFO liquidation may not be replenished, and may result in a permanent LIFO liquidation of approximately $10 million to $15 million . This change in natural gas cost would be recovered in rates. GOODWILL We discuss goodwill in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Changes in the carrying amount of goodwill on the Sempra Energy Consolidated Balance Sheets are as follows: GOODWILL (Dollars in millions) Sempra South American Utilities Sempra Mexico Sempra Natural Gas Total Balance at December 31, 2015 $ 722 $ 25 $ 72 $ 819 Acquisition of business — 1,375 — 1,375 Sale of business — — (72 ) (72 ) Foreign currency translation(1) 28 — — 28 Balance at September 30, 2016 $ 750 $ 1,400 $ — $ 2,150 (1) We record the offset of this fluctuation to Other Comprehensive Income (Loss). In September 2016, Sempra Mexico recorded goodwill of $1,375 million in connection with the acquisition of GdC, and Sempra Natural Gas reduced goodwill by $72 million in connection with the sale of EnergySouth. We discuss this acquisition and divestiture in Note 3. 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 on 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 supplies all of the natural gas to fuel the power plant (i.e., tolling agreements). SDG&E’s obligation to absorb natural gas costs may be a significant variable interest. In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based upon our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility’s useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which we consider the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If we determine that SDG&E is the primary beneficiary, SDG&E and Sempra Energy consolidate the entity that owns the facility as a VIE. 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 exercise its option, under certain circumstances, it may be required to purchase the power plant at a predetermined price, which we refer to as the put option. The facility owner, Otay Mesa Energy Center LLC (OMEC LLC), is a VIE (Otay Mesa VIE), of which SDG&E is the primary beneficiary. SDG&E has no OMEC LLC voting rights, holds no equity in OMEC LLC and does not operate OMEC. In addition to the risks absorbed under the tolling agreement, SDG&E absorbs separately through the put option a significant portion of the risk that the value of Otay Mesa VIE could decline. Accordingly, SDG&E and Sempra Energy have consolidated Otay Mesa VIE. Otay Mesa VIE’s equity of $50 million at September 30, 2016 and $53 million at December 31, 2015 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E. OMEC LLC has a loan outstanding of $307 million at September 30, 2016 , the proceeds of which were used for the construction of OMEC. The loan is with third party lenders and is secured by OMEC’s property, plant and equipment. SDG&E is not a party to the loan agreement and does not have any additional implicit or explicit financial responsibility to OMEC LLC. The loan fully matures in April 2019 and bears interest at rates varying with market rates. In addition, OMEC LLC has entered into interest rate swap agreements to moderate its exposure to interest rate changes. We provide additional information concerning the interest rate swaps in Note 7. 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 below generally correspond to SDG&E’s Condensed Consolidated Statements of Operations. AMOUNTS ASSOCIATED WITH OTAY MESA VIE (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 Operating expenses Cost of electric fuel and purchased power $ (28 ) $ (27 ) $ (62 ) $ (66 ) Operation and maintenance 4 3 23 13 Depreciation and amortization 8 7 25 19 Total operating expenses (16 ) (17 ) (14 ) (34 ) Operating income 16 17 14 34 Interest expense (5 ) (5 ) (15 ) (14 ) Income (loss) before income taxes/Net income (loss) 11 12 (1 ) 20 (Earnings) losses attributable to noncontrolling interest (11 ) (12 ) 1 (20 ) 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 of a variable interest entity at September 30, 2016 . In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs, and other components of cash flow expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects are not expected to significantly affect the financial position, results of operations, or liquidity of SDG&E. In addition, SDG&E is not exposed to losses or gains as a result of these other VIEs, because all such variability would be recovered in rates. 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 Statements 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 a VIE principally 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) related to interest-rate cash flow hedges at Cameron LNG JV, was $838 million at September 30, 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 Statements in the Annual 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 on the qualitative and quantitative analyses described above. Certain of these entities are service companies that are VIEs. As the primary beneficiary of these service companies, we consolidate them; 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 September 30, 2016 2015 2016 2015 Service cost $ 26 $ 27 $ 4 $ 5 Interest cost 40 38 9 10 Expected return on assets (41 ) (42 ) (17 ) (17 ) Amortization of: Prior service cost (credit) 2 3 — (1 ) Actuarial loss (gain) 10 9 (1 ) — Settlements — 4 — — Regulatory adjustment (28 ) (27 ) 5 4 Total net periodic benefit cost $ 9 $ 12 $ — $ 1 Nine months ended September 30, 2016 2015 2016 2015 Service cost $ 81 $ 86 $ 15 $ 19 Interest cost 120 116 31 33 Expected return on assets (124 ) (130 ) (52 ) (51 ) Amortization of: Prior service cost (credit) 8 8 — (2 ) Actuarial loss (gain) 23 28 (1 ) — Settlements — 4 — — Regulatory adjustment (84 ) (86 ) 9 4 Total net periodic benefit cost $ 24 $ 26 $ 2 $ 3 NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2016 2015 2016 2015 Service cost $ 7 $ 6 $ 1 $ 1 Interest cost 10 9 2 2 Expected return on assets (12 ) (14 ) (3 ) (2 ) Amortization of: Actuarial loss 2 3 — — Regulatory adjustment (7 ) (3 ) — (1 ) Total net periodic benefit cost $ — $ 1 $ — $ — Nine months ended September 30, 2016 2015 2016 2015 Service cost $ 22 $ 22 $ 3 $ 5 Interest cost 31 29 6 6 Expected return on assets (37 ) (41 ) (8 ) (8 ) Amortization of: Prior service cost 1 1 2 2 Actuarial loss (gain) 7 7 (1 ) — Regulatory adjustment (22 ) (15 ) (2 ) (5 ) Total net periodic benefit cost $ 2 $ 3 $ — $ — NET PERIODIC BENEFIT COST – SOCALGAS (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2016 2015 2016 2015 Service cost $ 16 $ 17 $ 4 $ 3 Interest cost 26 25 7 8 Expected return on assets (26 ) (25 ) (15 ) (14 ) Amortization of: Prior service cost (credit) 3 2 (1 ) (2 ) Actuarial loss 3 5 — — Regulatory adjustment (21 ) (24 ) 5 5 Total net periodic benefit cost $ 1 $ — $ — $ — Nine months ended September 30, 2016 2015 2016 2015 Service cost $ 51 $ 55 $ 11 $ 13 Interest cost 76 74 24 26 Expected return on assets (78 ) (79 ) (43 ) (42 ) Amortization of: Prior service cost (credit) 7 6 (3 ) (6 ) Actuarial loss 8 16 — — Regulatory adjustment (62 ) (71 ) 11 9 Total net periodic benefit cost $ 2 $ 1 $ — $ — Benefit Plan Contributions The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2016: BENEFIT PLAN CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Contributions through September 30, 2016: Pension plans $ 24 $ 2 $ 1 Other postretirement benefit plans 3 — 1 Total expected contributions in 2016: Pension plans $ 124 $ 7 $ 73 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 $439 million and $464 million at September 30, 2016 and December 31, 2015 , respectively. EARNINGS PER SHARE The following table provides EPS computations for the three months and nine months ended September 30, 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 September 30, Nine months ended September 30, 2016 2015 2016 2015 Numerator: Earnings/Income attributable to common shares $ 622 $ 248 $ 991 $ 980 Denominator: Weighted-average common shares outstanding for basic EPS(1) 250,386 248,432 250,073 248,090 Dilutive effect of stock options, restricted stock awards and restricted stock units(2) 2,019 2,592 1,903 2,575 Weighted-average common shares outstanding for diluted EPS(2) 252,405 251,024 251,976 250,665 Earnings per share: Basic $ 2.48 $ 1.00 $ 3.96 $ 3.95 Diluted 2.46 0.99 3.93 3.91 (1) Includes 572 and 504 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended September 30, 2016 and 2015 , respectively, and 565 and 486 of such units for the nine months ended September 30, 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. (2) Reflects the prospective adoption of ASU 2016-09 as of January 1, 2016, as we discuss in Note 2. Prior to the adoption, the dilutive effect of stock options, restricted stock awards and restricted stock units was reduced by excess tax benefits assumed to be used to repurchase shares on the open market. The potentially dilutive impact from stock options, restricted stock awards (RSAs) and restricted stock units (RSUs) is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS excludes 2,426 RSUs for the nine months ended September 30, 2016 because to include them would be antidilutive for the period. However, these RSUs could potentially dilute basic EPS in the future. There were no antidilutive RSUs for the three months ended September 30, 2016 , and there were no antidilutive stock options or RSAs for the three months and nine months ended September 30, 2016 . There were no antidilutive RSUs, stock options or RSAs for the three months and nine months ended September 30, 2015 . Prior to adoption of ASU 2016-09 as of January 1, 2016, which we discuss in Note 2, excess tax benefits were also assumed to be used to repurchase shares on the open market when applying the treasury stock method. The excess tax benefits are tax deductions we would receive upon the assumed exercise of stock options and assumed vesting of RSAs and RSUs in excess of the deferred income taxes we recorded related to the compensation expense on such stock options, awards and units. Tax shortfalls occur when the assumed tax deductions are less than recorded deferred income taxes. Upon adoption of ASU 2016-09, as a result of the provision to recognize excess tax benefits and shortfalls in earnings, these benefits and shortfalls are no longer included in the calculation of diluted EPS beginning January 1, 2016. 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 targets. TSR RSUs represent the right to receive from zero to 1.5 shares ( 2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate. We discuss performance-based RSU awards further in Note 8 of the Notes to Consolidated 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 include our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of both Sempra Energy stock and the comparative indices, dilutive TSR RSU shares may vary widely from period-to-period. If it were assumed that performance goals for all performance-based RSUs were met at maximum levels and if the treasury stock method were not applied to any of our RSAs or RSUs, the incremental potential dilutive shares would be 2,273,102 and 2,001,020 for the three months ended September 30, 2016 and 2015 , respectively, and 2,406,512 and 2,047,656 for the nine months ended September 30, 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 for each of the three months ended September 30, 2016 and 2015 , and $20 million and $22 million for the nine months ended September 30, 2016 and 2015 , respectively. Pursuant to our Sempra Energy share-based compensation plans, Sempra Energy’s compensation committee granted 373,070 TSR RSUs, 94,760 EPS RSUs and 95,876 service-based RSUs during the nine months ended September 30, 2016 , primarily in January. During the nine months ended September 30, 2016 , IEnova issued 378,367 RSUs from the IEnova 2013 Long-Term Incentive Plan, under which awards are cash settled at vesting based on the price of IEnova common stock. CAPITALIZED FINANCING COSTS Capitalized financing costs include capitalized interest costs and 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 and nine months ended September 30, 2016 and 2015 . CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 Sempra Energy Consolidated: AFUDC related to debt $ 7 $ 6 $ 22 $ 19 AFUDC related to equity 29 26 86 84 Other capitalized interest 26 18 64 52 Total Sempra Energy Consolidated $ 62 $ 50 $ 172 $ 155 SDG&E: AFUDC related to debt $ 4 $ 3 $ 12 $ 10 AFUDC related to equity 11 9 35 27 Total SDG&E $ 15 $ 12 $ 47 $ 37 SoCalGas: AFUDC related to debt $ 3 $ 3 $ 10 $ 9 AFUDC related to equity 10 10 30 29 Other capitalized interest 1 1 1 1 Total SoCalGas $ 14 $ 14 $ 41 $ 39 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) Foreign currency translation adjustments Financial instruments Pension and other postretirement benefits Total accumulated other comprehensive income (loss) Three months ended September 30, 2016 and 2015 2016: Balance as of June 30, 2016 $ (503 ) $ (264 ) $ (85 ) $ (852 ) Other comprehensive (loss) income before reclassifications (28 ) 8 — (20 ) Amounts reclassified from accumulated other comprehensive income — 5 2 7 Net other comprehensive (loss) income (28 ) 13 2 (13 ) Balance as of September 30, 2016 $ (531 ) $ (251 ) $ (83 ) $ (865 ) 2015: Balance as of June 30, 2015 $ (427 ) $ (86 ) $ (83 ) $ (596 ) Other comprehensive loss before reclassifications (92 ) (79 ) — (171 ) Amounts reclassified from accumulated other comprehensive income — 1 5 6 Net other comprehensive (loss) income (92 ) (78 ) 5 (165 ) Balance as of September 30, 2015 $ (519 ) $ (164 ) $ (78 ) $ (761 ) Nine months ended September 30, 2016 and 2015 2016: Balance as of December 31, 2015 $ (582 ) $ (137 ) $ (87 ) $ (806 ) Other comprehensive income (loss) before reclassifications 51 (122 ) — (71 ) Amounts reclassified from accumulated other comprehensive income — 8 4 12 Net other comprehensive income (loss) 51 (114 ) 4 (59 ) Balance as of September 30, 2016 $ (531 ) $ (251 ) $ (83 ) $ (865 ) 2015: . Balance as of December 31, 2014 $ (322 ) $ (90 ) $ (85 ) $ (497 ) Other comprehensive loss before reclassifications (197 ) (76 ) — (273 ) Amounts reclassified from accumulated other comprehensive income — 2 7 9 Net other comprehensive (loss) income (197 ) (74 ) 7 (264 ) Balance as of September 30, 2015 $ (519 ) $ (164 ) $ (78 ) $ (761 ) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) SOUTHERN CALIFORNIA GAS COMPANY (Dollars in Millions) Financial instruments Pension and other Total accumulated other comprehensive income (loss) Three months ended September 30, 2016 and 2015 2016: Balance as of June 30, 2016 $ (14 ) $ (5 ) $ (19 ) Amounts reclassified from accumulated other comprehensive income 1 — 1 Net other comprehensive income 1 — 1 Balance as of September 30, 2016 $ (13 ) $ (5 ) $ (18 ) 2015: Balance as of June 30 and September 30, 2015 $ (14 ) $ (4 ) $ (18 ) Nine months ended September 30, 2016 and 2015 2016: Balance as of December 31, 2015 $ (14 ) $ (5 ) $ (19 ) Amounts reclassified from accumulated other comprehensive income 1 — 1 Net other comprehensive income 1 — 1 Balance as of September 30, 2016 $ (13 ) $ (5 ) $ (18 ) 2015: Balance as of December 31, 2014 and September 30, 2015 $ (14 ) $ (4 ) $ (18 ) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests. RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated other Amounts reclassified Affected line item on Condensed Three months ended September 30, 2016 2015 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments $ 4 $ 5 Interest Expense Interest rate instruments 3 3 Equity Earnings, Before Income Tax Interest rate and foreign exchange instruments 7 — Remeasurement of Equity Method Investment Interest rate and foreign exchange instruments (2 ) — Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery — (3 ) Revenues: Energy-Related Businesses Total before income tax 12 5 (3 ) (1 ) Income Tax Expense Net of income tax 9 4 (4 ) (3 ) Earnings Attributable to Noncontrolling Interests $ 5 $ 1 Pension and other postretirement benefits: Amortization of actuarial loss $ 4 $ 7 See note (1) below (2 ) (2 ) Income Tax Expense Net of income tax $ 2 $ 5 Total reclassifications for the period, net of tax $ 7 $ 6 SDG&E: Financial instruments: Interest rate instruments $ 3 $ 3 Interest Expense (3 ) (3 ) (Earnings) Losses Attributable to Noncontrolling Interest Total reclassifications for the period, net of tax $ — $ — SoCalGas: Financial instruments: Interest rate instruments $ 1 $ — Interest Expense Total reclassifications for the period, net of tax $ 1 $ — (1) Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated other Amounts reclassified Affected line item on Condensed Nine months ended September 30, 2016 2015 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments $ 11 $ 14 Interest Expense Interest rate instruments 8 9 Equity Earnings, Before Income Tax Interest rate and foreign exchange instruments 7 — Remeasurement of Equity Method Investment Interest rate and foreign exchange instruments 4 — Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery (7 ) (10 ) Revenues: Energy-Related Businesses Total before income tax 23 13 (4 ) (1 ) Income Tax Expense Net of income tax 19 12 (11 ) (10 ) Earnings Attributable to Noncontrolling Interests $ 8 $ 2 Pension and other postretirement benefits: Amortization of actuarial loss $ 8 $ 11 See note (1) below (4 ) (4 ) Income Tax Expense Net of income tax $ 4 $ 7 Total reclassifications for the period, net of tax $ 12 $ 9 SDG&E: Financial instruments: Interest rate instruments $ 9 $ 9 Interest Expense (9 ) (9 ) (Earnings) Losses Attributable to Noncontrolling Interest Total reclassifications for the period, net of tax $ — $ — SoCalGas: Financial instruments: Interest rate instruments $ 1 $ — Interest Expense Total reclassifications for the period, net of tax $ 1 $ — (1) Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above). For the three months and nine months ended September 30, 2016 and 2015 , Other Comprehensive Income (Loss) (OCI), excluding amounts attributable to noncontrolling interests, at SDG&E was negligible. SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS The following tables provide reconciliations of changes in Sempra Energy’s, SDG&E’s and SoCalGas’ shareholders’ equity and noncontrolling interests for the nine months ended September 30, 2016 and 2015 . SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Sempra Energy ’ equity Non- Total Balance at December 31, 2015 $ 11,809 $ 770 $ 12,579 Cumulative-effect adjustment from change in accounting principle 107 — 107 Comprehensive income 933 117 1,050 Preferred dividends of subsidiary (1 ) — (1 ) Share-based compensation expense 38 — 38 Common stock dividends declared (565 ) — (565 ) Issuances of common stock 80 — 80 Repurchases of common stock (55 ) — (55 ) Equity contributed by noncontrolling interests — 2 2 Distributions to noncontrolling interests — (44 ) (44 ) Balance at September 30, 2016 $ 12,346 $ 845 $ 13,191 Balance at December 31, 2014 $ 11,326 $ 774 $ 12,100 Comprehensive income 717 56 773 Preferred dividends of subsidiary (1 ) — (1 ) Share-based compensation expense 39 — 39 Common stock dividends declared (520 ) — (520 ) Issuances of common stock 82 — 82 Repurchases of common stock (74 ) — (74 ) Tax benefit related to share-based compensation 56 — 56 Equity contributed by noncontrolling interest — 1 1 Distributions to noncontrolling interests — (60 ) (60 ) Balance at September 30, 2015 $ 11,625 $ 771 $ 12,396 (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 ’ s Non- Total Balance at December 31, 2015 $ 5,223 $ 53 $ 5,276 Cumulative-effect adjustment from change in accounting principle 23 — 23 Comprehensive income 419 3 422 Common stock dividends declared (175 ) — (175 ) Equity contributed by noncontrolling interest — 1 1 Distributions to noncontrolling interest — (7 ) (7 ) Balance at September 30, 2016 $ 5,490 $ 50 $ 5,540 Balance at December 31, 2014 $ 4,932 $ 60 $ 4,992 Comprehensive income 443 20 463 Common stock dividends declared (150 ) — (150 ) Distributions to noncontrolling interest — (16 ) (16 ) Balance at September 30, 2015 $ 5,225 $ 64 $ 5,289 SHAREHOLDERS’ EQUITY – SOCALGAS (Dollars in millions) SoCalGas Balance at December 31, 2015 $ 3,149 Cumulative-effect adjustment from change in accounting principle 15 Comprehensive income 200 Preferred stock dividends declared (1 ) Balance at September 30, 2016 $ 3,363 Balance at December 31, 2014 $ 2,781 Comprehensive income 277 Preferred stock dividends declared (1 ) Common stock dividends declared (50 ) Balance at September 30, 2015 $ 3,007 Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as noncontrolling interests. As a result, noncontrolling interests are reported as a separate component of equity on the Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income (Loss). Preferred Stock At Sempra Energy, the preferred stock of SoCalGas is presented as a noncontrolling interest and preferred stock dividends are charges against income related to noncontrolling interests. We provide additional inf

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Debt and Credit Facilities	DEBT AND CREDIT FACILITIES LINES OF CREDIT At September 30, 2016 , Sempra Energy Consolidated had an aggregate of $4.3 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 principal terms of which we describe below. Available unused credit on these lines at September 30, 2016 was approximately $2.0 billion . Our foreign operations have additional general purpose credit facilities aggregating $1.1 billion at September 30, 2016 . Available unused credit on these lines totaled $429 million at September 30, 2016 . Sempra Energy Sempra Energy has a $1 billion , five -year syndicated revolving credit agreement expiring in October 2020. On September 30, 2016, an additional lender was added to the facility. Citibank, N.A. serves as administrative agent for the syndicate of, now, 21 lenders, and no single lender has greater than a 7 -percent share. 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 total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At September 30, 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 Energy with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. At September 30, 2016 , Sempra Energy had no outstanding borrowings or letters of credit supported by the facility. Sempra Global Sempra Global has a five -year syndicated revolving credit agreement expiring in October 2020. On September 30, 2016, an additional lender was added to the facility, and the borrowing capacity increased from $2.21 billion to $2.34 billion . Citibank, N.A. serves as administrative agent for the syndicate of, now, 21 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 total capitalization (as defined in the agreement) of no more than 65 percent at the end of each quarter. At September 30, 2016 , Sempra Energy was in compliance with this and all other financial covenants under the credit facility. At September 30, 2016 , Sempra Global had $2.26 billion of commercial paper outstanding supported by the facility and $79 million of available unused credit on the line. California Utilities SDG&E and SoCalGas have a combined $1 billion , five -year syndicated revolving credit agreement expiring in October 2020. On September 30, 2016, an additional lender was added to the facility. JPMorgan Chase Bank, N.A. serves as administrative agent for the syndicate of, now, 21 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 to a combined limit of $1 billion for both utilities. It also provides for the issuance of letters of credit on behalf of each utility subject to a combined letter of credit commitment of $250 million for both utilities. The amount of borrowings otherwise available under the facility is reduced by the amount of outstanding letters of credit. 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 September 30, 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 utility. At September 30, 2016 , SDG&E had $54 million of commercial paper outstanding and SoCalGas had no outstanding borrowings supported by the facility. Available unused credit on the line at September 30, 2016 was $696 million and $750 million at SDG&E and SoCalGas, respectively, subject to the $1 billion maximum combined credit limit. Sempra South American Utilities Sempra South American Utilities has Peruvian Sol- and Chilean Peso-denominated credit facilities with a borrowing capacity of $506 million U.S. dollar equivalent. 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 September 30, 2016 , Sempra South American Utilities was in compliance with this financial covenant under the credit facilities. At September 30, 2016 , Sempra South American Utilities had outstanding borrowings against the Peruvian facilities of $140 million , expiring between 2016 and 2019, bank guarantees of $16 million , and $236 million of available unused credit. There were no outstanding borrowings at September 30, 2016 under the $114 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, Banco Nacional de Mexico, S.A. Integrante del Grupo Financiero Banamex, The Bank of Tokyo - Mitsubishi UFJ, LTD., The Bank of Nova Scotia and Sumitomo Mitsui Banking Corporation. At September 30, 2016 , IEnova had $521 million of outstanding borrowings supported by the facility, and available unused credit on the line was $79 million . WEIGHTED AVERAGE INTEREST RATES The weighted average interest rates on the total short-term debt at Sempra Energy Consolidated were 1.19 percent and 1.09 percent at September 30, 2016 and December 31, 2015 , respectively. The weighted average interest rates on total short-term debt at SDG&E were 1.06 percent and 1.01 percent at September 30, 2016 and December 31, 2015 , respectively. LONG-TERM DEBT Sempra Energy In October 2016, Sempra Energy publicly offered and sold $500 million of 1.625 -percent, fixed-rate notes maturing in 2019. Sempra Energy used the proceeds from this offering to repay outstanding commercial paper. SDG&E In May 2016, SDG&E publicly offered and sold $500 million of 2.50 -percent first mortgage bonds maturing in 2026. SDG&E used the proceeds from the offering to redeem, prior to a scheduled maturity in 2027, $105 million aggregate principal amount of 5 -percent, tax-exempt industrial development revenue bonds, to repay outstanding commercial paper and for other general corporate purposes. SoCalGas In June 2016, SoCalGas publicly offered and sold $500 million of 2.60 -percent first mortgage bonds maturing in 2026. SoCalGas used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. Sempra South American Utilities In July 2016, Luz del Sur publicly offered and sold $50 million of corporate bonds at 6.50 percent maturing in 2025. Sempra Mexico In September 2016, IEnova completed the acquisition of PEMEX’s 50 -percent interest in GdC, as we discuss in Note 3. Pursuant to the agreement, IEnova assumed $364 million of long-term debt, of which $49 million is classified as current at September 30, 2016. Principal and interest payments are due quarterly each year, and the loan fully matures in December 2026. The loan bears interest equal to London Interbank Offered Rate (LIBOR) plus a spread of 2 percent to 2.75 percent , which varies over the term of the loan. To moderate exposure to interest rate and associated cash flow variability, GdC entered into floating-to-fixed interest rate swaps for the full loan amount, resulting in an all-in fixed rate of 2.63 percent plus the corresponding spread. The loan is collateralized by the TDF S. de R.L. de C.V. liquid petroleum gas pipeline and the San Fernando natural gas pipeline, which are wholly owned projects at GdC. The loan agreement contains various covenants, including maintaining a certain interest coverage ratio and a minimum members’ equity during the term of the loan. At September 30, 2016, GdC was in compliance with these financial covenants. S empra Natural Gas I n September 2016, Sempra Natural Gas completed the sale of EnergySouth, the parent company of Mobile Gas and Willmut Gas. Sempra Natural Gas received $318 million , net of $2 million cash sold, in cash proceeds and the buyer assumed debt of $67 million , which included $20 million of 4.14 -percent first mortgage bonds and $42 million of 5 -percent first mortgage bonds at Mobile Gas, and $5 million of 3.1 -percent notes at Willmut Gas. We discuss the sale of EnergySouth in Note 3. INTEREST RATE SWAPS We discuss our fair value interest rate swaps and interest rate swaps to hedge cash flows in Note 7.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Financial Instruments	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 in anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not 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) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (loss) (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows. 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 combination of the derivative and debt instrument results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, 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 exchange-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 activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. • SDG&E is allocated and may purchase congestion revenue rights (CRRs), which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. • Sempra Mexico, Sempra Natural Gas, and Sempra Renewables 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 and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico also uses natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its Mexican distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Condensed Consolidated Statements of Operations. • From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel. We summarize net energy derivative volumes at September 30, 2016 and December 31, 2015 as follows: NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) Segment and Commodity Unit of measure September 30, December 31, California Utilities: SDG&E: Natural gas MMBtu(1) 56 70 Electricity MWh(2) 4 1 Congestion revenue rights MWh 46 36 SoCalGas – natural gas MMBtu 2 1 Energy-Related Businesses: Sempra Natural Gas – natural gas MMBtu 35 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 physical locations of contractual obligations and assets, such as natural gas purchases and sales. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We 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 and joint ventures. Interest rate derivatives are generally accounted for as hedges, and although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes. At September 30, 2016 and December 31, 2015 , the net notional amounts of our interest rate derivatives, excluding joint ventures, were: INTEREST RATE DERIVATIVES (Dollars in millions) September 30, 2016 December 31, 2015 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges(1)(2) $ 753 2016-2028 $ 384 2016-2028 Fair value hedges — — 300 2016 SDG&E: Cash flow hedge(1) 307 2016-2019 315 2016-2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. (2) At September 30, 2016, includes GdC, which was previously a joint venture and excluded from this table. 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. From time to time, Sempra Mexico and its joint ventures may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. 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 assets 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 exposure to significant fluctuations in our income tax expense and equity earnings from these impacts. In January 2016 and September 2016, we entered into foreign currency derivatives with notional amounts totaling $550 million and $914 million , respectively. At September 30, 2016 and December 31, 2015 , the net notional amounts of our foreign currency derivatives, excluding joint ventures, were: FOREIGN CURRENCY DERIVATIVES (Dollars in millions) September 30, 2016 December 31, 2015 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 408 2016-2023 $ 408 2016-2023 Other foreign currency derivatives(1) 1,481 2016-2018 — — (1) At September 30, 2016, includes GdC, which was previously a joint venture and excluded from this table. In addition, Sempra South American Utilities uses foreign currency derivatives at its subsidiaries and joint ventures as a means to manage foreign currency rate risk. We discuss these derivatives 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 The Condensed Consolidated Balance Sheets reflect the offsetting of net derivative positions and cash collateral with the same counterparty when a legal right of offset exists. The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets at September 30, 2016 and December 31, 2015 , including the amount of cash collateral receivables that were not offset, as the cash collateral is in excess of liability positions. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2016 Current Other Current liabilities: Deferred Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 3 $ — $ (20 ) $ (224 ) Commodity contracts not subject to rate recovery — — (4 ) — Derivatives not designated as hedging instruments: Foreign exchange instruments 2 — (25 ) — Commodity contracts not subject to rate recovery 122 25 (128 ) (17 ) Associated offsetting commodity contracts (114 ) (15 ) 114 15 Associated offsetting cash collateral — (2 ) 17 2 Commodity contracts subject to rate recovery 11 86 (59 ) (165 ) Associated offsetting commodity contracts (5 ) (1 ) 5 1 Associated offsetting cash collateral — — 12 17 Net amounts presented on the balance sheet 19 93 (88 ) (371 ) Additional cash collateral for commodity contracts not subject to rate recovery 15 — — — Additional cash collateral for commodity contracts subject to rate recovery 19 — — — Total(4) $ 53 $ 93 $ (88 ) $ (371 ) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ — $ — $ (13 ) $ (18 ) Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery 8 86 (55 ) (165 ) Associated offsetting commodity contracts (3 ) (1 ) 3 1 Associated offsetting cash collateral — — 12 17 Net amounts presented on the balance sheet 5 85 (53 ) (165 ) Additional cash collateral for commodity contracts not subject to rate recovery 1 — — — Additional cash collateral for commodity contracts subject to rate recovery 17 — — — Total(4) $ 23 $ 85 $ (53 ) $ (165 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (4 ) $ — Associated offsetting commodity contracts (2 ) — 2 — Net amounts presented on the balance sheet 1 — (2 ) — 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 $ — $ (2 ) $ — (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 Current Other Current liabilities: Deferred 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 Statements of Operations and in OCI and AOCI for the three months and nine months ended September 30 were: FAIR VALUE HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Three months ended September 30, Nine months ended September 30, Location 2016 2015 2016 2015 Sempra Energy Consolidated: Interest rate instruments Interest Expense $ — $ 1 $ 3 $ 5 Interest rate instruments Other Income, Net — — (2 ) (2 ) Total(1) $ — $ 1 $ 1 $ 3 (1) There was no hedge ineffectiveness in either the three months or nine months ended September 30, 2016 or 2015 . All other changes in the fair value of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt and are recorded in Other Income, Net. CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) recognized in OCI Pretax (loss) gain reclassified from AOCI into earnings Three months ended September 30, Three months ended September 30, 2016 2015 Location 2016 2015 Sempra Energy Consolidated: Interest rate and foreign exchange instruments(1) $ (16 ) $ (10 ) Interest Expense $ (4 ) $ (5 ) Interest rate instruments 17 (134 ) Equity Earnings, Before Income Tax (3 ) (3 ) Interest rate and foreign exchange instruments — — Remeasurement of Equity Method Investment (7 ) — Interest rate and foreign exchange instruments 13 — Equity Earnings, Net of Income Tax 2 — Commodity contracts not subject to rate recovery 2 6 Revenues: Energy- Related Businesses — 3 Total(2) $ 16 $ (138 ) $ (12 ) $ (5 ) SDG&E: Interest rate instruments(1)(2) $ 2 $ (4 ) Interest Expense $ (3 ) $ (3 ) SoCalGas: Interest rate instruments(2) $ — $ — Interest Expense $ (1 ) $ — Nine months ended September 30, Nine months ended September 30, 2016 2015 Location 2016 2015 Sempra Energy Consolidated: Interest rate and foreign $ (26 ) $ (22 ) Interest Expense $ (11 ) $ (14 ) Interest rate instruments (190 ) (123 ) Equity Earnings, (8 ) (9 ) Interest rate and foreign exchange instruments — — Remeasurement of Equity Method Investment (7 ) — Interest rate and foreign (20 ) — Equity Earnings, Net of Income Tax (4 ) — Commodity contracts not subject (2 ) 6 Revenues: Energy- 7 10 Total(2) $ (238 ) $ (139 ) $ (23 ) $ (13 ) SDG&E: Interest rate instruments(1)(2) $ (5 ) $ (9 ) Interest Expense $ (9 ) $ (9 ) SoCalGas: Interest rate instruments(2) $ — $ — Interest Expense $ (1 ) $ — (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 and nine months ended September 30, 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. SoCalGas expects that negligible losses, net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next twelve months as the hedged items affect earnings. Actual amounts ultimately reclassified into earnings depend on the interest rates in effect when derivative contracts mature. For all forecasted transactions, the maximum remaining term over which we are hedging exposure to the variability of cash flows at September 30, 2016 is approximately 12 years and 3 years for Sempra Energy Consolidated and 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 Consolidated Statements of Operations for the three months and nine months ended September 30 were: UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Three months ended Nine months ended Location 2016 2015 2016 2015 Sempra Energy Consolidated: Foreign exchange instruments Other Income, Net $ (11 ) $ (4 ) $ (23 ) $ (7 ) Foreign exchange instruments Equity Earnings, Net of Income Tax 1 (3 ) 3 (4 ) Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses 3 21 (26 ) 33 Commodity contracts not subject to rate recovery Operation and Maintenance — (2 ) 1 (1 ) Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (118 ) (27 ) (90 ) (100 ) Commodity contracts subject to rate recovery Cost of Natural Gas — — (2 ) 1 Total $ (125 ) $ (15 ) $ (137 ) $ (78 ) SDG&E: Commodity contracts subject to rate recovery Operation and Maintenance $ — $ (1 ) $ — $ (1 ) Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (118 ) (27 ) (90 ) (100 ) Total $ (118 ) $ (28 ) $ (90 ) $ (101 ) SoCalGas: Commodity contracts not subject to rate recovery Operation and Maintenance $ — $ (1 ) $ — $ — Commodity contracts subject to rate recovery Cost of Natural Gas — — (2 ) 1 Total $ — $ (1 ) $ (2 ) $ 1 CONTINGENT FEATURES For Sempra Energy Consolidated and SDG&E, certain of our derivative instruments contain credit limits which vary depending on our credit ratings. Generally, these provisions, if applicable, may reduce our credit limit if a specified credit rating agency reduces our ratings. In certain cases, if our credit ratings were to fall below investment grade, the counterparty to these derivative liability instruments could request immediate payment or demand immediate and ongoing full collateralization. For Sempra Energy Consolidated, the total fair value of this group of derivative instruments in a net liability position is $6 million at each of September 30, 2016 and December 31, 2015 . At September 30, 2016 , if the credit ratings of Sempra Energy were reduced below investment grade, $8 million of additional assets could be required to be posted as collateral for these derivative contracts. For SDG&E, the total fair value of this group of derivative instruments in a net liability position at September 30, 2016 and December 31, 2015 is $3 million and $5 million , respectively. At September 30, 2016 , if the credit ratings of SDG&E were reduced below investment grade, $5 million of additional assets could be required to be posted as collateral for these derivative contracts. For Sempra Energy Consolidated, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS We discuss the valuation techniques and inputs we use to measure fair value and the definition of the three levels of the fair value hierarchy in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. 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 September 30, 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 affect the valuation of fair value assets and liabilities, and their placement within the fair value hierarchy levels. We have not changed the valuation techniques or types of inputs we use to measure recurring fair values during the nine months ended September 30, 2016 . The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis at September 30, 2016 and December 31, 2015 in the tables below include the following: ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances. A third party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Equity and certain debt securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪ For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market 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 relate 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 active market in which the identical security is traded (Level 1). These investments in marketable securities were negligible at both September 30, 2016 and December 31, 2015 . There were no transfers into or out of Level 1, Level 2 or Level 3 for Sempra Energy Consolidated, SDG&E or SoCalGas during the periods presented. RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at September 30, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 607 $ — $ — $ — $ 607 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 52 — — 100 Municipal bonds — 161 — — 161 Other securities — 188 — — 188 Total debt securities 48 401 — — 449 Total nuclear decommissioning trusts(2) 655 401 — — 1,056 Interest rate and foreign exchange instruments — 5 — — 5 Commodity contracts not subject to rate recovery — 18 — 13 31 Commodity contracts subject to rate recovery — 1 90 19 110 Total $ 655 $ 425 $ 90 $ 32 $ 1,202 Liabilities: Interest rate and foreign exchange instruments $ — $ 269 $ — $ — $ 269 Commodity contracts not subject to rate recovery 19 1 — (19 ) 1 Commodity contracts subject to rate recovery 1 40 177 (29 ) 189 Total $ 20 $ 310 $ 177 $ (48 ) $ 459 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 September 30, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 607 $ — $ — $ — $ 607 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 52 — — 100 Municipal bonds — 161 — — 161 Other securities — 188 — — 188 Total debt securities 48 401 — — 449 Total nuclear decommissioning trusts(2) 655 401 — — 1,056 Commodity contracts not subject to rate recovery — — — 1 1 Commodity contracts subject to rate recovery — — 90 17 107 Total $ 655 $ 401 $ 90 $ 18 $ 1,164 Liabilities: Interest rate instruments $ — $ 31 $ — $ — $ 31 Commodity contracts subject to rate recovery — 39 177 (29 ) 187 Total $ — $ 70 $ 177 $ (29 ) $ 218 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 September 30, 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 subject to rate recovery $ 1 $ 1 $ — $ — $ 2 Total $ 1 $ 1 $ — $ — $ 2 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 rights (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 September 30, 2016 2015 Balance as of July 1 $ 24 $ 42 Realized and unrealized losses (145 ) (49 ) Settlements 34 43 Balance as of September 30 $ (87 ) $ 36 Change in unrealized losses relating to instruments still held at September 30 $ (114 ) $ (8 ) Nine months ended September 30, 2016 2015 Balance as of January 1 $ 19 $ 107 Realized and unrealized losses (138 ) (103 ) Allocated transmission instruments — 1 Settlements 32 31 Balance as of September 30 $ (87 ) $ 36 Change in unrealized losses relating to instruments still held at September 30 $ (111 ) $ (54 ) 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 through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California Independent System Operator (CAISO), an objective source. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following year. The impact associated with discounting is negligible. Because auction prices are a less observable 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 MWh 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 negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 7. Long-term, fixed-price electricity positions 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 September 30, 2016 , these electricity forward prices range from $19.20 per MWh to $58.50 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 Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. The following table provides the carrying amounts and fair values of certain other financial instruments that are not recorded at fair value on the Condensed Consolidated Balance Sheets at September 30, 2016 and December 31, 2015 : FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) September 30, 2016 Carrying Fair value Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Due from unconsolidated affiliates(1) $ 180 $ — $ 91 $ 81 $ 172 Total long-term debt(2)(3) 14,149 — 15,335 532 15,867 Preferred stock of subsidiary 20 — 26 — 26 SDG&E: Total long-term debt(3)(4) $ 4,656 $ — $ 5,024 $ 307 $ 5,331 SoCalGas: Total long-term debt(5) $ 3,009 $ — $ 3,323 $ — $ 3,323 Preferred stock 22 — 28 — 28 December 31, 2015 Carrying Fair value 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 $15 million and $11 million at September 30, 2016 and December 31, 2015 , respectively. (2) Before reductions for unamortized discount (net of premium) and debt issuance costs of $108 million and $107 million at September 30, 2016 and December 31, 2015 , respectively, and excluding build-to-suit and capital lease obligations of $385 million and $387 million at September 30, 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 $307 million and $315 million at September 30, 2016 and December 31, 2015 , respectively, related to Otay Mesa VIE. (4) Before reductions for unamortized discount and debt issuance costs of $46 million and $43 million at September 30, 2016 and December 31, 2015 , respectively, and excluding capital lease obligations of $241 million and $244 million at September 30, 2016 and December 31, 2015 , respectively. (5) Before reductions for unamortized discount and debt issuance costs of $27 million and $24 million at September 30, 2016 and December 31, 2015 , respectively, and excluding capital lease obligations of $1 million at both September 30, 2016 and December 31, 2015 , respectively. We determine the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock based 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 costs (Level 3). We value other long-term debt using an income approach based on the present value of estimated future cash flows discounted at rates available for similar securities (Level 3). We provide the fair values for the securities held in the nuclear decommissioning trust funds related to the San Onofre Nuclear Generating Station (SONGS) in Note 9 below. Non-Recurring Fair Value Measures – Sempra Energy Consolidated Sempra Mexico GdC. On September 26, 2016, IEnova completed the acquisition of PEMEX’s 50 -percent interest in GdC, increasing its ownership interest to 100 percent . As a result of IEnova obtaining control over GdC, in the three months and nine months ended September 30, 2016, Sempra Mexico recognized a pretax gain of $617 million ( $432 million after-tax) for the excess of the acquisition-date fair value of its previously held equity interest in GdC ( $1.144 billion ) over the carrying value of that interest ( $520 million ) and losses reclassified from AOCI ( $7 million ), included as Remeasurement of Equity Method Investment on Sempra Energy’s Condensed Consolidated Statements of Operations. The valuation technique used to measure the acquisition-date fair value of our equity interest in GDC immediately prior to the business acquisition was based on the fair value of the entire business combination ( $2.288 billion ) less the fair value of the consideration paid ( $1.144 billion , the equity sale price). We considered use of the equity sale price to be a market participant input that is a Level 2 measurement in the fair value hierarchy. We discuss the GdC acquisition in Note 3. TdM. In February 2016, management approved a plan to market and sell its TdM natural gas-fired power plant, and it was classified as held for sale on the Sempra Energy Condensed Consolidated Balance Sheet, as we discuss in Note 3. In September 2016, we received market information that indicated that the fair value of TdM may be less than its carrying value. As a result, after performing an analysis of the information, Sempra Mexico reduced the carrying value of TdM by recognizing a noncash impairment charge of $131 million ( $111 million after-tax) in the three months and nine months ended September 30, 2016 in Impairment Losses on the Sempra Energy Condensed Consolidated Statements of Operations. Market values resulting from a third party bidding process are considered to be Level 2 inputs in the fair value hierarchy. Sempra Natural Gas Rockies Express. As we discuss in Note 3, in March 2016, Sempra Natural Gas agreed to sell its 25 -percent interest in Rockies Express for cash consideration of $440 million , subject to adjustment at closing. The transaction closed in May 2016. In March 2016, we recorded a noncash impairment of our investment in Rockies Express of $44 million ( $27 million after-tax). The charge is included in Equity Earnings, Before Income Tax, on the Sempra Energy Condensed Consolidated Statement of Operations for the nine months ended September 30, 2016 . We considered the sale price for our equity interest in Rockies Express to be a market participants’ view of the total value of Rockies Express and measured the fair value of our investment based on the equity sale price. 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 our non-recurring fair value measures: NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Estimated fair value Valuation technique Fair value hierarchy % of fair value measurement Inputs used to develop measurement Range of inputs TdM $ 145 (1) Market approach Level 2 100% Purchase price offers 100% Investment in GdC $ 1,144 (2) Market approach Level 2 100% Equity sale price 100% Investment in $ 440 (3) Market approach Level 2 100% Equity sale price 100% (1) At measurement date of September 29, 2016. At September 30, 2016, TdM has a carrying value of $146 million , reflecting subsequent business activity, and is classified as held for sale. (2) At measurement date of September 26, 2016, immediately prior to acquiring a 100 -percent ownership interest in GdC. (3) At measurement date of March 29, 2016. On May 9, 2016, Sempra Natural Gas sold its equity interest in Rockies Express.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION (SONGS)	9 Months Ended
	Sep. 30, 2016
Regulated Operations [Abstract]
San Onofre Nuclear Generating Station (SONGS)	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 Commission (NRC) to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of expenses and capital expenditures. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Condensed Consolidated Statements of Operations. SONGS Steam Generator Replacement Project As part of the Steam Generator Replacement Project, 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. These 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 Mitsubishi Heavy Industries America, Inc. (collectively MHI). In July 2013, SDG&E filed a lawsuit against MHI seeking to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators. In October 2013, Edison instituted binding arbitration proceedings against MHI seeking damages as well. SDG&E is participating in the arbitration as a claimant and respondent. The arbitration hearing concluded in April 2016, and a decision could come as early as this year. 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 outage, 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 in the SONGS OII proceeding a Settlement Agreement, along with Edison, The Utility Reform Network (TURN), the CPUC Office of Ratepayer Advocates (ORA) and two other intervenors who joined the Settlement Agreement (collectively, the Settling Parties). In September 2014, the Settling Parties executed an Amended and Restated Settlement Agreement (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 proceedings before the NRC, or litigation or arbitration related to potential future recoveries from third parties (except for the allocation to ratepayers of any recoveries as described below) or proceedings addressing decommissioning activities and costs. We discuss 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 reopen 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 regarding 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. In August 2015, ORA, also a party to the Amended Settlement Agreement, filed a PFM with the CPUC, withdrawing its support for the Amended Settlement 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 disclosures concerning Edison ex parte communications 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. In May 2016, the CPUC issued a ruling reopening the record of the OII to address the issue of whether the Amended Settlement Agreement is reasonable and in the public interest. In accordance with the ruling, Edison and SDG&E filed separate reports with the CPUC in June 2016 on the Amended Settlement Agreement and the status of its implementation, and filed separate legal briefs in July 2016 asserting that the Amended Settlement Agreement is reasonable and in the public interest. Accounting and Financial Impacts Through December 31, 2015 and September 30, 2016 , the cumulative after-tax loss from plant closure recorded by Sempra Energy and SDG&E is $125 million , including a reduction in the after-tax loss of $13 million recorded in the first quarter of 2015. The remaining regulatory asset for the expected recovery of SONGS costs, consistent with the Amended Settlement Agreement, is $195 million ( $45 million current and $150 million long-term) at September 30, 2016 and is recorded on the Condensed Consolidated Balance Sheets in Other Current Assets and Regulatory 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 commenced in January 2015 following the CPUC’s final decision approving the Amended Settlement Agreement in November 2014. Settlement with Nuclear Electric Insurance Limited (NEIL) NEIL insures domestic and international 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 reimbursement 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 permanently 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 accordance with state and federal requirements and regulations, SDG&E has assets held in trusts, referred to as the Nuclear Decommissioning Trusts (NDT), to fund decommissioning costs for SONGS Units 1, 2 and 3. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work will be done when Units 2 and 3 are decommissioned. At September 30, 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 administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In April 2016, the CPUC adopted a decision approving a total decommissioning cost estimate for SONGS Units 2 and 3 of $4.411 billion (in 2014 dollars), of which SDG&E’s share is $899 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 annual 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. SDG&E has received authorization from the CPUC to access trust funds for SONGS decommissioning costs of up to $218 million for 2013 through 2016 (forecasted). The total of $218 million includes $37 million authorized for withdrawal that is pending satisfactory clarification by final settlement of unresolved spent fuel storage costs with the U.S. Department of Energy (DOE) or 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 settlement or clarification will be obtained. 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. We discuss matters related to spent nuclear fuel in Note 11. Nuclear Decommissioning Trusts The amounts collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of 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 losses 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) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At September 30, 2016: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1) $ 95 $ 5 $ — $ 100 Municipal bonds(2) 150 11 — 161 Other securities(2) 183 9 (4 ) 188 Total debt securities 428 25 (4 ) 449 Equity securities 188 422 (3 ) 607 Cash and cash equivalents 12 — — 12 Total $ 628 $ 447 $ (7 ) $ 1,068 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 2017-2065. (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 Nine months ended 2016 2015 2016 2015 Proceeds from sales(1) $ 282 $ 210 $ 486 $ 431 Gross realized gains 24 18 32 24 Gross realized losses (3 ) (6 ) (14 ) (13 ) (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. 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. In September 2015, the California Utilities filed settlement agreements with the CPUC to resolve all material matters related to the proceeding, except for the revenue requirement implications of certain income tax benefits associated with flow-through tax repair deductions, discussed below. The settlement agreements were with eight of eleven intervening parties. In June 2016, the CPUC issued a final decision in the 2016 GRC. The final decision (2016 GRC FD) adopts substantially all of the terms of the settlement agreements entered into between SDG&E and SoCalGas and eight of the eleven intervening parties in the 2016 GRC. The 2016 GRC FD adopts two revenue requirement changes, the first of which, relating to the extension of bonus depreciation, is the only significant change to the settlement agreements. The second revenue requirement adjustment relates to income tax benefits associated with flow-through repair deductions (the settling parties did not reach agreement on this second matter). With these adjustments, the final decision adopts a 2016 revenue requirement of $1.791 billion for SDG&E, which is $20 million less than the $1.811 billion proposed in the settlement agreements. For SoCalGas, the final decision’s adjustments result in a 2016 revenue requirement of $2.204 billion , which is $15 million less than the $2.219 billion proposed in the settlement agreements. The 2016 GRC FD also requires certain refunds to be paid to customers and establishes a two-way income tax expense memorandum account, each discussed below. Consistent with the settlement agreements, the 2016 GRC FD adopts subsequent annual escalation of the adopted revenue requirements by 3.5 percent for years 2017 and 2018 and continuation of the Z-Factor mechanism for qualifying cost recovery. The Z-Factor mechanism allows the California Utilities to seek cost recovery of significant cost increases, under certain unforeseen circumstances, incurred between GRC filings, subject to a $5 million deductible per event. Also, the 2016 GRC FD denies a separate agreement between the ORA and the California Utilities requesting a four-year GRC period and instead adopts a three-year GRC period (through 2018). The California Utilities recorded revenues in the first quarter of 2016 based on levels authorized for 2015 under the 2012 GRC, because a final decision in the 2016 GRC was not issued by March 31, 2016. The 2016 GRC FD is effective retroactive to January 1, 2016, and the California Utilities recorded the retroactive impacts in the second quarter of 2016. For SoCalGas and SDG&E, these amounts include an incremental after-tax earnings impact of $12 million and $9 million , respectively, related to the first quarter of 2016. The adopted revenue requirements associated with the seven-month period through July 2016 will be recovered in rates over a 17-month period, beginning August 2016. At September 30, 2016 , SoCalGas is reporting on its Condensed Balance Sheet a regulatory asset of $58 million , with $12 million as noncurrent, representing retroactive revenue from the 2016 GRC FD from January 1 through June 30, 2016 to be recovered in rates through December 2017. At September 30, 2016 , SDG&E is reporting on its Condensed Consolidated Balance Sheet a regulatory asset of $25 million , with $5 million as noncurrent, representing retroactive revenue from the 2016 GRC FD from January 1 through June 30, 2016 to be recovered in rates through December 2017. The 2016 GRC FD results in certain accounting impacts associated with the income tax repairs deduction matter. In general, the 2016 GRC FD considers that the income tax benefits obtained from income tax repairs deductions exceeded amounts forecasted by the California Utilities from 2011 to 2015, and that they were attributed to shareholders during that time. The 2016 GRC FD reallocates the economic benefit of this tax deduction forecasting difference to ratepayers. Accordingly, revenues corresponding to income tax repair deductions that exceeded forecasted amounts relating to 2015, which have been tracked in memorandum accounts, are ordered to be refunded to customers. The 2015 estimated amounts in the memorandum accounts totaled $72 million for SoCalGas and $37 million for SDG&E. Pursuant to this refund requirement, SoCalGas and SDG&E recorded regulatory liabilities for these amounts, resulting in after-tax charges to earnings of $43 million and $22 million , respectively, in the second quarter of 2016 (summarized below). In addition, the 2016 GRC FD reduced rate base by $38 million at SoCalGas and $55 million at SDG&E. The corresponding reductions in the 2016 revenue requirement will be $5 million at SoCalGas and $7 million at SDG&E (which reductions are included in the adopted 2016 revenue requirement amounts described above). The rate base reductions reallocate to ratepayers the economic benefits associated with tax repair deductions that were previously provided to the shareholders for the period of 2012-2014 for SoCalGas and 2011-2014 for SDG&E. The rate base reductions do not result in an impairment of any of our reported assets, but will impact our revenues and earnings prospectively. The 2016 GRC FD also requires us to notify the CPUC if the 2012-2015 repairs deductions estimated in this GRC are different from the actual repairs deductions for SDG&E and SoCalGas. SoCalGas and SDG&E recorded regulatory liabilities of $11 million and $15 million , respectively, related to 2012-2014, resulting in after-tax charges to earnings for these differences of $6 million and $9 million in the second quarter of 2016 for SoCalGas and SDG&E, respectively (summarized below). In the third quarter of 2016, SDG&E and SoCalGas completed their 2015 calendar year tax returns, and final tax deductions associated with tax repair benefits to be refunded to ratepayers associated with the 2015 memo account are lower than the amounts estimated in 2015. Accordingly, the amounts to be refunded decreased by $5 million for SDG&E and $19 million for SoCalGas. In October 2016, SDG&E and SoCalGas filed a regulatory account update with the CPUC to reflect their final total 2015 repair allowance deductions of $32 million and $53 million , respectively. After recording the related income tax effect and corresponding regulatory revenue adjustments for income tax purposes, there was no net impact to earnings from the adjustments to the 2015 tax repairs deductions recorded in the third quarter of 2016. Accordingly, the earnings impacts in the table below are also the impacts in the nine months ended September 30, 2016 . Following is a summary of immediate earnings impacts from the 2016 GRC FD recorded in the second quarter of 2016: EARNINGS IMPACTS FROM THE 2016 GRC FD RECORDED IN THE SECOND QUARTER OF 2016 (Dollars in millions) SoCalGas SDG&E Pretax earnings (charge) After-tax earnings (charge) Pretax After-tax Retroactive revenue requirement increase for the first quarter of 2016 $ 20 $ 12 $ 15 $ 9 Adjustments to revenue related to tax repairs deductions: 2015 memorandum account balance $ (72 ) $ (43 ) $ (37 ) $ (22 ) True-up of 2012-2014 estimates to actuals (11 ) (6 ) (15 ) (9 ) Total $ (83 ) $ (49 ) $ (52 ) $ (31 ) In July 2016, SDG&E, SoCalGas and the parties to the settlement agreements filed a joint motion indicating their agreement to accept the CPUC’s adjustments to the original settlements with one additional change. The settlement parties agree that SDG&E and SoCalGas will retain the right to seek further review and modification of the bonus depreciation adjustment made by the CPUC, so that SDG&E and/or SoCalGas can pursue relief in the form of full or partial restoration of the total revenue requirements reflected in the original settlement agreements. We expect CPUC action on the joint motion in 2016 or 2017. Finally, the 2016 GRC FD requires the establishment of a two-way income tax expense memorandum account to track any revenue differences resulting from differences between the income tax expense forecasted in the GRC and the income tax expense incurred by the California Utilities from 2016 through 2018. The differences tracked are to specifically include tax expense differences relating to ▪ net revenue changes; ▪ mandatory tax law, tax accounting, tax procedural, or tax policy changes; and ▪ elective tax law, tax accounting, tax procedural, or tax policy changes. The account will remain open, and the balance in the account will be reviewed in subsequent GRC proceedings, until the CPUC decides to close the account. In July 2016, to address the implementation of the 2016 GRC FD, the California Utilities filed an advice letter to establish a two-way memorandum account to track revenue requirement differences resulting from the differences in the income tax expense forecasted in the GRC proceedings of SDG&E and SoCalGas and the income tax expense incurred by them during the GRC period. Starting in the second quarter of 2016, SoCalGas and SDG&E are recording liabilities associated with tracking the differences in the income tax expense forecasted in the GRC proceedings and the income tax expense incurred, which for the three months and nine months ended September 30, 2016 resulted in after-tax charges to earnings of $2 million ( $4 million pretax) and $11 million ( $19 million pretax), respectively, for SoCalGas and negligible amounts for SDG&E. 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 final decision to implement 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 criteria to determine the amounts that would not be eligible for cost recovery, including: ◦ certain costs incurred or to be incurred searching for pipeline test records, ◦ the cost of pressure testing pipelines installed after July 1, 1961 for which the company has not found sufficient records of testing, and ◦ any undepreciated balances for pipelines installed after 1961 that were replaced due to insufficient documentation of pressure testing. As a result of this decision, SoCalGas recorded an after-tax earnings charge of $5 million in 2014 for costs incurred in prior periods that were no longer subject to recovery. After taking the amounts disallowed for recovery into consideration, as of September 30, 2016 , SDG&E and SoCalGas have recorded PSEP costs of $18 million and $212 million , respectively, in the CPUC-authorized regulatory account. 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 of abandoned pipelines. In January 2016, SoCalGas and SDG&E jointly filed a request with the CPUC seeking rehearing of its December 2015 decision. In May 2016, the CPUC issued a decision denying the request for rehearing. Through September 30, 2016 , the after-tax disallowed costs for SoCalGas and SDG&E are $3.6 million and $0.5 million , respectively. In October 2014, SDG&E and SoCalGas filed a petition with the CPUC requesting authority to begin to recover PSEP costs from customers in the year in which the costs are incurred, subject to refund pending the results of a reasonableness review by the CPUC, instead of recovery of such costs in a subsequent year. In August 2016, the CPUC issued a final decision authorizing SoCalGas and SDG&E to recover, subject to refund pending reasonableness reviews, the revenue requirements associated with 50 percent of their incurred PSEP Phase 1 costs recorded to regulatory accounts; file two reasonableness review applications for Phase 1 projects completed through 2017; file a Phase 2 revenue requirement forecast application for costs to be incurred in 2017 and 2018; and include in their 2019 GRC applications, and any future GRCs, all other PSEP costs not the subject of prior applications. In December 2014, SDG&E and SoCalGas filed an application with the CPUC for recovery of $0.1 million and $46 million , respectively, in costs recorded in the regulatory account through June 11, 2014. In June 2015, SDG&E and SoCalGas agreed to remove certain projects from the filing and defer their review to future proceedings when the projects are fully completed. 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 project management and consulting costs. The CPUC issued a proposed decision in September 2016, revised in October 2016, finding the costs associated with completed projects reasonable and approving $0.1 million and $33.1 million of the total costs requested by SDG&E and SoCalGas, respectively. The proposed decision does not approve approximately $2 million in insurance-related costs, but allows SDG&E and SoCalGas to seek recovery at a later date. A final decision is expected in the fourth quarter of 2016. In September 2016, SoCalGas and SDG&E filed a joint application with the CPUC for reasonableness review and rate recovery of costs of certain pipeline safety projects completed by June 30, 2015 and recorded in their authorized regulatory accounts. The total costs submitted for review are $180.5 million for SoCalGas and $14.9 million for SDG&E. SoCalGas and SDG&E expect a decision from the CPUC in 2017. SDG&E MATTERS 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 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, the CPUC issued a ruling establishing the scope and schedule 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 legal claims in relation to the wildfires were reasonable. In October 2016, intervening parties submitted Phase 1 testimony raising various concerns with SDG&E’s operations and management prior to and during the 2007 wildfires. Participating parties asked that the CPUC reject SDG&E’s request for cost recovery. 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 requested abeyance of SDG&E’s request to recover 2007 wildfire damage expenses. In April 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 revenue requirement and the recovery of $23.1 million of wildfire damage expenses allocated to SDG&E’s FERC-regulated operations. We provide additional information about wildfire litigation costs and their recovery in Note 11. SONGS We discuss regulatory and other matters related to SONGS in Note 9. SOCALGAS MATTERS Aliso Canyon Turbine Replacement Project In September 2016, SoCalGas received a citation from the CPUC alleging non-compliance with environmental mitigation measures outlined in the final environmental impact report for the Aliso Canyon Turbine Replacement Project. In particular, the allegations assert that SoCalGas failed to properly implement and maintain mitigation measures prescribed in the project’s Storm Water Pollution Prevention Plan, which is designed primarily to protect overall water quality and to minimize erosion and sedimentation during construction. Additionally, the CPUC alleges that SoCalGas crews repeatedly encroached upon a nesting bird buffer zone during construction. As a result of procedural matters, the CPUC re-issued the citation on October 26, 2016. The fines associated with the citation are approximately $700,000 . SoCalGas is in the process of evaluating the citation and its options in response to the citation . Aliso Canyon Natural Gas Storage Facility We discuss various regulatory matters regarding the Aliso Canyon natural gas storage facility and leak in Note 11. Natural Gas Procurement In June 2016, SoCalGas filed an application for a gas cost incentive mechanism award of $5 million for natural gas procured for its core customers during the 12-month period ended March 31, 2016. The CPUC’s current schedule calls for a decision in the first half of 2017. 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 (North-South Pipeline) ▪ In July 2016, the CPUC issued a final decision which denies the California Utilities’ request for a permit to construct. ▪ In June 2016, SoCalGas recorded an after-tax impairment charge of $13 million for the development costs it had invested in the project. The pretax charge of $22 million is included in Impairment Losses on Sempra Energy’s and SoCalGas’ Condensed Consolidated Statements of Operations for the nine months ended September 30, 2016. We expect to make a filing to the CPUC

CALIFORNIA UTILITIES' REGULATOR

CALIFORNIA UTILITIES' REGULATORY MATTERS	9 Months Ended
	Sep. 30, 2016
Regulated Operations [Abstract]
California Utilities' Regulatory Matters	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 Commission (NRC) to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of expenses and capital expenditures. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Condensed Consolidated Statements of Operations. SONGS Steam Generator Replacement Project As part of the Steam Generator Replacement Project, 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. These 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 Mitsubishi Heavy Industries America, Inc. (collectively MHI). In July 2013, SDG&E filed a lawsuit against MHI seeking to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators. In October 2013, Edison instituted binding arbitration proceedings against MHI seeking damages as well. SDG&E is participating in the arbitration as a claimant and respondent. The arbitration hearing concluded in April 2016, and a decision could come as early as this year. 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 outage, 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 in the SONGS OII proceeding a Settlement Agreement, along with Edison, The Utility Reform Network (TURN), the CPUC Office of Ratepayer Advocates (ORA) and two other intervenors who joined the Settlement Agreement (collectively, the Settling Parties). In September 2014, the Settling Parties executed an Amended and Restated Settlement Agreement (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 proceedings before the NRC, or litigation or arbitration related to potential future recoveries from third parties (except for the allocation to ratepayers of any recoveries as described below) or proceedings addressing decommissioning activities and costs. We discuss 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 reopen 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 regarding 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. In August 2015, ORA, also a party to the Amended Settlement Agreement, filed a PFM with the CPUC, withdrawing its support for the Amended Settlement 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 disclosures concerning Edison ex parte communications 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. In May 2016, the CPUC issued a ruling reopening the record of the OII to address the issue of whether the Amended Settlement Agreement is reasonable and in the public interest. In accordance with the ruling, Edison and SDG&E filed separate reports with the CPUC in June 2016 on the Amended Settlement Agreement and the status of its implementation, and filed separate legal briefs in July 2016 asserting that the Amended Settlement Agreement is reasonable and in the public interest. Accounting and Financial Impacts Through December 31, 2015 and September 30, 2016 , the cumulative after-tax loss from plant closure recorded by Sempra Energy and SDG&E is $125 million , including a reduction in the after-tax loss of $13 million recorded in the first quarter of 2015. The remaining regulatory asset for the expected recovery of SONGS costs, consistent with the Amended Settlement Agreement, is $195 million ( $45 million current and $150 million long-term) at September 30, 2016 and is recorded on the Condensed Consolidated Balance Sheets in Other Current Assets and Regulatory 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 commenced in January 2015 following the CPUC’s final decision approving the Amended Settlement Agreement in November 2014. Settlement with Nuclear Electric Insurance Limited (NEIL) NEIL insures domestic and international 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 reimbursement 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 permanently 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 accordance with state and federal requirements and regulations, SDG&E has assets held in trusts, referred to as the Nuclear Decommissioning Trusts (NDT), to fund decommissioning costs for SONGS Units 1, 2 and 3. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work will be done when Units 2 and 3 are decommissioned. At September 30, 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 administrative costs, CPUC approval is required for SDG&E to access the NDT assets to fund SONGS decommissioning costs for Units 2 and 3. In April 2016, the CPUC adopted a decision approving a total decommissioning cost estimate for SONGS Units 2 and 3 of $4.411 billion (in 2014 dollars), of which SDG&E’s share is $899 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 annual 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. SDG&E has received authorization from the CPUC to access trust funds for SONGS decommissioning costs of up to $218 million for 2013 through 2016 (forecasted). The total of $218 million includes $37 million authorized for withdrawal that is pending satisfactory clarification by final settlement of unresolved spent fuel storage costs with the U.S. Department of Energy (DOE) or 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 settlement or clarification will be obtained. 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. We discuss matters related to spent nuclear fuel in Note 11. Nuclear Decommissioning Trusts The amounts collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of 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 losses 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) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At September 30, 2016: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1) $ 95 $ 5 $ — $ 100 Municipal bonds(2) 150 11 — 161 Other securities(2) 183 9 (4 ) 188 Total debt securities 428 25 (4 ) 449 Equity securities 188 422 (3 ) 607 Cash and cash equivalents 12 — — 12 Total $ 628 $ 447 $ (7 ) $ 1,068 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 2017-2065. (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 Nine months ended 2016 2015 2016 2015 Proceeds from sales(1) $ 282 $ 210 $ 486 $ 431 Gross realized gains 24 18 32 24 Gross realized losses (3 ) (6 ) (14 ) (13 ) (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. 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. In September 2015, the California Utilities filed settlement agreements with the CPUC to resolve all material matters related to the proceeding, except for the revenue requirement implications of certain income tax benefits associated with flow-through tax repair deductions, discussed below. The settlement agreements were with eight of eleven intervening parties. In June 2016, the CPUC issued a final decision in the 2016 GRC. The final decision (2016 GRC FD) adopts substantially all of the terms of the settlement agreements entered into between SDG&E and SoCalGas and eight of the eleven intervening parties in the 2016 GRC. The 2016 GRC FD adopts two revenue requirement changes, the first of which, relating to the extension of bonus depreciation, is the only significant change to the settlement agreements. The second revenue requirement adjustment relates to income tax benefits associated with flow-through repair deductions (the settling parties did not reach agreement on this second matter). With these adjustments, the final decision adopts a 2016 revenue requirement of $1.791 billion for SDG&E, which is $20 million less than the $1.811 billion proposed in the settlement agreements. For SoCalGas, the final decision’s adjustments result in a 2016 revenue requirement of $2.204 billion , which is $15 million less than the $2.219 billion proposed in the settlement agreements. The 2016 GRC FD also requires certain refunds to be paid to customers and establishes a two-way income tax expense memorandum account, each discussed below. Consistent with the settlement agreements, the 2016 GRC FD adopts subsequent annual escalation of the adopted revenue requirements by 3.5 percent for years 2017 and 2018 and continuation of the Z-Factor mechanism for qualifying cost recovery. The Z-Factor mechanism allows the California Utilities to seek cost recovery of significant cost increases, under certain unforeseen circumstances, incurred between GRC filings, subject to a $5 million deductible per event. Also, the 2016 GRC FD denies a separate agreement between the ORA and the California Utilities requesting a four-year GRC period and instead adopts a three-year GRC period (through 2018). The California Utilities recorded revenues in the first quarter of 2016 based on levels authorized for 2015 under the 2012 GRC, because a final decision in the 2016 GRC was not issued by March 31, 2016. The 2016 GRC FD is effective retroactive to January 1, 2016, and the California Utilities recorded the retroactive impacts in the second quarter of 2016. For SoCalGas and SDG&E, these amounts include an incremental after-tax earnings impact of $12 million and $9 million , respectively, related to the first quarter of 2016. The adopted revenue requirements associated with the seven-month period through July 2016 will be recovered in rates over a 17-month period, beginning August 2016. At September 30, 2016 , SoCalGas is reporting on its Condensed Balance Sheet a regulatory asset of $58 million , with $12 million as noncurrent, representing retroactive revenue from the 2016 GRC FD from January 1 through June 30, 2016 to be recovered in rates through December 2017. At September 30, 2016 , SDG&E is reporting on its Condensed Consolidated Balance Sheet a regulatory asset of $25 million , with $5 million as noncurrent, representing retroactive revenue from the 2016 GRC FD from January 1 through June 30, 2016 to be recovered in rates through December 2017. The 2016 GRC FD results in certain accounting impacts associated with the income tax repairs deduction matter. In general, the 2016 GRC FD considers that the income tax benefits obtained from income tax repairs deductions exceeded amounts forecasted by the California Utilities from 2011 to 2015, and that they were attributed to shareholders during that time. The 2016 GRC FD reallocates the economic benefit of this tax deduction forecasting difference to ratepayers. Accordingly, revenues corresponding to income tax repair deductions that exceeded forecasted amounts relating to 2015, which have been tracked in memorandum accounts, are ordered to be refunded to customers. The 2015 estimated amounts in the memorandum accounts totaled $72 million for SoCalGas and $37 million for SDG&E. Pursuant to this refund requirement, SoCalGas and SDG&E recorded regulatory liabilities for these amounts, resulting in after-tax charges to earnings of $43 million and $22 million , respectively, in the second quarter of 2016 (summarized below). In addition, the 2016 GRC FD reduced rate base by $38 million at SoCalGas and $55 million at SDG&E. The corresponding reductions in the 2016 revenue requirement will be $5 million at SoCalGas and $7 million at SDG&E (which reductions are included in the adopted 2016 revenue requirement amounts described above). The rate base reductions reallocate to ratepayers the economic benefits associated with tax repair deductions that were previously provided to the shareholders for the period of 2012-2014 for SoCalGas and 2011-2014 for SDG&E. The rate base reductions do not result in an impairment of any of our reported assets, but will impact our revenues and earnings prospectively. The 2016 GRC FD also requires us to notify the CPUC if the 2012-2015 repairs deductions estimated in this GRC are different from the actual repairs deductions for SDG&E and SoCalGas. SoCalGas and SDG&E recorded regulatory liabilities of $11 million and $15 million , respectively, related to 2012-2014, resulting in after-tax charges to earnings for these differences of $6 million and $9 million in the second quarter of 2016 for SoCalGas and SDG&E, respectively (summarized below). In the third quarter of 2016, SDG&E and SoCalGas completed their 2015 calendar year tax returns, and final tax deductions associated with tax repair benefits to be refunded to ratepayers associated with the 2015 memo account are lower than the amounts estimated in 2015. Accordingly, the amounts to be refunded decreased by $5 million for SDG&E and $19 million for SoCalGas. In October 2016, SDG&E and SoCalGas filed a regulatory account update with the CPUC to reflect their final total 2015 repair allowance deductions of $32 million and $53 million , respectively. After recording the related income tax effect and corresponding regulatory revenue adjustments for income tax purposes, there was no net impact to earnings from the adjustments to the 2015 tax repairs deductions recorded in the third quarter of 2016. Accordingly, the earnings impacts in the table below are also the impacts in the nine months ended September 30, 2016 . Following is a summary of immediate earnings impacts from the 2016 GRC FD recorded in the second quarter of 2016: EARNINGS IMPACTS FROM THE 2016 GRC FD RECORDED IN THE SECOND QUARTER OF 2016 (Dollars in millions) SoCalGas SDG&E Pretax earnings (charge) After-tax earnings (charge) Pretax After-tax Retroactive revenue requirement increase for the first quarter of 2016 $ 20 $ 12 $ 15 $ 9 Adjustments to revenue related to tax repairs deductions: 2015 memorandum account balance $ (72 ) $ (43 ) $ (37 ) $ (22 ) True-up of 2012-2014 estimates to actuals (11 ) (6 ) (15 ) (9 ) Total $ (83 ) $ (49 ) $ (52 ) $ (31 ) In July 2016, SDG&E, SoCalGas and the parties to the settlement agreements filed a joint motion indicating their agreement to accept the CPUC’s adjustments to the original settlements with one additional change. The settlement parties agree that SDG&E and SoCalGas will retain the right to seek further review and modification of the bonus depreciation adjustment made by the CPUC, so that SDG&E and/or SoCalGas can pursue relief in the form of full or partial restoration of the total revenue requirements reflected in the original settlement agreements. We expect CPUC action on the joint motion in 2016 or 2017. Finally, the 2016 GRC FD requires the establishment of a two-way income tax expense memorandum account to track any revenue differences resulting from differences between the income tax expense forecasted in the GRC and the income tax expense incurred by the California Utilities from 2016 through 2018. The differences tracked are to specifically include tax expense differences relating to ▪ net revenue changes; ▪ mandatory tax law, tax accounting, tax procedural, or tax policy changes; and ▪ elective tax law, tax accounting, tax procedural, or tax policy changes. The account will remain open, and the balance in the account will be reviewed in subsequent GRC proceedings, until the CPUC decides to close the account. In July 2016, to address the implementation of the 2016 GRC FD, the California Utilities filed an advice letter to establish a two-way memorandum account to track revenue requirement differences resulting from the differences in the income tax expense forecasted in the GRC proceedings of SDG&E and SoCalGas and the income tax expense incurred by them during the GRC period. Starting in the second quarter of 2016, SoCalGas and SDG&E are recording liabilities associated with tracking the differences in the income tax expense forecasted in the GRC proceedings and the income tax expense incurred, which for the three months and nine months ended September 30, 2016 resulted in after-tax charges to earnings of $2 million ( $4 million pretax) and $11 million ( $19 million pretax), respectively, for SoCalGas and negligible amounts for SDG&E. 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 final decision to implement 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 criteria to determine the amounts that would not be eligible for cost recovery, including: ◦ certain costs incurred or to be incurred searching for pipeline test records, ◦ the cost of pressure testing pipelines installed after July 1, 1961 for which the company has not found sufficient records of testing, and ◦ any undepreciated balances for pipelines installed after 1961 that were replaced due to insufficient documentation of pressure testing. As a result of this decision, SoCalGas recorded an after-tax earnings charge of $5 million in 2014 for costs incurred in prior periods that were no longer subject to recovery. After taking the amounts disallowed for recovery into consideration, as of September 30, 2016 , SDG&E and SoCalGas have recorded PSEP costs of $18 million and $212 million , respectively, in the CPUC-authorized regulatory account. 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 of abandoned pipelines. In January 2016, SoCalGas and SDG&E jointly filed a request with the CPUC seeking rehearing of its December 2015 decision. In May 2016, the CPUC issued a decision denying the request for rehearing. Through September 30, 2016 , the after-tax disallowed costs for SoCalGas and SDG&E are $3.6 million and $0.5 million , respectively. In October 2014, SDG&E and SoCalGas filed a petition with the CPUC requesting authority to begin to recover PSEP costs from customers in the year in which the costs are incurred, subject to refund pending the results of a reasonableness review by the CPUC, instead of recovery of such costs in a subsequent year. In August 2016, the CPUC issued a final decision authorizing SoCalGas and SDG&E to recover, subject to refund pending reasonableness reviews, the revenue requirements associated with 50 percent of their incurred PSEP Phase 1 costs recorded to regulatory accounts; file two reasonableness review applications for Phase 1 projects completed through 2017; file a Phase 2 revenue requirement forecast application for costs to be incurred in 2017 and 2018; and include in their 2019 GRC applications, and any future GRCs, all other PSEP costs not the subject of prior applications. In December 2014, SDG&E and SoCalGas filed an application with the CPUC for recovery of $0.1 million and $46 million , respectively, in costs recorded in the regulatory account through June 11, 2014. In June 2015, SDG&E and SoCalGas agreed to remove certain projects from the filing and defer their review to future proceedings when the projects are fully completed. 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 project management and consulting costs. The CPUC issued a proposed decision in September 2016, revised in October 2016, finding the costs associated with completed projects reasonable and approving $0.1 million and $33.1 million of the total costs requested by SDG&E and SoCalGas, respectively. The proposed decision does not approve approximately $2 million in insurance-related costs, but allows SDG&E and SoCalGas to seek recovery at a later date. A final decision is expected in the fourth quarter of 2016. In September 2016, SoCalGas and SDG&E filed a joint application with the CPUC for reasonableness review and rate recovery of costs of certain pipeline safety projects completed by June 30, 2015 and recorded in their authorized regulatory accounts. The total costs submitted for review are $180.5 million for SoCalGas and $14.9 million for SDG&E. SoCalGas and SDG&E expect a decision from the CPUC in 2017. SDG&E MATTERS 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 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, the CPUC issued a ruling establishing the scope and schedule 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 legal claims in relation to the wildfires were reasonable. In October 2016, intervening parties submitted Phase 1 testimony raising various concerns with SDG&E’s operations and management prior to and during the 2007 wildfires. Participating parties asked that the CPUC reject SDG&E’s request for cost recovery. 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 requested abeyance of SDG&E’s request to recover 2007 wildfire damage expenses. In April 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 revenue requirement and the recovery of $23.1 million of wildfire damage expenses allocated to SDG&E’s FERC-regulated operations. We provide additional information about wildfire litigation costs and their recovery in Note 11. SONGS We discuss regulatory and other matters related to SONGS in Note 9. SOCALGAS MATTERS Aliso Canyon Turbine Replacement Project In September 2016, SoCalGas received a citation from the CPUC alleging non-compliance with environmental mitigation measures outlined in the final environmental impact report for the Aliso Canyon Turbine Replacement Project. In particular, the allegations assert that SoCalGas failed to properly implement and maintain mitigation measures prescribed in the project’s Storm Water Pollution Prevention Plan, which is designed primarily to protect overall water quality and to minimize erosion and sedimentation during construction. Additionally, the CPUC alleges that SoCalGas crews repeatedly encroached upon a nesting bird buffer zone during construction. As a result of procedural matters, the CPUC re-issued the citation on October 26, 2016. The fines associated with the citation are approximately $700,000 . SoCalGas is in the process of evaluating the citation and its options in response to the citation . Aliso Canyon Natural Gas Storage Facility We discuss various regulatory matters regarding the Aliso Canyon natural gas storage facility and leak in Note 11. Natural Gas Procurement In June 2016, SoCalGas filed an application for a gas cost incentive mechanism award of $5 million for natural gas procured for its core customers during the 12-month period ended March 31, 2016. The CPUC’s current schedule calls for a decision in the first half of 2017. 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 (North-South Pipeline) ▪ In July 2016, the CPUC issued a final decision which denies the California Utilities’ request for a permit to construct. ▪ In June 2016, SoCalGas recorded an after-tax impairment charge of $13 million for the development costs it had invested in the project. The pretax charge of $22 million is included in Impairment Losses on Sempra Energy’s and SoCalGas’ Condensed Consolidated Statements of Operations for the nine months ended September 30, 2016. We expect to make a filing to the CPUC

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES LEGAL PROCEEDINGS We accrue losses for a legal proceeding when it is probable that a loss has been incurred and the amount of the loss can be reasonably estimated. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued. At September 30, 2016 , Sempra Energy’s accrued liabilities for legal proceedings, including associated legal fees and costs of litigation, on a consolidated basis, were $23 million . At September 30, 2016 , accrued liabilities for legal proceedings were $21 million for SDG&E and $1 million for SoCalGas. Amounts for Sempra Energy and SoCalGas include $1 million 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 fires 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 punitive damages, from the three fires. They asserted various bases for recovery, including inverse condemnation based upon a California Court of Appeal decision finding that another California investor-owned utility was subject to strict liability, without regard to foreseeability or negligence, for property damages resulting from a wildfire ignited by power lines. SDG&E has resolved almost all of these lawsuits. One Superior Court case remains in which the plaintiff is challenging the dismissal of her lawsuit and an appeal is likely. Only one appeal remains 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 September 30, 2016 , Sempra Energy and SDG&E have recorded assets of $356 million in Other Regulatory Assets (long-term) on their Condensed Consolidated Balance Sheets, including $354 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 recover 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 related to CPUC-regulated operations was no longer probable or was less than currently estimated at September 30, 2016 , the resulting after-tax charge against earnings would have been up to approximately $210 million . A failure to obtain substantial or full recovery 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 sought injunctive relief and recovery of unspecified amounts of damages. The third party vendor has settled the lawsuit without cost to SDG&E, and a dismissal was entered in federal court on July 20, 2016. Lawsuit Against Mitsubishi Heavy Industries, Ltd. On July 18, 2013, SDG&E filed a lawsuit in the Superior Court of California in the County of San Diego against Mitsubishi Heavy Industries, Ltd., Mitsubishi Nuclear Energy Systems, Inc., and Mitsubishi Heavy Industries America, Inc. (collectively MHI). The lawsuit seeks to recover damages SDG&E has incurred and will incur related to the design defects in the steam generators MHI provided to the SONGS nuclear power plant. The lawsuit asserts a number of causes of action, including fraud, based on the representations MHI made about its qualifications and ability to design generators free from defects of the kind that resulted in the permanent shutdown of the plant and further seeks to set aside the contractual limitation of damages that MHI has asserted. On July 24, 2013, MHI removed the lawsuit to the United States District Court for the Southern District of California and on August 8, 2013, MHI moved to stay the proceeding pending resolution of the dispute resolution process involving MHI and Edison arising from their contract for the purchase and sale of the steam generators. On October 16, 2013, Edison initiated an arbitration proceeding against MHI seeking damages stemming from the failure of the replacement steam generators. In late December 2013, MHI answered and filed a counterclaim against Edison. On March 14, 2014, MHI’s motion to stay the United States District Court proceeding was granted with instructions that require the parties to allow SDG&E to participate in the ongoing Edison/MHI arbitration. As a result, SDG&E 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. Rim Rock 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 were 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 and the project developer began litigating claims against each other regarding whether the project developer had timely satisfied all contractual conditions necessary to trigger SDG&E’s obligations to invest in the project and purchase renewable energy credits. On February 11, 2016, SDG&E, the project developer and several of the project developer’s parent and affiliated entities entered into a settlement agreement, which was approved by the CPUC in July 2016 and all related lawsuits were dismissed. Under the settlement agreement, among other things, the parties agreed to terminate the tax equity investment arrangement, continue the power purchase agreement for the wind farm generation and release all claims against each other, while generally continuing the other elements of the 2011 approved decision. The settlement agreement will result in a $39 million credit to ratepayers. SoCalGas Aliso Canyon Natural Gas Storage Facility Gas Leak On October 23, 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 Resources (DOGGR) confirmed that the well was permanently sealed. Pursuant to a stipulation and court order, SoCalGas provided temporary relocation support to residents in the nearby community who requested it before the well was permanently sealed. In connection with the temporary relocation support, on April 27, 2016, the Los Angeles County Superior Court (Superior Court) issued an order extending the relocation support term pending the completion of the Los Angeles County Department of Public Health’s (DPH) indoor testing. Following the release of the results of the DPH’s indoor testing of certain homes in the Porter Ranch community, which concluded that indoor conditions did not present a long-term health risk and that it was safe for residents to return home, the Superior Court issued an order on May 20, 2016, as supplemented by the Superior Court on May 25, 2016, ruling that: (1) currently relocated residents be given the choice to request residence cleaning, to be performed according to the DPH’s proposed protocol and at SoCalGas’ expense, and (2) the relocation program for currently relocated residents would terminate. SoCalGas completed the cleaning program, and the relocation program ended July 24, 2016. Apart from the Superior Court order, on May 13, 2016, the DPH also issued a directive that SoCalGas professionally clean (in accordance with the proposed protocol prepared by the DPH) the homes of all residents located within the Porter Ranch Neighborhood Council boundary, or who participated in the relocation program, or who are located within a five mile radius of the Aliso Canyon natural gas storage facility and have experienced symptoms from the natural gas leak (the Directive). SoCalGas contends that the Directive is invalid and unenforceable and has filed a petition for writ of mandate to set aside the Directive. The total costs incurred to remediate and stop the leak and to mitigate local community impacts are significant and may increase, and to the extent not covered by insurance (including any costs in excess of applicable policy limits), 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. As of September 30, 2016 , SoCalGas recorded estimated costs of $763 million related to the leak. Of this amount, approximately 70 percent is for the temporary relocation program (including cleaning costs and certain labor costs) and approximately 20 percent is for efforts 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 portion of the $763 million includes legal costs incurred to defend litigation, the value of lost gas, the costs to mitigate the actual natural gas released, and other costs. As the value of lost gas reflects the current replacement cost, the value may fluctuate until such time as replacement gas is purchased and injected into storage. 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. SoCalGas adjusts its estimated total liability associated with the leak as additional information becomes available. During the third quarter of 2016, the increase in the estimated costs of $46 million was primarily based on the increased scope and duration of the root cause analysis effort, which is controlled by DOGGR, as well as the claims recovery process associated with the relocation program. The $763 million represents management’s best estimate of these costs related to the leak. Of these costs, a substantial portion has been paid and $73 million is recorded as Reserve for Aliso Canyon Costs as of September 30, 2016 on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets for amounts expected to be paid after September 30, 2016 . As of September 30, 2016 , we recorded the expected recovery of the costs described in the immediately preceding paragraph related to the leak of $664 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets. This amount is net of insurance retentions and $94 million of insurance proceeds we received in the second and third quarters of 2016 related to control of well expenses and temporary relocation costs. 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 would be charged against earnings, which would have a material adverse effect on SoCalGas’ and Sempra Energy’s financial condition, results of operations and cash flows. The above amounts do not include any unsettled damage awards, restitution, or any civil, administrative 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 proceeding 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 reasonably estimated at this time. In addition, the above amounts do not include the cost to clean additional homes pursuant to the DPH Directive, future legal costs necessary to defend litigation and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. In March 2016, the CPUC issued a decision directing SoCalGas to establish a memorandum account to prospectively track its authorized revenue 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 ratepayers. Pursuant to the CPUC’s decision, 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 intervening parties. In July 2016, SoCalGas filed a supplemental advice letter that replaced the term “actual costs” with “normal, business as usual” before each reference to costs. In September 2016, the supplemental filing was approved and made effective as of March 17, 2016, the date of the decision directing the establishment of the account. Insurance. Excluding directors and officers liability insurance, we have four kinds of insurance policies that together provide between $1.2 billion to $1.4 billion in insurance coverage, depending on the nature of the claims. We cannot predict all of the potential categories of costs or the total amount of costs that we may incur as a result of the leak. In reviewing each of our policies, and subject to various policy limits, exclusions and conditions, based upon what we know as of the filing date of this report, we believe that our insurance policies collectively should cover the following categories of costs: the costs incurred for temporary relocation (including cleaning costs and certain labor costs), 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 costs incurred to mitigate the actual natural gas released, the costs associated with litigation and claims by nearby residents and businesses, the cost to clean additional homes as directed by the DPH, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have been communicating with our insurance carriers and, as discussed above, we have received insurance payments for control of well costs and temporary relocation costs. We intend to pursue the full extent of our insurance coverage for the costs we have incurred or may incur. 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 earnings of SoCalGas and Sempra Energy. Our estimate as of September 30, 2016 of $763 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 insurance (including any costs in excess of applicable policy limits), 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. In addition, any costs not included in the $763 million estimate could be material, and to the extent not covered by insurance (including any costs in excess of applicable policy limits), could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Governmental Investigations and Civil and Criminal Litigation. Various governmental agencies, including the DOGGR, DPH, South Coast Air Quality Management District (SCAQMD), California Air Resources Board (CARB), Los Angeles Regional Water Quality Control Board (RWQCB), California Division of Occupational Safety and Health (DOSH), CPUC, Pipeline and Hazardous Materials Safety Administration (PHMSA), U.S. Environmental Protection Agency (EPA), Los Angeles County District Attorney’s Office and California Attorney General’s Office, are investigating this incident. Other federal agencies (e.g., the U.S. Departments of Energy (DOE) and Interior (DOI)) also are investigating the incident as part of the joint interagency task force discussed below. On January 25, 2016, the DOGGR and CPUC selected Blade Energy Partners (Blade) 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 the first half of 2017, but the timing is under the control of Blade, the DOGGR and the CPUC. As of November 1, 2016, 212 lawsuits, including over 12,000 plaintiffs, have been filed in the Los Angeles County Superior Court against SoCalGas, some of which have also named Sempra Energy. These various lawsuits assert causes of action for negligence, negligence per se, strict liability, property damage, fraud, public and private nuisance (continuing and permanent), trespass, inverse condemnation, fraudulent concealment, unfair business practices and loss of consortium, among other things, and additional litigation may be filed against us in the future related to this incident. A complaint alleging violations of Proposition 65 was also filed. Many of these complaints seek class action status, compensatory and punitive damages, civil penalties, injunctive relief, costs of future medical monitoring and attorneys’ fees. All of these cases, other than a matter brought by the Los Angeles County District Attorney, the federal securities class action and the four shareholder derivative actions discussed below, are coordinated before a single court in the Los Angeles County Superior Court for pretrial management. In addition to the lawsuits described above, a federal securities class action alleging violation of the federal securities laws has been filed against Sempra Energy and certain of its officers and directors in the United States District Court for the Southern District of California, and four shareholder derivative actions alleging breach of fiduciary duties have been filed against certain officers and directors of Sempra Energy and/or SoCalGas, one in the San Diego County Superior Court, one in the United States District Court for the Southern District of California, and two in the Los Angeles County Superior Court. Pursuant to the parties’ agreement, the Los Angeles County Superior Court ordered that the individual and business entity plaintiffs (other than the Proposition 65 case, the federal securities class action and the shareholder derivative actions), would proceed by filing consolidated master complaints. Accordingly, on July 25, 2016, the individuals and business entities asserting tort claims filed a Consolidated Case Complaint for Individual Actions through which their separate lawsuits will be managed for pretrial purposes. The consolidated complaint asserts causes of action for negligence, negligence per se, private and public nuisance (continuing and permanent), trespass, inverse condemnation, strict liability, negligent and intentional infliction of emotional distress, fraudulent concealment and loss of consortium against SoCalGas, with certain causes also naming Sempra Energy. The consolidated complaint seeks compensatory and punitive damages for personal injuries, property damage and diminution in property value, a temporary injunction, costs of future medical monitoring, and attorneys’ fees. On August 8, 2016, also pursuant to the coordination proceeding, a Consolidated Property Class Action Complaint on behalf of a putative class of persons and businesses who own or lease real property within a five-mile radius of the well was filed against SoCalGas and Sempra Energy. The complaint asserts claims for strict liability for ultra-hazardous activities, negligence, negligence per se, trespass, permanent and continuing public and private nuisance, violation of the California Unfair Competition Law and inverse condemnation, and seeks compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. Also on August 8, 2016, a Consolidated Class Action Business Complaint was filed against SoCalGas and Sempra Energy on behalf of a putative class of all persons and entities conducting business within five miles of the Aliso Canyon facility. The complaint asserts claims for strict liability for ultra-hazardous activities, negligence, negligent interference with prospective economic advantage and violation of the California Unfair Competition Law, and seeks compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. Three complaints have also been filed by public entities, as follows. These lawsuits are included in the coordinated proceedings in the Los Angeles County Superior Court. On August 8, 2016, the California Attorney General, acting in her independent capacity and on behalf of the people of the State of California and the CARB, together with the Los Angeles City Attorney, filed a third amended complaint on behalf of the people of the State of California against SoCalGas alleging public nuisance, violation of the California Unfair Competition Law, violations of California Health and Safety Code sections 41700, prohibiting discharge of air contaminants that cause annoyance to the public, and 25510, requiring reporting of the release of hazardous material, as well as California Government Code section 12607 for equitable relief for the protection of natural resources. The complaint seeks an order for injunctive relief, to abate the public nuisance, and to impose civil penalties. The SCAQMD filed a complaint against SoCalGas seeking civil penalties for alleged violations of several nuisance-related statutory provisions arising from the leak and delays in stopping the leak. That suit seeks up to $250,000 in civil penalties for each day the violations occurred. On July 13, 2016, the SCAQMD amended its complaint to seek a declaration that SoCalGas is required to pay the costs of a longitudinal study of the health of persons exposed to the gas leak. On July 25, 2016, the County of Los Angeles, on behalf of itself and the people of the State of California, filed a complaint against SoCalGas in the Los Angeles County Superior Court for public nuisance, unfair competition, breach of franchise agreement, breach of lease, and damages. This suit alleges that the four natural gas storage fields operated or formerly operated by SoCalGas in Los Angeles County require safety upgrades, including the installation of sub-surface safety shut-off valves on every well. It additionally alleges that SoCalGas failed to comply with the DPH Directive. It seeks preliminary and permanent injunctive relief, civil penalties, and damages for the County’s costs to respond to the leak, as well as punitive damages and attorneys’ fees. Separately, on February 2, 2016, the Los Angeles County District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas seeking penalties and other remedies 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 allegedly violating California Health and Safety Code section 41700 prohibiting discharge of air contaminants that cause annoyance to the public. On February 16, 2016, SoCalGas pled not guilty to the complaint. On September 13, 2016, SoCalGas entered a plea of no contest to the notice charge under Health and Safety Code section 25510(a) and agreed to pay the maximum fine of $75,000 , penalty assessments of approximately $232,500 , and up to $4 million in operational commitments, reimbursement and assessments in exchange for the District Attorney’s Office moving to dismiss the remaining counts at sentencing and settling the complaint. The sentencing hearing is currently scheduled for November 29, 2016, at which we expect the court to rule on the motion to dismiss and determine whether to enter judgment on the notice count pursuant to the plea agreement. On October 18, 2016, certain plaintiffs in the separate civil cases filed a “Victims’ Request for Withdrawal of Plea Agreement” seeking to have the court order the withdrawal of the no contest plea or permit a restitution hearing on the nuisance count (SoCalGas pled not guilty to the nuisance count, which under the plea agreement is to be dismissed at sentencing). SoCalGas is implementing the operational commitments pursuant to the terms of the settlement agreement, and we expect that upon completion of those commitments and all other obligations of SoCalGas under the settlement agreement, the District Attorney will move to dismiss the remaining counts at the sentencing hearing. 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, as well as the costs of mitigating the actual natural gas released, could be significant and to the extent not covered by insurance (including any costs in excess of applicable policy limits), or if there were to be significant delays in receiving insurance recoveries, could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Governmental Orders, Additional Regulation and Reliability. On January 6, 2016, the 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 directs the following: • 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 community 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. • Ensuring 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 Oversight: 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 verification 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 the state; and a comprehensive risk management plan for each facility that evaluates and prepares for risks, including corrosion potential of pipes and equipment. Additionally, the DOGGR, CPUC, CARB and California Energy Commission (CEC) will submit to 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 from the leak 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 states that full mitigation requires that the program generate reductions in short-lived climate pollutants and other greenhouse 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 regulating emissions, resulting in a target of approximately 9,000,000 metric tons of carbon dioxide equivalent. CARB’s program also provides that all of the mitigation is to occur in California over the next five to ten years without the use of allowances or offsets. On October 21, 2016, CARB issued its final report, Determination of Total Methane Emissions from the Aliso Canyon Natural Gas Leak Incident . The report documents the CARB staff’s determination of the total methane emissions and the amount needed for full mitigation of the climate impacts. CARB concluded that the incident resulted in total emissions from 90,350 to 108,950 metric tons of m

SEGMENT INFORMATION

SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION We have six separately managed, reportable segments, as follows: 1. SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. 2. SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. 3. Sempra South American Utilities develops, owns and operates, or holds interests in, electric transmission, distribution and generation infrastructure in Chile and Peru. 4. Sempra Mexico develops, owns and operates, or holds interests in, natural gas transmission pipelines and propane and ethane systems, a liquid petroleum gas pipeline and associated storage terminal, a natural gas distribution utility, electric generation facilities (including wind and solar), 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 TdM natural gas-fired power plant located in Mexicali, Baja California, as we discuss in Note 3. 5. Sempra Renewables develops, owns and operates, or holds interests in, wind and solar energy projects in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Michigan, Minnesota, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States. 6. Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. In September 2016, Sempra Natural Gas sold EnergySouth, the parent company of Mobile Gas and Willmut Gas, and in May 2016, sold its 25-percent interest in Rockies Express, as we discuss in Note 3. 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 Utilities and Sempra Mexico comprise our Sempra International operating unit. Sempra Renewables and Sempra Natural Gas comprise our Sempra U.S. Gas & Power operating unit. We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC. The California Utilities’ operations are based on rates set by the CPUC and the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation. The following tables show selected information by segment from our Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of parent organizations. SEGMENT INFORMATION (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 REVENUES SDG&E $ 1,209 48 % $ 1,230 50 % $ 3,192 44 % $ 3,168 42 % SoCalGas 686 27 620 25 2,336 32 2,448 33 Sempra South American Utilities 385 15 373 15 1,170 16 1,151 15 Sempra Mexico 196 8 193 8 481 7 508 7 Sempra Renewables 12 1 12 — 25 — 30 — Sempra Natural Gas 164 6 160 6 384 5 512 7 Adjustments and eliminations (1 ) — — — (1 ) — (1 ) — Intersegment revenues(1) (116 ) (5 ) (107 ) (4 ) (274 ) (4 ) (286 ) (4 ) Total $ 2,535 100 % $ 2,481 100 % $ 7,313 100 % $ 7,530 100 % INTEREST EXPENSE SDG&E $ 49 $ 51 $ 145 $ 155 SoCalGas 25 23 71 61 Sempra South American Utilities 9 9 29 22 Sempra Mexico 5 7 13 18 Sempra Renewables — 1 — 3 Sempra Natural Gas 11 13 33 57 All other 68 65 214 193 Intercompany eliminations (31 ) (26 ) (84 ) (93 ) Total $ 136 $ 143 $ 421 $ 416 INTEREST INCOME SoCalGas $ — $ — $ — $ 3 Sempra South American Utilities 5 5 15 14 Sempra Mexico 2 1 5 5 Sempra Renewables 1 2 2 3 Sempra Natural Gas 19 16 52 60 All other 1 — 1 — Intercompany eliminations (21 ) (18 ) (56 ) (62 ) Total $ 7 $ 6 $ 19 $ 23 DEPRECIATION AND AMORTIZATION SDG&E $ 161 49 % $ 152 48 % $ 478 49 % $ 446 48 % SoCalGas 121 37 116 37 355 37 342 37 Sempra South American Utilities 14 4 12 4 41 4 37 4 Sempra Mexico 15 5 18 6 47 5 52 6 Sempra Renewables 1 — 2 — 4 — 5 — Sempra Natural Gas 12 4 12 4 37 4 36 4 All other 4 1 3 1 8 1 7 1 Total $ 328 100 % $ 315 100 % $ 970 100 % $ 925 100 % INCOME TAX EXPENSE (BENEFIT) SDG&E $ 91 $ 75 $ 204 $ 217 SoCalGas 21 (20 ) 75 91 Sempra South American Utilities 17 16 46 50 Sempra Mexico 142 (6 ) 170 7 Sempra Renewables (7 ) (9 ) (29 ) (37 ) Sempra Natural Gas 51 — (77 ) 29 All other (33 ) (41 ) (105 ) (81 ) Total $ 282 $ 15 $ 284 $ 276 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 EQUITY EARNINGS (LOSSES) Earnings (losses) recorded before tax: Sempra Renewables $ 12 $ 8 $ 30 $ 20 Sempra Natural Gas — 25 (26 ) 59 Total $ 12 $ 33 $ 4 $ 79 Earnings (losses) recorded net of tax: Sempra South American Utilities $ 1 $ (3 ) $ 3 $ (4 ) Sempra Mexico 18 30 66 68 Total $ 19 $ 27 $ 69 $ 64 EARNINGS (LOSSES) SDG&E $ 183 $ 170 $ 419 $ 443 SoCalGas(2) — (8 ) 198 276 Sempra South American Utilities 46 43 127 129 Sempra Mexico 332 63 407 160 Sempra Renewables 17 15 43 47 Sempra Natural Gas 77 1 (104 ) 43 All other (33 ) (36 ) (99 ) (118 ) Total $ 622 $ 248 $ 991 $ 980 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 959 31 % $ 835 38 % SoCalGas 949 31 946 42 Sempra South American Utilities 133 4 105 5 Sempra Mexico 232 8 185 8 Sempra Renewables 700 23 47 2 Sempra Natural Gas 100 3 61 3 All other 14 — 48 2 Total $ 3,087 100 % $ 2,227 100 % September 30, 2016 December 31, 2015 ASSETS SDG&E $ 17,446 38 % $ 16,515 40 % SoCalGas 13,148 29 12,104 29 Sempra South American Utilities 3,488 8 3,235 8 Sempra Mexico 6,359 14 3,783 9 Sempra Renewables 2,112 5 1,441 4 Sempra Natural Gas 5,377 12 5,566 13 All other 640 1 734 2 Intersegment receivables (3,044 ) (7 ) (2,228 ) (5 ) Total $ 45,526 100 % $ 41,150 100 % EQUITY METHOD AND OTHER INVESTMENTS Sempra South American Utilities $ (1 ) $ (4 ) Sempra Mexico 108 519 Sempra Renewables 819 855 Sempra Natural Gas 838 1,460 All other 76 75 Total $ 1,840 $ 2,905 (1) Revenues for reportable segments include intersegment revenues of $2 million , $21 million , $26 million and $67 million for the three months ended September 30, 2016 ; $5 million , $56 million , $80 million and $133 million for the nine months ended September 30, 2016 ; $2 million , $19 million , $24 million and $62 million for the three months ended September 30, 2015 ; and $7 million , $55 million , $73 million and $151 million for the nine months ended September 30, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively. (2) After preferred dividends.

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2016
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENT On October 13, 2016, IEnova priced a private follow-on offering of its common stock (which trades under the symbol IENOVA on the Mexican Stock Exchange) in the U.S. and outside of Mexico (the International Offering) and a concurrent public common stock offering in Mexico (the Mexican Offering) at 80.00 Mexican pesos per share. The initial purchasers in the International Offering and the underwriters in the Mexican Offering were granted a 30-day option to purchase additional common shares at the global offering price, less the underwriting discount, to cover overallotments. These options were exercised on October 17, 2016. Sempra Energy also participated in the Mexican Offering by purchasing 83,125,000 shares of common stock for approximately $351 million . After the offerings and the exercise of the overallotment options, the aggregate shares of common stock sold in the offerings totaled 380,000,000 . Upon completion of the offerings on October 19, 2016, Sempra Energy beneficially owns approximately 66.4 percent of IEnova. The net proceeds of the offerings, including the additional option shares, were approximately $1.57 billion in U.S. dollars or 29.86 billion Mexican pesos. IEnova used the net proceeds of the offerings to repay the $1.150 billion bridge loan from Sempra Global that was used to finance the GdC acquisition and expects to use part of such proceeds to pay for a portion of the purchase price to acquire Ventika in the fourth quarter of 2016. We discuss these acquisitions in Note 3. Any remaining proceeds will be used to fund capital expenditures and for general corporate purposes. All U.S. dollar equivalents presented here were based on an exchange rate of 18.96 Mexican pesos to 1.00 U.S. dollar as of October 13, 2016, the pricing date for the offerings. Net proceeds are after reduction for underwriting discounts and commissions and offering expenses. The International Offering was exempt from registration under the U.S. Securities Act of 1933, as amended (the Securities Act), and shares in the International Offering were offered and sold only to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to persons outside of the United States, in accordance with Regulation S under the Securities Act. The shares were not registered under the Securities Act or any state securities laws, and may not be offered or sold in the United States absent registration or an applicable exemption from the registration requirements of the Securities Act and applicable securities laws.

NEW ACCOUNTING STANDARDS (Polic

NEW ACCOUNTING STANDARDS (Policies)	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Basis of Presentation	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. Throughout this report, we refer to the following as Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements when discussed together or collectively: ▪ the Condensed Consolidated Financial Statements and related Notes of Sempra Energy and its subsidiaries and VIEs, ▪ the Condensed Consolidated Financial Statements and related Notes of SDG&E and its VIE, and ▪ the Condensed Financial Statements and related Notes of SoCalGas. We have prepared the Condensed Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America (U.S. GAAP) and in accordance with the interim-period-reporting requirements of Form 10-Q. Results of operations for interim periods are not necessarily indicative of results for the entire year. We evaluated events and transactions that occurred after September 30, 2016 through the date the financial statements were issued and, in the opinion of management, the accompanying statements reflect all adjustments necessary for a fair presentation. These adjustments are only of a normal, recurring nature. All December 31, 2015 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2015 Consolidated Financial Statements in the Annual Report. Certain information and note disclosures normally included in annual financial statements prepared in accordance with U.S. GAAP have been condensed or omitted pursuant to the interim-period-reporting provisions of U.S. GAAP and the Securities and Exchange Commission. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. We follow the same accounting policies for interim reporting purposes. You should read the information in this Quarterly Report in conjunction with the Annual Report.
New Accounting Standards	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, “Deferral of the Effective Date,” ASU 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” ASU 2016-10, “Identifying Performance Obligations and Licensing,” and ASU 2016-12, “Narrow-Scope Improvements and Practical Expedients”: ASU 2014-09 provides accounting guidance for the recognition of 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 recognition of gains and losses on the sale of certain nonfinancial assets, such as property and equipment, including real estate. This guidance must be adopted using either a full retrospective approach for all periods presented in the period of adoption or a modified retrospective approach. Amending ASU 2014-09, ASU 2016-08 clarifies the implementation guidance on principal versus agent considerations, 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, and ASU 2016-12 provides guidance on transition, collectability, noncash consideration, and the presentation of sales and other similar taxes. 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 for fiscal years beginning after December 15, 2017, with early adoption permitted for fiscal years beginning after December 15, 2016, and is effective for interim periods in the year of adoption. We plan to adopt ASU 2014-09 on January 1, 2018 and are currently evaluating the transition method and the effect on our ongoing financial reporting. As part of our evaluation, we continue to actively monitor outstanding issues currently being addressed by the American Institute of Certified Public Accountants’ Revenue Recognition Working Group and the Financial Accounting Standards Board’s Transition Resource Group, since conclusions reached by these groups may impact our application of these ASU’s. ASU 2016-01, “Recognition and Measurement of Financial Assets and Financial Liabilities”: In addition to the presentation and disclosure 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 the 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 adjusted 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 values 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 requires entities to include substantially all leases on the balance sheet by requiring the recognition of right-of-use assets and lease liabilities for all leases. Entities may elect to exclude from the balance sheet those leases with a maximum possible term of less than 12 months . For lessees, a lease is classified as finance or operating, and the asset and liability are initially measured at the present value of the lease payments. For lessors, accounting for leases is largely unchanged from previous U.S. GAAP, other than certain changes to align lessor accounting to specific changes made to lessee accounting and ASU 2014-09. ASU 2016-02 also requires qualitative disclosures along with specific quantitative disclosures for both lessees and lessors. For public entities, ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, with early adoption permitted, and is effective for interim periods in the year of adoption. The standard requires lessees and 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 commence before the effective date of the standard in accordance with previous U.S. GAAP unless the lease is modified, except for the lessee requirement to recognize right-of-use assets and lease liabilities for all operating leases on the balance sheet 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 accounting 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 individual statutory tax rate without resulting in liability classification of the award and clarifies that cash payments made to taxing authorities in connection with withheld shares should be classified as financing activities in the statement of cash flows. 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 early adoption permitted, and is effective for interim periods in the year of adoption. We early adopted the provisions of ASU 2016-09 during the three months ended September 30, 2016, with an effective date of January 1, 2016. Upon adoption: ▪ Sempra Energy, SDG&E and SoCalGas recognized a cumulative-effect adjustment to retained earnings and a deferred tax asset as of January 1, 2016 of $107 million , $23 million and $15 million , respectively, for previously unrecognized excess tax benefits from share-based compensation. ▪ Sempra Energy, SDG&E and SoCalGas recognized earnings consisting of excess tax benefits on the Condensed Consolidated Statements of Operations of $34 million , $7 million and $4 million , respectively, in the nine months ended September 30, 2016, all of which related to the three months ended March 31, 2016. The $34 million was previously recorded in Sempra Energy Shareholders’ Equity in Common Stock prior to adoption of ASU 2016-09. ▪ The $34 million of excess tax benefits from share-based compensation for Sempra Energy related to the three months ended March 31, 2016 was previously classified as a financing activity on Sempra Energy’s Condensed Consolidated Statement of Cash Flows. As now required, the $34 million of excess tax benefits for Sempra Energy, as well as the $7 million for SDG&E and $4 million for SoCalGas, are included in Cash Flows From Operating Activities on the Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2016. This amendment was adopted prospectively, and therefore, we have not adjusted the Condensed Consolidated Statements of Cash Flows for the prior period presented. ▪ As a result of the provision to recognize excess tax benefits in earnings, these benefits are no longer included in the calculation of diluted earnings per share (EPS) effective January 1, 2016. The weighted-average number of common shares outstanding for diluted EPS increased by 75 thousand shares for the three months ended March 31, 2016 and 98 thousand shares and 89 thousand shares for the three months and six months ended June 30, 2016, respectively. We discuss the impact further in Note 5 under “Earnings Per Share.” Upon adoption of ASU 2016-09, we elected to continue estimating the number of awards expected to be forfeited and adjusting our estimate on an ongoing basis. All other provisions of ASU 2016-09 did not impact our financial condition, results of operations or cash flows. ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13 changes how entities will measure credit losses for most financial assets and certain other instruments. The standard introduces an “expected credit loss” impairment model that requires immediate recognition of estimated credit losses expected to occur over the remaining life of most financial assets measured at amortized cost, including trade and other receivables, loan commitments and financial guarantees. ASU 2016-13 also requires use of an allowance to record estimated credit losses on available-for-sale debt securities and expands disclosure requirements regarding an entity’s assumptions, models and methods for estimating the credit losses. For public entities, ASU 2016-13 is effective for fiscal years beginning after December 15, 2019, with early adoption permitted for fiscal years beginning after December 15, 2018. We are currently evaluating the year in which we will adopt the standard and its effect on our ongoing financial reporting. ASU 2016-15, “Classification of Certain Cash Receipts and Cash Payments”: ASU 2016-15 provides guidance on how certain cash receipts and cash payments are to be presented and classified in the statement of cash flows in order to reduce diversity in practice. For public entities, ASU 2016-15 is effective for fiscal years beginning after December 15, 2017, with early adoption permitted, and is effective for interim periods in the year of adoption. An entity that elects early adoption must adopt all of the amendments in the same period. Entities must apply the guidance retrospectively to all periods presented, but may apply it prospectively if retrospective application would be impracticable. We are currently evaluating the year in which we will adopt the standard and its effect on our ongoing financial reporting.
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 on qualitative and quantitative analyses, which assess ▪ the purpose and design of the VIE; ▪ the nature of the VIE’s risks and the risks we absorb; ▪ the power to direct activities that most significantly impact the economic performance of the VIE; and ▪ the obligation to absorb losses or right to receive benefits that could be significant to the VIE
Noncontrolling Interest Policy	Ownership interests that are held by owners other than Sempra Energy and SDG&E in subsidiaries or entities consolidated by them are accounted for and reported as noncontrolling interests. As a result, noncontrolling interests are reported as a separate component of equity on the Condensed Consolidated Balance Sheets. Earnings or losses attributable to noncontrolling interests are separately identified on the Condensed Consolidated Statements of Operations, and comprehensive income or loss attributable to noncontrolling interests is separately identified on the Condensed Consolidated Statements of Comprehensive Income (Loss).
Earnings Per Share Policy	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 targets. TSR RSUs represent the right to receive from zero to 1.5 shares ( 2.0 shares for awards granted during or after 2014) of Sempra Energy common stock if performance targets are met. EPS RSUs represent the right to receive from zero to 2.0 shares of Sempra Energy common stock if performance targets are met. If performance falls between the targets specified for each performance metric, we calculate the payout using linear interpolation. Participants also receive additional shares for dividend equivalents on shares subject to RSUs, which are deemed reinvested to purchase additional units that become subject to the same vesting conditions as the RSUs to which the dividends relate. We discuss performance-based RSU awards further in Note 8 of the Notes to Consolidated 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 include our TSR RSUs and EPS RSUs in potential dilutive shares at zero to up to 200 percent to the extent that they currently meet the performance requirements for vesting, subject to the application of the treasury stock method. Due to market fluctuations of both Sempra Energy stock and the comparative indices, dilutive TSR RSU shares may vary widely from period-to-period. 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.
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 factored 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, Mexican currency translation and inflation adjustments, deferred income tax benefits associated with impairment of a book investment and certain impacts of regulatory matters) are recorded in the interim period in which they actually occur, which can result in variability in the effective income tax rate.
Flow-through rate-making treatment tax policy	For SDG&E and SoCalGas, the California Public Utilities Commission (CPUC) requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the current effective income tax rate. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the effective income tax rate. The following items are subject to flow-through treatment: ▪ repairs expenditures related to a certain portion of utility plant assets ▪ the equity portion of AFUDC ▪ a portion of the cost of removal of utility plant assets ▪ utility self-developed software expenditures ▪ depreciation on a certain portion of utility plant assets ▪ state income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico is also subject to flow-through treatment. The final decision in the 2016 General Rate Case (2016 GRC) issued by the CPUC in June 2016 affecting the California Utilities requires the establishment of a two-way income tax expense memorandum account for SDG&E and SoCalGas to track any revenue variances resulting from certain differences arising between the income tax expense forecasted in the 2016 GRC and the income tax expense incurred from 2016 through 2018. The variances to be tracked include tax expense differences relating to ▪ net revenue changes, ▪ mandatory tax law, tax accounting, tax procedural, or tax policy changes, and ▪ elective tax law, tax accounting, tax procedural, or tax policy changes. The account will remain open, and the balance in the account will be reviewed in subsequent GRC proceedings, until the CPUC decides to close the account. We believe the future disposition of these tracked balances may result in refunds being directed to ratepayers to the extent tax expense incurred is lower than forecasted tax expense in the GRC process as a result of certain flow-through item deductions, as described above, or other items. We discuss the memo account further in Note 10. Differences arising from the forecasted amounts will be tracked in the two-way income tax expense tracking account, except for the equity portion of AFUDC, which is not subject to taxation. We expect that certain amounts recorded in the tracking account may give rise to regulatory assets or liabilities until the CPUC disposes with the account. The CPUC tracking account does not affect the recovery of income tax expense in Federal Energy Regulatory Commission (FERC) formulaic rates.
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 in anticipated revenues or increases in anticipated expenses, or (2) that our asset values may fall or our liabilities increase. Accordingly, our derivative activity summarized below generally represents an impact that is intended to offset associated revenues, expenses, assets or liabilities that are not 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) undesignated. Depending on the applicability of hedge accounting and, for the California Utilities and other operations subject to regulatory accounting, the requirement to pass impacts through to customers, the impact of derivative instruments may be offset in other comprehensive income (loss) (cash flow hedge), on the balance sheet (fair value hedges and regulatory offsets), or recognized in earnings. We classify cash flows from the settlements of derivative instruments as operating activities on the Condensed Consolidated Statements of Cash Flows. 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 combination of the derivative and debt instrument results in fixing that portion of the fair value of the debt that is related to benchmark interest rates. Designating fair value hedges is dependent on the instrument being used, the effectiveness of the instrument in offsetting changes in the fair value of our debt instruments, and other criteria. ENERGY DERIVATIVES Our market risk is primarily related to natural gas and electricity price volatility and the specific physical locations where we transact. We use energy derivatives to manage these risks. The use of energy derivatives in our various businesses depends on the particular energy market, and the operating and regulatory environments applicable to the business, 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 exchange-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 activities are recorded as commodity costs that are offset by regulatory account balances and are recovered in rates. Net commodity cost impacts on the Condensed Consolidated Statements of Operations are reflected in Cost of Electric Fuel and Purchased Power or in Cost of Natural Gas. • SDG&E is allocated and may purchase congestion revenue rights (CRRs), which serve to reduce the regional electricity price volatility risk that may result from local transmission capacity constraints. Unrealized gains and losses do not impact earnings, as they are offset by regulatory account balances. Realized gains and losses associated with CRRs, which are recoverable in rates, are recorded in Cost of Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. • Sempra Mexico, Sempra Natural Gas, and Sempra Renewables 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 and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Cost of Natural Gas, Electric Fuel and Purchased Power on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico also uses natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its Mexican distribution operations. These derivatives, which are recorded as commodity costs that are offset by regulatory account balances and recovered in rates, are recognized in Cost of Natural Gas on the Condensed Consolidated Statements of Operations. • From time to time, our various businesses, including the California Utilities, may use other energy derivatives to hedge exposures such as the price of vehicle fuel. 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. From time to time, Sempra Mexico and its joint ventures may use other foreign currency derivatives to hedge exposures related to cash flows associated with revenues from contracts denominated in Mexican pesos that are indexed to the U.S. dollar. 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 assets 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 exposure to significant fluctuations in our income tax expense and equity earnings from these impacts. In January 2016 and September 2016, we entered into foreign currency derivatives with notional amounts totaling $550 million and $914 million , respectively. In addition to the amounts noted above, we frequently use commodity derivatives to manage risks associated with the physical locations of contractual obligations and assets, such as natural gas purchases and sales. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. We periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. We 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 and joint ventures. Interest rate derivatives are generally accounted for as hedges, and although the California Utilities generally recover borrowing costs in rates over time, the use of interest rate derivatives is subject to certain regulatory constraints, and the impact of interest rate derivatives may not be recovered from customers as timely as described above with regard to energy derivatives. Separately, Otay Mesa VIE has entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes.
Fair Value Measurement Policy	We determine the fair value of certain noncurrent amounts due from unconsolidated affiliates, long-term debt and preferred stock based 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 costs (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). 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 through customer rates. As such, there is no impact to earnings from changes in the fair value of these instruments. CRRs are recorded at fair value based almost entirely on the most current auction prices published by the California Independent System Operator (CAISO), an objective source. Annual auction prices are published once a year, typically in the middle of November, and remain in effect for the following year. The impact associated with discounting is negligible. Because auction prices are a less observable input, these instruments are classified as Level 3. The fair value of these instruments is derived from auction price differences between two locations. We classify financial assets and liabilities in their entirety based on the lowest level of input that is significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities, and their placement within the fair value hierarchy levels. We have not changed the valuation techniques or types of inputs we use to measure recurring fair values during the nine months ended September 30, 2016 . The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 7 under “Financial Statement Presentation.” The determination of fair values, shown in the tables below, incorporates various factors, including but not limited to, the credit standing of the counterparties involved and the impact of credit enhancements (such as cash deposits, letters of credit and priority interests). Our financial assets and liabilities that were accounted for at fair value on a recurring basis at September 30, 2016 and December 31, 2015 in the tables below include the following: ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s nuclear decommissioning trusts, excluding cash balances. A third party trustee values the trust assets using prices from a pricing service based on a market approach. We validate these prices by comparison to prices from other independent data sources. Equity and certain debt securities are valued using quoted prices listed on nationally recognized securities exchanges or based on closing prices reported in the active market in which the identical security is traded (Level 1). Other debt securities are valued based on yields that are currently available for comparable securities of issuers with similar credit ratings (Level 2). ▪ For commodity contracts, interest rate derivatives and foreign exchange instruments, we primarily use a market approach with market participant assumptions to value these derivatives. Market participant assumptions include those about risk, and the risk inherent in the inputs to the valuation techniques. These inputs can be readily observable, market 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 relate 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 active market in which the identical security is traded (Level 1). These investments in marketable securities were negligible at both September 30, 2016 and December 31, 2015 . 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 Deferred Compensation Plans are carried at cash surrender values, which represent the amount of cash that could be realized under the contracts. Positive values between two locations represent expected future reductions in congestion costs, whereas negative values between two locations represent expected future charges. Valuation of our CRRs is sensitive to a change in auction price. If auction prices at one location increase (decrease) relative to another location, this could result in a higher (lower) fair value measurement. We summarize CRR volumes in Note 7. Long-term, fixed-price electricity positions 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.
Segment Policy	We have six separately managed, reportable segments, as follows: 1. SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. 2. SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. 3. Sempra South American Utilities develops, owns and operates, or holds interests in, electric transmission, distribution and generation infrastructure in Chile and Peru. 4. Sempra Mexico develops, owns and operates, or holds interests in, natural gas transmission pipelines and propane and ethane systems, a liquid petroleum gas pipeline and associated storage terminal, a natural gas distribution utility, electric generation facilities (including wind and solar), 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 TdM natural gas-fired power plant located in Mexicali, Baja California, as we discuss in Note 3. 5. Sempra Renewables develops, owns and operates, or holds interests in, wind and solar energy projects in Arizona, California, Colorado, Hawaii, Indiana, Kansas, Michigan, Minnesota, Nebraska, Nevada and Pennsylvania to serve wholesale electricity markets in the United States. 6. Sempra Natural Gas develops, owns and operates, or holds interests in, natural gas pipelines and storage facilities and a terminal for the import and export of LNG and sale of natural gas, all within the United States. In September 2016, Sempra Natural Gas sold EnergySouth, the parent company of Mobile Gas and Willmut Gas, and in May 2016, sold its 25-percent interest in Rockies Express, as we discuss in Note 3. 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 Utilities and Sempra Mexico comprise our Sempra International operating unit. Sempra Renewables and Sempra Natural Gas comprise our Sempra U.S. Gas & Power operating unit. We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings. The California Utilities operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC. The California Utilities’ operations are based on rates set by the CPUC and the FERC. We describe the accounting policies of all of our segments in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Common services shared by the business segments are assigned directly or allocated based on various cost factors, depending on the nature of the service provided. Interest income and expense is recorded on intercompany loans. The loan balances and related interest are eliminated in consolidation.
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. However, the uncertainties inherent in legal proceedings make it difficult to estimate with reasonable certainty the costs and effects of resolving these matters. Accordingly, actual costs incurred may differ materially from amounts accrued, may exceed applicable insurance coverage and could materially adversely affect our business, cash flows, results of operations, financial condition and prospects. Unless otherwise indicated, we are unable to estimate reasonably possible losses in excess of any amounts accrued.

ACQUISITION AND DIVESTITURE A21

ACQUISITION AND DIVESTITURE ACTIVITY (Tables)	9 Months Ended
	Sep. 30, 2016
Business Combinations [Abstract]
Schedule of Business Acquisition Table	The following table summarizes the total fair value of the business combination and the values of the assets acquired and liabilities assumed at the date of acquisition: PURCHASE PRICE ALLOCATION – GdC (Dollars in millions) September 26, 2016 Fair value of business combination: Cash consideration (fair value of total consideration) $ 1,144 Fair value of equity interest in GdC immediately prior to acquisition 1,144 Total fair value of business combination $ 2,288 Recognized amounts of identifiable assets acquired and liabilities assumed: Cash and cash equivalents $ 66 Accounts receivable(1) 39 Other current assets 6 Property, plant and equipment 1,248 Other noncurrent assets 1 Accounts payable (11 ) Due to unconsolidated affiliates (3 ) Current portion of long-term debt (49 ) Fixed-price contracts and other derivatives, current (6 ) Other current liabilities (20 ) Long-term debt (315 ) Asset retirement obligations (5 ) Deferred income taxes (8 ) Fixed-price contracts and other derivatives, noncurrent (19 ) Other noncurrent liabilities (11 ) Total identifiable net assets 913 Goodwill 1,375 Total fair value of business combination $ 2,288 (1) We expect acquired accounts receivable to be substantially realizable in cash. Accounts receivable are net of negligible collection allowances.
Schedule of Pro Forma Information Table	The following table presents the pro forma results for the three months and nine months ended September 30, 2016 and 2015. The pro forma financial information combines the historical results of operations of Sempra Energy and GdC as though the acquisition occurred on January 1, 2015. The pro forma information is not necessarily indicative of results that would have been achieved had the business been combined during the periods presented or the results that we will experience going forward. PRO FORMA INFORMATION – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 Revenues $ 2,608 $ 2,545 $ 7,529 $ 7,708 Net income 308 308 744 1,550 Earnings 299 255 685 1,280
Schedule of Assets Held for Sale and Deconsolidation of Subsidiary Table	The following table summarizes the deconsolidation: DECONSOLIDATION OF SUBSIDIARY (Dollars in millions) EnergySouth Inc. Proceeds from sale, net of transaction costs $ 304 Cash (2 ) Inventory (3 ) Other current assets (14 ) Regulatory assets (12 ) Goodwill (72 ) Other assets (53 ) Property, plant and equipment, net (199 ) Accounts payable 12 Other current liabilities 13 Long-term debt 67 Deferred income taxes 36 Regulatory liabilities 23 Asset retirement obligations 12 Other liabilities 18 Gain on sale of business(1) $ 130 (1) Included in Gain on Sale of Assets on Sempra Energy’s Condensed Consolidated Statements of Operations. At September 30, 2016 , the carrying amounts of the major classes of assets and related liabilities held for sale associated with TdM are as follows: ASSETS HELD FOR SALE AT SEPTEMBER 30, 2016 (Dollars in millions) Termoeléctrica de Mexicali Cash and cash equivalents $ 1 Inventories 8 Other current assets 25 Deferred income taxes 5 Other assets 22 Property, plant and equipment, net 120 Total assets held for sale $ 181 Accounts payable $ 1 Other current liabilities 7 Asset retirement obligations 4 Other liabilities 23 Total liabilities held for sale $ 35

OTHER FINANCIAL DATA (Tables)

OTHER FINANCIAL DATA (Tables)	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Inventory Table	The components of inventories by segment are as follows: INVENTORY BALANCES (Dollars in millions) Natural gas Liquefied natural gas Materials and supplies Total September 30, 2016 December 31, 2015 September 30, 2016 December 31, 2015 September 30, 2016 December 31, 2015 September 30, 2016 December 31, 2015 SDG&E $ 1 $ 6 $ — $ — $ 72 $ 69 $ 73 $ 75 SoCalGas(1) 24 49 — — 53 30 77 79 Sempra South American Utilities — — — — 46 30 46 30 Sempra Mexico — — 4 3 2 10 6 13 Sempra Renewables — — — — 3 3 3 3 Sempra Natural Gas 94 94 3 3 — 1 97 98 Sempra Energy Consolidated $ 119 $ 149 $ 7 $ 6 $ 176 $ 143 $ 302 $ 298 (1) At both September 30, 2016 and December 31, 2015 , SoCalGas’ natural gas inventory for core customers is net of an inventory loss related to the Aliso Canyon natural gas leak, which we discuss in Note 11.
Schedule of Goodwill Table	Changes in the carrying amount of goodwill on the Sempra Energy Consolidated Balance Sheets are as follows: GOODWILL (Dollars in millions) Sempra South American Utilities Sempra Mexico Sempra Natural Gas Total Balance at December 31, 2015 $ 722 $ 25 $ 72 $ 819 Acquisition of business — 1,375 — 1,375 Sale of business — — (72 ) (72 ) Foreign currency translation(1) 28 — — 28 Balance at September 30, 2016 $ 750 $ 1,400 $ — $ 2,150 (1) We record the offset of this fluctuation to Other Comprehensive Income (Loss).
Variable Interest Entity Table	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 below generally correspond to SDG&E’s Condensed Consolidated Statements of Operations. AMOUNTS ASSOCIATED WITH OTAY MESA VIE (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 Operating expenses Cost of electric fuel and purchased power $ (28 ) $ (27 ) $ (62 ) $ (66 ) Operation and maintenance 4 3 23 13 Depreciation and amortization 8 7 25 19 Total operating expenses (16 ) (17 ) (14 ) (34 ) Operating income 16 17 14 34 Interest expense (5 ) (5 ) (15 ) (14 ) Income (loss) before income taxes/Net income (loss) 11 12 (1 ) 20 (Earnings) losses attributable to noncontrolling interest (11 ) (12 ) 1 (20 ) Earnings attributable to common shares $ — $ — $ — $ —
Net Periodic Benefit Cost Table	NET PERIODIC BENEFIT COST – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2016 2015 2016 2015 Service cost $ 26 $ 27 $ 4 $ 5 Interest cost 40 38 9 10 Expected return on assets (41 ) (42 ) (17 ) (17 ) Amortization of: Prior service cost (credit) 2 3 — (1 ) Actuarial loss (gain) 10 9 (1 ) — Settlements — 4 — — Regulatory adjustment (28 ) (27 ) 5 4 Total net periodic benefit cost $ 9 $ 12 $ — $ 1 Nine months ended September 30, 2016 2015 2016 2015 Service cost $ 81 $ 86 $ 15 $ 19 Interest cost 120 116 31 33 Expected return on assets (124 ) (130 ) (52 ) (51 ) Amortization of: Prior service cost (credit) 8 8 — (2 ) Actuarial loss (gain) 23 28 (1 ) — Settlements — 4 — — Regulatory adjustment (84 ) (86 ) 9 4 Total net periodic benefit cost $ 24 $ 26 $ 2 $ 3 NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2016 2015 2016 2015 Service cost $ 7 $ 6 $ 1 $ 1 Interest cost 10 9 2 2 Expected return on assets (12 ) (14 ) (3 ) (2 ) Amortization of: Actuarial loss 2 3 — — Regulatory adjustment (7 ) (3 ) — (1 ) Total net periodic benefit cost $ — $ 1 $ — $ — Nine months ended September 30, 2016 2015 2016 2015 Service cost $ 22 $ 22 $ 3 $ 5 Interest cost 31 29 6 6 Expected return on assets (37 ) (41 ) (8 ) (8 ) Amortization of: Prior service cost 1 1 2 2 Actuarial loss (gain) 7 7 (1 ) — Regulatory adjustment (22 ) (15 ) (2 ) (5 ) Total net periodic benefit cost $ 2 $ 3 $ — $ — NET PERIODIC BENEFIT COST – SOCALGAS (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2016 2015 2016 2015 Service cost $ 16 $ 17 $ 4 $ 3 Interest cost 26 25 7 8 Expected return on assets (26 ) (25 ) (15 ) (14 ) Amortization of: Prior service cost (credit) 3 2 (1 ) (2 ) Actuarial loss 3 5 — — Regulatory adjustment (21 ) (24 ) 5 5 Total net periodic benefit cost $ 1 $ — $ — $ — Nine months ended September 30, 2016 2015 2016 2015 Service cost $ 51 $ 55 $ 11 $ 13 Interest cost 76 74 24 26 Expected return on assets (78 ) (79 ) (43 ) (42 ) Amortization of: Prior service cost (credit) 7 6 (3 ) (6 ) Actuarial loss 8 16 — — Regulatory adjustment (62 ) (71 ) 11 9 Total net periodic benefit cost $ 2 $ 1 $ — $ —
Contributions to Benefit Plans Table	The following table shows our year-to-date contributions to pension and other postretirement benefit plans and the amounts we expect to contribute in 2016: BENEFIT PLAN CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Contributions through September 30, 2016: Pension plans $ 24 $ 2 $ 1 Other postretirement benefit plans 3 — 1 Total expected contributions in 2016: Pension plans $ 124 $ 7 $ 73 Other postretirement benefit plans 6 2 1
Earnings Per Share Computations Table	The following table provides EPS computations for the three months and nine months ended September 30, 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 September 30, Nine months ended September 30, 2016 2015 2016 2015 Numerator: Earnings/Income attributable to common shares $ 622 $ 248 $ 991 $ 980 Denominator: Weighted-average common shares outstanding for basic EPS(1) 250,386 248,432 250,073 248,090 Dilutive effect of stock options, restricted stock awards and restricted stock units(2) 2,019 2,592 1,903 2,575 Weighted-average common shares outstanding for diluted EPS(2) 252,405 251,024 251,976 250,665 Earnings per share: Basic $ 2.48 $ 1.00 $ 3.96 $ 3.95 Diluted 2.46 0.99 3.93 3.91 (1) Includes 572 and 504 average fully vested restricted stock units held in our Deferred Compensation Plan for the three months ended September 30, 2016 and 2015 , respectively, and 565 and 486 of such units for the nine months ended September 30, 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. (2) Reflects the prospective adoption of ASU 2016-09 as of January 1, 2016, as we discuss in Note 2. Prior to the adoption, the dilutive effect of stock options, restricted stock awards and restricted stock units was reduced by excess tax benefits assumed to be used to repurchase shares on the open market.
Capitalized Financing Costs Table	The following table shows capitalized financing costs for the three months and nine months ended September 30, 2016 and 2015 . CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 Sempra Energy Consolidated: AFUDC related to debt $ 7 $ 6 $ 22 $ 19 AFUDC related to equity 29 26 86 84 Other capitalized interest 26 18 64 52 Total Sempra Energy Consolidated $ 62 $ 50 $ 172 $ 155 SDG&E: AFUDC related to debt $ 4 $ 3 $ 12 $ 10 AFUDC related to equity 11 9 35 27 Total SDG&E $ 15 $ 12 $ 47 $ 37 SoCalGas: AFUDC related to debt $ 3 $ 3 $ 10 $ 9 AFUDC related to equity 10 10 30 29 Other capitalized interest 1 1 1 1 Total SoCalGas $ 14 $ 14 $ 41 $ 39
Schedule of Accumulated Other Comprehensive Income (Loss) Table	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) Foreign currency translation adjustments Financial instruments Pension and other postretirement benefits Total accumulated other comprehensive income (loss) Three months ended September 30, 2016 and 2015 2016: Balance as of June 30, 2016 $ (503 ) $ (264 ) $ (85 ) $ (852 ) Other comprehensive (loss) income before reclassifications (28 ) 8 — (20 ) Amounts reclassified from accumulated other comprehensive income — 5 2 7 Net other comprehensive (loss) income (28 ) 13 2 (13 ) Balance as of September 30, 2016 $ (531 ) $ (251 ) $ (83 ) $ (865 ) 2015: Balance as of June 30, 2015 $ (427 ) $ (86 ) $ (83 ) $ (596 ) Other comprehensive loss before reclassifications (92 ) (79 ) — (171 ) Amounts reclassified from accumulated other comprehensive income — 1 5 6 Net other comprehensive (loss) income (92 ) (78 ) 5 (165 ) Balance as of September 30, 2015 $ (519 ) $ (164 ) $ (78 ) $ (761 ) Nine months ended September 30, 2016 and 2015 2016: Balance as of December 31, 2015 $ (582 ) $ (137 ) $ (87 ) $ (806 ) Other comprehensive income (loss) before reclassifications 51 (122 ) — (71 ) Amounts reclassified from accumulated other comprehensive income — 8 4 12 Net other comprehensive income (loss) 51 (114 ) 4 (59 ) Balance as of September 30, 2016 $ (531 ) $ (251 ) $ (83 ) $ (865 ) 2015: . Balance as of December 31, 2014 $ (322 ) $ (90 ) $ (85 ) $ (497 ) Other comprehensive loss before reclassifications (197 ) (76 ) — (273 ) Amounts reclassified from accumulated other comprehensive income — 2 7 9 Net other comprehensive (loss) income (197 ) (74 ) 7 (264 ) Balance as of September 30, 2015 $ (519 ) $ (164 ) $ (78 ) $ (761 ) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1) SOUTHERN CALIFORNIA GAS COMPANY (Dollars in Millions) Financial instruments Pension and other Total accumulated other comprehensive income (loss) Three months ended September 30, 2016 and 2015 2016: Balance as of June 30, 2016 $ (14 ) $ (5 ) $ (19 ) Amounts reclassified from accumulated other comprehensive income 1 — 1 Net other comprehensive income 1 — 1 Balance as of September 30, 2016 $ (13 ) $ (5 ) $ (18 ) 2015: Balance as of June 30 and September 30, 2015 $ (14 ) $ (4 ) $ (18 ) Nine months ended September 30, 2016 and 2015 2016: Balance as of December 31, 2015 $ (14 ) $ (5 ) $ (19 ) Amounts reclassified from accumulated other comprehensive income 1 — 1 Net other comprehensive income 1 — 1 Balance as of September 30, 2016 $ (13 ) $ (5 ) $ (18 ) 2015: Balance as of December 31, 2014 and September 30, 2015 $ (14 ) $ (4 ) $ (18 ) (1) All amounts are net of income tax, if subject to tax, and exclude noncontrolling interests.
Reclassifications out of AOCI Table	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated other Amounts reclassified Affected line item on Condensed Three months ended September 30, 2016 2015 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments $ 4 $ 5 Interest Expense Interest rate instruments 3 3 Equity Earnings, Before Income Tax Interest rate and foreign exchange instruments 7 — Remeasurement of Equity Method Investment Interest rate and foreign exchange instruments (2 ) — Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery — (3 ) Revenues: Energy-Related Businesses Total before income tax 12 5 (3 ) (1 ) Income Tax Expense Net of income tax 9 4 (4 ) (3 ) Earnings Attributable to Noncontrolling Interests $ 5 $ 1 Pension and other postretirement benefits: Amortization of actuarial loss $ 4 $ 7 See note (1) below (2 ) (2 ) Income Tax Expense Net of income tax $ 2 $ 5 Total reclassifications for the period, net of tax $ 7 $ 6 SDG&E: Financial instruments: Interest rate instruments $ 3 $ 3 Interest Expense (3 ) (3 ) (Earnings) Losses Attributable to Noncontrolling Interest Total reclassifications for the period, net of tax $ — $ — SoCalGas: Financial instruments: Interest rate instruments $ 1 $ — Interest Expense Total reclassifications for the period, net of tax $ 1 $ — (1) Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above). RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated other Amounts reclassified Affected line item on Condensed Nine months ended September 30, 2016 2015 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments $ 11 $ 14 Interest Expense Interest rate instruments 8 9 Equity Earnings, Before Income Tax Interest rate and foreign exchange instruments 7 — Remeasurement of Equity Method Investment Interest rate and foreign exchange instruments 4 — Equity Earnings, Net of Income Tax Commodity contracts not subject to rate recovery (7 ) (10 ) Revenues: Energy-Related Businesses Total before income tax 23 13 (4 ) (1 ) Income Tax Expense Net of income tax 19 12 (11 ) (10 ) Earnings Attributable to Noncontrolling Interests $ 8 $ 2 Pension and other postretirement benefits: Amortization of actuarial loss $ 8 $ 11 See note (1) below (4 ) (4 ) Income Tax Expense Net of income tax $ 4 $ 7 Total reclassifications for the period, net of tax $ 12 $ 9 SDG&E: Financial instruments: Interest rate instruments $ 9 $ 9 Interest Expense (9 ) (9 ) (Earnings) Losses Attributable to Noncontrolling Interest Total reclassifications for the period, net of tax $ — $ — SoCalGas: Financial instruments: Interest rate instruments $ 1 $ — Interest Expense Total reclassifications for the period, net of tax $ 1 $ — (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	The following tables provide reconciliations of changes in Sempra Energy’s, SDG&E’s and SoCalGas’ shareholders’ equity and noncontrolling interests for the nine months ended September 30, 2016 and 2015 . SHAREHOLDERS’ EQUITY AND NONCONTROLLING INTERESTS – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Sempra Energy ’ equity Non- Total Balance at December 31, 2015 $ 11,809 $ 770 $ 12,579 Cumulative-effect adjustment from change in accounting principle 107 — 107 Comprehensive income 933 117 1,050 Preferred dividends of subsidiary (1 ) — (1 ) Share-based compensation expense 38 — 38 Common stock dividends declared (565 ) — (565 ) Issuances of common stock 80 — 80 Repurchases of common stock (55 ) — (55 ) Equity contributed by noncontrolling interests — 2 2 Distributions to noncontrolling interests — (44 ) (44 ) Balance at September 30, 2016 $ 12,346 $ 845 $ 13,191 Balance at December 31, 2014 $ 11,326 $ 774 $ 12,100 Comprehensive income 717 56 773 Preferred dividends of subsidiary (1 ) — (1 ) Share-based compensation expense 39 — 39 Common stock dividends declared (520 ) — (520 ) Issuances of common stock 82 — 82 Repurchases of common stock (74 ) — (74 ) Tax benefit related to share-based compensation 56 — 56 Equity contributed by noncontrolling interest — 1 1 Distributions to noncontrolling interests — (60 ) (60 ) Balance at September 30, 2015 $ 11,625 $ 771 $ 12,396 (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 ’ s Non- Total Balance at December 31, 2015 $ 5,223 $ 53 $ 5,276 Cumulative-effect adjustment from change in accounting principle 23 — 23 Comprehensive income 419 3 422 Common stock dividends declared (175 ) — (175 ) Equity contributed by noncontrolling interest — 1 1 Distributions to noncontrolling interest — (7 ) (7 ) Balance at September 30, 2016 $ 5,490 $ 50 $ 5,540 Balance at December 31, 2014 $ 4,932 $ 60 $ 4,992 Comprehensive income 443 20 463 Common stock dividends declared (150 ) — (150 ) Distributions to noncontrolling interest — (16 ) (16 ) Balance at September 30, 2015 $ 5,225 $ 64 $ 5,289 SHAREHOLDERS’ EQUITY – SOCALGAS (Dollars in millions) SoCalGas Balance at December 31, 2015 $ 3,149 Cumulative-effect adjustment from change in accounting principle 15 Comprehensive income 200 Preferred stock dividends declared (1 ) Balance at September 30, 2016 $ 3,363 Balance at December 31, 2014 $ 2,781 Comprehensive income 277 Preferred stock dividends declared (1 ) Common stock dividends declared (50 ) Balance at September 30, 2015 $ 3,007
Ownership Interests Held By Others Table	At September 30, 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 Energy’s Condensed Consolidated Balance Sheets: OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by others September 30, December 31, September 30, December 31, SDG&E: Otay Mesa VIE 100 % 100 % $ 50 $ 53 Sempra South American Utilities: Chilquinta Energía subsidiaries(1) 23.1 – 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(2) 18.9 18.9 537 468 Sempra Natural Gas: Bay Gas Storage Company, Ltd. 9.1 9.1 26 25 Liberty Gas Storage, LLC 23.3 23.2 14 14 Southern Gas Transmission Company 49.0 49.0 1 1 Total Sempra Energy $ 825 $ 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. (2) On October 19, 2016, IEnova completed follow-on equity offerings that increased the 18.9 percent ownership held by others to 33.6 percent , as we discuss in Note 13.
Transactions with Affiliates Table	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) September 30, 2016 December 31, 2015 Sempra Energy Consolidated: Total due from various unconsolidated affiliates - current $ 8 $ 6 Sempra South American Utilities(1): Eletrans S.A. and Eletrans II S.A.: 4% Note(2) $ 83 $ 72 Other related party receivables 1 — Sempra Mexico(1): Affiliate of joint venture with DEN: Note due November 13, 2017(3) 3 3 Note due November 14, 2018(3) 43 42 Note due November 14, 2018(3) 35 34 Note due November 14, 2018(3) 8 8 Energía Sierra Juárez: Note due June 15, 2018(4) 14 24 Sempra Natural Gas: Cameron LNG JV 8 3 Total due from unconsolidated affiliates - noncurrent $ 195 $ 186 Total due to various unconsolidated affiliates - current $ (9 ) $ (14 ) SDG&E: Sempra Energy(5) $ 88 $ — Other affiliates — 1 Total due from unconsolidated affiliates - current $ 88 $ 1 Sempra Energy $ — $ (34 ) SoCalGas (5 ) (13 ) Other affiliates (5 ) (8 ) Total due to unconsolidated affiliates - current $ (10 ) $ (55 ) Income taxes due from Sempra Energy(6) $ 109 $ 28 SoCalGas: Sempra Energy(7) $ 30 $ 35 SDG&E 5 13 Total due from unconsolidated affiliates - current $ 35 $ 48 Income taxes due from Sempra Energy(6) $ 16 $ 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 of Chilquinta Energía. (3) U.S. dollar-denominated loan, at a variable interest rate based on a 30-day LIBOR plus 450 basis points ( 5.03 percent at September 30, 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 ( 6.91 percent at September 30, 2016), to finance the first phase of the Energía Sierra Juárez wind project, which is a joint venture of IEnova. (5) At September 30, 2016 , net receivable included outstanding advances to Sempra Energy of $107 million at an interest rate of 0.60 percent. (6) 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. (7) At September 30, 2016 , net receivable included outstanding advances to Sempra Energy of $51 million at an interest rate of 0.57 percent. 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 from unconsolidated affiliates are as follows: REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 REVENUES Sempra Energy Consolidated $ 5 $ 6 $ 15 $ 22 SDG&E 2 3 5 8 SoCalGas 21 19 56 55 COST OF SALES Sempra Energy Consolidated $ 10 $ 29 $ 60 $ 78 SDG&E 16 15 46 33
Other Income and Expense Table	Other Income, Net on the Condensed Consolidated Statements of Operations consists of the following: OTHER INCOME, NET (Dollars in millions) Three months ended Nine months ended 2016 2015 2016 2015 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 29 $ 26 $ 86 $ 84 Investment gains (losses)(1) 9 (12 ) 29 (5 ) Losses on interest rate and foreign exchange instruments, net (11 ) (4 ) (23 ) (7 ) Foreign currency transaction losses (2 ) (3 ) (9 ) (6 ) Sale of other investments 1 2 3 8 Electrical infrastructure relocation income(2) 1 — 4 4 Regulatory interest, net(3) 1 1 4 3 Sundry, net (2 ) 2 4 7 Total $ 26 $ 12 $ 98 $ 88 SDG&E: Allowance for equity funds used during construction $ 11 $ 9 $ 35 $ 27 Regulatory interest, net(3) — 1 3 3 Sundry, net — (2 ) — (4 ) Total $ 11 $ 8 $ 38 $ 26 SoCalGas: Allowance for equity funds used during construction $ 10 $ 10 $ 30 $ 29 Regulatory interest, net(3) 1 — 1 — Sundry, net (3 ) (2 ) (7 ) (4 ) Total $ 8 $ 8 $ 24 $ 25 (1) Represents investment gains (losses) 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 (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Income tax expense Effective income tax rate Income tax expense (benefit) Effective income tax rate Three months ended September 30, 2016 2015 Sempra Energy Consolidated $ 282 29 % $ 15 6 % SDG&E 91 32 75 29 SoCalGas 21 100 (20 ) 71 Nine months ended September 30, 2016 2015 Sempra Energy Consolidated $ 284 21 % $ 276 22 % SDG&E 204 33 217 32 SoCalGas 75 27 91 25

DERIVATIVE FINANCIAL INSTRUME23

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Volumes Table	We summarize net energy derivative volumes at September 30, 2016 and December 31, 2015 as follows: NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) Segment and Commodity Unit of measure September 30, December 31, California Utilities: SDG&E: Natural gas MMBtu(1) 56 70 Electricity MWh(2) 4 1 Congestion revenue rights MWh 46 36 SoCalGas – natural gas MMBtu 2 1 Energy-Related Businesses: Sempra Natural Gas – natural gas MMBtu 35 43 (1) Million British thermal units (2) Megawatt hours
Notional Amounts of Interest Rate Derivatives Table	At September 30, 2016 and December 31, 2015 , the net notional amounts of our interest rate derivatives, excluding joint ventures, were: INTEREST RATE DERIVATIVES (Dollars in millions) September 30, 2016 December 31, 2015 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges(1)(2) $ 753 2016-2028 $ 384 2016-2028 Fair value hedges — — 300 2016 SDG&E: Cash flow hedge(1) 307 2016-2019 315 2016-2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. (2) At September 30, 2016, includes GdC, which was previously a joint venture and excluded from this table. At September 30, 2016 and December 31, 2015 , the net notional amounts of our foreign currency derivatives, excluding joint ventures, were: FOREIGN CURRENCY DERIVATIVES (Dollars in millions) September 30, 2016 December 31, 2015 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 408 2016-2023 $ 408 2016-2023 Other foreign currency derivatives(1) 1,481 2016-2018 — — (1) At September 30, 2016, includes GdC, which was previously a joint venture and excluded from this table.
Derivative Instruments on the Condensed Consolidated Balance Sheets Table	The following tables provide the fair values of derivative instruments on the Condensed Consolidated Balance Sheets at September 30, 2016 and December 31, 2015 , including the amount of cash collateral receivables that were not offset, as the cash collateral is in excess of liability positions. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2016 Current Other Current liabilities: Deferred Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments(3) $ 3 $ — $ (20 ) $ (224 ) Commodity contracts not subject to rate recovery — — (4 ) — Derivatives not designated as hedging instruments: Foreign exchange instruments 2 — (25 ) — Commodity contracts not subject to rate recovery 122 25 (128 ) (17 ) Associated offsetting commodity contracts (114 ) (15 ) 114 15 Associated offsetting cash collateral — (2 ) 17 2 Commodity contracts subject to rate recovery 11 86 (59 ) (165 ) Associated offsetting commodity contracts (5 ) (1 ) 5 1 Associated offsetting cash collateral — — 12 17 Net amounts presented on the balance sheet 19 93 (88 ) (371 ) Additional cash collateral for commodity contracts not subject to rate recovery 15 — — — Additional cash collateral for commodity contracts subject to rate recovery 19 — — — Total(4) $ 53 $ 93 $ (88 ) $ (371 ) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments(3) $ — $ — $ (13 ) $ (18 ) Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery 8 86 (55 ) (165 ) Associated offsetting commodity contracts (3 ) (1 ) 3 1 Associated offsetting cash collateral — — 12 17 Net amounts presented on the balance sheet 5 85 (53 ) (165 ) Additional cash collateral for commodity contracts not subject to rate recovery 1 — — — Additional cash collateral for commodity contracts subject to rate recovery 17 — — — Total(4) $ 23 $ 85 $ (53 ) $ (165 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (4 ) $ — Associated offsetting commodity contracts (2 ) — 2 — Net amounts presented on the balance sheet 1 — (2 ) — 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 $ — $ (2 ) $ — (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 Current Other Current liabilities: Deferred 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	The effects of derivative instruments designated as hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI for the three months and nine months ended September 30 were: FAIR VALUE HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Three months ended September 30, Nine months ended September 30, Location 2016 2015 2016 2015 Sempra Energy Consolidated: Interest rate instruments Interest Expense $ — $ 1 $ 3 $ 5 Interest rate instruments Other Income, Net — — (2 ) (2 ) Total(1) $ — $ 1 $ 1 $ 3 (1) There was no hedge ineffectiveness in either the three months or nine months ended September 30, 2016 or 2015 . All other changes in the fair value of the interest rate swap agreements are exactly offset by changes in the fair value of the underlying long-term debt and are recorded in Other Income, Net.
Cash Flow Hedge Impact on the Condensed Consolidated Statements of Comprehensive Income Table	CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax gain (loss) recognized in OCI Pretax (loss) gain reclassified from AOCI into earnings Three months ended September 30, Three months ended September 30, 2016 2015 Location 2016 2015 Sempra Energy Consolidated: Interest rate and foreign exchange instruments(1) $ (16 ) $ (10 ) Interest Expense $ (4 ) $ (5 ) Interest rate instruments 17 (134 ) Equity Earnings, Before Income Tax (3 ) (3 ) Interest rate and foreign exchange instruments — — Remeasurement of Equity Method Investment (7 ) — Interest rate and foreign exchange instruments 13 — Equity Earnings, Net of Income Tax 2 — Commodity contracts not subject to rate recovery 2 6 Revenues: Energy- Related Businesses — 3 Total(2) $ 16 $ (138 ) $ (12 ) $ (5 ) SDG&E: Interest rate instruments(1)(2) $ 2 $ (4 ) Interest Expense $ (3 ) $ (3 ) SoCalGas: Interest rate instruments(2) $ — $ — Interest Expense $ (1 ) $ — Nine months ended September 30, Nine months ended September 30, 2016 2015 Location 2016 2015 Sempra Energy Consolidated: Interest rate and foreign $ (26 ) $ (22 ) Interest Expense $ (11 ) $ (14 ) Interest rate instruments (190 ) (123 ) Equity Earnings, (8 ) (9 ) Interest rate and foreign exchange instruments — — Remeasurement of Equity Method Investment (7 ) — Interest rate and foreign (20 ) — Equity Earnings, Net of Income Tax (4 ) — Commodity contracts not subject (2 ) 6 Revenues: Energy- 7 10 Total(2) $ (238 ) $ (139 ) $ (23 ) $ (13 ) SDG&E: Interest rate instruments(1)(2) $ (5 ) $ (9 ) Interest Expense $ (9 ) $ (9 ) SoCalGas: Interest rate instruments(2) $ — $ — Interest Expense $ (1 ) $ — (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 and nine months ended September 30, 2016 and 2015 .
Undesignated Derivative Impact on the Condensed Consolidated Statements of Operations Table	The effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations for the three months and nine months ended September 30 were: UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Three months ended Nine months ended Location 2016 2015 2016 2015 Sempra Energy Consolidated: Foreign exchange instruments Other Income, Net $ (11 ) $ (4 ) $ (23 ) $ (7 ) Foreign exchange instruments Equity Earnings, Net of Income Tax 1 (3 ) 3 (4 ) Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses 3 21 (26 ) 33 Commodity contracts not subject to rate recovery Operation and Maintenance — (2 ) 1 (1 ) Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (118 ) (27 ) (90 ) (100 ) Commodity contracts subject to rate recovery Cost of Natural Gas — — (2 ) 1 Total $ (125 ) $ (15 ) $ (137 ) $ (78 ) SDG&E: Commodity contracts subject to rate recovery Operation and Maintenance $ — $ (1 ) $ — $ (1 ) Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (118 ) (27 ) (90 ) (100 ) Total $ (118 ) $ (28 ) $ (90 ) $ (101 ) SoCalGas: Commodity contracts not subject to rate recovery Operation and Maintenance $ — $ (1 ) $ — $ — Commodity contracts subject to rate recovery Cost of Natural Gas — — (2 ) 1 Total $ — $ (1 ) $ (2 ) $ 1

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at September 30, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 607 $ — $ — $ — $ 607 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 52 — — 100 Municipal bonds — 161 — — 161 Other securities — 188 — — 188 Total debt securities 48 401 — — 449 Total nuclear decommissioning trusts(2) 655 401 — — 1,056 Interest rate and foreign exchange instruments — 5 — — 5 Commodity contracts not subject to rate recovery — 18 — 13 31 Commodity contracts subject to rate recovery — 1 90 19 110 Total $ 655 $ 425 $ 90 $ 32 $ 1,202 Liabilities: Interest rate and foreign exchange instruments $ — $ 269 $ — $ — $ 269 Commodity contracts not subject to rate recovery 19 1 — (19 ) 1 Commodity contracts subject to rate recovery 1 40 177 (29 ) 189 Total $ 20 $ 310 $ 177 $ (48 ) $ 459 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 September 30, 2016 Level 1 Level 2 Level 3 Netting(1) Total Assets: Nuclear decommissioning trusts: Equity securities $ 607 $ — $ — $ — $ 607 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 48 52 — — 100 Municipal bonds — 161 — — 161 Other securities — 188 — — 188 Total debt securities 48 401 — — 449 Total nuclear decommissioning trusts(2) 655 401 — — 1,056 Commodity contracts not subject to rate recovery — — — 1 1 Commodity contracts subject to rate recovery — — 90 17 107 Total $ 655 $ 401 $ 90 $ 18 $ 1,164 Liabilities: Interest rate instruments $ — $ 31 $ — $ — $ 31 Commodity contracts subject to rate recovery — 39 177 (29 ) 187 Total $ — $ 70 $ 177 $ (29 ) $ 218 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 September 30, 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 subject to rate recovery $ 1 $ 1 $ — $ — $ 2 Total $ 1 $ 1 $ — $ — $ 2 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	The following table sets forth reconciliations of changes in the fair value of congestion revenue rights (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 September 30, 2016 2015 Balance as of July 1 $ 24 $ 42 Realized and unrealized losses (145 ) (49 ) Settlements 34 43 Balance as of September 30 $ (87 ) $ 36 Change in unrealized losses relating to instruments still held at September 30 $ (114 ) $ (8 ) Nine months ended September 30, 2016 2015 Balance as of January 1 $ 19 $ 107 Realized and unrealized losses (138 ) (103 ) Allocated transmission instruments — 1 Settlements 32 31 Balance as of September 30 $ (87 ) $ 36 Change in unrealized losses relating to instruments still held at September 30 $ (111 ) $ (54 )
Fair Value of Financial Instruments Table	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 September 30, 2016 and December 31, 2015 : FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) September 30, 2016 Carrying Fair value Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Due from unconsolidated affiliates(1) $ 180 $ — $ 91 $ 81 $ 172 Total long-term debt(2)(3) 14,149 — 15,335 532 15,867 Preferred stock of subsidiary 20 — 26 — 26 SDG&E: Total long-term debt(3)(4) $ 4,656 $ — $ 5,024 $ 307 $ 5,331 SoCalGas: Total long-term debt(5) $ 3,009 $ — $ 3,323 $ — $ 3,323 Preferred stock 22 — 28 — 28 December 31, 2015 Carrying Fair value 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 $15 million and $11 million at September 30, 2016 and December 31, 2015 , respectively. (2) Before reductions for unamortized discount (net of premium) and debt issuance costs of $108 million and $107 million at September 30, 2016 and December 31, 2015 , respectively, and excluding build-to-suit and capital lease obligations of $385 million and $387 million at September 30, 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 $307 million and $315 million at September 30, 2016 and December 31, 2015 , respectively, related to Otay Mesa VIE. (4) Before reductions for unamortized discount and debt issuance costs of $46 million and $43 million at September 30, 2016 and December 31, 2015 , respectively, and excluding capital lease obligations of $241 million and $244 million at September 30, 2016 and December 31, 2015 , respectively. (5) Before reductions for unamortized discount and debt issuance costs of $27 million and $24 million at September 30, 2016 and December 31, 2015 , respectively, and excluding capital lease obligations of $1 million at both September 30, 2016 and December 31, 2015 , respectively.
Fair Value Measurements, Nonrecurring Table	The following table summarizes significant inputs impacting our non-recurring fair value measures: NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Estimated fair value Valuation technique Fair value hierarchy % of fair value measurement Inputs used to develop measurement Range of inputs TdM $ 145 (1) Market approach Level 2 100% Purchase price offers 100% Investment in GdC $ 1,144 (2) Market approach Level 2 100% Equity sale price 100% Investment in $ 440 (3) Market approach Level 2 100% Equity sale price 100% (1) At measurement date of September 29, 2016. At September 30, 2016, TdM has a carrying value of $146 million , reflecting subsequent business activity, and is classified as held for sale. (2) At measurement date of September 26, 2016, immediately prior to acquiring a 100 -percent ownership interest in GdC. (3) At measurement date of March 29, 2016. On May 9, 2016, Sempra Natural Gas sold its equity interest in Rockies Express.

SAN ONOFRE NUCLEAR GENERATING25

SAN ONOFRE NUCLEAR GENERATING STATION (SONGS) (Tables)	9 Months Ended
	Sep. 30, 2016
Public Utilities, General Disclosures [Abstract]
Schedule of Nuclear Decommissioning Trusts Investments	The following table shows the fair values and gross unrealized gains and losses 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) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At September 30, 2016: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1) $ 95 $ 5 $ — $ 100 Municipal bonds(2) 150 11 — 161 Other securities(2) 183 9 (4 ) 188 Total debt securities 428 25 (4 ) 449 Equity securities 188 422 (3 ) 607 Cash and cash equivalents 12 — — 12 Total $ 628 $ 447 $ (7 ) $ 1,068 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 2017-2065. (2) Maturity dates are 2016-2115.
Schedule of Sales of Securities By Nuclear Decommissioning Trusts	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 Nine months ended 2016 2015 2016 2015 Proceeds from sales(1) $ 282 $ 210 $ 486 $ 431 Gross realized gains 24 18 32 24 Gross realized losses (3 ) (6 ) (14 ) (13 ) (1) Excludes securities that are held to maturity.

CALIFORNIA UTILITIES' REGULAT26

CALIFORNIA UTILITIES' REGULATORY MATTERS (Tables)	9 Months Ended
	Sep. 30, 2016
Regulated Operations [Abstract]
Schedule of Regulatory Matters	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 (North-South Pipeline) ▪ In July 2016, the CPUC issued a final decision which denies the California Utilities’ request for a permit to construct. ▪ In June 2016, SoCalGas recorded an after-tax impairment charge of $13 million for the development costs it had invested in the project. The pretax charge of $22 million is included in Impairment Losses on Sempra Energy’s and SoCalGas’ Condensed Consolidated Statements of Operations for the nine months ended September 30, 2016. We expect to make a filing to the CPUC seeking recovery of all or a portion of these costs. 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 May 2016, the CPUC issued a final decision granting SDG&E a permit to construct. The project will be installed at an estimated cost of $680 million : $470 million for the various transmission-level facilities and $210 million for associated distribution-level facilities, including distribution circuits and additional undergrounding required by the final environmental impact statement. ▪ In July 2016, the Cleveland National Forest Foundation and the Protect Our Communities Foundation filed a joint application for rehearing of the final decision. Sycamore-Peñasquitos Transmission Project ▪ In October 2016, the CPUC issued a final decision granting SDG&E a Certificate of Public Convenience and Necessity (CPCN) to construct the project, with a cost cap of $260 million . South Orange County Reliability Enhancement ▪ CPUC issued its final environmental impact report (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. ▪ In September 2016, draft and alternate decisions were issued by the Administrative Law Judge (ALJ) and Assigned Commissioner. The ALJ decision rejects SDG&E’s proposed project and grants a CPCN to construct the project identified as environmentally superior in the final EIR. The Assigned Commissioner decision determines that the environmentally superior project is infeasible and, given overriding considerations, grants SDG&E a CPCN to construct its proposed project with a project cost cap of $381 million . ▪ Final CPUC decision expected in fourth quarter of 2016. Energy Storage Projects ▪ In August 2016, the CPUC approved SDG&E’s request to own and operate two energy storage projects totaling 37.5 MW. The purpose of the two projects is to enhance electric reliability in the San Diego service territory. ▪ Expected completion in the first quarter of 2017. Following is a summary of immediate earnings impacts from the 2016 GRC FD recorded in the second quarter of 2016: EARNINGS IMPACTS FROM THE 2016 GRC FD RECORDED IN THE SECOND QUARTER OF 2016 (Dollars in millions) SoCalGas SDG&E Pretax earnings (charge) After-tax earnings (charge) Pretax After-tax Retroactive revenue requirement increase for the first quarter of 2016 $ 20 $ 12 $ 15 $ 9 Adjustments to revenue related to tax repairs deductions: 2015 memorandum account balance $ (72 ) $ (43 ) $ (37 ) $ (22 ) True-up of 2012-2014 estimates to actuals (11 ) (6 ) (15 ) (9 ) Total $ (83 ) $ (49 ) $ (52 ) $ (31 )

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Segment Information	The following tables show selected information by segment from our Condensed Consolidated Statements of Operations and Condensed Consolidated Balance Sheets. Amounts labeled as “All other” in the following tables consist primarily of parent organizations. SEGMENT INFORMATION (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 REVENUES SDG&E $ 1,209 48 % $ 1,230 50 % $ 3,192 44 % $ 3,168 42 % SoCalGas 686 27 620 25 2,336 32 2,448 33 Sempra South American Utilities 385 15 373 15 1,170 16 1,151 15 Sempra Mexico 196 8 193 8 481 7 508 7 Sempra Renewables 12 1 12 — 25 — 30 — Sempra Natural Gas 164 6 160 6 384 5 512 7 Adjustments and eliminations (1 ) — — — (1 ) — (1 ) — Intersegment revenues(1) (116 ) (5 ) (107 ) (4 ) (274 ) (4 ) (286 ) (4 ) Total $ 2,535 100 % $ 2,481 100 % $ 7,313 100 % $ 7,530 100 % INTEREST EXPENSE SDG&E $ 49 $ 51 $ 145 $ 155 SoCalGas 25 23 71 61 Sempra South American Utilities 9 9 29 22 Sempra Mexico 5 7 13 18 Sempra Renewables — 1 — 3 Sempra Natural Gas 11 13 33 57 All other 68 65 214 193 Intercompany eliminations (31 ) (26 ) (84 ) (93 ) Total $ 136 $ 143 $ 421 $ 416 INTEREST INCOME SoCalGas $ — $ — $ — $ 3 Sempra South American Utilities 5 5 15 14 Sempra Mexico 2 1 5 5 Sempra Renewables 1 2 2 3 Sempra Natural Gas 19 16 52 60 All other 1 — 1 — Intercompany eliminations (21 ) (18 ) (56 ) (62 ) Total $ 7 $ 6 $ 19 $ 23 DEPRECIATION AND AMORTIZATION SDG&E $ 161 49 % $ 152 48 % $ 478 49 % $ 446 48 % SoCalGas 121 37 116 37 355 37 342 37 Sempra South American Utilities 14 4 12 4 41 4 37 4 Sempra Mexico 15 5 18 6 47 5 52 6 Sempra Renewables 1 — 2 — 4 — 5 — Sempra Natural Gas 12 4 12 4 37 4 36 4 All other 4 1 3 1 8 1 7 1 Total $ 328 100 % $ 315 100 % $ 970 100 % $ 925 100 % INCOME TAX EXPENSE (BENEFIT) SDG&E $ 91 $ 75 $ 204 $ 217 SoCalGas 21 (20 ) 75 91 Sempra South American Utilities 17 16 46 50 Sempra Mexico 142 (6 ) 170 7 Sempra Renewables (7 ) (9 ) (29 ) (37 ) Sempra Natural Gas 51 — (77 ) 29 All other (33 ) (41 ) (105 ) (81 ) Total $ 282 $ 15 $ 284 $ 276 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 EQUITY EARNINGS (LOSSES) Earnings (losses) recorded before tax: Sempra Renewables $ 12 $ 8 $ 30 $ 20 Sempra Natural Gas — 25 (26 ) 59 Total $ 12 $ 33 $ 4 $ 79 Earnings (losses) recorded net of tax: Sempra South American Utilities $ 1 $ (3 ) $ 3 $ (4 ) Sempra Mexico 18 30 66 68 Total $ 19 $ 27 $ 69 $ 64 EARNINGS (LOSSES) SDG&E $ 183 $ 170 $ 419 $ 443 SoCalGas(2) — (8 ) 198 276 Sempra South American Utilities 46 43 127 129 Sempra Mexico 332 63 407 160 Sempra Renewables 17 15 43 47 Sempra Natural Gas 77 1 (104 ) 43 All other (33 ) (36 ) (99 ) (118 ) Total $ 622 $ 248 $ 991 $ 980 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 959 31 % $ 835 38 % SoCalGas 949 31 946 42 Sempra South American Utilities 133 4 105 5 Sempra Mexico 232 8 185 8 Sempra Renewables 700 23 47 2 Sempra Natural Gas 100 3 61 3 All other 14 — 48 2 Total $ 3,087 100 % $ 2,227 100 % September 30, 2016 December 31, 2015 ASSETS SDG&E $ 17,446 38 % $ 16,515 40 % SoCalGas 13,148 29 12,104 29 Sempra South American Utilities 3,488 8 3,235 8 Sempra Mexico 6,359 14 3,783 9 Sempra Renewables 2,112 5 1,441 4 Sempra Natural Gas 5,377 12 5,566 13 All other 640 1 734 2 Intersegment receivables (3,044 ) (7 ) (2,228 ) (5 ) Total $ 45,526 100 % $ 41,150 100 % EQUITY METHOD AND OTHER INVESTMENTS Sempra South American Utilities $ (1 ) $ (4 ) Sempra Mexico 108 519 Sempra Renewables 819 855 Sempra Natural Gas 838 1,460 All other 76 75 Total $ 1,840 $ 2,905 (1) Revenues for reportable segments include intersegment revenues of $2 million , $21 million , $26 million and $67 million for the three months ended September 30, 2016 ; $5 million , $56 million , $80 million and $133 million for the nine months ended September 30, 2016 ; $2 million , $19 million , $24 million and $62 million for the three months ended September 30, 2015 ; and $7 million , $55 million , $73 million and $151 million for the nine months ended September 30, 2015 for SDG&E, SoCalGas, Sempra Mexico and Sempra Natural Gas, respectively. (2) After preferred dividends.

NEW ACCOUNTING STANDARDS (Detai

NEW ACCOUNTING STANDARDS (Details) - USD ($) shares in Thousands, $ in Millions	3 Months Ended				6 Months Ended	9 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2016	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment								$ 107
Net cash provided by financing activities						$ 1,848	$ 29
Net cash provided by operating activities						$ 1,691	$ 2,089
Reduction in weighted-average common shares outstanding for diluted EPS (in shares)	(252,405)			(251,024)		(251,976)	(250,665)
San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment								23
Net cash provided by financing activities						$ 52	$ (272)
Net cash provided by operating activities						933	1,094
Southern California Gas Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment								15
Net cash provided by financing activities						491	544
Net cash provided by operating activities						409	$ 690
Effect of Early Adoption of New Accounting Pronouncement [Member] | Accounting Standards Update 2016-09 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Excess tax benefits						34
Net cash provided by financing activities						(34)
Net cash provided by operating activities						34
Reduction in weighted-average common shares outstanding for diluted EPS (in shares)		(98)	(75)		(89)
Deferred tax assets, net								107
Effect of Early Adoption of New Accounting Pronouncement [Member] | Accounting Standards Update 2016-09 [Member] | San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Excess tax benefits						7
Net cash provided by operating activities						7
Deferred tax assets, net								23
Effect of Early Adoption of New Accounting Pronouncement [Member] | Accounting Standards Update 2016-09 [Member] | Southern California Gas Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Excess tax benefits						4
Net cash provided by operating activities						$ 4
Deferred tax assets, net								15
Effect of Early Adoption of New Accounting Pronouncement [Member] | Retained Earnings [Member] | Accounting Standards Update 2016-09 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment								107
Effect of Early Adoption of New Accounting Pronouncement [Member] | Retained Earnings [Member] | Accounting Standards Update 2016-09 [Member] | San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment								23
Effect of Early Adoption of New Accounting Pronouncement [Member] | Retained Earnings [Member] | Accounting Standards Update 2016-09 [Member] | Southern California Gas Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Cumulative-effect adjustment								$ 15

ACQUISITION AND DIVESTITURE A29

ACQUISITION AND DIVESTITURE ACTIVITY - RECENT BUSINESS ACQUISITIONS (Details) MXN in Millions, $ in Millions	Oct. 13, 2016USD ($)MXN / $	Oct. 13, 2016MXNMXN / $	Sep. 26, 2016USD ($)	Sep. 05, 2016USD ($)MW	Jul. 01, 2016USD ($)	Jul. 31, 2016USD ($)MW	Mar. 31, 2015USD ($)MW	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 25, 2016
Business Acquisition [Line Items]
Total purchase price net of cash acquired											$ (1,096)	$ (3)
Acquisition related costs									$ 2	$ 1	2	1
Revenues									2,535	2,481	7,313	7,530
Earnings (losses)									622	$ 248	991	$ 980
Sempra Mexico [Member] | GdC [Member]
Business Acquisition [Line Items]
Cash consideration			$ 1,144
Cash acquired			66
Revenues									3		3
Earnings (losses)									(1)		(1)
Accounts payable acquired			11
Long-term debt assumed			$ 315
Sempra Mexico [Member] | Ventika [Member]
Business Acquisition [Line Items]
Ownership percentage acquired				100.00%
Power generating capacity | MW				252
Purchase price				$ 852
Long-term debt assumed				$ 477
Sempra Mexico [Member] | IEnova [Member] | GdC [Member]
Business Acquisition [Line Items]
Ownership percentage acquired			50.00%
Total purchase price net of cash acquired			$ 1,078
Ownership percentage after acquisition			100.00%
Ownership percentage before acquisition													50.00%
Cash consideration			$ 1,144
Cash acquired			66
Debt assumed			364
Proceeds from Notes Payable			$ 1,150
Pretax gain for the excess of acquisition date fair value over carrying value									617		617
After-tax gain for the excess of acquisition date fair value over carrying value									432		432
Long-term debt assumed									$ 364		$ 364
Sempra Mexico [Member] | IEnova [Member] | Ramones Norte Pipeline [Member]
Business Acquisition [Line Items]
Ownership percentage			25.00%
Sempra Mexico [Member] | IEnova [Member] | DEN [Member]
Business Acquisition [Line Items]
Ownership percentage after acquisition			50.00%
Sempra Renewables [Member] | Black Oak Getty Wind [Member]
Business Acquisition [Line Items]
Ownership percentage after acquisition							100.00%
Power generating capacity | MW							78
Power purchase agreement term							20 years
Purchase price							$ 8
Sempra Renewables [Member] | Apple Blossom Wind [Member]
Business Acquisition [Line Items]
Ownership percentage after acquisition						100.00%
Cash consideration					$ 18	$ 22
Power generating capacity | MW						100
Power purchase agreement term						15 years
Sempra Renewables [Member] | Apple Blossom Wind [Member] | Forecast [Member]
Business Acquisition [Line Items]
Cash consideration								$ 4
Subsequent Event [Member] | IEnova [Member]
Business Acquisition [Line Items]
Cash consideration	$ 351
Proceeds from follow-on share offering	$ 1,570	MXN 29,860
Exchange rate | MXN / $	18.96	18.96
Subsequent Event [Member] | Sempra Mexico [Member] | IEnova [Member] | GdC [Member]
Business Acquisition [Line Items]
Proceeds from follow-on share offering	$ 1,570	MXN 29,860
Exchange rate | MXN / $	18.96	18.96

ACQUISITION AND DIVESTITURE A30

ACQUISITION AND DIVESTITURE ACTIVITY - ASSETS ACQUIRED AND LIBILITIES ASSUMED (Details) - USD ($) $ in Millions	Sep. 26, 2016	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Business Acquisition [Line Items]
Fair value of equity interest in GdC immediately prior to acquisition		$ 1,144	$ 0
Recognized amounts of identifiable assets acquired and liabilities assumed:
Goodwill		2,150		$ 819	[1]
Sempra Mexico [Member]
Recognized amounts of identifiable assets acquired and liabilities assumed:
Goodwill		$ 1,400		$ 25
Sempra Mexico [Member] | GdC [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)	$ 1,144
Fair value of equity interest in GdC immediately prior to acquisition	1,144
Total fair value of business combination	2,288
Recognized amounts of identifiable assets acquired and liabilities assumed:
Cash and cash equivalents	66
Accounts receivable	39
Other current assets	6
Property, plant and equipment	1,248
Other noncurrent assets	1
Accounts payable	(11)
Due to unconsolidated affiliates	(3)
Current portion of long-term debt	(49)
Fixed-price contracts and other derivatives, current	(6)
Other current liabilities	(20)
Long-term debt	(315)
Asset retirement obligations	(5)
Deferred income taxes	(8)
Fixed-price contracts and other derivatives, noncurrent	(19)
Other noncurrent liabilities	(11)
Total identifiable net assets	913
Goodwill	1,375
Total fair value of business combination	$ 2,288
[1]	Derived from audited financial statements.

ACQUISITION AND DIVESTITURE A31

ACQUISITION AND DIVESTITURE ACTIVITY - PRO FORMA INFORMATION (Details) - GdC [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Business Acquisition, Pro Forma Information [Abstract]
Revenues	$ 2,608	$ 2,545	$ 7,529	$ 7,708
Net income	308	308	744	1,550
Earnings	$ 299	$ 255	$ 685	$ 1,280
Sempra Mexico [Member]
Business Acquisition, Pro Forma Information [Abstract]
Noncontrolling interest ownership	18.90%		18.90%
Pro Forma [Member] | Sempra Mexico [Member]
Business Acquisition, Pro Forma Information [Abstract]
Noncontrolling interest ownership	33.60%		33.60%

ACQUISITION AND DIVESTITURE A32

ACQUISITION AND DIVESTITURE ACTIVITY - ASSETS HELD FOR SALE (Details) $ in Millions	1 Months Ended	3 Months Ended	6 Months Ended	9 Months Ended
	Feb. 29, 2016MW	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Sep. 30, 2016USD ($)
Assets Held for Sale [Line Items]
Impairment of equity method investment				$ 131
Impairment of equity method investment after-tax				111
Sempra Mexico [Member] | TdM [Member]
Assets Held for Sale [Line Items]
Power generating capacity | MW	625
Impairment of equity method investment		$ 131
Impairment of equity method investment after-tax		111
Deferred tax expense from the outside basis difference			$ 32
Deferred Tax Benefit From The Outside Basis Difference		31
Sempra Mexico [Member] | Disposal Group, Held-for-sale, Not Discontinued Operations [Member] | TdM [Member]
Assets Held for Sale, Assets [Abstract]
Cash and cash equivalents		1		1
Inventories		8		8
Other current assets		25		25
Deferred income taxes		5		5
Other assets		22		22
Property, plant and equipment, net		120		120
Total assets held for sale		181		181
Assets Held for Sale, Liabilities [Abstract]
Accounts payable		1		1
Other current liabilities		7		7
Asset retirement obligations		4		4
Other liabilities		23		23
Total liabilities held for sale		$ 35		$ 35

ACQUISITION AND DIVESTITURE A33

ACQUISITION AND DIVESTITURE ACTIVITY - DIVESTITURES (Details) $ in Millions	Sep. 12, 2016USD ($)	May 31, 2016USD ($)	Apr. 30, 2016	Mar. 31, 2016USD ($)	Apr. 30, 2015USD ($)MW	Sep. 30, 2016USD ($)	Mar. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Mar. 29, 2016
Schedule of Equity Method Investments [Line Items]
Debt assumed								$ 448	$ 2
Impairment of equity method investment								131
Impairment of equity method investment after-tax								111
Sempra Natural Gas [Member] | Rockies Express [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage		25.00%		25.00%			25.00%			25.00%
Proceeds from sale of equity method investment		$ 443		$ 440
Carrying value of equity method investment				484			$ 484
Fair value of equity method investment				$ 440			440
Impairment of equity method investment							44	44
Impairment of equity method investment after-tax							$ 27	27
Sempra Natural Gas [Member] | Energy South [Member]
Schedule of Equity Method Investments [Line Items]
Pre-tax gain on sale								130
After-tax gain on sale								$ 78
Sempra Natural Gas [Member] | Mesquite Power [Member]
Schedule of Equity Method Investments [Line Items]
Pre-tax gain on sale									61
After-tax gain on sale									$ 36
Proceeds from divestiture of businesses					$ 347
Power generating capacity | MW					625
Disposed of by Sale [Member] | Sempra Natural Gas [Member] | Energy South [Member]
Schedule of Equity Method Investments [Line Items]
Percentage of ownership before transaction			100.00%
Cash proceeds on sale	$ 318
Debt assumed	67
Pre-tax gain on sale	130					$ 130
After-tax gain on sale						$ 78
Proceeds from sale, net of transaction costs	304
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Cash	(2)
Inventory	(3)
Other current assets	(14)
Disposal Group, Including Discontinued Operation, Assets, Noncurrent [Abstract]
Regulatory assets	(12)
Goodwill	(72)
Other assets	(53)
Property, plant and equipment, net	(199)
Disposal Group, Including Discontinued Operation, Liabilities, Current [Abstract]
Accounts payable	12
Other current liabilities	13
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent [Abstract]
Long-term debt	67
Deferred income taxes	36
Regulatory liabilities	23
Asset retirement obligations	12
Other liabilities	$ 18

INVESTMENTS IN UNCONSOLIDATED34

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Apr. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Sep. 27, 2016	Sep. 26, 2016	Sep. 25, 2016	May 31, 2016	Mar. 31, 2016	Mar. 29, 2016
Schedule of Equity Method Investments [Line Items]
Capitalized interest		$ 26	$ 18	$ 64	$ 52
Maximum exposure under guarantor obligations		4,500		4,500
Aggregate carrying value of guarantor obligations		$ 58		$ 58
Sempra Mexico [Member] | GdC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage acquired							50.00%
Ownership percentage						100.00%	100.00%	50.00%
Sempra Mexico [Member] | IEnova [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage		40.00%		40.00%
Natural gas transportation service agreement term				25 years
Sempra Mexico [Member] | TransCanada [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage		60.00%		60.00%
Sempra Mexico [Member] | Infraestructura Marina del Golfo [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period				$ 56
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period				18	18
Sempra Natural Gas [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period					10
Capitalized interest				$ 36	$ 36
Sempra Natural Gas [Member] | Rockies Express [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage									25.00%	25.00%	25.00%
Investments made during period	$ 113

OTHER FINANCIAL DATA - INVENTOR

OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Inventory [Line Items]
Natural gas	$ 119	$ 149
Liquefied natural gas	7	6
Materials and supplies	176	143
Total	302	298	[1]
LIFO reserve	8
SDG&E [Member]
Inventory [Line Items]
Natural gas	1	6
Liquefied natural gas	0	0
Materials and supplies	72	69
Total	73	75
SoCalGas [Member]
Inventory [Line Items]
Natural gas	24	49
Liquefied natural gas	0	0
Materials and supplies	53	30
Total	77	79
Sempra South American Utilities [Member]
Inventory [Line Items]
Natural gas	0	0
Liquefied natural gas	0	0
Materials and supplies	46	30
Total	46	30
Sempra Mexico [Member]
Inventory [Line Items]
Natural gas	0	0
Liquefied natural gas	4	3
Materials and supplies	2	10
Total	6	13
Sempra Renewables [Member]
Inventory [Line Items]
Natural gas	0	0
Liquefied natural gas	0	0
Materials and supplies	3	3
Total	3	3
Sempra Natural Gas [Member]
Inventory [Line Items]
Natural gas	94	94
Liquefied natural gas	3	3
Materials and supplies	0	1
Total	97	98
Southern California Gas Company [Member]
Inventory [Line Items]
Total	77	$ 79	[1]
LIFO reserve	8
Southern California Gas Company [Member] | Minimum [Member]
Inventory [Line Items]
Permanent LIFO liquidation	10
Southern California Gas Company [Member] | Maximum [Member]
Inventory [Line Items]
Permanent LIFO liquidation	$ 15
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - GOODWILL

OTHER FINANCIAL DATA - GOODWILL (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)
Goodwill [Roll Forward]
Goodwill, beginning balance	$ 819	[1]
Acquisition of business	1,375
Sale of business	(72)
Foreign currency translation	28
Goodwill, ending balance	2,150
Sempra South American Utilities [Member]
Goodwill [Roll Forward]
Goodwill, beginning balance	722
Acquisition of business	0
Sale of business	0
Foreign currency translation	28
Goodwill, ending balance	750
Sempra Mexico [Member]
Goodwill [Roll Forward]
Goodwill, beginning balance	25
Acquisition of business	1,375
Sale of business	0
Foreign currency translation	0
Goodwill, ending balance	1,400
Sempra Natural Gas [Member]
Goodwill [Roll Forward]
Goodwill, beginning balance	72
Acquisition of business	0
Sale of business	(72)
Foreign currency translation	0
Goodwill, ending balance	$ 0
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - VARIABLE

OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)MW	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Variable Interest Entities [Line Items]
Operation and maintenance	$ 703	$ 701	$ 2,109	$ 2,072
Depreciation and amortization	328	315	970	925
Interest expense	(136)	(143)	(421)	(416)
Income (loss) before income taxes/Net income (loss)	719	282	1,110	1,060
(Earnings) losses attributable to noncontrolling interest	(97)	(34)	(118)	(79)
Earnings attributable to common shares	622	248	991	980
Sempra Natural Gas [Member] | Cameron LNG Holdings [Member]
Investments [Abstract]
Carrying value of equity method investment	838		838		$ 983
San Diego Gas and Electric Company [Member]
Variable Interest Entities [Line Items]
Operating income	323	300	729	809
Interest expense	(49)	(51)	(145)	(155)
Income (loss) before income taxes/Net income (loss)	194	182	418	463
(Earnings) losses attributable to noncontrolling interest	(11)	(12)	$ 1	(20)
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Variable Interest Entities [Line Items]
Power generating capacity | MW			605
Equity of variable interest entity	50		$ 50		$ 53
Secured debt of variable interest entity	307		307
Cost of electric fuel and purchased power	(28)	(27)	(62)	(66)
Operation and maintenance	4	3	23	13
Depreciation and amortization	8	7	25	19
Total operating expenses	(16)	(17)	(14)	(34)
Operating income	16	17	14	34
Interest expense	(5)	(5)	(15)	(14)
Income (loss) before income taxes/Net income (loss)	11	12	(1)	20
(Earnings) losses attributable to noncontrolling interest	(11)	(12)	1	(20)
Earnings attributable to common shares	$ 0	$ 0	$ 0	$ 0

OTHER FINANCIAL DATA - PENSION

OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Pension benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 26	$ 27	$ 81	$ 86
Interest cost	40	38	120	116
Expected return on assets	(41)	(42)	(124)	(130)
Amortization of prior service cost (credit)	2	3	8	8
Amortization of actuarial loss (gain)	10	9	23	28
Settlements	0	4	0	4
Regulatory adjustment	(28)	(27)	(84)	(86)
Total net periodic benefit cost	9	12	24	26
Contributions by employer			24
Expected contributions in current fiscal year			124
Pension benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	7	6	22	22
Interest cost	10	9	31	29
Expected return on assets	(12)	(14)	(37)	(41)
Amortization of prior service cost (credit)			1	1
Amortization of actuarial loss (gain)	2	3	7	7
Regulatory adjustment	(7)	(3)	(22)	(15)
Total net periodic benefit cost	0	1	2	3
Contributions by employer			2
Expected contributions in current fiscal year			7
Pension benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	16	17	51	55
Interest cost	26	25	76	74
Expected return on assets	(26)	(25)	(78)	(79)
Amortization of prior service cost (credit)	3	2	7	6
Amortization of actuarial loss (gain)	3	5	8	16
Regulatory adjustment	(21)	(24)	(62)	(71)
Total net periodic benefit cost	1	0	2	1
Contributions by employer			1
Expected contributions in current fiscal year			73
Other postretirement benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	5	15	19
Interest cost	9	10	31	33
Expected return on assets	(17)	(17)	(52)	(51)
Amortization of prior service cost (credit)	0	(1)	0	(2)
Amortization of actuarial loss (gain)	(1)	0	(1)	0
Settlements	0	0	0	0
Regulatory adjustment	5	4	9	4
Total net periodic benefit cost	0	1	2	3
Contributions by employer			3
Expected contributions in current fiscal year			6
Other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1	3	5
Interest cost	2	2	6	6
Expected return on assets	(3)	(2)	(8)	(8)
Amortization of prior service cost (credit)			2	2
Amortization of actuarial loss (gain)	0	0	(1)	0
Regulatory adjustment	0	(1)	(2)	(5)
Total net periodic benefit cost	0	0	0	0
Contributions by employer			0
Expected contributions in current fiscal year			2
Other postretirement benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	3	11	13
Interest cost	7	8	24	26
Expected return on assets	(15)	(14)	(43)	(42)
Amortization of prior service cost (credit)	(1)	(2)	(3)	(6)
Amortization of actuarial loss (gain)	0	0	0	0
Regulatory adjustment	5	5	11	9
Total net periodic benefit cost	$ 0	$ 0	0	$ 0
Contributions by employer			1
Expected contributions in current fiscal year			$ 1

OTHER FINANCIAL DATA - RABBI TR

OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Rabbi trust	$ 439	$ 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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Earnings attributable to common shares	$ 622	$ 248	$ 991	$ 980
Weighted-average common shares outstanding for basic EPS (in shares)	250,386,000	248,432,000	250,073,000	248,090,000
Dilutive effect of stock options, restricted stock awards and restricted stock units (in shares)	2,019,000	2,592,000	1,903,000	2,575,000
Weighted-average common shares outstanding for diluted EPS (in shares)	252,405,000	251,024,000	251,976,000	250,665,000
Basic earnings per common share (in dollars per share)	$ 2.48	$ 1	$ 3.96	$ 3.95
Diluted earnings per common share (in dollars per share)	$ 2.46	$ 0.99	$ 3.93	$ 3.91
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from potential dilutive shares if performance goals fully met	2,273,102	2,001,020	2,406,512	2,047,656
Deferred Compensation Plan [Member] | RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Weighted-average common shares outstanding for basic EPS (in shares)	572,000	504,000	565,000	486,000
RSUs [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from earnings per share	0	0	2,426	0
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from earnings per share	0	0	0	0
RSAs [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from earnings per share	0	0	0	0

OTHER FINANCIAL DATA - EARNIN41

OTHER FINANCIAL DATA - EARNINGS PER SHARE - SHARE BASED COMPENSATION (Details)	9 Months Ended
	Sep. 30, 2016shares
Performance-based RSUs [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of shares included in potentially dilutive shares calculation	0.00%
Performance-based RSUs [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percentage of shares included in potentially dilutive shares calculation	200.00%
Performance-based RSUs [Member] | Awarded During or After Two Thousand and Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	3 years
Performance-based RSUs [Member] | Awarded Prior to Two Thousand and Fifteen [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Award vesting period	4 years
TSR RSUs [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares receivable under award	0
TSR RSUs [Member] | Awarded Prior to 2014 [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares receivable under award	1.5
TSR RSUs [Member] | Awarded During Or After 2014 [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares receivable under award	2
EPS RSUs [Member] | Minimum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares receivable under award	0
EPS RSUs [Member] | Maximum [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares receivable under award	2
RSAs and Service-based RSUs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Number of shares receivable under award	1
Percentage of shares included in potentially dilutive shares calculation	100.00%

OTHER FINANCIAL DATA - SHARE-BA

OTHER FINANCIAL DATA - SHARE-BASED COMPENSATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based compensation expense, net of tax	$ 7	$ 7	$ 20	$ 22
TSR RSUs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards, granted (in shares)			373,070
EPS RSUs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards, granted (in shares)			94,760
Service-based RSUs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards, granted (in shares)			95,876
RSUs [Member] | IENova Plans [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity awards, granted (in shares)			378,367

OTHER FINANCIAL DATA - CAPITALI

OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Schedule of Capitalization [Line Items]
AFUDC related to debt	$ 7	$ 6	$ 22	$ 19
AFUDC related to equity	29	26	86	84
Other capitalized interest	26	18	64	52
Total capitalized financing costs	62	50	172	155
San Diego Gas and Electric Company [Member]
Schedule of Capitalization [Line Items]
AFUDC related to debt	4	3	12	10
AFUDC related to equity	11	9	35	27
Total capitalized financing costs	15	12	47	37
Southern California Gas Company [Member]
Schedule of Capitalization [Line Items]
AFUDC related to debt	3	3	10	9
AFUDC related to equity	10	10	30	29
Other capitalized interest	1	1	1	1
Total capitalized financing costs	$ 14	$ 14	$ 41	$ 39

OTHER FINANCIAL DATA - CHANGES

OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	$ (852)	$ (596)	$ (806)	[1]	$ (497)
Other comprehensive income (loss), before reclassifications	(20)	(171)	(71)		(273)
Amounts reclassified from accumulated other comprehensive income	7	6	12		9
Total other comprehensive loss	(13)	(165)	(59)		(264)
AOCI, ending balance	(865)	(761)	(865)		(761)
Foreign currency translation adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(503)	(427)	(582)		(322)
Other comprehensive income (loss), before reclassifications	(28)	(92)	51		(197)
Amounts reclassified from accumulated other comprehensive income	0	0	0		0
Total other comprehensive loss	(28)	(92)	51		(197)
AOCI, ending balance	(531)	(519)	(531)		(519)
Financial instruments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(264)	(86)	(137)		(90)
Other comprehensive income (loss), before reclassifications	8	(79)	(122)		(76)
Amounts reclassified from accumulated other comprehensive income	5	1	8		2
Total other comprehensive loss	13	(78)	(114)		(74)
AOCI, ending balance	(251)	(164)	(251)		(164)
Pension and other postretirement benefits [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(85)	(83)	(87)		(85)
Other comprehensive income (loss), before reclassifications	0	0	0		0
Amounts reclassified from accumulated other comprehensive income	2	5	4		7
Total other comprehensive loss	2	5	4		7
AOCI, ending balance	(83)	(78)	(83)		(78)
Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(19)	(18)	(19)	[1]	(18)
Amounts reclassified from accumulated other comprehensive income	1	0	1		0
Total other comprehensive loss	1		1
AOCI, ending balance	(18)	(18)	(18)		(18)
Southern California Gas Company [Member] | Financial instruments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(14)	(14)	(14)		(14)
Amounts reclassified from accumulated other comprehensive income	1		1
Total other comprehensive loss	1		1
AOCI, ending balance	(13)	(14)	(13)		(14)
Southern California Gas Company [Member] | Pension and other postretirement benefits [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(5)	(4)	(5)		(4)
Amounts reclassified from accumulated other comprehensive income	0		0
Total other comprehensive loss	0		0
AOCI, ending balance	$ (5)	$ (4)	$ (5)		$ (4)
[1]	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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ (136)	$ (143)	$ (421)	$ (416)
Equity earnings, before income tax	12	33	4	79
Remeasurement of equity method investment	617	0	617	0
Equity earnings, net of income tax	19	27	69	64
Revenues: Energy-Related Businesses	271	268	613	762
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	982	270	1,325	1,272
Income Tax Expense	(282)	(15)	(284)	(276)
Earnings Attributable to Noncontrolling Interests	(97)	(34)	(118)	(79)
Earnings (losses)	622	248	991	980
Total reclassifications for the period, net of tax	7	6	12	9
Gains (Losses) on Cash Flow hedges Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications for the period, net of tax	5	1	8	2
Gain (Loss) on Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Reclassification from AOCI	4	7	8	11
Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income tax expense	(2)	(2)	(4)	(4)
Total reclassifications for the period, net of tax	2	5	4	7
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	12	5	23	13
Income Tax Expense	(3)	(1)	(4)	(1)
Net of income tax	9	4	19	12
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Interest rate and foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	4	5	11	14
Remeasurement of equity method investment	7	0	7	0
Equity earnings, net of income tax	(2)	0	4	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Interest rate instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings, before income tax	3	3	8	9
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on 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	0	(3)	(7)	(10)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges Attributable to Noncontrolling Interests [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings Attributable to Noncontrolling Interests	(4)	(3)	(11)	(10)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings (losses)	5	1	8	2
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(49)	(51)	(145)	(155)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	285	257	622	680
Income Tax Expense	(91)	(75)	(204)	(217)
Earnings Attributable to Noncontrolling Interests	(11)	(12)	1	(20)
Total reclassifications for the period, net of tax	0	0	0	0
San Diego Gas and Electric Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Interest rate instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	3	3	9	9
San Diego Gas and Electric Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges Attributable to Noncontrolling Interests [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings Attributable to Noncontrolling Interests	(3)	(3)	(9)	(9)
Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(25)	(23)	(71)	(61)
Income before income taxes and equity earnings of certain unconsolidated subsidiaries	21	(28)	274	368
Income Tax Expense	(21)	20	(75)	(91)
Total reclassifications for the period, net of tax	1	0	1	0
Southern California Gas Company [Member] | Gains (Losses) on Cash Flow hedges Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications for the period, net of tax	1		1
Southern California Gas Company [Member] | Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications for the period, net of tax	0		0
Southern California Gas Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Interest rate instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ 1	$ 0	$ 1	$ 0

OTHER FINANCIAL DATA - SHAREHOL

OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) - USD ($)		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016		Sep. 30, 2015	Dec. 31, 2015
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				$ 12,579,000,000	[1]	$ 12,100,000,000
Equity, beginning of period	[1]			11,809,000,000
Cumulative-effect adjustment from change in accounting principle							$ 107,000,000
Comprehensive income (loss)				1,050,000,000		773,000,000
Preferred dividends of subsidiary		$ 0	$ 0	(1,000,000)		(1,000,000)
Share-based compensation expense				38,000,000		39,000,000
Common stock dividends declared				(565,000,000)		(520,000,000)
Issuances of common stock				80,000,000		82,000,000
Repurchases of common stock				(55,000,000)		(74,000,000)
Tax benefit related to share-based compensation						56,000,000
Equity contributed by noncontrolling interests				2,000,000		1,000,000
Distributions to noncontrolling interests				(44,000,000)		(60,000,000)
Equity, end of period		13,191,000,000	12,396,000,000	13,191,000,000		12,396,000,000
Equity, end of period		12,346,000,000		12,346,000,000
Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				11,809,000,000		11,326,000,000
Cumulative-effect adjustment from change in accounting principle							107,000,000
Comprehensive income (loss)				933,000,000		717,000,000
Preferred dividends of subsidiary				(1,000,000)		(1,000,000)
Share-based compensation expense				38,000,000		39,000,000
Common stock dividends declared				(565,000,000)		(520,000,000)
Issuances of common stock				80,000,000		82,000,000
Repurchases of common stock				(55,000,000)		(74,000,000)
Tax benefit related to share-based compensation						56,000,000
Equity contributed by noncontrolling interests				0		0
Distributions to noncontrolling interests				0		0
Equity, end of period		12,346,000,000	11,625,000,000	12,346,000,000		11,625,000,000
Noncontrolling Interest [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				770,000,000		774,000,000
Cumulative-effect adjustment from change in accounting principle							0
Comprehensive income (loss)				117,000,000		56,000,000
Preferred dividends of subsidiary				0		0
Share-based compensation expense				0		0
Common stock dividends declared				0		0
Issuances of common stock				0		0
Repurchases of common stock				0		0
Tax benefit related to share-based compensation						0
Equity contributed by noncontrolling interests				2,000,000		1,000,000
Distributions to noncontrolling interests				(44,000,000)		(60,000,000)
Equity, end of period		845,000,000	771,000,000	845,000,000		771,000,000
San Diego Gas and Electric Company [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				5,276,000,000	[1]	4,992,000,000
Equity, beginning of period	[1]			5,223,000,000
Cumulative-effect adjustment from change in accounting principle							23,000,000
Comprehensive income (loss)				422,000,000		463,000,000
Common stock dividends declared				(175,000,000)		(150,000,000)
Equity contributed by noncontrolling interests				1,000,000
Distributions to noncontrolling interests				(7,000,000)		(16,000,000)
Equity, end of period		5,540,000,000	5,289,000,000	5,540,000,000		5,289,000,000
Equity, end of period		5,490,000,000		5,490,000,000
San Diego Gas and Electric Company [Member] | Parent [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				5,223,000,000		4,932,000,000
Cumulative-effect adjustment from change in accounting principle							23,000,000
Comprehensive income (loss)				419,000,000		443,000,000
Common stock dividends declared				(175,000,000)		(150,000,000)
Equity contributed by noncontrolling interests				0
Distributions to noncontrolling interests				0		0
Equity, end of period		5,490,000,000	5,225,000,000	5,490,000,000		5,225,000,000
San Diego Gas and Electric Company [Member] | Noncontrolling Interest [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				53,000,000		60,000,000
Cumulative-effect adjustment from change in accounting principle							0
Comprehensive income (loss)				3,000,000		20,000,000
Common stock dividends declared				0		0
Equity contributed by noncontrolling interests				1,000,000
Distributions to noncontrolling interests				(7,000,000)		(16,000,000)
Equity, end of period		50,000,000	64,000,000	50,000,000		64,000,000
Southern California Gas Company [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity, beginning of period				3,149,000,000	[1]	2,781,000,000
Cumulative-effect adjustment from change in accounting principle							$ 15,000,000
Comprehensive income (loss)				200,000,000		277,000,000
Common stock dividends declared						(50,000,000)
Preferred stock dividends declared		0	0	(1,000,000)		(1,000,000)
Equity, end of period		$ 3,363,000,000	$ 3,007,000,000	$ 3,363,000,000		$ 3,007,000,000
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - OTHER NO

OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Oct. 19, 2016	Sep. 30, 2016	Dec. 31, 2015
Noncontrolling Interest [Line Items]
Noncontrolling interests		$ 825	$ 750	[1]
Deferred credits and other		$ 1,508	$ 1,176	[1]
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		100.00%	100.00%
Noncontrolling interests		$ 50	$ 53
Sempra South American Utilities [Member] | Chilquinta Energía subsidiaries [Member]
Noncontrolling Interest [Line Items]
Noncontrolling interests		$ 22	$ 21
Sempra South American Utilities [Member] | Chilquinta Energía subsidiaries [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		23.10%	23.50%
Sempra South American Utilities [Member] | Chilquinta Energía subsidiaries [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		43.40%	43.40%
Sempra South American Utilities [Member] | Luz del Sur [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		16.40%	16.40%
Noncontrolling interests		$ 171	$ 164
Sempra South American Utilities [Member] | Tecsur [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		9.80%	9.80%
Noncontrolling interests		$ 4	$ 4
Sempra Mexico [Member] | IEnova [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		18.90%	18.90%
Noncontrolling interests		$ 537	$ 468
Sempra Natural Gas [Member] | Bay Gas Storage Company, Ltd. [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		9.10%	9.10%
Noncontrolling interests		$ 26	$ 25
Sempra Natural Gas [Member] | Liberty Gas Storage, LLC [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		23.30%	23.20%
Noncontrolling interests		$ 14	$ 14
Sempra Natural Gas [Member] | Southern Gas Transmission Company [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others		49.00%	49.00%
Noncontrolling interests		$ 1	$ 1
Sempra Renewables [Member]
Noncontrolling Interest [Line Items]
Deferred credits and other		$ 78
Subsequent Event [Member] | Sempra Mexico [Member] | IEnova [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by others	33.60%
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - DUE TO D

OTHER FINANCIAL DATA - DUE TO DUE FROM AFFILIATES (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 8	$ 6	[1]
Due from unconsolidated affiliates - noncurrent	195	186	[1]
Due to affiliaties, current	$ (9)	(14)	[1]
Joint venture with PEMEX [Member]
Related Party Transaction [Line Items]
Interest rate on due from affiliate, noncurrent	5.03%
Joint venture with PEMEX [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate	4.50%
ESJ joint venture [Member]
Related Party Transaction [Line Items]
Interest rate on due from affiliate, noncurrent	6.91%
ESJ joint venture [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate	6.375%
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 88	1	[1]
Due to affiliaties, current	(10)	(55)	[1]
San Diego Gas and Electric Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	88	0
Due to affiliaties, current	0	(34)
Income taxes due from Sempra Energy	$ 109	28
Interest rate on due from affiliate, noncurrent	0.60%
Loan to unconsolidated affiliate, principal	$ 107
San Diego Gas and Electric Company [Member] | Due to/from Other Affiliates [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	0	1
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas [Member]
Related Party Transaction [Line Items]
Due to affiliaties, current	(5)	(13)
San Diego Gas and Electric Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due to affiliaties, current	(5)	(8)
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	35	48	[1]
Southern California Gas Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	30	35
Income taxes due from Sempra Energy	$ 16	$ 1
Interest rate on due from affiliate, noncurrent	0.57%	0.11%
Loan to unconsolidated affiliate, principal	$ 51	$ 50
Southern California Gas Company [Member] | Due to/from SDG&E [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	5	13
Sempra South American Utilities [Member] | Eletrans [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	$ 83	72
Interest rate on due from affiliate, noncurrent	4.00%
Sempra South American Utilities [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	$ 1	0
Sempra Mexico [Member] | PEMEX Three year loan A [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	3	3
Sempra Mexico [Member] | PEMEX Four year loan A [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	43	42
Sempra Mexico [Member] | PEMEX Four year loan B [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	35	34
Sempra Mexico [Member] | PEMEX Four year loan C [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	8	8
Sempra Mexico [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	14	24
Sempra Natural Gas [Member] | Cameron LNG [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	$ 8	$ 3
[1]	Derived from audited financial statements.

OTHER FINANCIAL DATA - AFFILIAT

OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Related Party Transaction [Line Items]
Revenue from related parties	$ 5	$ 6	$ 15	$ 22
Costs of sales to related parties	10	29	60	78
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	2	3	5	8
Costs of sales to related parties	16	15	46	33
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	$ 21	$ 19	$ 56	$ 55

OTHER FINANCIAL DATA - OTHER IN

OTHER FINANCIAL DATA - OTHER INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Other Income [Line Items]
Allowance for equity funds used during construction	$ 29	$ 26	$ 86	$ 84
Investment gains (losses)	9	(12)	29	(5)
Losses on interest rate and foreign exchange instruments, net	(11)	(4)	(23)	(7)
Foreign currency transaction losses	(2)	(3)	(9)	(6)
Sale of other investments	1	2	3	8
Electrical infrastructure relocation income	1	0	4	4
Regulatory Interest, net	1	1	4	3
Sundry, net	(2)	2	4	7
Total	26	12	98	88
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction	11	9	35	27
Regulatory Interest, net	0	1	3	3
Sundry, net	0	(2)	0	(4)
Total	11	8	38	26
Southern California Gas Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction	10	10	30	29
Regulatory Interest, net	1	0	1	0
Sundry, net	(3)	(2)	(7)	(4)
Total	$ 8	$ 8	$ 24	$ 25

OTHER FINANCIAL DATA - INCOME T

OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 282	$ 15	$ 284	$ 276
Effective income tax rate	29.00%	6.00%	21.00%	22.00%
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 91	$ 75	$ 204	$ 217
Effective income tax rate	32.00%	29.00%	33.00%	32.00%
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense	$ 21	$ (20)	$ 75	$ 91
Effective income tax rate	100.00%	71.00%	27.00%	25.00%

DEBT AND CREDIT FACILITIES - LI

DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details)	9 Months Ended
	Sep. 30, 2016USD ($)lenderline_of_credit	Sep. 29, 2016USD ($)	Dec. 31, 2015
Sempra Energy Consolidated [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 4,300,000,000
Number of primary lines of credit | line_of_credit	3
Remaining borrowing capacity	$ 2,000,000,000
Weighted average interest rate on total short-term debt outstanding	1.19%		1.09%
Foreign Operations [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,100,000,000
Remaining borrowing capacity	429,000,000
Sempra Energy [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,000,000,000
Term of debt agreement	5 years
Number of Lenders | lender	21
Maximum percentage held by lenders participating syndicated lending agreement	7.00%
Maximum ratio of indebtedness to total capitalization	65.00%
Capacity for issuance of letters of credit	$ 400,000,000
Outstanding commercial paper supported by committed lines of credit	0
Sempra Global [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	2,340,000,000	$ 2,210,000,000
Remaining borrowing capacity	$ 79,000,000
Term of debt agreement	5 years
Number of Lenders | lender	21
Maximum percentage held by lenders participating syndicated lending agreement	7.00%
Maximum ratio of indebtedness to total capitalization	65.00%
Outstanding commercial paper supported by committed lines of credit	$ 2,260,000,000
California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 1,000,000,000
Term of debt agreement	5 years
Number of Lenders | lender	21
Maximum percentage held by lenders participating syndicated lending agreement	7.00%
Capacity for issuance of letters of credit	$ 250,000,000
SDGE [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	750,000,000
Remaining borrowing capacity	$ 696,000,000
Maximum ratio of indebtedness to total capitalization	65.00%
Outstanding commercial paper supported by committed lines of credit	$ 54,000,000
Weighted average interest rate on total short-term debt outstanding	1.06%		1.01%
Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 750,000,000
Remaining borrowing capacity	$ 750,000,000
Maximum ratio of indebtedness to total capitalization	65.00%
Outstanding commercial paper supported by committed lines of credit	$ 0
Sempra South American Utilities [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	506,000,000
Sempra South American Utilities [Member] | Chile [Member]
Line of Credit Facility [Line Items]
Remaining borrowing capacity	114,000,000
Committed lines of credit outstanding borrowings	0
Sempra South American Utilities [Member] | Peru [Member]
Line of Credit Facility [Line Items]
Remaining borrowing capacity	$ 236,000,000
Committed lines of credit, maximum ratio of debt to equity	170.00%
Committed lines of credit outstanding borrowings	$ 140,000,000
Bank guarantee	16,000,000
Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	600,000,000
Remaining borrowing capacity	$ 79,000,000
Term of debt agreement	5 years
Committed lines of credit outstanding borrowings	$ 521,000,000

DEBT AND CREDIT FACILITIES - LO

DEBT AND CREDIT FACILITIES - LONG TERM DEBT (Details) - USD ($)	1 Months Ended
	Sep. 30, 2016	Oct. 04, 2016	Sep. 26, 2016	Sep. 12, 2016	Jul. 31, 2016	Jun. 30, 2016	May 31, 2016
South American Utilities [Member] | Corporate bonds maturing 2025 [Member]
Debt Instrument [Line Items]
Debt amount offered and sold					$ 50,000,000
Stated rate of debt offered and sold					6.50%
Sempra Mexico [Member] | GdC [Member]
Debt Instrument [Line Items]
Long-term debt assumed			$ 315,000,000
Current portion of long-term debt			$ 49,000,000
Sempra Natural Gas [Member] | Energy South [Member] | Disposed of by Sale [Member]
Debt Instrument [Line Items]
Cash proceeds on sale				$ 318,000,000
Cash sold				2,000,000
Debt assumed by buyer				$ 67,000,000
Sempra Natural Gas [Member] | Energy South [Member] | Disposed of by Sale [Member] | Mobile Gas [Member] | 4.14% first mortgage bonds [Member]
Debt Instrument [Line Items]
Stated rate of debt offered and sold				4.14%
Debt assumed by buyer				$ 20,000,000
Sempra Natural Gas [Member] | Energy South [Member] | Disposed of by Sale [Member] | Mobile Gas [Member] | 5% first mortgage bonds [Member]
Debt Instrument [Line Items]
Stated rate of debt offered and sold				5.00%
Debt assumed by buyer				$ 42,000,000
Sempra Natural Gas [Member] | Energy South [Member] | Disposed of by Sale [Member] | Willmut Gas [Member] | 3.1% notes payable [Member]
Debt Instrument [Line Items]
Stated rate of debt offered and sold				3.10%
Debt assumed by buyer				$ 5,000,000
San Diego Gas and Electric Company [Member] | First mortgage bonds maturing 2026 [Member]
Debt Instrument [Line Items]
Debt amount offered and sold							$ 500,000,000
Stated rate of debt offered and sold							2.50%
San Diego Gas and Electric Company [Member] | Other long term debt variable rate due 2027 [Member]
Debt Instrument [Line Items]
Stated rate of debt offered and sold							5.00%
Amount of debt redeemed early							$ 105,000,000
Southern California Gas Company [Member] | First mortgage bonds maturing 2026 [Member]
Debt Instrument [Line Items]
Debt amount offered and sold						$ 500,000,000
Stated rate of debt offered and sold						2.60%
IEnova [Member] | Sempra Mexico [Member] | GdC [Member]
Debt Instrument [Line Items]
Ownership percentage acquired			50.00%
Long-term debt assumed	$ 364,000,000
Current portion of long-term debt	$ 49,000,000
IEnova [Member] | Sempra Mexico [Member] | GdC [Member] | LIBOR [Member] | Minimum [Member]
Debt Instrument [Line Items]
Spread on variable rate	2.00%
IEnova [Member] | Sempra Mexico [Member] | GdC [Member] | LIBOR [Member] | Maximum [Member]
Debt Instrument [Line Items]
Spread on variable rate	2.75%
IEnova [Member] | Sempra Mexico [Member] | GdC [Member] | Interest Rate Swap [Member]
Debt Instrument [Line Items]
Fixed interest rate on floating-to-fixed interest rate swaps	2.63%
Subsequent Event [Member] | Sempra Energy [Member] | Other long term debt fixed rate due 2019 [Member]
Debt Instrument [Line Items]
Debt amount offered and sold		$ 500,000,000
Stated rate of debt offered and sold		1.625%

DERIVATIVE FINANCIAL INSTRUME54

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details) MWh in Millions, MMBTU in Millions	Sep. 30, 2016MWhMMBTU	Dec. 31, 2015MWhMMBTU
SDG&E [Member]
Derivatives, Fair Value [Line Items]
Natural gas	56	70
Electricity | MWh	4	1
Congestion revenue rights | MWh	46	36
SoCalGas [Member]
Derivatives, Fair Value [Line Items]
Natural gas	2	1
Sempra Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural gas	35	43

DERIVATIVE FINANCIAL INSTRUME55

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2015	Jan. 31, 2016
Other foreign currency derivatives [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative	$ 914		$ 550
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative	$ 753	$ 384
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Minimum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2016	Dec. 31, 2016
Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2028	Dec. 31, 2028
Fair Value Hedging [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative	$ 0	$ 300
Maturity date		Dec. 31, 2016
Sempra Mexico [Member] | Cross currency swaps [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative	$ 408	$ 408
Sempra Mexico [Member] | Cross currency swaps [Member] | Minimum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2016	Dec. 31, 2016
Sempra Mexico [Member] | Cross currency swaps [Member] | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2023	Dec. 31, 2023
Sempra Mexico [Member] | Other foreign currency derivatives [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative	$ 1,481	$ 0
Sempra Mexico [Member] | Other foreign currency derivatives [Member] | Minimum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2016
Sempra Mexico [Member] | Other foreign currency derivatives [Member] | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2018
San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative	$ 307	$ 315
San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Minimum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2016	Dec. 31, 2016
San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member] | Maximum [Member]
Derivatives, Fair Value [Line Items]
Maturity date	Dec. 31, 2019	Dec. 31, 2019

DERIVATIVE FINANCIAL INSTRUME56

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 19,000,000	$ 50,000,000
Additional cash collateral for commodity contracts not subject to rate recovery	15,000,000	2,000,000
Additional cash collateral for commodity contracts subject to rate recovery	19,000,000	28,000,000
Total	53,000,000	80,000,000
Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	93,000,000	60,000,000
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	93,000,000	60,000,000
Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(88,000,000)	(49,000,000)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(88,000,000)	(49,000,000)
Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(371,000,000)	(193,000,000)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(371,000,000)	(193,000,000)
Designated as Hedging Instrument [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	3,000,000	4,000,000
Commodity contracts not subject to rate recovery	0	13,000,000
Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	0	1,000,000
Commodity contracts not subject to rate recovery	0	0
Designated as Hedging Instrument [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(20,000,000)	(15,000,000)
Commodity contracts not subject to rate recovery	(4,000,000)	0
Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(224,000,000)	(156,000,000)
Commodity contracts not subject to rate recovery	0	0
Not Designated as Hedging Instrument [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	2,000,000
Commodity contracts not subject to rate recovery	122,000,000	245,000,000
Associated offsetting commodity contracts	(114,000,000)	(232,000,000)
Associated offsetting cash collateral	0	(6,000,000)
Commodity contracts subject to rate recovery	11,000,000	28,000,000
Associated offsetting commodity contracts	(5,000,000)	(2,000,000)
Associated offsetting cash collateral	0	0
Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	0
Commodity contracts not subject to rate recovery	25,000,000	32,000,000
Associated offsetting commodity contracts	(15,000,000)	(20,000,000)
Associated offsetting cash collateral	(2,000,000)	0
Commodity contracts subject to rate recovery	86,000,000	49,000,000
Associated offsetting commodity contracts	(1,000,000)	(2,000,000)
Associated offsetting cash collateral	0	0
Not Designated as Hedging Instrument [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	(25,000,000)
Commodity contracts not subject to rate recovery	(128,000,000)	(239,000,000)
Associated offsetting commodity contracts	114,000,000	232,000,000
Associated offsetting cash collateral	17,000,000	4,000,000
Commodity contracts subject to rate recovery	(59,000,000)	(61,000,000)
Associated offsetting commodity contracts	5,000,000	2,000,000
Associated offsetting cash collateral	12,000,000	28,000,000
Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	0
Commodity contracts not subject to rate recovery	(17,000,000)	(21,000,000)
Associated offsetting commodity contracts	15,000,000	20,000,000
Associated offsetting cash collateral	2,000,000	0
Commodity contracts subject to rate recovery	(165,000,000)	(64,000,000)
Associated offsetting commodity contracts	1,000,000	2,000,000
Associated offsetting cash collateral	17,000,000	26,000,000
San Diego Gas and Electric Company [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	5,000,000	25,000,000
Additional cash collateral for commodity contracts not subject to rate recovery	1,000,000	1,000,000
Additional cash collateral for commodity contracts subject to rate recovery	17,000,000	27,000,000
Total	23,000,000	53,000,000
San Diego Gas and Electric Company [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	85,000,000	47,000,000
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	85,000,000	47,000,000
San Diego Gas and Electric Company [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(53,000,000)	(44,000,000)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(53,000,000)	(44,000,000)
San Diego Gas and Electric Company [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(165,000,000)	(59,000,000)
Additional cash collateral for commodity contracts not subject to rate recovery	0	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(165,000,000)	(59,000,000)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives designated as hedging instruments:
Interest rate instruments	0	0
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives designated as hedging instruments:
Interest rate instruments	0	0
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives designated as hedging instruments:
Interest rate instruments	(13,000,000)	(14,000,000)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives designated as hedging instruments:
Interest rate instruments	(18,000,000)	(23,000,000)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		0
Associated offsetting cash collateral		0
Commodity contracts subject to rate recovery	8,000,000	27,000,000
Associated offsetting commodity contracts	(3,000,000)	(2,000,000)
Associated offsetting cash collateral	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		0
Associated offsetting cash collateral		0
Commodity contracts subject to rate recovery	86,000,000	49,000,000
Associated offsetting commodity contracts	(1,000,000)	(2,000,000)
Associated offsetting cash collateral	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		(1,000,000)
Associated offsetting cash collateral		1,000,000
Commodity contracts subject to rate recovery	(55,000,000)	(60,000,000)
Associated offsetting commodity contracts	3,000,000	2,000,000
Associated offsetting cash collateral	12,000,000	28,000,000
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		0
Associated offsetting cash collateral		0
Commodity contracts subject to rate recovery	(165,000,000)	(64,000,000)
Associated offsetting commodity contracts	1,000,000	2,000,000
Associated offsetting cash collateral	17,000,000	26,000,000
Southern California Gas Company [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	1,000,000	1,000,000
Additional cash collateral for commodity contracts not subject to rate recovery	1,000,000
Additional cash collateral for commodity contracts subject to rate recovery	2,000,000	1,000,000
Total	4,000,000	2,000,000
Southern California Gas Company [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	0
Additional cash collateral for commodity contracts not subject to rate recovery	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	0	0
Southern California Gas Company [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(2,000,000)	(1,000,000)
Additional cash collateral for commodity contracts not subject to rate recovery	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(2,000,000)	(1,000,000)
Southern California Gas Company [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	0
Additional cash collateral for commodity contracts not subject to rate recovery	0
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	0	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Current assets: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		0
Associated offsetting cash collateral		0
Commodity contracts subject to rate recovery	3,000,000	1,000,000
Associated offsetting commodity contracts	(2,000,000)
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		0
Associated offsetting cash collateral		0
Commodity contracts subject to rate recovery	0	0
Associated offsetting commodity contracts	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		(1,000,000)
Associated offsetting cash collateral		1,000,000
Commodity contracts subject to rate recovery	(4,000,000)	(1,000,000)
Associated offsetting commodity contracts	2,000,000
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Fixed-price contracts and other derivatives [Member]
Derivatives not designated as hedging instruments:
Commodity contracts not subject to rate recovery		0
Associated offsetting cash collateral		0
Commodity contracts subject to rate recovery	0	$ 0
Associated offsetting commodity contracts	$ 0

DERIVATIVE FINANCIAL INSTRUME57

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON THE INCOME (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings			$ (39,000,000)	$ 20,000,000
Fair Value Hedging [Member] | Interest Expense [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Hedge ineffectiveness	$ 0	$ 0	0	0
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	1,000,000	1,000,000	3,000,000
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member] | Interest Expense [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	1,000,000	3,000,000	5,000,000
Designated as Hedging Instrument [Member] | Fair Value Hedging [Member] | Other Income, Net [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	0	(2,000,000)	(2,000,000)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	16,000,000	(138,000,000)	(238,000,000)	(139,000,000)
Pretax (loss) gain reclassified from AOCI into earnings	(12,000,000)	(5,000,000)	(23,000,000)	(13,000,000)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	(16,000,000)	(10,000,000)	(26,000,000)	(22,000,000)
Pretax (loss) gain reclassified from AOCI into earnings	(4,000,000)	(5,000,000)	(11,000,000)	(14,000,000)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Equity Earnings, Before Income Tax [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	17,000,000	(134,000,000)	(190,000,000)	(123,000,000)
Pretax (loss) gain reclassified from AOCI into earnings	(3,000,000)	(3,000,000)	(8,000,000)	(9,000,000)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Remeasurement of Equity Method Investment [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	(7,000,000)	0	(7,000,000)	0
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Equity Earnings, Net of Income Tax [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	13,000,000	0	(20,000,000)	0
Pretax (loss) gain reclassified from AOCI into earnings	2,000,000	0	(4,000,000)	0
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Revenues: Energy- Related Businesses [Member] | Commodity Contract Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	2,000,000	6,000,000	(2,000,000)	6,000,000
Pretax (loss) gain reclassified from AOCI into earnings	0	3,000,000	7,000,000	10,000,000
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(125,000,000)	(15,000,000)	(137,000,000)	(78,000,000)
Not Designated as Hedging Instrument [Member] | Other Income, Net [Member] | Other foreign currency derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(11,000,000)	(4,000,000)	(23,000,000)	(7,000,000)
Not Designated as Hedging Instrument [Member] | Equity Earnings, Net of Income Tax [Member] | Other foreign currency derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	1,000,000	(3,000,000)	3,000,000	(4,000,000)
Not Designated as Hedging Instrument [Member] | Revenues: Energy- Related Businesses [Member] | Commodity Contract Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	3,000,000	21,000,000	(26,000,000)	33,000,000
Not Designated as Hedging Instrument [Member] | Operation and Maintenance [Member] | Commodity Contract Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	(2,000,000)	1,000,000	(1,000,000)
Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(118,000,000)	(27,000,000)	(90,000,000)	(100,000,000)
Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	0	(2,000,000)	1,000,000
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings			2,000,000	3,000,000
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	2,000,000	(4,000,000)	(5,000,000)	(9,000,000)
Pretax (loss) gain reclassified from AOCI into earnings	(3,000,000)	(3,000,000)	(9,000,000)	(9,000,000)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(118,000,000)	(28,000,000)	(90,000,000)	(101,000,000)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Operation and Maintenance [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	(1,000,000)	0	(1,000,000)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	(118,000,000)	(27,000,000)	(90,000,000)	(100,000,000)
Southern California Gas Company [Member] | Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest Rate Contract [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	(1,000,000)	0	(1,000,000)	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	(1,000,000)	(2,000,000)	1,000,000
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Operation and Maintenance [Member] | Commodity Contract Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	0	(1,000,000)	0	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivatives recognized in earnings	$ 0	$ 0	$ (2,000,000)	$ 1,000,000

DERIVATIVE FINANCIAL INSTRUME58

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Losses on cash flow hedges to be reclassified from AOCI within 12 months	$ 21
Maximum remaining term of cash flow hedges	12 years
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum remaining term of cash flow hedges	3 years
Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Losses on cash flow hedges to be reclassified from AOCI within 12 months	$ 0
Equity Method Investee [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum remaining term of cash flow hedges	19 years
Noncontrolling Interest [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Losses on cash flow hedges to be reclassified from AOCI within 12 months	$ 12

DERIVATIVE FINANCIAL INSTRUME59

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Derivative Instruments, Gain (Loss) [Line Items]
Net liability position for derivatives with credit limits	$ 6	$ 6
Additional collateral that wil be required if credit rating falls below investment grade	8
San Diego Gas and Electric Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Net liability position for derivatives with credit limits	3	$ 5
Additional collateral that wil be required if credit rating falls below investment grade	$ 5

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - Recurring [Member] - USD ($)	Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	$ 607,000,000	$ 619,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	100,000,000	91,000,000
Nuclear decommissioning trusts - Municipal bonds	161,000,000	156,000,000
Nuclear decommissioning trusts - Other securities	188,000,000	182,000,000
Nuclear decommissioning trusts - Total debt securities	449,000,000	429,000,000
Nuclear decommissioning trusts - Netting	0	0
Total nuclear decommissioning trusts	1,056,000,000	1,048,000,000
Derivative asset netting	32,000,000	24,000,000
Total	1,202,000,000	1,188,000,000
Derivative liability netting	(48,000,000)	(58,000,000)
Total	459,000,000	242,000,000
Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5,000,000	5,000,000
Derivative asset netting	0	0
Derivative liabilities	269,000,000	171,000,000
Derivative liability netting	0	0
Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	31,000,000	34,000,000
Derivative asset netting	13,000,000	(4,000,000)
Derivative liabilities	1,000,000	4,000,000
Derivative liability netting	(19,000,000)	(4,000,000)
Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	110,000,000	101,000,000
Derivative asset netting	19,000,000	28,000,000
Derivative liabilities	189,000,000	67,000,000
Derivative liability netting	(29,000,000)	(54,000,000)
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	607,000,000	619,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48,000,000	47,000,000
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	48,000,000	47,000,000
Total nuclear decommissioning trusts	655,000,000	666,000,000
Total	655,000,000	688,000,000
Total	20,000,000	5,000,000
Level 1 [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	0
Level 1 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	22,000,000
Derivative liabilities	19,000,000	5,000,000
Level 1 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	1,000,000	0
Level 2 [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	52,000,000	44,000,000
Nuclear decommissioning trusts - Municipal bonds	161,000,000	156,000,000
Nuclear decommissioning trusts - Other securities	188,000,000	182,000,000
Nuclear decommissioning trusts - Total debt securities	401,000,000	382,000,000
Total nuclear decommissioning trusts	401,000,000	382,000,000
Total	425,000,000	404,000,000
Total	310,000,000	242,000,000
Level 2 [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	5,000,000	5,000,000
Derivative liabilities	269,000,000	171,000,000
Level 2 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	18,000,000	16,000,000
Derivative liabilities	1,000,000	3,000,000
Level 2 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1,000,000	1,000,000
Derivative liabilities	40,000,000	68,000,000
Level 3 [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	0	0
Total	90,000,000	72,000,000
Total	177,000,000	53,000,000
Level 3 [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	0
Level 3 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	0
Level 3 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	90,000,000	72,000,000
Derivative liabilities	177,000,000	53,000,000
San Diego Gas and Electric Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	607,000,000	619,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	100,000,000	91,000,000
Nuclear decommissioning trusts - Municipal bonds	161,000,000	156,000,000
Nuclear decommissioning trusts - Other securities	188,000,000	182,000,000
Nuclear decommissioning trusts - Total debt securities	449,000,000	429,000,000
Nuclear decommissioning trusts - Netting	0	0
Total nuclear decommissioning trusts	1,056,000,000	1,048,000,000
Derivative asset netting	18,000,000	28,000,000
Total	1,164,000,000	1,148,000,000
Derivative liability netting	(29,000,000)	(55,000,000)
Total	218,000,000	103,000,000
San Diego Gas and Electric Company [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1,000,000	1,000,000
Derivative asset netting	1,000,000	1,000,000
Derivative liabilities		0
Derivative liability netting		(1,000,000)
San Diego Gas and Electric Company [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	107,000,000	99,000,000
Derivative asset netting	17,000,000	27,000,000
Derivative liabilities	187,000,000	66,000,000
Derivative liability netting	(29,000,000)	(54,000,000)
San Diego Gas and Electric Company [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	31,000,000	37,000,000
Derivative liability netting	0	0
San Diego Gas and Electric Company [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	607,000,000	619,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48,000,000	47,000,000
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	48,000,000	47,000,000
Total nuclear decommissioning trusts	655,000,000	666,000,000
Total	655,000,000	666,000,000
Total	0	1,000,000
San Diego Gas and Electric Company [Member] | Level 1 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities		1,000,000
San Diego Gas and Electric Company [Member] | Level 1 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	0	0
San Diego Gas and Electric Company [Member] | Level 1 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
San Diego Gas and Electric Company [Member] | Level 2 [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	52,000,000	44,000,000
Nuclear decommissioning trusts - Municipal bonds	161,000,000	156,000,000
Nuclear decommissioning trusts - Other securities	188,000,000	182,000,000
Nuclear decommissioning trusts - Total debt securities	401,000,000	382,000,000
Total nuclear decommissioning trusts	401,000,000	382,000,000
Total	401,000,000	382,000,000
Total	70,000,000	104,000,000
San Diego Gas and Electric Company [Member] | Level 2 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities		0
San Diego Gas and Electric Company [Member] | Level 2 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	39,000,000	67,000,000
San Diego Gas and Electric Company [Member] | Level 2 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	31,000,000	37,000,000
San Diego Gas and Electric Company [Member] | Level 3 [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	0	0
Total	90,000,000	72,000,000
Total	177,000,000	53,000,000
San Diego Gas and Electric Company [Member] | Level 3 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities		0
San Diego Gas and Electric Company [Member] | Level 3 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	90,000,000	72,000,000
Derivative liabilities	177,000,000	53,000,000
San Diego Gas and Electric Company [Member] | Level 3 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities	0	0
Southern California Gas Company [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset netting	3,000,000	1,000,000
Total	4,000,000	2,000,000
Derivative liability netting	0	(1,000,000)
Total	2,000,000	1,000,000
Southern California Gas Company [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1,000,000
Derivative asset netting	1,000,000
Derivative liabilities		0
Derivative liability netting		(1,000,000)
Southern California Gas Company [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	3,000,000	2,000,000
Derivative asset netting	2,000,000	1,000,000
Derivative liabilities	2,000,000	1,000,000
Derivative liability netting	0	0
Southern California Gas Company [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	0	0
Total	1,000,000	1,000,000
Southern California Gas Company [Member] | Level 1 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liabilities		1,000,000
Southern California Gas Company [Member] | Level 1 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	1,000,000	0
Southern California Gas Company [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	1,000,000	1,000,000
Total	1,000,000	1,000,000
Southern California Gas Company [Member] | Level 2 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liabilities		0
Southern California Gas Company [Member] | Level 2 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	1,000,000	1,000,000
Derivative liabilities	1,000,000	1,000,000
Southern California Gas Company [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total	0	0
Total	0	0
Southern California Gas Company [Member] | Level 3 [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0
Derivative liabilities		0
Southern California Gas Company [Member] | Level 3 [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	0	0
Derivative liabilities	$ 0	$ 0

FAIR VALUE MEASUREMENTS - RECON

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning of period	$ 24,000,000	$ 42,000,000	$ 19,000,000	$ 107,000,000
Realized and unrealized losses	(145,000,000)	(49,000,000)	(138,000,000)	(103,000,000)
Allocated transmission instruments			0	1,000,000
Settlements	(34,000,000)	(43,000,000)	(32,000,000)	(31,000,000)
End of period	(87,000,000)	36,000,000	(87,000,000)	36,000,000
Change in unrealized gains relating to instruments still held at the end of the period	(114,000,000)	$ (8,000,000)	(111,000,000)	$ (54,000,000)
Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion Revenue Rights						$ (16)
Market Electricity Forward Price Inputs	19.20		19.20
Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion Revenue Rights						$ 8
Market Electricity Forward Price Inputs	$ 58.50		$ 58.50
Forecast [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion Revenue Rights					$ (24)
Forecast [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion Revenue Rights					$ 10

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Noncurrent due from unconsolidated affiliates	$ 180	$ 175
Total long-term debt	14,149	13,761
Preferred stock	20	20
Accumulated interest outstanding	15	11
Unamortized discount (net of premium) and debt issuance costs	108	107
Build-to-suit and capital lease obligations	385	387
Carrying amount [Member] | Otay Mesa VIE [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt, gross	307	315
Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Noncurrent due from unconsolidated affiliates	172	166
Total long-term debt	15,867	14,633
Preferred stock	26	23
Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Noncurrent due from unconsolidated affiliates	0	0
Total long-term debt	0	0
Preferred stock	0	0
Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Noncurrent due from unconsolidated affiliates	91	97
Total long-term debt	15,335	13,985
Preferred stock	26	23
Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Noncurrent due from unconsolidated affiliates	81	69
Total long-term debt	532	648
Preferred stock	0	0
San Diego Gas and Electric Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,656	4,304
Unamortized discount (net of premium) and debt issuance costs	46	43
Capital lease obligations	241	244
San Diego Gas and Electric Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,331	4,670
San Diego Gas and Electric Company [Member] | Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
San Diego Gas and Electric Company [Member] | Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,024	4,355
San Diego Gas and Electric Company [Member] | Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	307	315
Southern California Gas Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	3,009	2,513
Preferred stock	22	22
Unamortized discount (net of premium) and debt issuance costs	27	24
Capital lease obligations	1	1
Southern California Gas Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	3,323	2,621
Preferred stock	28	25
Southern California Gas Company [Member] | Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Preferred stock	0	0
Southern California Gas Company [Member] | Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	3,323	2,621
Preferred stock	28	25
Southern California Gas Company [Member] | Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	0	0
Preferred stock	$ 0	$ 0

FAIR VALUE MEASUREMENTS - NONRE

FAIR VALUE MEASUREMENTS - NONRECURRING INPUTS (Details) - USD ($) $ in Millions	Sep. 26, 2016	May 31, 2016	Mar. 31, 2016	Sep. 30, 2016	Mar. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	Sep. 29, 2016	Sep. 27, 2016	Sep. 25, 2016	Mar. 29, 2016
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Pretax gain for the excess of acquisition date fair value over carrying value						$ 617	$ 0
Impairment of equity method investment						131
Impairment of equity method investment after-tax						111
TdM [Member] | Carrying amount [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair value of equity method investment				$ 146		146
Market Approach Valuation Technique [Member] | Level 2 [Member] | TdM [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair value of equity method investment								$ 145
Fair Value Inputs, Percentage of Fair Value Measurement								100.00%
Fair Value Inputs, Range of Inputs								100.00%
Market Approach Valuation Technique [Member] | Level 2 [Member] | GdC [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair value of equity method investment	$ 1,144
Fair Value Inputs, Percentage of Fair Value Measurement	100.00%
Fair Value Inputs, Range of Inputs	100.00%
Market Approach Valuation Technique [Member] | Level 2 [Member] | Rockies Express [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Fair value of equity method investment											$ 440
Fair Value Inputs, Percentage of Fair Value Measurement											100.00%
Fair Value Inputs, Range of Inputs											100.00%
Sempra Mexico [Member] | TdM [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Impairment of equity method investment				131
Impairment of equity method investment after-tax				$ 111
Sempra Mexico [Member] | GdC [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Ownership percentage acquired	50.00%
Ownership percentage	100.00%								100.00%	50.00%
Pretax gain for the excess of acquisition date fair value over carrying value	$ 617
After-tax gain for the excess of acquisition date fair value over carrying value	432
Fair value of equity method investment	1,144
Carrying value of equity method investment	520
Losses reclassified from accumulated other comprehensive loss	7
Total fair value of business combination	$ 2,288
Sempra Natural Gas [Member] | Rockies Express [Member]
Fair Value Inputs, Assets, Quantitative Information [Line Items]
Ownership percentage		25.00%	25.00%		25.00%						25.00%
Fair value of equity method investment			$ 440		$ 440
Carrying value of equity method investment			484		484
Impairment of equity method investment					44	44
Impairment of equity method investment after-tax					$ 27	$ 27
Proceeds from sale of equity method investment		$ 443	$ 440

SAN ONOFRE NUCLEAR GENERATING64

SAN ONOFRE NUCLEAR GENERATING STATION (SONGS) (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended	9 Months Ended	12 Months Ended		21 Months Ended
	Apr. 30, 2016	Oct. 31, 2015	Mar. 31, 2015	Sep. 30, 2016	Dec. 31, 2015		Sep. 30, 2016
Jointly Owned Utility Plant Interests [Line Items]
Regulatory asset, noncurrent				$ 3,424	$ 3,273	[1]	$ 3,424
Insurance recoveries		$ 400
Nuclear decommissioning trusts				1,068	1,063	[1]	1,068
Environmental exit costs, anticipated cost	$ 4,411
Authorized recovery amount, nuclear decommissioning trust funding				218			$ 218
Amount pending IRS clarification				$ 37
Ratepayers [Member]
Jointly Owned Utility Plant Interests [Line Items]
Insurance recoveries		75
San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share				20.00%			20.00%
Loss from plant closure, after tax					125		$ 125
Adjustment to loss from plant closure, after tax			$ 13
Regulatory asset, current				$ 124	107	[1]	124
Regulatory asset, noncurrent				1,036	977	[1]	1,036
Insurance recoveries		$ 80
Nuclear decommissioning trusts				1,068	1,063	[1]	1,068
Environmental exit costs, anticipated cost	$ 899
Authorized recovery amount, nuclear decommissioning trust funding				218			218
San Diego Gas and Electric Company [Member] | Asset Retirement Obligation Costs [Member]
Jointly Owned Utility Plant Interests [Line Items]
Regulatory asset				195			195
Regulatory asset, current				45			45
Regulatory asset, noncurrent				150			150
Sempra Energy [Member]
Jointly Owned Utility Plant Interests [Line Items]
Loss from plant closure, after tax					$ 125		125
Adjustment to loss from plant closure, after tax			$ 13
Sempra Energy [Member] | Asset Retirement Obligation Costs [Member]
Jointly Owned Utility Plant Interests [Line Items]
Regulatory asset				195			195
Regulatory asset, current				45			45
Regulatory asset, noncurrent				$ 150			$ 150
[1]	Derived from audited financial statements.

SAN ONOFRE NUCLEAR GENERATING65

SAN ONOFRE NUCLEAR GENERATING STATION (SONGS) - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Cost	$ 628		$ 628		$ 660
Gross unrealized gains	447		447		423
Gross unrealized losses	(7)		(7)		(20)
Estimated fair value	1,068		1,068		1,063
Proceeds from sales	282	$ 210	486	$ 431
Gross realized gains	24	18	32	24
Gross realized losses	(3)	$ (6)	(14)	$ (13)
Total debt securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	428		428		431
Gross unrealized gains	25		25		11
Gross unrealized losses	(4)		(4)		(13)
Estimated fair value	449		449		429
U.S. government corporations and agencies [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	95		95		89
Gross unrealized gains	5		5		2
Gross unrealized losses	0		0		0
Estimated fair value	100		100		91
Municipal bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	150		150		148
Gross unrealized gains	11		11		8
Gross unrealized losses	0		0		0
Estimated fair value	161		161		156
Other securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	183		183		194
Gross unrealized gains	9		9		1
Gross unrealized losses	(4)		(4)		(13)
Estimated fair value	188		188		182
Equity securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	188		188		214
Gross unrealized gains	422		422		412
Gross unrealized losses	(3)		(3)		(7)
Estimated fair value	607		607		619
Cash and cash equivalents [Member]
Schedule of Available-for-sale Securities [Line Items]
Cost	12		12		15
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ 12		$ 12		$ 15

CALIFORNIA UTILITIES' REGULAT66

CALIFORNIA UTILITIES' REGULATORY MATTERS - GENERAL RATE CASE (Details) - USD ($) $ in Millions	Oct. 31, 2016	Jun. 30, 2016	Sep. 30, 2016
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Retroactive revenue requirement increase for the first quarter of 2016, After-tax		$ 9
Refund of 2015 memorandum account, Pretax		37
Refund of 2015 memorandum account, After-tax		22
Adjustment To Revenue, True Up Of 2012-2014 Tax Estimates		9
Increase (decrease) in final tax deduction refund			$ (5)
San Diego Gas and Electric Company [Member] | Year 2015 [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate decrease from proposed settlement	$ 32
San Diego Gas and Electric Company [Member] | Year 2016 [Member]
Public Utilities, General Disclosures [Line Items]
Revenue requirement			1,791
Requested rate decrease from proposed settlement			20
Revenue revised requirement			1,811
Regulatory asset			25
Regulatory asset, Noncurrent			5
Reduction in rate base			55
Reduction in revenue requirements			$ 7
Regulatory Liability		15
San Diego Gas and Electric Company [Member] | Years 2017 and 2018 [Member]
Public Utilities, General Disclosures [Line Items]
Annual escalation (percentage)			3.50%
Deductible			$ 5
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Retroactive revenue requirement increase for the first quarter of 2016, After-tax		12
Refund of 2015 memorandum account, Pretax		72
Refund of 2015 memorandum account, After-tax		43
Adjustment To Revenue, True Up Of 2012-2014 Tax Estimates		6
Increase (decrease) in final tax deduction refund			(19)
Southern California Gas Company [Member] | Year 2015 [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Requested rate decrease from proposed settlement	$ 53
Southern California Gas Company [Member] | Year 2016 [Member]
Public Utilities, General Disclosures [Line Items]
Revenue requirement			2,204
Requested rate decrease from proposed settlement			15
Revenue revised requirement			2,219
Regulatory asset			58
Regulatory asset, Noncurrent			12
Reduction in rate base			38
Reduction in revenue requirements			$ 5
Regulatory Liability		$ 11
Southern California Gas Company [Member] | Years 2017 and 2018 [Member]
Public Utilities, General Disclosures [Line Items]
Annual escalation (percentage)			3.50%
Deductible			$ 5

CALIFORNIA UTILITIES' REGULAT67

CALIFORNIA UTILITIES' REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE DECISION IMPACT ON EARNINGS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2016
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Retroactive revenue requirement increase for the first quarter of 2016. Pretax		$ 20
Retroactive revenue requirement increase for the first quarter of 2016, After-tax		12
Adjustments to revenue related to tax repairs deductions:
2015 memorandum account, Pretax		(72)
True-up of 2012-2014 estimates to actuals, Pretax		(11)
Total, Pretax	$ 4	(83)	$ 19
2015 memorandum account, After-tax		(43)
True-up of 2012-2014 estimates to actuals, After-tax		(6)
Total, After-tax	$ 2	(49)	$ 11
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Retroactive revenue requirement increase for the first quarter of 2016. Pretax		15
Retroactive revenue requirement increase for the first quarter of 2016, After-tax		9
Adjustments to revenue related to tax repairs deductions:
2015 memorandum account, Pretax		(37)
True-up of 2012-2014 estimates to actuals, Pretax		(15)
Total, Pretax		(52)
2015 memorandum account, After-tax		(22)
True-up of 2012-2014 estimates to actuals, After-tax		(9)
Total, After-tax		$ (31)

CALIFORNIA UTILITIES' REGULAT68

CALIFORNIA UTILITIES' REGULATORY MATTERS - NATURAL GAS PIPELINE OPERATIONS SAFETY ASSESSMENTS (Details) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2014	Oct. 31, 2016	Jun. 11, 2014
Southern California Gas Company [Member] | Pipeline Safety Enhancement Plan [Member]
Public Utilities, General Disclosures [Line Items]
Disallowed costs impact on earnings after tax		$ 5
Pipeline safety plan regulatory account	$ 212
Recovery requested, PSEP costs	180.5			$ 46
Southern California Gas Company [Member] | Pipeline Safety Enhancement Plan [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Recovery requested, PSEP costs			$ 2
Southern California Gas Company [Member] | Pipeline Safety Enhancement Plan [Member] | Deferred Project Costs [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Pipeline safety plan regulatory account			33.1
Southern California Gas Company [Member] | Pipeline Testing/Replacing 1956 to 1961 [Member]
Public Utilities, General Disclosures [Line Items]
Disallowed costs impact on earnings after tax	3.6
San Diego Gas and Electric Company [Member] | Pipeline Safety Enhancement Plan [Member]
Public Utilities, General Disclosures [Line Items]
Pipeline safety plan regulatory account	18
Recovery requested, PSEP costs	14.9			$ 0.1
San Diego Gas and Electric Company [Member] | Pipeline Safety Enhancement Plan [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Recovery requested, PSEP costs			2
San Diego Gas and Electric Company [Member] | Pipeline Safety Enhancement Plan [Member] | Deferred Project Costs [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Pipeline safety plan regulatory account			$ 0.1
San Diego Gas and Electric Company [Member] | Pipeline Testing/Replacing 1956 to 1961 [Member]
Public Utilities, General Disclosures [Line Items]
Disallowed costs impact on earnings after tax	$ 0.5

CALIFORNIA UTILITIES' REGULAT69

CALIFORNIA UTILITIES' REGULATORY MATTERS - WILDFIRE COST RECOVERY (Details) - San Diego Gas and Electric Company [Member] $ in Millions	3 Months Ended
	Sep. 30, 2016USD ($)
Public Utilities, General Disclosures [Line Items]
Requested recovery	$ 379
Incurred costs	2,400
Insurance reimbursement	1,100
Third party settlement recoveries	824
FERC jurisdictional rates	$ 80
Voluntary shareholder contribution percentage	10.00%
WEMA balance	$ 42
FERC-approved wildfire damage expenses	$ 23.1

CALIFORNIA UTILITIES' REGULAT70

CALIFORNIA UTILITIES' REGULATORY MATTERS - SOCALGAS MATTERS (Details) - Southern California Gas Company [Member] - USD ($) $ in Thousands	Sep. 30, 2016	Jun. 30, 2016
Unfavorable Regulatory Action [Member] | Pending Litigation [Member] | Aliso Canyon Turbine Replacement Project [Member]
Public Utilities, General Disclosures [Line Items]
Estimate of possible loss/fines	$ 700
Year 2016 [Member]
Public Utilities, General Disclosures [Line Items]
Requested gas cost incentive mechanism award		$ 5,000

CALIFORNIA UTILITIES' REGULAT71

CALIFORNIA UTILITIES' REGULATORY MATTERS - MAJOR PROJECTS UPDATES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)	Oct. 31, 2016USD ($)	Aug. 31, 2016projectMW
Southern Gas System Member [Member]
Public Utilities, General Disclosures [Line Items]
Impairment charge after tax	$ 13
Impairment charge pre-tax	22
Pipeline Safety And Reliability Project [Member]
Public Utilities, General Disclosures [Line Items]
Revised estimated project cost	633
San Diego Gas and Electric Company [Member] | Cleveland National Forest Transmissions Projects [Member]
Public Utilities, General Disclosures [Line Items]
Estimated project cost	680
San Diego Gas and Electric Company [Member] | Cleveland National Forest Projects Transmission Level Facilities [Member]
Public Utilities, General Disclosures [Line Items]
Estimated project cost	470
San Diego Gas and Electric Company [Member] | Cleveland National Forest Projects Distribution Level Facilities [Member]
Public Utilities, General Disclosures [Line Items]
Estimated project cost	210
San Diego Gas and Electric Company [Member] | Energy Storage Projects [Member]
Public Utilities, General Disclosures [Line Items]
Number of Projects | project			2
Energy Storage Capacity | MW			37.5
San Diego Gas and Electric Company [Member] | Maximum [Member] | Sycamore Penasquitos Transmission Project [Member] | Subsequent Event [Member]
Public Utilities, General Disclosures [Line Items]
Estimated project cost		$ 260
San Diego Gas and Electric Company [Member] | Maximum [Member] | South Orange County Reliability Enhancement [Member]
Public Utilities, General Disclosures [Line Items]
Estimated project cost	$ 381

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details)	Nov. 01, 2016plaintifflawsuit	Apr. 05, 2016plaintiff	Mar. 31, 2016t	Feb. 16, 2016USD ($)	Jan. 23, 2016	Sep. 30, 2016USD ($)Bcf	Sep. 30, 2016USD ($)Bcfappeal	Sep. 30, 2016USD ($)Bcf	Oct. 21, 2016t	Sep. 28, 2016wellMMcf	Jun. 28, 2016wellBcf	Jan. 31, 2016Bcf	Dec. 31, 2015USD ($)	[1]	Oct. 23, 2015Bcf
Loss Contingencies [Line Items]
Loss contingency accrual						$ 23,000,000	$ 23,000,000	$ 23,000,000
Reserve for Aliso Canyon costs						73,000,000	73,000,000	73,000,000					$ 274,000,000
Insurance receivable for Aliso Canyon costs						664,000,000	664,000,000	664,000,000					325,000,000
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Loss contingency accrual						21,000,000	$ 21,000,000	21,000,000
San Diego Gas and Electric Company [Member] | Wildfire [Member]
Loss Contingencies [Line Items]
Number of appeals pending | appeal							1
Regulatory assets arising from wildfire litigation costs						356,000,000	$ 356,000,000	356,000,000
Portion of regulatory assets arising from wildfire litigation related to CPUC operations						354,000,000	354,000,000	354,000,000
Potential after-tax charge for nonrecovery of CPUC regulatory assets						210,000,000	210,000,000	210,000,000
San Diego Gas and Electric Company [Member] | Wind Farm [Member]
Loss Contingencies [Line Items]
Estimated tax equity investment						285,000,000	285,000,000	285,000,000
Settlement credit to ratepayers							39,000,000
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Loss contingency accrual						1,000,000	1,000,000	1,000,000
Reserve for Aliso Canyon costs						73,000,000	73,000,000	73,000,000					274,000,000
Insurance receivable for Aliso Canyon costs						664,000,000	664,000,000	664,000,000					$ 325,000,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Loss contingency accrual						$ 763,000,000	$ 763,000,000	$ 763,000,000
Estimated costs related to temporary relocation (percentage)						70.00%	70.00%	70.00%
Estimated costs related to controlling well and stopping leak and emissions (percentage)						20.00%	20.00%	20.00%
Increase in reserve						$ 46,000,000
Insurance proceeds							$ 94,000,000
Number of plaintiffs | plaintiff		24
Total penalties							$ 60,800
Period of required climate reductions			20 years
Period of required regulatory climate reductions			100 years
Target emissions level (in metric tons) | t			9,000,000
Environmental monitoring period					30 days
Estimated withdrawal capacity required to meet customer reliability needs (in Bcf) | Bcf											1,119,000,000
Number of wells required to be kept available for reliability related withdrawals | well										17	17
Required minimum hourly withdrawal capacity (in cubic feet) | MMcf										8,600,000
Required minimum daily withdrawal capacity (in cubic feet) | MMcf										207
Amount of natural gas delivered | Bcf								57
Amount of natural gas in storage | Bcf															77
Amount of natural gas released | Bcf								4.62
Amount of natural gas to be retained in storage | Bcf												15
Storage facility capacity | Bcf						86	86	86
Proportion of total gas storage capacity (percentage)						63.00%	63.00%	63.00%
Net book value of Aliso Canyon facility						$ 491,000,000	$ 491,000,000	$ 491,000,000
Construction work in progress of new compressor station						217,000,000	217,000,000	217,000,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit	212
Number of plaintiffs | plaintiff	12,000
Loss Contingency, Total Actual Emissions, Floor (in metric tons) | t									90,350
Loss Contingency, Total Actual Emissions, Ceiling (in metric tons) | t									108,950
Mitigation requirements (in metric tons) | t									109,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Minimum [Member]
Loss Contingencies [Line Items]
Liability insurance coverage						1,200,000,000	1,200,000,000	1,200,000,000
Environmental mitigation period			5 years
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Maximum [Member]
Loss Contingencies [Line Items]
Liability insurance coverage						$ 1,400,000,000	1,400,000,000	$ 1,400,000,000
Environmental mitigation period			10 years
Southern California Gas Company [Member] | South Coast Air Quality Management District [Member]
Loss Contingencies [Line Items]
Civil penalties per day							$ 250,000
Southern California Gas Company [Member] | Damages from Product Defects [Member]
Loss Contingencies [Line Items]
Maximum occupational safety and health fines				$ 75,000
Penalty assessments				232,500
Maximum other assessments in settlement of criminal complaint				$ 4,000,000
Southern California Gas Company [Member] | So Cal Gas PCB Litigation [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed							7
Number of lawsuits settled							6
[1]	Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIES73

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) £ in Millions, $ in Millions	Oct. 21, 2016t	Sep. 30, 2016USD ($)	Oct. 01, 2015GBP (£)	Sep. 01, 2012GBP (£)
HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT tax claim paid upon appeal | £			£ 146	£ 86
Investment in RBS Sempra commodities LLP | $		$ 67
Southern California Gas Company [Member] | Subsequent Event [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Loss Contingency, Total Actual Emissions, Floor	90,350
Loss Contingency, Total Actual Emissions, Ceiling	108,950

COMMITMENTS AND CONTINGENCIES74

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Dec. 31, 2015
Sempra Energy [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase in asset retirement obligations	$ 342
Southern California Gas Company [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase in asset retirement obligations	316
Sempra Natural Gas [Member] | Natural Gas Contracts [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase (decrease) in commitment amount	(224)
Increase (decrease) in commitment amount, 2016	(168)
Increase (decrease) in commitment amount, 2017	2
Increase (decrease) in commitment amount, 2018	(17)
Increase (decrease) in commitment amount, 2019	(20)
Increase (decrease) in commitment amount, 2020	(8)
Increase (decrease) in commitment amount, thereafter	(13)
Charges related to permanent capacity releases, pretax	206
Charges related to permanent capacity releases, after tax	123
Obligation to make future capacity payments, current	44
Obligation to make future capacity payments, noncurrent	106
Sempra Natural Gas [Member] | Liquefied Natural Gas Contracts [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase (decrease) in commitment amount, 2016	(306)
Increase (decrease) in commitment amount, 2017	41
Increase (decrease) in commitment amount, 2018	(18)
Increase (decrease) in commitment amount, 2019	(59)
Increase (decrease) in commitment amount, 2020	(98)
Increase (decrease) in commitment amount, thereafter	$ (542)
Escalation percentage beyond year 2028	1.00%
San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase in asset retirement obligations	$ 26
San Diego Gas and Electric Company [Member] | Purchased Power Contracts [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase (decrease) in commitment amount	526
Increase (decrease) in commitment amount, 2016	19
Increase (decrease) in commitment amount, 2017	56
Increase (decrease) in commitment amount, 2018	57
Increase (decrease) in commitment amount, 2019	57
Increase (decrease) in commitment amount, 2020	57
Increase (decrease) in commitment amount, thereafter	280
Power transmission tolling fee		$ 1,400
Sempra Mexico [Member] | Construction and Development Projects [Member]
Unrecorded Unconditional Purchase Obligation [Line Items]
Increase (decrease) in commitment amount, 2016	180
Commitment amount due in remainder of fiscal year	4
Commitment amount due in 2017	15
Commitment amount due in 2018	15
Commitment amount due in 2019	16
Commitment amount due in 2020	16
Commitment amount due thereafter	$ 114

COMMITMENTS AND CONTINGENCIES75

COMMITMENTS AND CONTINGENCIES - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Thousands	Sep. 30, 2016USD ($)
Schedule Of Nuclear Insurance [Line Items]
Maximum nuclear liability insurance coverage	$ 375,000
Maximum secondary financial protection	13,200,000
Maximum company contribution to secondary financial protection	50,930
Annual maximum secondary financial protection contribution by company	7,600
Maximum nuclear property insurance coverage	2,750,000
Deductible per loss	2,500
Maximum premium assessment under nuclear property damage insurance	9,700
Maximum nuclear property insurance terrorism coverage	$ 3,240,000

COMMITMENTS AND CONTINGENCIES76

COMMITMENTS AND CONTINGENCIES - NUCLEAR FUEL DISPOSAL (Details) - San Diego Gas and Electric Company [Member] - USD ($) $ in Millions	Apr. 18, 2016	Sep. 30, 2016	May 31, 2016
Total Ownership [Member]
Jointly Owned Utility Plant Interests [Line Items]
Spent nuclear fuel damages awarded	$ 162
Filed claims amount		$ 56
SDG&E Ownership [Member]
Jointly Owned Utility Plant Interests [Line Items]
Spent nuclear fuel damages awarded			$ 32
Decrease In SONGS regulatory asset			23
Decrease In nuclear decommissioning balancing account			8
Decrease In operation and maintenance cost balancing account			$ 1
Filed claims amount		$ 11

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)segment	Sep. 30, 2015USD ($)	Dec. 31, 2015USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment			6
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 2,535	$ 2,481	$ 7,313	$ 7,530
Percentage of consolidated revenues	100.00%	100.00%	100.00%	100.00%
INTEREST EXPENSE	$ 136	$ 143	$ 421	$ 416
INTEREST INCOME	7	6	19	23
DEPRECIATION AND AMORTIZATION	$ 328	$ 315	$ 970	$ 925
Percentage of consolidated depreciation and amortization	100.00%	100.00%	100.00%	100.00%
INCOME TAX EXPENSE (BENEFIT)	$ 282	$ 15	$ 284	$ 276
Equity earnings, before income tax	12	33	4	79
Equity earnings (losses) net of tax	19	27	69	64
EARNINGS (LOSSES)	622	248	991	980
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 3,087	$ 2,227
Percentage of consolidated expenditures for property, plant & equipment			100.00%	100.00%
ASSETS	$ 45,526		$ 45,526		$ 41,150	[1]
Percentage of consolidated assets	100.00%		100.00%		100.00%
EQUITY METHOD AND OTHER INVESTMENTS	$ 1,840		$ 1,840		$ 2,905	[1]
Operating Segments [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 1,209	$ 1,230	$ 3,192	$ 3,168
Percentage of consolidated revenues	48.00%	50.00%	44.00%	42.00%
INTEREST EXPENSE	$ 49	$ 51	$ 145	$ 155
DEPRECIATION AND AMORTIZATION	$ 161	$ 152	$ 478	$ 446
Percentage of consolidated depreciation and amortization	49.00%	48.00%	49.00%	48.00%
INCOME TAX EXPENSE (BENEFIT)	$ 91	$ 75	$ 204	$ 217
EARNINGS (LOSSES)	183	170	419	443
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 959	$ 835
Percentage of consolidated expenditures for property, plant & equipment			31.00%	38.00%
ASSETS	$ 17,446		$ 17,446		$ 16,515
Percentage of consolidated assets	38.00%		38.00%		40.00%
Operating Segments [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 686	$ 620	$ 2,336	$ 2,448
Percentage of consolidated revenues	27.00%	25.00%	32.00%	33.00%
INTEREST EXPENSE	$ 25	$ 23	$ 71	$ 61
INTEREST INCOME	0	0	0	3
DEPRECIATION AND AMORTIZATION	$ 121	$ 116	$ 355	$ 342
Percentage of consolidated depreciation and amortization	37.00%	37.00%	37.00%	37.00%
INCOME TAX EXPENSE (BENEFIT)	$ 21	$ (20)	$ 75	$ 91
EARNINGS (LOSSES)	0	(8)	198	276
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 949	$ 946
Percentage of consolidated expenditures for property, plant & equipment			31.00%	42.00%
ASSETS	$ 13,148		$ 13,148		$ 12,104
Percentage of consolidated assets	29.00%		29.00%		29.00%
Operating Segments [Member] | Sempra South American Utilities [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 385	$ 373	$ 1,170	$ 1,151
Percentage of consolidated revenues	15.00%	15.00%	16.00%	15.00%
INTEREST EXPENSE	$ 9	$ 9	$ 29	$ 22
INTEREST INCOME	5	5	15	14
DEPRECIATION AND AMORTIZATION	$ 14	$ 12	$ 41	$ 37
Percentage of consolidated depreciation and amortization	4.00%	4.00%	4.00%	4.00%
INCOME TAX EXPENSE (BENEFIT)	$ 17	$ 16	$ 46	$ 50
Equity earnings (losses) net of tax	1	(3)	3	(4)
EARNINGS (LOSSES)	46	43	127	129
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 133	$ 105
Percentage of consolidated expenditures for property, plant & equipment			4.00%	5.00%
ASSETS	$ 3,488		$ 3,488		$ 3,235
Percentage of consolidated assets	8.00%		8.00%		8.00%
EQUITY METHOD AND OTHER INVESTMENTS	$ (1)		$ (1)		$ (4)
Operating Segments [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 196	$ 193	$ 481	$ 508
Percentage of consolidated revenues	8.00%	8.00%	7.00%	7.00%
INTEREST EXPENSE	$ 5	$ 7	$ 13	$ 18
INTEREST INCOME	2	1	5	5
DEPRECIATION AND AMORTIZATION	$ 15	$ 18	$ 47	$ 52
Percentage of consolidated depreciation and amortization	5.00%	6.00%	5.00%	6.00%
INCOME TAX EXPENSE (BENEFIT)	$ 142	$ (6)	$ 170	$ 7
Equity earnings (losses) net of tax	18	30	66	68
EARNINGS (LOSSES)	332	63	407	160
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 232	$ 185
Percentage of consolidated expenditures for property, plant & equipment			8.00%	8.00%
ASSETS	$ 6,359		$ 6,359		$ 3,783
Percentage of consolidated assets	14.00%		14.00%		9.00%
EQUITY METHOD AND OTHER INVESTMENTS	$ 108		$ 108		$ 519
Operating Segments [Member] | Sempra Renewables [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 12	$ 12	$ 25	$ 30
Percentage of consolidated revenues	1.00%	0.00%	0.00%	0.00%
INTEREST EXPENSE	$ 0	$ 1	$ 0	$ 3
INTEREST INCOME	1	2	2	3
DEPRECIATION AND AMORTIZATION	$ 1	$ 2	$ 4	$ 5
Percentage of consolidated depreciation and amortization	0.00%	0.00%	0.00%	0.00%
INCOME TAX EXPENSE (BENEFIT)	$ (7)	$ (9)	$ (29)	$ (37)
Equity earnings, before income tax	12	8	30	20
EARNINGS (LOSSES)	17	15	43	47
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 700	$ 47
Percentage of consolidated expenditures for property, plant & equipment			23.00%	2.00%
ASSETS	$ 2,112		$ 2,112		$ 1,441
Percentage of consolidated assets	5.00%		5.00%		4.00%
EQUITY METHOD AND OTHER INVESTMENTS	$ 819		$ 819		$ 855
Operating Segments [Member] | Sempra Natural Gas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 164	$ 160	$ 384	$ 512
Percentage of consolidated revenues	6.00%	6.00%	5.00%	7.00%
INTEREST EXPENSE	$ 11	$ 13	$ 33	$ 57
INTEREST INCOME	19	16	52	60
DEPRECIATION AND AMORTIZATION	$ 12	$ 12	$ 37	$ 36
Percentage of consolidated depreciation and amortization	4.00%	4.00%	4.00%	4.00%
INCOME TAX EXPENSE (BENEFIT)	$ 51	$ 0	$ (77)	$ 29
Equity earnings, before income tax	0	25	(26)	59
EARNINGS (LOSSES)	77	1	(104)	43
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 100	$ 61
Percentage of consolidated expenditures for property, plant & equipment			3.00%	3.00%
ASSETS	$ 5,377		$ 5,377		$ 5,566
Percentage of consolidated assets	12.00%		12.00%		13.00%
EQUITY METHOD AND OTHER INVESTMENTS	$ 838		$ 838		$ 1,460
Adjustments and eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ (1)	$ 0	$ (1)	$ (1)
Percentage of consolidated revenues	0.00%	0.00%	0.00%	0.00%
All other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
INTEREST EXPENSE	$ 68	$ 65	$ 214	$ 193
INTEREST INCOME	1	0	1	0
DEPRECIATION AND AMORTIZATION	$ 4	$ 3	$ 8	$ 7
Percentage of consolidated depreciation and amortization	1.00%	1.00%	1.00%	1.00%
INCOME TAX EXPENSE (BENEFIT)	$ (33)	$ (41)	$ (105)	$ (81)
EARNINGS (LOSSES)	(33)	(36)	(99)	(118)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT			$ 14	$ 48
Percentage of consolidated expenditures for property, plant & equipment			0.00%	2.00%
ASSETS	$ 640		$ 640		$ 734
Percentage of consolidated assets	1.00%		1.00%		2.00%
EQUITY METHOD AND OTHER INVESTMENTS	$ 76		$ 76		$ 75
Intersegment eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ (116)	$ (107)	$ (274)	$ (286)
Percentage of consolidated revenues	(5.00%)	(4.00%)	(4.00%)	(4.00%)
INTEREST EXPENSE	$ (31)	$ (26)	$ (84)	$ (93)
INTEREST INCOME	(21)	(18)	(56)	(62)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	$ (3,044)		$ (3,044)		$ (2,228)
Percentage of consolidated assets	(7.00%)		(7.00%)		(5.00%)
Intersegment eliminations [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 2	2	$ 5	7
Intersegment eliminations [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	21	19	56	55
Intersegment eliminations [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	26	24	80	73
Intersegment eliminations [Member] | Sempra Natural Gas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 67	$ 62	$ 133	$ 151
[1]	Derived from audited financial statements.

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - Subsequent Event [Member] - IEnova [Member] MXN / shares in Units, MXN in Millions, $ in Millions	Oct. 13, 2016USD ($)shares	Oct. 13, 2016MXNMXN / sharesMXN / $shares	Oct. 19, 2016
Subsequent Event [Line Items]
Public offering price per share | MXN / shares		MXN 80
Shares acquired in public offering | shares		83,125,000
Purchase price of shares acquired | $	$ 351
Shares issued in public offering | shares	380,000,000	380,000,000
Parent Ownership Percentage of Consolidated Subsidiary			66.40%
Proceeds from follow-on share offering	$ 1,570	MXN 29,860
Exchange rate | MXN / $		18.96
Bridge Loan [Member]
Subsequent Event [Line Items]
Repayments of Notes Payable | $	$ 1,150