Sempra (SRE) 10-Q 1 Nov 19 2019 Q3 Quarterly report Financial data

COVER

COVER - shares	9 Months Ended
	Sep. 30, 2019	Oct. 28, 2019
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2019
Document Transition Report	false
Entity File Number	1-14201
Entity Registrant Name	SEMPRA ENERGY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	33-0732627
Entity Address, Address Line One	488 8th Avenue
Entity Address, City or Town	San Diego,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92101
City Area Code	(619)
Local Phone Number	696-2000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Shares Outstanding		281,895,936
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001032208
San Diego Gas and Electric Company [Member]
Document Information [Line Items]
Entity File Number	1-03779
Entity Registrant Name	SAN DIEGO GAS & ELECTRIC COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1184800
Entity Address, Address Line One	8326 Century Park Court
Entity Address, City or Town	San Diego,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	92123
City Area Code	(619)
Local Phone Number	696-2000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000086521
Southern California Gas Company [Member]
Document Information [Line Items]
Entity File Number	1-01402
Entity Registrant Name	SOUTHERN CALIFORNIA GAS COMPANY
Entity Incorporation, State or Country Code	CA
Entity Tax Identification Number	95-1240705
Entity Address, Address Line One	555 West Fifth Street
Entity Address, City or Town	Los Angeles,
Entity Address, State or Province	CA
Entity Address, Postal Zip Code	90013
City Area Code	(213)
Local Phone Number	244-1200
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Central Index Key	0000092108
Common Stock [Member]
Document Information [Line Items]
Title of 12(b) Security	Sempra Energy Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
Convertible Preferred Stock Series A [Member]
Document Information [Line Items]
Title of 12(b) Security	Sempra Energy 6% Mandatory Convertible Preferred Stock, Series A, $100 liquidation preference
Trading Symbol	SREPRA
Security Exchange Name	NYSE
Convertible Preferred Stock Series B [Member]
Document Information [Line Items]
Title of 12(b) Security	Sempra Energy 6.75% Mandatory Convertible Preferred Stock, Series B, $100 liquidation preference
Trading Symbol	SREPRB
Security Exchange Name	NYSE
Sempra Energy 5.75% Junior Subordinated Notes Due 2079 [Member]
Document Information [Line Items]
Title of 12(b) Security	Sempra Energy 5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
REVENUES
Utilities operating revenue	$ 2,398	$ 2,102	$ 6,808	$ 6,112
Energy-related businesses	360	463	1,078	1,164
Total revenues	2,758	2,565	7,886	7,276
Operating expenses
Operation and maintenance	(845)	(792)	(2,515)	(2,275)
Depreciation and amortization	(402)	(366)	(1,174)	(1,115)
Franchise fees and other taxes	(127)	(131)	(369)	(352)
Operating expenses
Impairment losses	(43)	(4)	(43)	(1,304)
(Loss) gain on sale of assets	(3)	0	63	0
Other (expense) income, net	(7)	96	103	192
Interest income	22	19	64	66
Interest expense	(279)	(222)	(797)	(656)
Income (loss) from continuing operations before income taxes and equity earnings	448	345	1,235	(245)
Income tax (expense) benefit	(61)	(139)	(150)	221
Equity earnings	266	74	485	49
Income from continuing operations, net of income tax	653	280	1,570	25
Income from discontinued operations, net of income tax	256	54	292	137
Net income	909	334	1,862	162
Earnings attributable to noncontrolling interests	(60)	(24)	(146)	(12)
Mandatory convertible preferred stock dividends	(36)	(36)	(107)	(89)
Preferred dividends of subsidiary	0	0	(1)	(1)
Earnings attributable to common shares	$ 813	$ 274	$ 1,608	$ 60
Basic earnings (losses) per common share:
Earnings (losses) from continuing operations attributable to common shares (in usd per share)	$ 2.04	$ 0.83	$ 4.86	$ (0.21)
Earnings from discontinued operations attributable to common shares (in usd per share)	0.89	0.17	0.97	0.44
Earnings attributable to common shares (in usd per share)	$ 2.93	$ 1	$ 5.83	$ 0.23
Weighted-average common shares outstanding	277,360	273,944	275,684	265,963
Diluted earnings (losses) per common share:
Earnings (losses) from continuing operations attributable to common shares (in usd per share)	$ 2	$ 0.82	$ 4.79	$ (0.21)
Earnings from discontinued operations attributable to common shares (in usd per share)	0.84	0.17	0.95	0.44
Earnings from continuing operations attributable to common shares (n usd per share)	$ 2.84	$ 0.99	$ 5.74	$ 0.23
Weighted-average common share outstanding, diluted	295,789	275,907	279,809	265,963
Natural gas [Member]
Operating expenses
Operating expenses	$ (122)	$ (255)	$ (789)	$ (782)
Electric fuel and purchased power [Member]
Operating expenses
Operating expenses	(410)	(446)	(929)	(1,037)
Energy-related businesses [Member]
Operating expenses
Operating expenses	(94)	(119)	(265)	(258)
San Diego Gas and Electric Company [Member]
REVENUES
Electric	1,271	1,192	3,184	3,014
Natural gas	156	107	482	391
Utilities operating revenue	1,427	1,299	3,666	3,405
Operating expenses
Cost of electric fuel and purchased power	411	448	934	1,045
Cost of natural gas	23	30	136	110
Operation and maintenance	295	262	857	761
Depreciation and amortization	196	174	571	509
Franchise fees and other taxes	79	85	220	217
Total operating expenses	1,004	999	2,718	2,642
Operating income	423	300	948	763
Other (expense) income, net	19	24	60	77
Interest income	1	1	3	3
Interest expense	(106)	(56)	(311)	(161)
Income (loss) from continuing operations before income taxes and equity earnings	337	269	700	682
Income tax (expense) benefit	(71)	(53)	(111)	(151)
Net income	266	216	589	531
Earnings attributable to noncontrolling interests	(3)	(11)	(7)	(10)
Earnings attributable to common shares	263	205	582	521
Southern California Gas Company [Member]
REVENUES
Utilities operating revenue	975	802	3,142	2,700
Operating expenses
Cost of natural gas	101	224	660	663
Operation and maintenance	427	394	1,291	1,160
Depreciation and amortization	154	141	449	414
Franchise fees and other taxes	43	38	132	111
Impairment losses	(37)	0	(37)	0
Total operating expenses	762	797	2,569	2,348
Operating income	213	5	573	352
Other (expense) income, net	1	3	18	49
Interest income	0	0	1	1
Interest expense	(36)	(29)	(104)	(82)
Income (loss) from continuing operations before income taxes and equity earnings	178	(21)	488	320
Income tax (expense) benefit	(35)	7	(50)	(75)
Net income	143	(14)	438	245
Preferred dividends	0	0	(1)	(1)
Earnings attributable to common shares	$ 143	$ (14)	$ 437	$ 244

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Net income	$ 909	$ 334	$ 1,862	$ 162
Other comprehensive income (loss):
Total other comprehensive (loss) income	(142)	(9)	(190)	32
Pretax amount [Member]
Net income	762	477	1,898	23
Other comprehensive income (loss):
Foreign currency translation adjustments	(91)	(16)	(45)	(78)
Financial instruments	(55)	22	(213)	145
Pension and other postretirement benefits	(3)	(14)	22	(8)
Total other comprehensive (loss) income	(149)	(8)	(236)	59
Comprehensive income			1,662	82
Preferred dividends of subsidiary			(1)	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary	613	469	1,661	81
Income tax (expense) benefit [Member]
Net income	87	(167)	(182)	127
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0	0
Financial instruments	18	(7)	70	(45)
Pension and other postretirement benefits	1	4	(6)	3
Total other comprehensive (loss) income	19	(3)	64	(42)
Comprehensive income			(118)	85
Preferred dividends of subsidiary			0	0
Comprehensive (loss) income, after preferred dividends of subsidiary	106	(170)	(118)	85
Net-of-tax amount [Member]
Net income	849	310	1,716	150
Other comprehensive income (loss):
Foreign currency translation adjustments	(91)	(16)	(45)	(78)
Financial instruments	(37)	15	(143)	100
Pension and other postretirement benefits	(2)	(10)	16	(5)
Total other comprehensive (loss) income	(130)	(11)	(172)	17
Comprehensive income			1,544	167
Preferred dividends of subsidiary			(1)	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary	719	299	1,543	166
Noncontrolling Interests (after-tax) [Member]
Net income	60	24	146	12
Other comprehensive income (loss):
Foreign currency translation adjustments	(8)	(2)	(2)	(5)
Financial instruments	(4)	4	(16)	20
Pension and other postretirement benefits	0	0	0	0
Total other comprehensive (loss) income	(12)	2	(18)	15
Comprehensive income			128	27
Preferred dividends of subsidiary			0	0
Comprehensive (loss) income, after preferred dividends of subsidiary	48	26	128	27
Total [Member]
Net income	909	334	1,862	162
Other comprehensive income (loss):
Foreign currency translation adjustments	(99)	(18)	(47)	(83)
Financial instruments	(41)	19	(159)	120
Pension and other postretirement benefits	(2)	(10)	16	(5)
Total other comprehensive (loss) income	(142)	(9)	(190)	32
Comprehensive income			1,672	194
Preferred dividends of subsidiary			(1)	(1)
Comprehensive (loss) income, after preferred dividends of subsidiary	767	325	1,671	193
San Diego Gas and Electric Company [Member]
Net income	266	216	589	531
Other comprehensive income (loss):
Total other comprehensive (loss) income	1	(4)	3	1
San Diego Gas and Electric Company [Member] | Pretax amount [Member]
Net income	334	258	693	672
Other comprehensive income (loss):
Financial instruments	0	0	0	0
Pension and other postretirement benefits		(8)	1	(8)
Total other comprehensive (loss) income	0	(8)	1	(8)
Comprehensive (loss) income, after preferred dividends of subsidiary	334	250	694	664
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit [Member]
Net income	(71)	(53)	(111)	(151)
Other comprehensive income (loss):
Financial instruments	0	0	0	0
Pension and other postretirement benefits		2	0	2
Total other comprehensive (loss) income	0	2	0	2
Comprehensive (loss) income, after preferred dividends of subsidiary	(71)	(51)	(111)	(149)
San Diego Gas and Electric Company [Member] | Net-of-tax amount [Member]
Net income	263	205	582	521
Other comprehensive income (loss):
Financial instruments	0	0	0	0
Pension and other postretirement benefits		(6)	1	(6)
Total other comprehensive (loss) income	0	(6)	1	(6)
Comprehensive (loss) income, after preferred dividends of subsidiary	263	199	583	515
San Diego Gas and Electric Company [Member] | Noncontrolling Interests (after-tax) [Member]
Net income	3	11	7	10
Other comprehensive income (loss):
Financial instruments	1	2	2	7
Pension and other postretirement benefits		0	0	0
Total other comprehensive (loss) income	1	2	2	7
Comprehensive (loss) income, after preferred dividends of subsidiary	4	13	9	17
San Diego Gas and Electric Company [Member] | Total [Member]
Net income	266	216	589	531
Other comprehensive income (loss):
Financial instruments	1	2	2	7
Pension and other postretirement benefits		(6)	1	(6)
Total other comprehensive (loss) income	1	(4)	3	1
Comprehensive (loss) income, after preferred dividends of subsidiary	267	212	592	532
Southern California Gas Company [Member]
Net income	143	(14)	438	245
Other comprehensive income (loss):
Total other comprehensive (loss) income	1		5	1
Southern California Gas Company [Member] | Pretax amount [Member]
Net income	178	(21)	488	320
Other comprehensive income (loss):
Financial instruments	1		1
Pension and other postretirement benefits			6	1
Total other comprehensive (loss) income	1		7	1
Comprehensive (loss) income, after preferred dividends of subsidiary	179	(21)	495	321
Southern California Gas Company [Member] | Income tax (expense) benefit [Member]
Net income	(35)	7	(50)	(75)
Other comprehensive income (loss):
Financial instruments	0		0
Pension and other postretirement benefits			(2)	0
Total other comprehensive (loss) income	0		(2)	0
Comprehensive (loss) income, after preferred dividends of subsidiary	(35)	7	(52)	(75)
Southern California Gas Company [Member] | Net-of-tax amount [Member]
Net income	143	(14)	438	245
Other comprehensive income (loss):
Financial instruments	1		1
Pension and other postretirement benefits			4	1
Total other comprehensive (loss) income	1		5	1
Comprehensive (loss) income, after preferred dividends of subsidiary	$ 144	$ (14)	$ 443	$ 246

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 106	$ 102	[1]
Restricted cash	28	35	[1]
Accounts receivable – trade, net	976	1,215	[1]
Accounts receivable – other, net	455	320	[1]
Dividends receivable from discontinued operations	422	0	[1]
Due from unconsolidated affiliates	40	37	[1]
Income taxes receivable	98	60	[1]
Inventories	270	258	[1]
Regulatory assets	183	138	[1]
Greenhouse gas allowances	59	59	[1]
Other	309	249	[1]
Total current assets	3,666	3,645	[1]
Other assets:
Restricted cash	3	21	[1]
Due from unconsolidated affiliates	712	644	[1]
Regulatory assets	1,942	1,589	[1]
Nuclear decommissioning trusts	1,049	974	[1]
Investment in Oncor Holdings	11,145	9,652	[1]
Other investments	2,076	2,320	[1]
Goodwill	1,602	1,602	[1]
Other intangible assets	216	224	[1]
Dedicated assets in support of certain benefit plans	439	416	[1]
Insurance receivable for Aliso Canyon costs	354	461	[1]
Deferred income taxes	157	141	[1]
Greenhouse gas allowances	483	289	[1]
Right-of-use assets – operating leases	595
Wildfire fund	381	0	[1]
Assets held for sale in discontinued operations	3,395	3,259	[1]
Sundry	850	962	[1]
Total other assets	25,399	22,554	[1]
Property, plant and equipment:
Property, plant and equipment	48,139	46,615	[1]
Less accumulated depreciation and amortization	(12,619)	(12,176)	[1]
Property, plant and equipment, net	35,520	34,439	[1]
Total assets	64,585	60,638	[1]
Current liabilities:
Short-term debt	3,588	2,024	[1]
Accounts payable – trade	959	1,160	[1]
Accounts payable – other	170	138	[1]
Due to unconsolidated affiliates	12	10	[1]
Dividends and interest payable	517	480	[1]
Accrued compensation and benefits	362	440	[1]
Regulatory liabilities	445	105	[1]
Current portion of long-term debt and finance leases	1,623	1,644	[1]
Reserve for Aliso Canyon costs	45	160	[1]
Greenhouse gas obligations	59	59	[1]
Liabilities held for sale in discontinued operations	804	368	[1]
Other	914	935	[1]
Total current liabilities	9,498	7,523	[1]
Long-term debt and finance leases	20,995	20,903	[1]
Deferred credits and other liabilities:
Due to unconsolidated affiliates	39	37	[1]
Pension and other postretirement benefit plan obligations, net of plan assets	1,120	1,143	[1]
Deferred income taxes	2,360	2,321	[1]
Deferred investment tax credits	22	24	[1]
Regulatory liabilities	3,823	4,016	[1]
Asset retirement obligations	2,824	2,786	[1]
Greenhouse gas obligations	281	131	[1]
Liabilities held for sale in discontinued operations	1,023	1,013	[1]
Deferred credits and other	2,049	1,493	[1]
Total deferred credits and other liabilities	13,541	12,964	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Common stock	6,374	5,540	[1]
Retained earnings	10,966	10,104	[1]
Accumulated other comprehensive income (loss)	(978)	(764)	[1]
Total shareholders’ equity	18,620	17,138	[1]
Preferred stock of subsidiary	20	20	[1]
Other noncontrolling interests	1,911	2,090	[1]
Total equity	20,551	19,248	[1]
Total liabilities and equity	64,585	60,638	[1]
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	24	8	[1]
Restricted cash	0	11	[1]
Accounts receivable – trade, net	446	368	[1]
Accounts receivable – other, net	106	106	[1]
Due from unconsolidated affiliates	1	0	[1]
Inventories	92	102	[1]
Prepaid expenses	160	74	[1]
Regulatory assets	171	123	[1]
Fixed-price contracts and other derivatives	26	82	[1]
Greenhouse gas allowances	15	15	[1]
Other	25	5	[1]
Total current assets	1,066	894	[1]
Other assets:
Restricted cash	0	18	[1]
Regulatory assets	519	454	[1]
Nuclear decommissioning trusts	1,049	974	[1]
Greenhouse gas allowances	194	155	[1]
Right-of-use assets – operating leases	126
Wildfire fund	381	0	[1]
Sundry	390	420	[1]
Total other assets	2,659	2,021	[1]
Property, plant and equipment:
Property, plant and equipment	22,038	21,662	[1]
Less accumulated depreciation and amortization	(5,427)	(5,352)	[1]
Property, plant and equipment, net	16,611	16,310	[1]
Total assets	20,336	19,225	[1]
Current liabilities:
Short-term debt	0	291	[1]
Accounts payable	444	439	[1]
Due to unconsolidated affiliates	26	61	[1]
Accrued compensation and benefits	103	117	[1]
Accrued franchise fees	46	64	[1]
Regulatory liabilities	118	53	[1]
Current portion of long-term debt and finance leases	55	81	[1]
Customer deposits	72	70	[1]
Greenhouse gas obligations	15	15	[1]
Asset retirement obligations	98	96	[1]
Other	268	141	[1]
Total current liabilities	1,245	1,428	[1]
Long-term debt and finance leases	6,307	6,138	[1]
Deferred credits and other liabilities:
Pension and other postretirement benefit plan obligations, net of plan assets	213	212	[1]
Deferred income taxes	1,715	1,616	[1]
Deferred investment tax credits	15	16	[1]
Regulatory liabilities	2,400	2,404	[1]
Asset retirement obligations	770	778	[1]
Greenhouse gas obligations	65	30	[1]
Deferred credits and other	686	488	[1]
Total deferred credits and other liabilities	5,864	5,544	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Preferred stock	0	0	[1]
Common stock	1,660	1,338	[1]
Retained earnings	5,271	4,687	[1]
Accumulated other comprehensive income (loss)	(11)	(10)	[1]
Total shareholders’ equity	6,920	6,015	[1]
Other noncontrolling interests	0	100	[1]
Total equity	6,920	6,115	[1]
Total liabilities and equity	20,336	19,225	[1]
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	5	18	[1]
Accounts receivable – trade, net	356	634	[1]
Accounts receivable – other, net	67	97	[1]
Due from unconsolidated affiliates	0	7	[1]
Inventories	134	134	[1]
Regulatory assets	7	12	[1]
Greenhouse gas allowances	37	37	[1]
Other	39	31	[1]
Total current assets	645	970	[1]
Other assets:
Regulatory assets	1,341	1,051	[1]
Insurance receivable for Aliso Canyon costs	354	461	[1]
Greenhouse gas allowances	261	116	[1]
Right-of-use assets – operating leases	99
Sundry	360	352	[1]
Total other assets	2,415	1,980	[1]
Property, plant and equipment:
Property, plant and equipment	18,904	18,138	[1]
Less accumulated depreciation and amortization	(5,941)	(5,699)	[1]
Property, plant and equipment, net	12,963	12,439	[1]
Total assets	16,023	15,389	[1]
Current liabilities:
Short-term debt	108	256	[1]
Accounts payable – trade	320	556	[1]
Accounts payable – other	111	93	[1]
Due to unconsolidated affiliates	187	34	[1]
Accrued compensation and benefits	146	159	[1]
Regulatory liabilities	327	52	[1]
Current portion of long-term debt and finance leases	5	3	[1]
Customer deposits	70	101	[1]
Reserve for Aliso Canyon costs	45	160	[1]
Greenhouse gas obligations	37	37	[1]
Asset retirement obligations	89	90	[1]
Other	223	217	[1]
Total current liabilities	1,668	1,758	[1]
Long-term debt and finance leases	3,784	3,427	[1]
Deferred credits and other liabilities:
Pension obligation, net of plan assets	747	760	[1]
Deferred income taxes	1,225	1,177	[1]
Deferred investment tax credits	7	8	[1]
Regulatory liabilities	1,423	1,612	[1]
Asset retirement obligations	2,015	1,973	[1]
Greenhouse gas obligations	184	86	[1]
Deferred credits and other	422	330	[1]
Total deferred credits and other liabilities	6,023	5,946	[1]
Commitments and contingencies (Note 11)			[1]
Equity:
Preferred stock	22	22	[1]
Common stock	866	866	[1]
Retained earnings	3,679	3,390	[1]
Accumulated other comprehensive income (loss)	(19)	(20)	[1]
Total shareholders’ equity	4,548	4,258	[1]
Total equity	4,548	4,258
Total liabilities and equity	16,023	15,389	[1]
Convertible Preferred Stock Series A [Member]
Equity:
Preferred stock	1,693	1,693	[1]
Convertible Preferred Stock Series B [Member]
Equity:
Preferred stock	565	565	[1]
Disposal Group Held-for-sale [Member]
Current assets:
Assets held for sale	0	713	[1]
Discontinued Operations, Held-for-sale [Member]
Current assets:
Assets held for sale	$ 720	$ 459	[1]
[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	9 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Property, plant and equipment, net	$ 35,520	$ 34,439	[1]
Current portion of long-term debt and finance leases	1,623	1,644	[1]
Long-term debt and finance leases	$ 20,995	$ 20,903	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares authorized (in shares)	750,000,000	750,000,000
Common stock, shares outstanding (in shares)	282,000,000	274,000,000
Otay Mesa VIE [Member]
Property, plant and equipment, net		$ 295
Current portion of long-term debt and finance leases		28
Long-term debt and finance leases		190
San Diego Gas and Electric Company [Member]
Property, plant and equipment, net	$ 16,611	16,310	[1]
Current portion of long-term debt and finance leases	55	81	[1]
Long-term debt and finance leases	$ 6,307	$ 6,138	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Common stock, shares outstanding (in shares)	117,000,000	117,000,000
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Property, plant and equipment, net		$ 295
Current portion of long-term debt and finance leases		28
Long-term debt and finance leases		190
Southern California Gas Company [Member]
Property, plant and equipment, net	$ 12,963	12,439	[1]
Current portion of long-term debt and finance leases	5	3	[1]
Long-term debt and finance leases	$ 3,784	$ 3,427	[1]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares issued (in shares)	1,000,000	1,000,000
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	91,000,000	91,000,000
Convertible Preferred Stock Series A [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred Stock, Dividend Rate, Percentage	6.00%	6.00%
Preferred stock, shares issued (in shares)	17,250,000	17,250,000
Preferred stock, shares outstanding (in shares)	17,250,000	17,250,000
Convertible Preferred Stock Series B [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred Stock, Dividend Rate, Percentage	6.75%	6.75%
Preferred stock, shares issued (in shares)	5,750,000	5,750,000
Preferred stock, shares outstanding (in shares)	5,750,000	5,750,000
[1]	Derived from audited financial statements.

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	3 Months Ended		9 Months Ended		21 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 909	$ 334	$ 1,862	$ 162
Less: Income from discontinued operations, net of income tax	(256)	(54)	(292)	(137)
Income from continuing operations, net of income tax	653	280	1,570	25
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	402	366	1,174	1,115
Deferred income taxes and investment tax credits			12	(328)
Impairment losses	43	4	43	1,304
Gain on sale of assets	3	0	(63)	0
Equity earnings			(485)	(49)
Share-based compensation expense			56	50
Fixed-price contracts and other derivatives			(12)	(44)
Other			16	36
Intercompany activities with discontinued operations, net			184	72
Net change in other working capital components			(200)	491
Insurance receivable for Aliso Canyon costs			107	(56)
Wildfire fund, current and noncurrent			(323)	0
Changes in other noncurrent assets and liabilities, net			(250)	(177)
Net cash provided by continuing operations			1,829	2,439
Net cash provided by discontinued operations			289	220
Net cash provided by operating activities			2,118	2,659
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment			(2,590)	(2,654)
Expenditures for investments and acquisition			(1,449)	(9,921)
Proceeds from sale of assets			899	1
Decrease in cash from deconsolidation of Otay Mesa VIE			(8)	0
Purchases of nuclear decommissioning trust assets			(728)	(703)
Proceeds from sales of nuclear decommissioning trust assets			728	703
Advances to unconsolidated affiliates			(16)	(81)
Repayments of advances to unconsolidated affiliates			12	4
Intercompany activities with discontinued operations, net			(257)	(18)
Other			33	38
Net cash used in continuing operations			(3,376)	(12,631)
Net cash used in discontinued operations			(63)	(161)
Net cash used in investing activities			(3,439)	(12,792)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid			(734)	(645)
Preferred dividends paid			(107)	(53)
Issuances of mandatory convertible preferred stock, net			0	2,259
Issuances of common stock, net			757	2,261
Repurchases of common stock			(23)	(20)
Issuances of debt (maturities greater than 90 days)			3,269	8,458
Payments on debt (maturities greater than 90 days) and finance leases			(2,500)	(2,836)
Increase (decrease) in short-term debt, net			888	715
Proceeds from sale of noncontrolling interests, net			5	90
Purchases of noncontrolling interests			(30)	0
Contributions from (distributions to) noncontrolling interests, net			171	(88)
Intercompany activities with discontinued operations, net			(128)	70
Other			(42)	(112)
Net cash provided by continuing operations			1,526	10,099
Net cash provided by (used in) discontinued operations			49	(34)
Net cash provided by financing activities			1,575	10,065
Effect of exchange rate changes in continuing operations			0	0
Effect of exchange rate changes in discontinued operations			(3)	(8)
Effect of exchange rate changes on cash, cash equivalents and restricted cash			(3)	(8)
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations			251	(76)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1			246	364	$ 364
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	497	288	497	288	497
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized			766	555
Income tax payments, net of refunds			289	69
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Assets acquired			0	9,670
Liabilities assumed			0	(104)
Cash paid			0	9,566
Accrued interest receivable from unconsolidated affiliate	55	45	55	45	55
Accrued capital expenditures			390	396
Increase in finance lease obligations for investment in property, plant and equipment			27	7
Common dividends receivable from discontinued operations	422	0	422	0	422
Common dividends issued in stock	41	41	41	41	41
Preferred stock [Member]
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	36	36	36	36	36
Common Stock [Member]
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Dividends declared but not paid	272	244	272	244	272
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	266	216	589	531
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	196	174	571	509
Deferred income taxes and investment tax credits			(20)	88
Other			7	(31)
Net change in other working capital components			(60)	150
Wildfire fund, current and noncurrent			(323)	0
Changes in other noncurrent assets and liabilities, net			(10)	(16)
Net cash provided by operating activities			754	1,231
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment			(1,071)	(1,194)
Decrease in cash from deconsolidation of Otay Mesa VIE			(8)	0
Purchases of nuclear decommissioning trust assets			(728)	(703)
Proceeds from sales of nuclear decommissioning trust assets			728	703
Increase in loans to affiliate, net			(25)	0
Other			7	0
Net cash used in investing activities			(1,097)	(1,194)
CASH FLOWS FROM FINANCING ACTIVITIES
Equity contribution from Sempra Energy			322	0
Issuances of debt (maturities greater than 90 days)			400	398
Payments on debt (maturities greater than 90 days) and finance leases			(269)	(204)
Increase (decrease) in short-term debt, net			(291)	(205)
Contributions from (distributions to) noncontrolling interests, net			172	(8)
Debt issuance costs			(4)	(3)
Net cash provided by financing activities			330	(22)
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations			(13)	15
Cash, cash equivalents and restricted cash, including discontinued operations, January 1			37	29	29
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	24	44	24	44	24
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized			285	139
Income tax payments, net of refunds			131	79
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures			117	113
Increase in finance lease obligations for investment in property, plant and equipment			12	0
Dividends declared but not paid	0	250	0	250	0
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	143	(14)	438	245
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	154	141	449	414
Deferred income taxes and investment tax credits			(79)	70
Impairment losses	37	0	37	0
Other			(5)	(4)
Net change in other working capital components			194	391
Insurance receivable for Aliso Canyon costs			107	(56)
Changes in other noncurrent assets and liabilities, net			(328)	(178)
Net cash provided by operating activities			813	882
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment			(1,019)	(1,127)
Increase in loans to affiliate, net			0	(88)
Other			1	6
Net cash used in investing activities			(1,018)	(1,209)
CASH FLOWS FROM FINANCING ACTIVITIES
Preferred dividends paid by subsidiary			(1)	(1)
Issuances of debt (maturities greater than 90 days)			349	949
Payments on debt (maturities greater than 90 days) and finance leases			(4)	(500)
Increase (decrease) in short-term debt, net			(148)	(116)
Debt issuance costs			(4)	(9)
Net cash provided by financing activities			192	323
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations			(13)	(4)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1			18	8	8
Cash, cash equivalents and restricted cash, including discontinued operations, September 30	5	4	5	4	5
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized			92	71
Income tax payments, net of refunds			115	(1)
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures			167	178
Increase in finance lease obligations for investment in property, plant and equipment			15	7
Dividends declared but not paid	$ 150	$ 50	$ 150	$ 50	$ 150

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total		Series A Preferred Stock [Member]	Series B Preferred Stock [Member]	Preferred stock [Member]	Preferred stock [Member]Series A Preferred Stock [Member]	Preferred stock [Member]Series B Preferred Stock [Member]	Common Stock [Member]	Retained earnings [Member]	Retained earnings [Member]Series A Preferred Stock [Member]	Retained earnings [Member]Series B Preferred Stock [Member]	Accumulated other comprehensive income (loss) [Member]	Shareholders' equity [Member]	Shareholders' equity [Member]Series A Preferred Stock [Member]	Shareholders' equity [Member]Series B Preferred Stock [Member]	Noncontrolling Interest [Member]	San Diego Gas and Electric Company [Member]		San Diego Gas and Electric Company [Member]Common Stock [Member]	San Diego Gas and Electric Company [Member]Retained earnings [Member]	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss) [Member]	San Diego Gas and Electric Company [Member]Shareholders' equity [Member]	San Diego Gas and Electric Company [Member]Noncontrolling Interest [Member]	Southern California Gas Company [Member]	Southern California Gas Company [Member]Preferred stock [Member]	Southern California Gas Company [Member]Common Stock [Member]	Southern California Gas Company [Member]Retained earnings [Member]	Southern California Gas Company [Member]Accumulated other comprehensive income (loss) [Member]
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative-effect adjustment from change in accounting principle	$ (1)								$ 2			$ (3)	$ (1)
Beginning Balance at Dec. 31, 2017	15,140				$ 0			$ 3,149	10,147			(626)	12,670			$ 2,470	$ 5,626		$ 1,338	$ 4,268	$ (8)	$ 5,598	$ 28	$ 3,907	$ 22	$ 866	$ 3,040	$ (21)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	162								150				150			12	531			521		521	10	245			245
Other comprehensive (loss) income	32											17	17			15	1				(6)	(6)	7	1				1
Share-based compensation expense	50							50					50
Dividends declared:
Preferred dividends			$ (79)	$ (10)						$ (79)	$ (10)			$ (79)	$ (10)									(1)			(1)
Common stock dividends declared	(724)								(724)				(724)				(250)			(250)		(250)		(50)			(50)
Preferred dividends of subsidiary	(1)								(1)				(1)
Issuances of stock	2,302		1,693	566		$ 1,693	$ 566	2,302					2,302	1,693	566
Repurchases of common stock	(20)							(20)					(20)
Noncontrolling interest activities:
Noncontrolling interests activities: Contributions	3															3	2						2
Noncontrolling interests activities: Distributions	(104)															(104)	(10)						(10)
Noncontrolling interests activities: Purchases	(1)															(1)
Noncontrolling interests activities: Sales	90							4					4			86
Noncontrolling interest activities: Acquisition	13															13
Ending balance at Sep. 30, 2018	19,111				2,259			5,485	9,485			(612)	16,617			2,494	5,900		1,338	4,539	(14)	5,863	37	4,102	22	866	3,234	(20)
Beginning Balance at Jun. 30, 2018	18,364				1,693			5,279	9,455			(601)	15,826			2,538	5,943		1,338	4,584	(8)	5,914	29	4,166	22	866	3,298	(20)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	334								310				310			24	216			205		205	11	(14)			(14)
Other comprehensive (loss) income	(9)											(11)	(11)			2	(4)				(6)	(6)	2
Share-based compensation expense	17							17					17
Dividends declared:
Preferred dividends			(26)	(10)						(26)	(10)			(26)	(10)									0			0
Common stock dividends declared	(244)								(244)				(244)				(250)			(250)		(250)		(50)			(50)
Preferred dividends of subsidiary	0
Issuances of stock	185			566			$ 566	185					185		566
Noncontrolling interest activities:
Noncontrolling interests activities: Contributions	2															2	1						1
Noncontrolling interests activities: Distributions	(86)															(86)	(6)						(6)
Noncontrolling interests activities: Sales	5							4					4			1
Noncontrolling interest activities: Acquisition	13															13
Ending balance at Sep. 30, 2018	19,111				2,259			5,485	9,485			(612)	16,617			2,494	5,900		1,338	4,539	(14)	5,863	37	4,102	22	866	3,234	(20)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative-effect adjustment from change in accounting principle	15								57			(42)	15				0			2	(2)	0		(2)			2	(4)
Beginning Balance at Dec. 31, 2018	19,248	[1]			2,258			5,540	10,104			(764)	17,138			2,110	6,115	[1]	1,338	4,687	(10)	6,015	100	4,258	22	866	3,390	(20)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	1,862								1,716				1,716			146	589			582		582	7	438			438
Other comprehensive (loss) income	(190)											(172)	(172)			(18)	3				1	1	2	5				5
Share-based compensation expense	56							56					56
Dividends declared:
Preferred dividends			(78)	(29)						(78)	(29)			(78)	(29)									(1)			(1)
Common stock dividends declared	(803)								(803)				(803)											(150)			(150)
Preferred dividends of subsidiary	(1)								(1)				(1)
Equity contribution																	322		322			322
Issuances of stock	798							798					798
Repurchases of common stock	(23)							(23)					(23)
Noncontrolling interest activities:
Noncontrolling interests activities: Contributions	175															175	175						175
Noncontrolling interests activities: Distributions	(17)							2					2			(19)	(3)						(3)
Noncontrolling interests activities: Purchases	(30)							(3)					(3)			(27)
Noncontrolling interests activities: Deconsolidation	(440)															(440)	(281)						(281)
Noncontrolling interests activities: Sales	5							4					4			1
Noncontrolling interest activities: Acquisition	3															3
Ending balance at Sep. 30, 2019	20,551				2,258			6,374	10,966			(978)	18,620			1,931	6,920		1,660	5,271	(11)	6,920	0	4,548	22	866	3,679	(19)
Beginning Balance at Jun. 30, 2019	19,434				2,258			5,605	10,425			(848)	17,440			1,994	6,438		1,338	5,008	(11)	6,335	103	4,554	22	866	3,686	(20)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	909								849				849			60	266			263		263	3	143			143
Other comprehensive (loss) income	(142)											(130)	(130)			(12)	1						1	1				1
Share-based compensation expense	17							17					17
Dividends declared:
Preferred dividends			$ (26)	$ (10)						$ (26)	$ (10)			$ (26)	$ (10)									0			0
Common stock dividends declared	(272)								(272)				(272)											(150)			(150)
Preferred dividends of subsidiary	0
Equity contribution																	322		322			322
Issuances of stock	751							751					751
Repurchases of common stock	(5)							(5)					(5)
Noncontrolling interest activities:
Noncontrolling interests activities: Contributions	175															175	175						175
Noncontrolling interests activities: Distributions	(5)							2					2			(7)	(1)						(1)
Noncontrolling interests activities: Purchases	(2)															(2)
Noncontrolling interests activities: Deconsolidation	(281)															(281)	(281)						(281)
Noncontrolling interests activities: Sales	5							4					4			1
Noncontrolling interest activities: Acquisition	3															3
Ending balance at Sep. 30, 2019	$ 20,551				$ 2,258			$ 6,374	$ 10,966			$ (978)	$ 18,620			$ 1,931	$ 6,920		$ 1,660	$ 5,271	$ (11)	$ 6,920	$ 0	$ 4,548	$ 22	$ 866	$ 3,679	$ (19)
[1]	Derived from audited financial statements.

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Dividends declared per share of common stock (in dollars per share)	$ 0.96	$ 0.90	$ 2.90	$ 2.69
San Diego Gas and Electric Company [Member]
Dividends declared per share of common stock (in dollars per share)		2.14		2.14
Southern California Gas Company [Member]
Dividends declared per share of preferred stock (in dollars per share)	0.38	0.38	1.13	1.13
Dividends declared per share of common stock (in dollars per share)	1.64	0.55	1.64	0.55
Series A Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)	1.50	1.50	4.50	4.60
Series B Preferred Stock [Member]
Dividends declared per share of preferred stock (in dollars per share)	$ 1.68	$ 1.73	$ 5.06	$ 1.73

GENERAL INFORMATION AND OTHER F

GENERAL INFORMATION AND OTHER FINANCIAL DATA	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
GENERAL INFORMATION AND OTHER FINANCIAL DATA	GENERAL INFORMATION AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Energy Sempra Energy’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based energy-services holding company, and its consolidated subsidiaries and VIEs. Sempra Global is the holding company for most of our subsidiaries that are not subject to California or Texas utility regulation. Sempra Energy’s businesses were managed within six separate reportable segments until April 2019 and five separate reportable segments thereafter, which we discuss in Note 12. In the first quarter of 2019, our Sempra LNG & Midstream segment was renamed “Sempra LNG.” This segment name change had no impact on our historical position, results of operations, cash flow or segment level results previously reported. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E was the primary beneficiary until August 23, 2019, at which time SDG&E deconsolidated the VIE, as we discuss below in “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. In this report, we refer to SDG&E and SoCalGas collectively as the California Utilities. 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 (until deconsolidation of the VIE on August 23, 2019); and ▪ the Condensed Financial Statements and related Notes of SoCalGas. We have prepared the Condensed Consolidated Financial Statements in conformity with 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, 2019 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, 2018 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2018 Consolidated Financial Statements in the Annual Report, which for Sempra Energy has been retrospectively adjusted for discontinued operations, as we discuss below. 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 SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. 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. Discontinued Operations On January 25, 2019, our board of directors approved a plan to sell our South American businesses based on our strategic focus on North America. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, as the planned sales represent a strategic shift that will have a major effect on our operations and financial results. Throughout this report, the financial information for all periods presented has been adjusted to reflect the presentation of these businesses as discontinued operations, which we discuss further in Note 5. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted. Regulated Operations The California Utilities and Sempra Mexico’s natural gas distribution utility, Ecogas, prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. We discuss the effects of regulation and revenue recognition at our utilities in Notes 1 and 3 of the Notes to Consolidated Financial Statements in the Annual Report. Our Sempra Texas Utilities segment is comprised of our equity method investments in holding companies that own interests in regulated electric transmission and distribution utilities in Texas and prepare their financial statements in accordance with the provisions of U.S. GAAP governing rate-regulated operations. Our Sempra Mexico segment includes the operating companies of our subsidiary, IEnova. Certain business activities at IEnova are regulated by the Comisión Reguladora de Energía (Energy Regulatory Commission of Mexico) and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects under construction at IEnova that meet the regulatory accounting requirements of U.S. GAAP record the impact of AFUDC related to equity. We discuss AFUDC below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. CASH, CASH EQUIVALENTS AND RESTRICTED CASH The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported on the Condensed Consolidated Balance Sheets to the sum of such amounts reported on the Condensed Consolidated Statements of Cash Flows. We provide information about the nature of restricted cash in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) September 30, December 31, 2019 2018 Sempra Energy Consolidated: Cash and cash equivalents $ 106 $ 102 Restricted cash, current 28 35 Restricted cash, noncurrent 3 21 Cash, cash equivalents and restricted cash in discontinued operations 360 88 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 497 $ 246 SDG&E: Cash and cash equivalents $ 24 $ 8 Restricted cash, current — 11 Restricted cash, noncurrent — 18 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 24 $ 37 INVENTORIES The following table presents the components of inventories by segment. INVENTORY BALANCES (Dollars in millions) Natural gas LNG Materials and supplies Total September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 SDG&E $ 1 $ — $ — $ — $ 91 $ 102 $ 92 $ 102 SoCalGas 87 92 — — 47 42 134 134 Sempra Mexico — — 6 4 16 15 22 19 Sempra LNG 22 3 — — — — 22 3 Sempra Energy Consolidated $ 110 $ 95 $ 6 $ 4 $ 154 $ 159 $ 270 $ 258 WILDFIRE FUND On July 12, 2019, AB 1054 and AB 111 (together, the Wildfire Legislation) were signed into law. The Wildfire Legislation addresses certain issues related to catastrophic wildfires in the State of California and their impact on electric IOUs. Investor-owned gas distribution utilities such as SoCalGas are not covered by this legislation. The issues addressed include wildfire mitigation, cost recovery standards and requirements, a wildfire fund, a cap on liability, and the establishment of a wildfire safety board. The Wildfire Legislation requires SDG&E to install at least $215 million of fire risk mitigation capital improvements, which will be the first $215 million of capital included in its wildfire mitigation plan, and recover its securitized financing costs without a ROE. The Wildfire Legislation establishes a revised legal standard for the recovery of wildfire costs (Revised Prudent Manager Standard) and establishes a fund (the Wildfire Fund) to provide liquidity to SDG&E, PG&E and Edison (each a California electric IOU) to pay IOU wildfire-related claims in the event that the governmental agency responsible for determining causation determines the applicable IOU’s equipment caused the ignition of a wildfire, the primary insurance coverage is exceeded and certain other conditions are satisfied. The primary purpose of the Wildfire Fund is to pool resources provided by shareholders and ratepayers of the IOUs and make those resources available to reimburse the IOUs for third-party wildfire claims incurred after July 12, 2019, the effective date of the Wildfire Legislation, subject to certain limitations. An IOU may seek payment from the Wildfire Fund for settled or adjudicated third-party damage claims arising from certain wildfires that exceed, in aggregate in a calendar year, the greater of $1 billion or the IOU’s required amount of insurance coverage as recommended by the Wildfire Fund’s administrator. Wildfire claims approved by the Wildfire Fund’s administrator will be paid by the Wildfire Fund to the IOU to the extent funds are available. These utilized funds will be subject to review by the CPUC, which will make a determination as to the degree an IOU’s conduct related to an ignition of a wildfire was prudent or imprudent. The Revised Prudent Manager Standard requires that the CPUC apply clear standards when reviewing wildfire liability losses paid when determining the reasonableness of an IOU’s conduct related to an ignition. Under this standard, the conduct under review related to the ignition may include factors within and beyond the IOU’s control, including humidity, temperature and winds. Costs and expenses may be allocated for cost recovery in full or in part. Also, under this standard, an IOU’s conduct will be deemed reasonable if a valid annual safety certification is in place at the time of the ignition, unless a serious doubt is raised, in which case the burden shifts to the utility to dispel that doubt. The IOUs will receive an annual safety certification from the CPUC if they meet various requirements. If an IOU has maintained a valid annual safety certification, to the extent it is found to be imprudent, claims will be reimbursable by the IOU to the Wildfire Fund up to a cap based on the IOU’s rate base. The aggregate requirement to reimburse the Wildfire Fund over a trailing three calendar year period is capped at 20 percent of the equity portion of an IOU’s electric transmission and distribution rate base in the year of the prudency determination. SDG&E received its annual safety certification from the CPUC on July 26, 2019, which is valid for 12 months. Based on 2018 rate base, the initial liability cap for SDG&E is approximately $825 million , which will be adjusted annually. The liability cap will apply on a rolling three-year basis so long as future annual safety certifications are received and the Wildfire Fund has not been terminated, which could occur if funds are exhausted. Amounts in excess of the liability cap and amounts that are determined to be prudently incurred do not need to be reimbursed by an IOU to the Wildfire Fund. The Wildfire Fund does not have a specified term and coverage will continue until the assets of the Wildfire Fund are exhausted and the Wildfire Fund is terminated, in which case, the remaining funds will be transferred to California’s general fund to be used for fire risk mitigation programs. The Wildfire Fund could initially be funded up to $10.5 billion by a loan from the State of California Surplus Money Investment Fund, $2 billion of which was loaned to the Wildfire Fund in August 2019. Such lending will subsequently be financed through an anticipated DWR bond, securitized through a dedicated surcharge on ratepayers’ bills attributable to the DWR. In October 2019, the CPUC adopted a decision authorizing a non-bypassable charge to be collected by the IOUs to support the anticipated DWR bond issuance authorized by AB 1054. The CPUC decision also determined that ratepayers of non-participating electrical corporations shall not pay the non-bypassable charge. PG&E has agreed to participate in the Wildfire Fund, subject to bankruptcy court approval. Accordingly, if PG&E is unable to participate in the Wildfire Fund, its customers will not pay the non-bypassable charge, resulting in significantly lower Wildfire Fund contributions from ratepayers than the anticipated $10.5 billion . The Wildfire Fund could also be funded by up to $7.5 billion in initial shareholder contributions from the IOUs (SDG&E’s share is $322.5 million , PG&E’s share is $4.8 billion and Edison’s share is $2.4 billion ). The IOUs could also be required to make annual shareholder contributions to the Wildfire Fund with an aggregate value of $3 billion over a 10 -year period (SDG&E’s share is $129 million , PG&E’s share is $1.9 billion and Edison’s share is $945 million ). If PG&E is unable to participate in the Wildfire Fund, SDG&E’s and Edison’s aggregate shareholder contributions to the Wildfire Fund will not change and are expected to total approximately $3.8 billion . When estimating the period of benefit of the Wildfire Fund asset that we discuss below, we assume PG&E will participate in the Wildfire Fund. The contributions are not subject to rate recovery. SDG&E paid its initial shareholder contribution of $322.5 million to the Wildfire Fund in September 2019. SDG&E funded this contribution with proceeds from an equity contribution from Sempra Energy. Sempra Energy funded the equity contribution to SDG&E with proceeds from settling forward sale agreements through physical delivery of shares of Sempra Energy common stock in exchange for cash, which we discuss in “Shareholders’ Equity and Noncontrolling Interests – Sempra Energy Common Stock Offerings” in Note 1. Edison paid its initial shareholder contribution in September 2019. In a complaint filed in U.S. District Court for the Northern District of California in July 2019, plaintiffs seek to invalidate AB 1054 based on allegations that the legislation violates federal law. The California Attorney General has moved to dismiss the complaint. Wildfire Fund Asset SDG&E recorded a Wildfire Fund asset for its commitment to make shareholder contributions totaling $451.5 million , measured at present value as of July 25, 2019 (the date by which both Edison and SDG&E opted to contribute to the Wildfire Fund). SDG&E is amortizing the Wildfire Fund asset to O&M on a straight-line basis over a 10 -year estimated period of benefit, as adjusted for utilization by the IOUs. The estimated period of benefit of the Wildfire Fund asset is based on several assumptions, including, but not limited to: • historical wildfire experience of each IOU in the State of California, including frequency and severity of the wildfires; • the value of property potentially damaged by wildfires; • the effectiveness of wildfire risk mitigation efforts by each IOU; • liability cap of each IOU; • IOU prudency determination levels; • FERC jurisdictional allocation levels; and • insurance coverage levels. The use of different assumptions, or changes to the assumptions used, could have a significant impact on the estimated period of benefit of the Wildfire Fund asset. We will periodically reevaluate the estimated period of benefit of the Wildfire Fund asset based on actual experience and changes in the above assumptions. SDG&E may recognize a reduction of its Wildfire Fund asset and record a charge against earnings in the period when there is a reduction of the available coverage due to recoverable claims from the IOUs. The reduction to the Wildfire Fund asset may be proportionate to the Wildfire Fund’s consumption (i.e., recoveries for outstanding wildfire claims that are recoverable from the Wildfire Fund, net of anticipated or actual reimbursement to the Wildfire Fund by the responsible IOU, would decrease the Wildfire Fund asset and remaining available coverage). In the three months ended September 30, 2019 , there were no such known claims from the IOUs requiring an incremental reduction of the Wildfire Fund asset. At September 30, 2019 , the current portion of the Wildfire Fund asset was $43 million in Other Current Assets on Sempra Energy’s Condensed Consolidated Balance Sheet and in Prepaid Expenses on SDG&E’s Condensed Consolidated Balance Sheet, and the noncurrent portion of $381 million was in Wildfire Fund on Sempra Energy’s and SDG&E’s Condensed Consolidated Balance Sheets. Wildfire Fund Obligation SDG&E recorded a Wildfire Fund obligation for its commitment to make shareholder contributions totaling $451.5 million , measured at present value as of July 25, 2019 (the date by which both Edison and SDG&E opted to contribute to the Wildfire Fund). SDG&E paid its initial shareholder contribution of $322.5 million to the Wildfire Fund in September 2019. At September 30, 2019 , SDG&E expects to make annual shareholder contributions of $12.9 million in each of the next 10 years by January 1 of each year, beginning July 25, 2019. SDG&E accretes the present value of the Wildfire Fund obligation to O&M until the liability is settled. At September 30, 2019 , the Wildfire Fund obligation was $12.9 million in Other Current Liabilities and $97 million in Deferred Credits and Other on Sempra Energy’s and SDG&E’s Condensed Consolidated Balance Sheets. 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 table below summarizes capitalized interest and AFUDC. CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Sempra Energy Consolidated $ 46 $ 47 $ 144 $ 150 SDG&E 19 20 56 67 SoCalGas 13 10 35 39 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 the right to receive benefits that could be significant to the VIE. We will continue to evaluate our VIEs for any changes that may impact our determination of the primary beneficiary. SDG&E SDG&E’s power procurement is subject to reliability requirements that may require SDG&E to enter into various PPAs that 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 on 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 Through October 3, 2019, SDG&E had a tolling agreement to purchase power generated at OMEC, a 605 -MW generating facility owned by OMEC LLC, which is a VIE that we refer to as Otay Mesa VIE. Under the terms of a related agreement, OMEC LLC could have required SDG&E to purchase the power plant (referred to as the put option) on or before October 3, 2019 for $280 million , subject to adjustments, or upon earlier termination of the PPA. SDG&E determined that it was the primary beneficiary of Otay Mesa VIE, and therefore, SDG&E and Sempra Energy consolidated Otay Mesa VIE. In October 2018, SDG&E and OMEC LLC signed a resource adequacy capacity agreement for a term that would commence at the expiration of the current tolling agreement in October 2019 and end in August 2024. The capacity agreement was approved by OMEC LLC’s lenders and the CPUC in December 2018 and February 2019, respectively. However, given certain then pending requests for rehearing of the CPUC’s decision approving the capacity agreement, on March 28, 2019, OMEC LLC exercised the put option requiring SDG&E to purchase the power plant. On August 6, 2019, the CPUC denied the rehearing requests, and on August 23, 2019, SDG&E and OMEC LLC executed an amended resource adequacy capacity agreement that irrevocably rescinded exercise of the put option. Consequently, SDG&E and Sempra Energy deconsolidated Otay Mesa VIE on August 23, 2019. No gain or loss was recognized upon deconsolidation. Prior to deconsolidation, on August 14, 2019, OMEC LLC paid in full its variable-rate loan that was scheduled to mature in August 2024, which we describe in Note 7. The following table summarizes the deconsolidation: DECONSOLIDATION OF OTAY MESA VIE (Dollars in millions) August 23, 2019 Cash and cash equivalents $ 8 Accounts receivable, net 11 Inventories 4 Total current assets 23 Property, plant and equipment, net 272 Other noncurrent assets 27 Total assets $ 322 Accounts payable $ 10 Other 2 Total current liabilities 12 Asset retirement obligations 2 Deferred credits and other 27 Total deferred credits and other liabilities 29 Noncontrolling interest 281 Total liabilities and equity $ 322 Otay Mesa VIE’s equity of $100 million at December 31, 2018 is included on the Condensed Consolidated Balance Sheets in Other Noncontrolling Interests for Sempra Energy and in Noncontrolling Interest for SDG&E. The Condensed Consolidated Statements of Operations of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE until its deconsolidation on August 23, 2019. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The captions in the table below 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, 2019 (1) 2018 2019 (1) 2018 Operating expenses Cost of electric fuel and purchased power $ (17 ) $ (28 ) $ (52 ) $ (60 ) Operation and maintenance 2 3 10 11 Depreciation and amortization 8 8 23 23 Total operating expenses (7 ) (17 ) (19 ) (26 ) Operating income 7 17 19 26 Interest expense (4 ) (6 ) (12 ) (16 ) Income before income taxes/Net income 3 11 7 10 Earnings attributable to noncontrolling interest (3 ) (11 ) (7 ) (10 ) Earnings attributable to common shares $ — $ — $ — $ — (1) Amounts for 2019 include activity until deconsolidation on August 23, 2019. SDG&E determined that none of its contracts resulted in SDG&E being the primary beneficiary of a VIE at September 30, 2019 . In addition to the tolling agreements described above, other variable interests involve various elements of fuel and power costs and other components of cash flows 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 could be significant to the financial position and liquidity of SDG&E and Sempra Energy. We provide additional information about PPAs with power plant facilities that are VIEs of which SDG&E is not the primary beneficiary in Note 16 of the Notes to Consolidated Financial Statements in the Annual Report. We provide additional information regarding Otay Mesa VIE in Note 11 below and in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Sempra Texas Utilities On March 9, 2018, we completed the acquisition of an indirect, 100 -percent interest in Oncor Holdings, a VIE that owns an 80.25 -percent interest in Oncor. Sempra Energy is not the primary beneficiary of the VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $11,145 million at September 30, 2019 and $9,652 million at December 31, 2018 . Sempra Renewables Certain of Sempra Renewables’ wind and solar power generation projects were held by limited liability companies whose members were Sempra Renewables and financial institutions. The financial institutions were noncontrolling tax equity investors to which earnings, tax attributes and cash flows were allocated in accordance with the respective limited liability company agreements. These entities were VIEs and Sempra Energy was the primary beneficiary, generally due to Sempra Energy’s power as the operator of the renewable energy projects to direct the activities that most significantly impacted the economic performance of these VIEs. As the primary beneficiary of these tax equity limited liability companies, we consolidated them. We sold the solar entities in December 2018 and the wind entities in April 2019. Sempra Energy’s Condensed Consolidated Balance Sheet includes equity of $158 million at December 31, 2018 of Other Noncontrolling Interests associated with these entities. Sempra Energy’s Condensed Consolidated Statements of Operations include the following amounts associated with the tax equity limited liability companies, net of eliminations of transactions between Sempra Energy and these entities. AMOUNTS ASSOCIATED WITH TAX EQUITY ARRANGEMENTS (1) (Dollars in millions) Three months ended September 30, Nine months ended 2018 2019 2018 REVENUES Energy-related businesses $ 28 $ 8 $ 77 EXPENSES Operation and maintenance (5 ) (2 ) (13 ) Depreciation and amortization (13 ) (4 ) (36 ) Income before income taxes 10 2 28 Income tax expense (4 ) — (16 ) Net income 6 2 12 Losses (earnings) attributable to noncontrolling interests (2) 9 (1 ) 50 Earnings attributable to common shares $ 15 $ 1 $ 62 ( 1) Amounts for 2019 include activity until deconsolidation of the wind entities in April 2019. Amounts for 2018 include activity until deconsolidation of the solar entities in December 2018 . (2) Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages. We provide additional information regarding the tax equity limited liability companies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. Sempra LNG Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra Energy is not the primary beneficiary of the VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, and therefore we account for our investment in Cameron LNG JV under the equity method. The carrying value of our investment, including amounts recognized in AOCI related to interest-rate cash flow hedges at Cameron LNG JV, was $1,216 million at September 30, 2019 and $1,271 million at December 31, 2018 . Our maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and the guarantees that we discuss in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report. Other Variable Interest Entities Sempra Energy’s other businesses also enter into arrangements that 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 or project companies that are VIEs because the total equity at risk is not sufficient for the entities to finance their activities without additional subordinated financial support. As the primary beneficiary of these companies, we consolidate them. The assets of these VIEs totaled approximately $779 million at September 30, 2019 and $286 million at December 31, 2018 and consisted primarily of PP&E and other long-term assets. Sempra Energy’s exposure to loss is equal to the carrying value of these assets. In all other cases, we have determined that these arrangements are not variable interests in a VIE and therefore are not subject to the U.S. GAAP requirements concerning the consolidation or disclosures of VIEs. PENSION AND OTHER POSTRETIREMENT BENEFITS Settlement Accounting for Lump Sum Payments In the nine months ended September 30, 2019, Sempra Energy recorded settlement charges of $22 million in net periodic benefit cost for lump sum payments from its non-qualified pension plan that were in excess of the plan’s service cost plus interest cost. Sale of Qualified Pension Plan Annuity Contracts In March 2018, an insurance company purchased certain annuities for current annuitants in the SDG&E and SoCalGas qualified pension plans and assumed the obligation for payment of these annuities. At SDG&E in the first quarter of 2018 and at SoCalGas in the second quarter of 2018, the liability transferred for these annuities, plus the total year-to-date lump-sum payments, exceeded the settlement threshold, which triggered settlement accounting. This resulted in a reduction of the recorded pension liability and pension plan assets of $300 million at Sempra Energy Consolidated, including $108 million at SDG&E and $192 million at SoCalGas. This also resulted in settlement charges in net periodic benefit cost of $3 million and $42 million at Sempra Energy Consolidated, including $1 million and $17 million at SDG&E and $2 million and $25 million at SoCalGas in the three months and nine months ended September 30, 2018 , respectively. The settlement charges were recorded as regulatory assets on the Condensed Consolidated Balance Sheets. 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, 2019 2018 2019 2018 Service cost $ 27 $ 29 $ 4 $ 4 Interest cost 34 35 9 9 Expected return on assets (36 ) (35 ) (17 ) (18 ) Amortization of: Prior service cost 3 3 — — Actuarial loss (gain)

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	9 Months Ended
	Sep. 30, 2019
Accounting Changes and Error Corrections [Abstract]
NEW ACCOUNTING STANDARDS	NEW ACCOUNTING STANDARDS We describe below recent accounting pronouncements that have had or may have a significant effect on our financial condition, results of operations, cash flows or disclosures. ASU 2016-02, “Leases,” ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” ASU 2018-10, “Codification Improvements to Topic 842, Leases,” ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” ASU 2018-20, “Narrow-Scope Improvements for Lessors” and ASU 2019-01, “Leases (Topic 842): Codification Improvements” (collectively referred to as the “lease standard”): In 2016, the Financial Accounting Standards Board began issuing the first in a series of ASUs intended to increase transparency and comparability among organizations with leasing activities. The most significant provision of the lease standard is the requirement that lessees recognize operating lease ROU assets and lease liabilities on the balance sheet. We adopted the lease standard on January 1, 2019, using the optional transition method to apply the new guidance prospectively as of January 1, 2019, rather than as of the earliest period presented. We elected the package of practical expedients that permits us to not reassess (a) whether a contract is or contains a lease, (b) lease classification or (c) determination of initial direct costs, which allows us to carry forward accounting conclusions under previous U.S. GAAP on contracts that commenced prior to adoption of the lease standard. We also elected the land easement practical expedient, which allows us to continue to account for pre-existing land easements under our accounting policy that existed before adoption of the lease standard. We did not elect the practical expedient to use hindsight in making judgments when determining the lease term. The adoption of the lease standard did not change our previously reported financial statements. However, in accordance with the lease standard, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Depreciation and Amortization Expense and Interest Expense on Sempra Energy’s and SDG&E’s statements of operations. Additionally, the adoption of the lease standard had a material impact on our balance sheets at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. Our finance leases were already included on our balance sheets prior to adoption of the lease standard, consistent with previous U.S. GAAP for capital leases. The following table shows the initial increases (decreases) on our balance sheets at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Assets held for sale $ 13 $ — $ — Sundry (71 ) — — Property, plant and equipment, net (147 ) — — Right-of-use assets – operating leases 603 130 116 Deferred income tax assets (3 ) — — Other current liabilities 80 20 23 Long-term debt (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — As a result of the adoption of the lease standard, we derecognized our corporate headquarters building lease in accordance with the transition provisions for build-to-suit arrangements. On a prospective basis, we will account for the corporate headquarters building lease as an operating lease. The initial impact is included in the above table. We include additional disclosures about our leases in Note 11. ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13, as amended by subsequently issued ASUs, 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, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2018. The amendments are to be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings at the beginning of the first reporting period in the year of adoption. We are currently evaluating the effect of the standard on our ongoing financial reporting. On a prospective basis, the new standard will primarily apply to our accounts receivable balances, amounts due from unconsolidated affiliates and off-balance sheet financial guarantees. We will adopt the standard on January 1, 2020. ASU 2017-04, “Simplifying the Test for Goodwill Impairment”: ASU 2017-04 removes the second step of the goodwill impairment test, which requires a hypothetical purchase price allocation. An entity will be required to apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. For public entities, ASU 2017-04 is effective for annual or interim goodwill impairment tests in fiscal years beginning after December 15, 2019, with early adoption permitted. The amendments are to be applied on a prospective basis. We will adopt the standard on January 1, 2020. ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: ASU 2018-02 contains amendments that allow a reclassification from AOCI to retained earnings for stranded tax effects resulting from the TCJA. Under ASU 2018-02, an entity is required to provide certain disclosures regarding stranded tax effects, including its accounting policy related to releasing the income tax effects from AOCI. The amendments in this update can be applied either as of the beginning of the period of adoption or retrospectively as of the date of enactment of the TCJA and to each period in which the effect of the TCJA is recognized. We adopted ASU 2018-02 on January 1, 2019 and reclassified the income tax effects of the TCJA from AOCI to retained earnings. The impact from adoption of ASU 2018-02 on January 1, 2019 was as follows: ▪ Sempra Energy: increase of $40 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $42 million to Accumulated Other Comprehensive Loss; ▪ SDG&E: increase of $2 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss; and ▪ SoCalGas: increase of $2 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $4 million to Accumulated Other Comprehensive Loss.

REVENUES

REVENUES	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
REVENUES	REVENUES We discuss revenue recognition for revenues from contracts with customers and from sources other than contracts with customers in Note 3 of the Notes to Consolidated Financial Statements in the Annual Report. The following table disaggregates our revenues from contracts with customers by major service line and market and provides a reconciliation to total revenues by segment. The majority of our revenue is recognized over time. DISAGGREGATED REVENUES (Dollars in millions) Three months ended September 30, 2019 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments, Parent & Other Sempra Energy Consolidated By major service line: Utilities $ 1,370 $ 765 $ 14 $ — $ — $ (18 ) $ 2,131 Midstream — — 158 — 48 (39 ) 167 Renewables — — 32 — — 2 34 Other — — 52 — 2 (3 ) 51 Revenues from contracts with customers $ 1,370 $ 765 $ 256 $ — $ 50 $ (58 ) $ 2,383 By market: Gas $ 100 $ 765 $ 171 $ — $ 48 $ (55 ) $ 1,029 Electric 1,270 — 85 — 2 (3 ) 1,354 Revenues from contracts with customers $ 1,370 $ 765 $ 256 $ — $ 50 $ (58 ) $ 2,383 Revenues from contracts with customers $ 1,370 $ 765 $ 256 $ — $ 50 $ (58 ) $ 2,383 Utilities regulatory revenues 57 210 — — — — 267 Other revenues — — 101 — 50 (43 ) 108 Total revenues $ 1,427 $ 975 $ 357 $ — $ 100 $ (101 ) $ 2,758 Nine months ended September 30, 2019 By major service line: Utilities $ 3,604 $ 3,170 $ 56 $ — $ — $ (56 ) $ 6,774 Midstream — — 472 — 134 (109 ) 497 Renewables — — 82 5 — 1 88 Other — — 147 — 5 (5 ) 147 Revenues from contracts with customers $ 3,604 $ 3,170 $ 757 $ 5 $ 139 $ (169 ) $ 7,506 By market: Gas $ 441 $ 3,170 $ 527 $ — $ 134 $ (160 ) $ 4,112 Electric 3,163 — 230 5 5 (9 ) 3,394 Revenues from contracts with customers $ 3,604 $ 3,170 $ 757 $ 5 $ 139 $ (169 ) $ 7,506 Revenues from contracts with customers $ 3,604 $ 3,170 $ 757 $ 5 $ 139 $ (169 ) $ 7,506 Utilities regulatory revenues 62 (28 ) — — — — 34 Other revenues — — 301 5 188 (148 ) 346 Total revenues $ 3,666 $ 3,142 $ 1,058 $ 10 $ 327 $ (317 ) $ 7,886 DISAGGREGATED REVENUES (CONTINUED) (Dollars in millions) Three months ended September 30, 2018 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments Sempra Energy Consolidated By major service line: Utilities $ 1,577 $ 719 $ 17 $ — $ — $ (16 ) $ 2,297 Midstream — — 194 — 82 (71 ) 205 Renewables — — 32 14 1 (1 ) 46 Other — — 71 — 1 (2 ) 70 Revenues from contracts with customers $ 1,577 $ 719 $ 314 $ 14 $ 84 $ (90 ) $ 2,618 By market: Gas $ 91 $ 719 $ 214 $ — $ 82 $ (86 ) $ 1,020 Electric 1,486 — 100 14 2 (4 ) 1,598 Revenues from contracts with customers $ 1,577 $ 719 $ 314 $ 14 $ 84 $ (90 ) $ 2,618 Revenues from contracts with customers $ 1,577 $ 719 $ 314 $ 14 $ 84 $ (90 ) $ 2,618 Utilities regulatory revenues (278 ) 83 — — — — (195 ) Other revenues — — 96 24 63 (41 ) 142 Total revenues $ 1,299 $ 802 $ 410 $ 38 $ 147 $ (131 ) $ 2,565 Nine months ended September 30, 2018 By major service line: Utilities $ 3,707 $ 2,529 $ 58 $ — $ — $ (51 ) $ 6,243 Midstream — — 484 — 171 (105 ) 550 Renewables — — 85 37 2 (1 ) 123 Other — — 142 — 5 (5 ) 142 Revenues from contracts with customers $ 3,707 $ 2,529 $ 769 $ 37 $ 178 $ (162 ) $ 7,058 By market: Gas $ 372 $ 2,529 $ 545 $ — $ 171 $ (153 ) $ 3,464 Electric 3,335 — 224 37 7 (9 ) 3,594 Revenues from contracts with customers $ 3,707 $ 2,529 $ 769 $ 37 $ 178 $ (162 ) $ 7,058 Revenues from contracts with customers $ 3,707 $ 2,529 $ 769 $ 37 $ 178 $ (162 ) $ 7,058 Utilities regulatory revenues (302 ) 171 — — — — (131 ) Other revenues — — 259 66 152 (128 ) 349 Total revenues $ 3,405 $ 2,700 $ 1,028 $ 103 $ 330 $ (290 ) $ 7,276 Remaining Performance Obligations For contracts greater than one year, at September 30, 2019 , we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such remaining performance obligations at September 30, 2019 . REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E 2019 (excluding first nine months of 2019) $ 87 $ 1 2020 409 4 2021 401 4 2022 405 4 2023 401 4 Thereafter 4,986 75 Total revenues to be recognized $ 6,689 $ 92 (1) Excludes intercompany transactions. Contract Balances from Revenues from Contracts with Customers Activities within Sempra Energy’s contract liabilities are presented below. There were no contract liabilities at SDG&E in the nine months ended September 30, 2018 or SoCalGas in the nine months ended September 30, 2019 and 2018 . CONTRACT LIABILITIES (Dollars in millions) Sempra Energy Consolidated SDG&E Balance at January 1, 2019 $ (70 ) $ — Revenue from performance obligations satisfied during reporting period 1 — Payments received in advance (95 ) (92 ) Balance at September 30, 2019 (1) $ (164 ) $ (92 ) Balance at January 1, 2018 $ — Adoption of ASC 606 adjustment (61 ) Revenue from performance obligations satisfied during reporting period 6 Payments received in advance (9 ) Balance at September 30, 2018 $ (64 ) (1) I ncludes $3 million and $3 million in Other Current Liabilities a nd $161 million and $89 million in Deferred Credits and Other on the Sempra Energy and SDG&E Condensed Consolidated Balance Sheets, respectively. Receivables from Revenues from Contracts with Customers The table below shows receivable balances associated with revenues from contracts with customers on our Condensed Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) September 30, 2019 December 31, 2018 Sempra Energy Consolidated: Accounts receivable – trade, net $ 875 $ 1,106 Accounts receivable – other, net 10 11 Due from unconsolidated affiliates – current (1) 6 4 Assets held for sale — 6 Total $ 891 $ 1,127 SDG&E: Accounts receivable – trade, net $ 446 $ 368 Accounts receivable – other, net 7 6 Due from unconsolidated affiliates – current (1) 3 3 Total $ 456 $ 377 SoCalGas: Accounts receivable – trade, net $ 356 $ 634 Accounts receivable – other, net 3 5 Total $ 359 $ 639 (1) A mount is presented net of amounts due to unconsolidated affiliates on the Condensed Consolidated Balance Sheets, when right of offset exists.

REGULATORY MATTERS

REGULATORY MATTERS	9 Months Ended
	Sep. 30, 2019
Regulated Operations [Abstract]
Regulatory Matters	REGULATORY MATTERS We discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and information about new regulatory matters below. REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) September 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ (136 ) $ (150 ) Deferred income taxes refundable in rates (118 ) (236 ) Pension and other postretirement benefit plan obligations 186 186 Removal obligations (1,999 ) (1,848 ) Environmental costs 26 28 Sunrise Powerlink fire mitigation 120 120 Regulatory balancing accounts (1) Commodity – electric 142 (8 ) Gas transportation 17 45 Safety and reliability 76 70 Public purpose programs (117 ) (62 ) 2019 GRC retroactive impacts 81 — Other balancing accounts 46 145 Other regulatory liabilities, net (2) (152 ) (170 ) Total SDG&E (1,828 ) (1,880 ) SoCalGas: Pension and other postretirement benefit plan obligations 452 470 Employee benefit costs 49 49 Removal obligations (754 ) (833 ) Deferred income taxes refundable in rates (214 ) (336 ) Environmental costs 28 28 Regulatory balancing accounts (1) Commodity – gas, including transportation (85 ) 196 Safety and reliability 310 332 Public purpose programs (329 ) (325 ) 2019 GRC retroactive impacts 286 — Other balancing accounts (30 ) (68 ) Other regulatory liabilities, net (2) (115 ) (114 ) Total SoCalGas (402 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 81 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (2,143 ) $ (2,394 ) (1) At September 30, 2019 and December 31, 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $117 million and $78 million , respectively, and for SoCalGas was $475 million and $185 million , respectively. (2) Includes regulatory assets earning a rate of return. CALIFORNIA UTILITIES CPUC General Rate Case The CPUC uses GRC proceedings to set rates designed to allow the California Utilities to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments. 2019 General Rate Case On September 26, 2019, the CPUC issued a final decision in the 2019 GRC approving SDG&E’s and SoCalGas’ test year revenues for 2019 and attrition year adjustments for 2020 and 2021. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD adopts a test year 2019 revenue requirement of $ 1,990 million for SDG&E’s combined operations ($ 1,590 million for its electric operations and $ 400 million for its natural gas operations), which is $ 213 million lower than the $ 2,203 million that SDG&E had requested in its updated application. SDG&E’s adopted 2019 revenue requirement represents an increase of $ 107 million ( 5.70 percent ) over its authorized 2018 revenue requirement. The 2019 GRC FD adopts a test year 2019 revenue requirement of $ 2,770 million for SoCalGas, which is $ 167 million lower than the $ 2,937 million that SoCalGas had requested in its updated application. SoCalGas’ adopted 2019 revenue requirement represents an increase of $ 314 million ( 12.80 percent ) over its authorized 2018 revenue requirement. The 2019 GRC FD retains a three-year GRC cycle for both utilities, specifying the 2020 and 2021 revenue requirement increases. The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00 We expect the adopted revenue requirements associated with the period from January 1, 2019 through September 30, 2019 to be recovered in rates through December 2021. At September 30, 2019 , SDG&E recorded an associated regulatory asset of $ 81 million , with $ 51 million as noncurrent, and SoCalGas recorded an associated regulatory asset of $ 286 million , with $ 179 million as noncurrent. The 2019 GRC FD approves for the California Utilities the establishment of two-way liability insurance premium balancing accounts, including wildfire insurance premium costs based on a specific level of coverage. The 2019 GRC FD also permits the California Utilities to seek recovery of additional liability insurance coverage. As we discuss in Notes 4 and 8 of the Notes to Consolidated Financial Statements in the Annual Report, pursuant to the 2016 GRC FD, SDG&E and SoCalGas each established a two-way income tax expense memorandum account to track, among other items, certain revenue variances resulting from certain differences between the income tax expense forecasted in the GRC and the income tax expense incurred from 2016 through 2018. SDG&E and SoCalGas recorded regulatory liabilities associated with the 2016 through 2018 tracked forecasting differences of $86 million and $88 million , respectively. The 2019 GRC FD clarifies that forecasting differences, which we previously included in this tracked activity, are not subject to tracking in the income tax expense memorandum account. However, its disposition is unclear. Final resolution of the scope of the two-way income tax expense memorandum account for the 2016 through 2018 period could impact the disposition of these regulatory liabilities. The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35 percent. As a result of the TCJA, the federal income tax rate of 21 percent became effective January 1, 2018. Since SDG&E and SoCalGas continued to collect authorized revenues based on a 35 percent tax rate, SDG&E and SoCalGas recorded regulatory liabilities of $88 million and $75 million , respectively. The 2019 GRC FD instructs SDG&E and SoCalGas to refund these balances to customers in future rates. SDG&E also recorded a $79 million regulatory liability at September 30, 2019 , relating to its FERC jurisdictional rates, in anticipation of amounts that will benefit customers in future rates for the decrease in the federal income tax rate. The California Utilities recorded revenues in the first six months of 2019 based on levels authorized for 2018 under the 2016 GRC FD because a final decision in the 2019 GRC was not issued by June 30, 2019. Since the 2019 GRC FD is effective retroactive to January 1, 2019, the California Utilities recorded the retroactive impacts in the third quarter of 2019. For SDG&E and SoCalGas, these amounts include an incremental earnings impact of $92 million ($ 66 million after tax) and $181 million ($ 130 million after tax), respectively, related to the first six months of 2019. CPUC Cost of Capital In April 2019, SDG&E and SoCalGas filed separate applications with the CPUC to update their cost of capital effective January 1, 2020. SDG&E proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent . SDG&E also proposed to increase its authorized ROE from 10.2 percent to 14.3 percent (with the aggregate ROE proposal including a quantified premium for wildfire liability risk), and to increase its authorized return on rate base from 7.55 percent to 10.03 percent . On August 1, 2019, SDG&E filed supplemental testimony to update its ROE request to reflect the impacts of AB 1054 and AB 111. In that supplementary testimony, SDG&E modified its proposal to increase its authorized ROE from 10.2 percent to 12.38 percent , including a revised premium for wildfire liability risk, and its authorized return on rate base from 7.55 percent to 8.95 percent . SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent . SoCalGas also proposed to increase its authorized ROE from 10.05 percent to 10.7 percent and to increase its authorized return on rate base from 7.34 percent to 7.85 percent . Intervenors are proposing a ROE for SDG&E ranging from 8.49 percent to 9.65 percent and for SoCalGas ranging from 8.49 percent to 9.63 percent . Intervenors have also proposed authorized returns on rate base for SDG&E ranging from 6.62 percent to 7.22 percent and for SoCalGas ranging from 6.45 percent to 6.72 percent . Intervenors also propose that the common equity levels remain authorized at 52 percent at both SDG&E and SoCalGas. The schedule for the proceeding indicates a final decision in the fourth quarter of 2019. SDG&E FERC Formulaic Rate Filing In October 2018, SDG&E submitted its TO5 filing to the FERC. This proceeding establishes the transmission revenue requirement, including rate of return, for SDG&E’s FERC-regulated electric transmission operations and assets. SDG&E’s TO5 filing proposed, among other items, an increase to SDG&E’s current authorized FERC ROE from 10.05 percent to 11.2 percent . On December 31, 2018, the FERC issued its order accepting and suspending SDG&E’s TO5 filing and established hearing and settlement procedures. In the order, the FERC suspended the TO5 filing for five months, during which the existing TO4 rates remained in effect. The suspension period ended on June 1, 2019, when the proposed TO5 rates took effect, subject to refund and the outcome of the rate filing. As a result, until a new ROE is authorized, the current ROE of 10.05 percent is the basis of SDG&E’s FERC-related revenue recognition. In July 2019, the settlement judge reported that SDG&E and the parties engaged in settlement negotiations had reached an impasse and directed the matter forward to hearings, which does not preclude continued settlement discussions among SDG&E and settling parties. In September 2019, the settlement judge issued an order suspending the hearing schedule for 60 days in anticipation of a settlement between the parties. In October 2019, SDG&E and settling parties reached an agreement on all issues set for hearing in the proceeding. The agreement provides for a ROE of 10.60 percent , consisting of a base ROE of 10.10 percent plus an additional 50 bps for participation in the California ISO. SDG&E will refund the California ISO additional 50 bps of ROE as of the refund effective date (June 1, 2019) in this proceeding if the FERC issues an order ruling that California IOUs are no longer eligible for the additional California ISO ROE. The agreement also includes the collection of additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. We expect a FERC order on the settlement terms in the first half of 2020. When we receive a final decision, SDG&E expects to record the cumulative earnings effect of retroactive application to June 1, 2019 for any difference between the current ROE and the approved ROE. SOCALGAS Billing Practices OII In May 2017, the CPUC issued an OII to determine whether SoCalGas violated any provisions of the California Public Utilities Code, General Orders, CPUC decisions, or other requirements pertaining to billing practices from 2014 through 2016. The CPUC examined the timeliness of monthly bills, extending the billing period for customers, and issuing estimated bills, including an examination of SoCalGas’ gas tariff rules. In January 2019, the CPUC ordered SoCalGas to pay $8 million in penalties, including $3 million that was paid in July 2019 to California’s general fund and $5 million to be credited to customers that received delayed bills (greater than 45 days) in the form of a $100 bill credit. SoCalGas filed an appeal of the CPUC’s conclusions in the order, which, in April 2019, the CPUC denied. SoCalGas filed a rehearing request on May 28, 2019, which is pending before the CPUC. The CPUC granted SoCalGas’ request to delay distribution of the $100 We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that ceased operations in June 2013, and in which SDG&E has a 20 percent ownership interest. We discuss SONGS further in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. The majority of the dismantlement work is expected to take 10 years after receipt of the required permits. The coastal development permit was issued in October 2019 and we expect major decommissioning work to begin in 2020. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20 percent of the total contract price. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. 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 NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra Energy and SDG&E Condensed Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. 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. SDG&E has received authorization from the CPUC to access NDT funds of up to $455 million for 2013 through 2019 (2019 forecasted) SONGS decommissioning costs. This includes up to $93 million authorized by the CPUC in January 2019 to be withdrawn from the NDT for forecasted 2019 SONGS Units 2 and 3 costs as decommissioning costs are incurred. In December 2016, the IRS and the U.S. Department of the Treasury issued proposed regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The proposed regulations state that costs related to the construction and maintenance of independent spent fuel management installations are included in the definition of “nuclear decommissioning costs.” The proposed regulations will be effective prospectively once they are finalized; however, the IRS has stated that it will not challenge taxpayer positions consistent with the proposed regulations for taxable years ending on or after the date the proposed regulations were issued. SDG&E is awaiting the adoption of, or additional refinement to, the proposed regulations before determining whether the proposed regulations will allow SDG&E to access the NDT funds for reimbursement or payment of the spent fuel management costs incurred in 2017 and subsequent years. Further clarification of the proposed regulations could enable SDG&E to access the NDT to recover spent fuel management costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. The IRS held public hearings on the proposed regulations in October 2017. It is unclear when clarification of the proposed regulations might be provided or when the proposed regulations will be finalized. 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 9 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At September 30, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 51 $ — $ — $ 51 Municipal bonds (2) 278 13 — 291 Other securities (3) 228 9 (1 ) 236 Total debt securities 557 22 (1 ) 578 Equity securities 170 309 (9 ) 470 Cash and cash equivalents 1 — — 1 Total $ 728 $ 331 $ (10 ) $ 1,049 At December 31, 2018: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 52 $ 1 $ — $ 53 Municipal bonds 266 4 (1 ) 269 Other securities 238 1 (5 ) 234 Total debt securities 556 6 (6 ) 556 Equity securities 168 253 (10 ) 411 Cash and cash equivalents 7 — — 7 Total $ 731 $ 259 $ (16 ) $ 974 (1) Maturity dates are 2021-2050. (2) Maturity dates are 2020-2056. (3) Maturity dates are 2019-2060. 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 IN THE NDT (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Proceeds from sales $ 231 $ 216 $ 728 $ 703 Gross realized gains 5 3 18 32 Gross realized losses (1 ) (1 ) (4 ) (6 ) Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities 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. ASSET RETIREMENT OBLIGATION AND SPENT NUCLEAR FUEL SDG&E’s ARO related to decommissioning costs for the SONGS units was $614 million at September 30, 2019 . That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. The ARO for all three units is based on a cost study prepared in 2017 that is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. SDG&E’s share of total decommissioning costs in 2019 dollars is approximately $834 million . U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC or temporarily in spent fuel pools. In October 2015, the California Coastal Commission approved Edison’s application for the proposed expansion of the ISFSI at SONGS. The ISFSI expansion began construction in 2016 and the transfer of the spent nuclear fuel from Units 2 and 3 to the ISFSI began in 2018. Edison suspended this transfer in August 2018 due to an incident that was subsequently resolved to the NRC’s satisfaction according to the NRC’s supplemental inspection report released in July 2019. Edison resumed spent fuel transfer operations in July 2019. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. However, it is unclear whether Edison will enter into a new settlement with the DOE or pursue litigation claims for spent fuel management costs incurred on or after January 1, 2017. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners, including SDG&E, also maintain nuclear property damage insurance at $1.5 billion , with a $500 million property damage sublimit on the ISFSI, which exceeds the minimum federal requirements of $1.06 billion . This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $10.4 million of retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion . This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

ACQUISITIONS, DIVESTITURES AND

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS	ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS 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 Texas Utilities Oncor Holdings On March 9, 2018, Sempra Energy completed the acquisition of an indirect, 100 -percent interest in Oncor Holdings, which owned 80.03 percent of Oncor, and other EFH assets and liabilities unrelated to Oncor, pursuant to the Merger Agreement with EFH. Under the Merger Agreement, we paid Merger Consideration of $ 9.45 billion in cash and an additional $ 31 million representing an adjustment for dividends and payments pursuant to a tax sharing agreement with Oncor and Oncor Holdings. Also on March 9, 2018, in a separate transaction, Sempra Energy, through its interest in Oncor Holdings, acquired an additional 0.22 percent of the outstanding membership interests in Oncor from OMI for $ 26 million in cash, bringing Sempra Energy’s indirect ownership in Oncor to 80.25 percent. TTI, an investment vehicle indirectly owned by third parties unaffiliated with Oncor Holdings or Sempra Energy, continues to own 19.75 percent of Oncor’s outstanding membership interests. We discuss this acquisition, including the purchase price allocation, in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report. After satisfying all conditions precedent, including final approval from the PUCT, on May 16, 2019, Oncor completed the acquisition of 100 percent of the issued and outstanding shares of InfraREIT and 100 percent of the limited partnership units of its subsidiary, InfraREIT Partners, pursuant to the InfraREIT Merger Agreement. Under the InfraREIT Merger Agreement, Oncor paid merger consideration of $ 1,275 million , or $ 21 per share, plus certain transaction costs incurred by InfraREIT and its subsidiaries and paid by Oncor on their behalf, including $ 40 million for a management agreement termination fee. In connection with and immediately after the closing, Oncor also extinguished all of InfraREIT’s outstanding debt (totaling $953 million ) by repaying an aggregate principal amount of $602 million on behalf of InfraREIT’s subsidiaries (using proceeds from a term loan and issuances of commercial paper), and exchanging an aggregate principal amount of $351 million of secured senior notes issued by InfraREIT subsidiaries for secured senior notes issued by Oncor. Oncor received a total of $1,330 million in capital contributions from Sempra Energy and certain indirect equity holders of TTI, proportionate to their respective ownership interest in Oncor, to fund the purchase price and certain expenses. We discuss Sempra Energy’s contribution in Note 6. As part of Oncor’s acquisition of interests in InfraREIT, immediately prior to closing the InfraREIT Merger Agreement, SDTS accepted and assumed certain assets and liabilities of SU in exchange for certain SDTS assets, pursuant to the Asset Exchange Agreement. SDTS received real property and other assets used in the electric transmission and distribution business in Central, North and West Texas, as well as the equity interests in GS Project Entity, LLC (a wholly owned subsidiary of SU) and SU received real property and other assets used in the electric transmission and distribution business near the Texas-Mexico border. Pursuant to the Asset Exchange Agreement, immediately prior to the completion of the exchange, SDTS became a wholly owned, indirect subsidiary of InfraREIT Partners. Sharyland Holdings On May 16, 2019, Sempra Energy acquired an indirect, 50 -percent interest in Sharyland Holdings for $102 million (subject to customary closing adjustments) pursuant to the Securities Purchase Agreement. In connection with and prior to the consummation of the Securities Purchase Agreement, Sharyland Holdings owned 100 percent of the membership interests in SU and SU converted into a limited liability company, named Sharyland Utilities, L.L.C. We account for our indirect, 50 -percent interest in Sharyland Holdings as an equity method investment. Sempra South American Utilities Compañía Transmisora del Norte Grande S.A. On December 18, 2018, Chilquinta Energía acquired a 100 -percent interest in Compañía Transmisora del Norte Grande S.A. through a sales and purchase agreement with AES Gener S.A. and its subsidiary Sociedad Eléctrica Angamos S.A. We completed the acquisition for a purchase price of $226 million and paid $208 million (net of $18 million cash acquired) with available cash on hand at Sempra South American Utilities. We accounted for this business combination using the acquisition method of accounting. We allocated the $208 million in cash paid ( $226 million purchase price less $18 million of cash acquired) to the identifiable assets acquired and liabilities assumed based on their respective fair values, with the excess recognized as goodwill, which is included in assets held for sale in discontinued operations. We consider the purchase price allocation at the acquisition date to be final. We discuss this acquisition, including the purchase price allocation, in Note 5 of the Notes to Consolidated Financial Statements in the Annual Report. DIVESTITURES In June 2018, our board of directors approved a plan to divest certain non-utility natural gas storage assets in the southeast U.S., and all our U.S. wind and U.S. solar assets (collectively, the Assets). As a result of our plan to sell the Assets, we recorded impairment charges totaling $1.5 billion ( $900 million after tax and NCI) in June 2018. These charges included $1.3 billion ( $755 million after tax and NCI) at Sempra LNG, which is included in Impairment Losses on Sempra Energy’s Condensed Consolidated Statements of Operations, and $200 million ( $145 million after tax) at Sempra Renewables, which is included in Equity Earnings on Sempra Energy’s Condensed Consolidated Statements of Operations for the nine months ended September 30, 2018. These impairment charges primarily represented an adjustment of the related assets’ carrying values to estimated fair values, less costs to sell when applicable, which we discuss in Notes 6 and 12 of the Notes to Consolidated Financial Statements in the Annual Report. Sempra Renewables In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments to AEP for $569 million , net of transaction costs, and recorded a $61 million ( $45 million after tax and NCI) gain, which is included in Gain on Sale of Assets on the Condensed Consolidated Statements of Operations for the nine months ended September 30, 2019 . Upon completion of the sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist. Sempra LNG On February 7, 2019, Sempra LNG completed the sale of its non-utility natural gas storage assets in the southeast U.S. (comprised of Mississippi Hub and Bay Gas), which we classified as held for sale at December 31, 2018, to an affiliate of ArcLight Capital Partners and received cash proceeds of $322 million , net of transaction costs. In January 2019, Sempra LNG completed the sale of other non-utility assets for $5 million DISCONTINUED OPERATIONS On January 25, 2019, our board of directors approved a plan to sell our South American businesses. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with those businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, as the planned sales represent a strategic shift that will have a major effect on our operations and financial results. We do not plan to have significant continuing involvement in or be able to exercise significant influence on the operating or financial policies of these operations after they are sold. Accordingly, the results of operations, financial position and cash flows for these businesses have been reclassified to discontinued operations for all periods presented. Discontinued operations that were previously in the Sempra South American Utilities segment include our 100 -percent interest in Chilquinta Energía in Chile, our 83.6 -percent interest in Luz del Sur in Peru and our interests in two energy-services companies, Tecnored and Tecsur, which provide electric construction and infrastructure services to Chilquinta Energía and Luz del Sur, respectively, as well as third parties. On September 27, 2019, we entered into a Purchase and Sale Agreement with China Yangtze Power International (Hongkong) Co., Limited to sell our equity interests in our Peruvian businesses, including our 83.6 -percent interest in Luz del Sur and its indirect ownership interest in Tecsur, for an aggregate base purchase price of $3.59 billion , subject to customary closing adjustments for working capital and changes in net indebtedness. The sale is subject to various conditions to closing, including approvals from the Peruvian anti-trust authority and the Bermuda Monetary Authority. We expect the sale to close in the first quarter of 2020. On October 12, 2019, we entered into a Purchase and Sale Agreement with State Grid International Development Limited to sell our equity interests in our Chilean businesses, including our 100 -percent interest in Chilquinta Energía and Tecnored and our 50 -percent interest in Eletrans, for an aggregate base purchase price of $2.23 billion , subject to customary adjustments for working capital and changes in net indebtedness and other adjustments. Chilquinta Energía also agreed to purchase the remaining 50 - percent interest in Eletrans from Sociedad Austral de Electricidad S.A., contingent on the sale of our Chilean businesses to State Grid International Development Limited. This acquisition by Chilquinta Energía would result in State Grid International Development Limited acquiring 100 percent of Eletrans , which we do not expect will have a significant economic impact on the sale of our Chilean businesses. The sale of our Chilean businesses is subject to various conditions to closing, including approval by the Chilean anti-trust authority, certain Chinese regulatory approvals and approval by the Bermuda Monetary Authority, but is not subject to Chilquinta Energía purchasing the remaining 50 - percent interest in Eletrans. We expect the sale to close in the first quarter of 2020. Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Revenues $ 398 $ 375 $ 1,222 $ 1,190 Cost of sales (249 ) (246 ) (765 ) (794 ) Operating expenses (38 ) (41 ) (123 ) (151 ) Interest and other (3 ) (6 ) (12 ) (15 ) Income before income taxes and equity earnings 108 82 322 230 Income tax benefit (expense) 148 (28 ) (32 ) (94 ) Equity earnings — — 2 1 Income from discontinued operations, net of income tax 256 54 292 137 Earnings attributable to noncontrolling interests (8 ) (8 ) (25 ) (22 ) Earnings from discontinued operations attributable to common shares $ 248 $ 46 $ 267 $ 115 The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations. ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS (Dollars in millions) September 30, December 31, 2018 Cash and cash equivalents $ 359 $ 88 Restricted cash (1) 1 — Accounts receivable, net 290 315 Due from unconsolidated affiliates 2 2 Inventories 44 38 Other current assets 24 16 Current assets $ 720 $ 459 Due from unconsolidated affiliates $ 51 $ 44 Goodwill and other intangible assets 803 819 Property, plant and equipment, net 2,502 2,357 Other noncurrent assets 39 39 Noncurrent assets $ 3,395 $ 3,259 Short-term debt $ 75 $ 55 Accounts payable 165 176 Dividends payable 428 8 Current portion of long-term debt and finance leases 39 29 Other current liabilities 97 100 Current liabilities $ 804 $ 368 Long-term debt and finance leases $ 687 $ 708 Deferred income taxes 274 250 Other noncurrent liabilities 62 55 Noncurrent liabilities $ 1,023 $ 1,013 (1) Primarily represents funds held in accordance with Peruvian tax law. At September 30, 2019 and December 31, 2018, $549 million and $506 million , respectively, of cumulative foreign currency translation adjustments related to our South American businesses are included in AOCI.

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	9 Months Ended
	Sep. 30, 2019
Investments [Abstract]
Investments in Unconsolidated Entities	INVESTMENTS IN UNCONSOLIDATED ENTITIES We generally account for investments under the equity method when we have significant influence over, but do not have control of, these entities. Equity earnings and losses, both before and net of income tax, are combined and presented as Equity Earnings on the Condensed Consolidated Statements of Operations. See Note 1 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR. Our equity method investments include various domestic and foreign entities. Our domestic equity method investees are typically partnerships that are pass-through entities for income tax purposes and therefore they do not record income tax. Sempra Energy’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax (Expense) Benefit on the Condensed Consolidated Statement of Operations. Our foreign equity method investees are corporations whose operations are generally taxable on a standalone basis in the countries in which they operate, and we recognize our equity in such income or loss net of investee income tax. Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra Energy. Rather, only our pretax equity earnings from our investment in Oncor Holdings (a disregarded entity for tax purposes) are included in our consolidated income tax return. A tax sharing agreement with TTI, Oncor Holdings and Oncor provides for the calculation of an income tax liability substantially as if Oncor Holdings and Oncor were taxed as corporations and requires tax payments determined on that basis. While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and Oncor being subject to the provisions of U.S. GAAP governing rate-regulated operations, Oncor recognizes amounts determined under cost-based regulatory rate-setting processes (with such costs including income taxes), as if it were taxed as a corporation. As a result, since Oncor Holdings consolidates Oncor, we recognize equity earnings from our investment in Oncor Holdings net of its recorded income tax. We provide additional information concerning our equity method investments in Note 5 above and in Notes 5 and 6 of the Notes to Consolidated Financial Statements in the Annual Report. SEMPRA TEXAS UTILITIES Oncor Holdings We account for our 100-percent ownership interest in Oncor Holdings as an equity method investment. Due to the ring-fencing measures, governance mechanisms, and commitments in effect following the Merger, we do not have the power to direct the significant activities of Oncor Holdings and Oncor. See Note 6 of the Notes to Consolidated Financial Statements in the Annual Report for additional information related to the restrictions on our ability to direct the significant activities of Oncor Holdings and Oncor. Sempra Energy contributed cash of $1,236 million and $117 million to Oncor in the nine months ended September 30, 2019 and 2018, respectively. The 2019 contributions include $1,067 million to fund Oncor’s May 2019 acquisition of interests in InfraREIT and certain acquisition-related expenses, which we discuss in Note 5 . In the nine months ended September 30, 2019 and 2018 , Oncor Holdings distributed to Sempra Energy $162 million and $9 million, respectively, in dividends and $9 million and $15 million, respectively, in tax sharing payments. We provide summarized income statement information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 March 9 - September 30, 2018 2019 2018 Operating revenues $ 1,211 $ 1,095 $ 3,268 $ 2,352 Operating expense (787 ) (748 ) (2,319 ) (1,663 ) Income from operations 424 347 949 689 Interest expense (97 ) (89 ) (276 ) (198 ) Income tax expense (53 ) (53 ) (106 ) (105 ) Net income 261 191 511 351 Noncontrolling interest held by TTI (52 ) (38 ) (102 ) (70 ) Earnings attributable to Sempra Energy 209 153 409 281 Sharyland Holdings As we discuss in Note 5 , on May 16, 2019, we acquired an indirect, 50 -percent interest in Sharyland Holdings for $102 million (subject to customary closing adjustments), which we account for as an equity method investment. SEMPRA MEXICO Sempra Mexico invested cash of $45 million in the IMG JV in the nine months ended September 30, 2018 . SEMPRA RENEWABLES As we discuss in Note 5 , Sempra Renewables recorded an other-than-temporary impairment on certain of its wind equity method investments totaling $ 200 million in June 2018. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. SEMPRA LNG Sempra LNG capitalized $32 million and $34 million of interest in the nine months ended September 30, 2019 and 2018 , respectively, related to its investment in Cameron LNG JV. In August 2019, the first of three trains of the Cameron LNG liquefaction project commenced commercial operation under the JV’s tolling agreements. In the nine months ended September 30, 2019 and 2018 , Sempra LNG invested cash of $77 million and $149 million, respectively, in this unconsolidated JV. RBS SEMPRA COMMODITIES In September 2018, we fully impaired our remaining equity method investment in RBS Sempra Commodities by recording a charge of $65 million in Equity Earnings on Sempra Energy’s Condensed Consolidated Statement of Operations. We discuss matters related to RBS Sempra Commodities further in Note 11. GUARANTEES At September 30, 2019 , we had outstanding guarantees aggregating a maximum of $3.9 billion . The related carrying value of these guarantees was fully amortized at September 30, 2019 . We discuss these guarantees in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Debt and Credit Facilities	DEBT AND CREDIT FACILITIES LINES OF CREDIT Primary U.S. Committed Lines of Credit Sempra Energy and Sempra Global On May 17, 2019, Sempra Energy and Sempra Global each entered into a separate five -year credit agreement, both expiring in May 2024. The credit agreements permit borrowings of up to $1.25 billion by Sempra Energy and $3.19 billion by Sempra Global. For both credit facilities, Citibank, N.A. serves as administrative agent for a syndicate of 23 lenders and no single lender has greater than a 6 -percent share of either credit facility. The credit agreements supersede Sempra Energy’s $1.25 billion credit agreement and Sempra Global’s $3.19 billion credit agreement, which were both set to expire in 2020. Borrowings for each credit facility bear interest at benchmark rates plus a margin based on Sempra Energy’s credit ratings. California Utilities On May 17, 2019, SDG&E and SoCalGas each entered into a separate five -year credit agreement, both expiring in May 2024. The credit agreements permit borrowings of up to $1.5 billion by SDG&E and $750 million by SoCalGas. For both credit facilities, JPMorgan Chase Bank, N.A. serves as administrative agent for a syndicate of 23 lenders and no single lender has greater than a 6 -percent share of either credit facility. The credit agreements replaced the California Utilities’ combined $1 billion credit agreement, which had a maximum of $750 million that could be borrowed by either utility, that was set to expire in 2020. Borrowings for each credit facility bear interest at benchmark rates plus a margin based on the borrowing utility’s credit ratings. At September 30, 2019 , these four primary U.S. committed lines of credit permit Sempra Energy Consolidated to borrow an aggregate amount of approximately $6.69 billion . The principal terms of these committed lines of credit, which provide liquidity and support commercial paper, are described below. PRIMARY U.S. COMMITTED LINES OF CREDIT (Dollars in millions) September 30, 2019 Total facility Commercial paper outstanding (1) Available unused credit Sempra Energy (2) $ 1,250 $ — $ 1,250 Sempra Global (3) 3,185 (2,345 ) 840 SDG&E (4) 1,500 — 1,500 SoCalGas (4) 750 (108 ) 642 Total $ 6,685 $ (2,453 ) $ 4,232 (1) Because the commercial paper programs are supported by these lines, we reflect the amount of commercial paper outstanding as a reduction to the available unused credit. (2) The facility also provides for issuance of $200 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. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra Energy has the right to increase the letter of credit commitment up to $500 million . No letters of credit were outstanding at September 30, 2019 . (3) Commercial paper outstanding is before reductions of unamortized discount of $3 million . Sempra Energy guarantees Sempra Global’s obligations under the credit facility. (4) The facility also provides for issuance of $100 million of letters of credit on behalf of the borrowing utility with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, the borrowing utility has the right to increase the letter of credit commitment up to $250 million . No letters of credit were outstanding at September 30, 2019 . Sempra Energy, SDG&E and SoCalGas each must maintain a ratio of indebtedness to total capitalization (as defined in each of the applicable credit facilities) of no more than 65 percent at the end of each quarter. At September 30, 2019 , each entity was in compliance with this ratio and all other financial covenants under its respective credit facility. Foreign Committed Lines of Credit In February 2019, IEnova revised the terms of its five -year revolving credit facility by increasing the amount available under the facility from $1.17 billion to $1.50 billion , extending the expiration of the facility from August 2020 to February 2024 and increasing the syndicate of lenders from eight to 10 . At September 30, 2019 , available unused credit on this line was approximately $642 million . On April 11, 2019, IEnova entered into a three-year, $100 million revolving credit agreement with Scotiabank Inverlat, S.A. Under the agreement, withdrawals may be made for up to one year in either U.S. dollars or Mexican pesos. At September 30, 2019 , available unused credit was $100 million . On September 23, 2019, IEnova entered into a two-year, $280 million revolving credit agreement with The Bank of Nova Scotia. Under the agreement, withdrawals may be made for up to two years in U.S. dollars. At September 30, 2019, there was no available unused credit. Letters of Credit Outside of our domestic and foreign committed credit facilities, we have bilateral unsecured standby letter of credit capacity with select lenders that is uncommitted and supported by reimbursement agreements. At September 30, 2019 , we had approximately $648 million in standby letters of credit outstanding under these agreement s. WEIGHTED-AVERAGE INTEREST RATES The weighted-average interest rates on total short-term debt at Sempra Energy Consolidated were 2.62 percent and 2.99 percent at September 30, 2019 and December 31, 2018 , respectively. The weighted-average interest rate on total short-term debt at SDG&E was 2.97 percent at December 31, 2018 . The weighted-average interest rates on total short-term debt at SoCalGas were 2.06 percent and 2.58 percent at September 30, 2019 and December 31, 2018 , respectively. LONG-TERM DEBT Sempra Energy In June 2019, we issued $758 million of 5.75 -percent, junior subordinated notes maturing in 2079, with a par value of $25 per note. We received proceeds of $735 million (net of underwriting discounts of $23 million ). We used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. We may redeem some or all of the notes before their maturity, as follows: ▪ on or after October 1, 2024, at a redemption price equal to 100 percent of the principal amount, plus accrued and unpaid interest; ▪ before October 1, 2024, if the U.S. federal tax law or regulations are amended or certain other events occur such that there is more than insubstantial risk that interest payable on the notes would no longer be deductible for federal income tax purposes, at a redemption price equal to 100 percent of the principal amount, plus accrued and unpaid interest; or ▪ before October 1, 2024, if a credit rating agency publicly changes certain equity credit methodology for securities such as these notes that results in a shortening of the length of time for equity credit initially assigned or lowers the equity credit initially assigned, at a redemption price equal to 102 percent of the principal amount, plus accrued and unpaid interest. The notes are unsecured obligations and rank junior and subordinate in right of payment to our existing and future senior indebtedness. The notes will rank equally in right of payment with any future unsecured indebtedness that we may incur if the terms of such indebtedness provide that it ranks equally with the notes in right of payment. The notes are effectively subordinated in right of payment to any secured indebtedness that we have or may incur and to all indebtedness and other liabilities of our subsidiaries. SDG&E In May 2019, SDG&E issued $400 million of 4.10 -percent, first mortgage bonds maturing in 2049. We received proceeds of $396 million (net of underwriting discounts and debt issuance costs of $4 million ). SDG&E used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. As we discuss in “Variable Interest Entities” in Note 1, on August 23, 2019, SDG&E deconsolidated Otay Mesa VIE. Prior to deconsolidation, on August 14, 2019, OMEC LLC paid in full the $211 million outstanding balance on its variable-rate loan that was scheduled to mature in August 2024. We describe this loan agreement and related floating-to-fixed interest rate swaps in Note 7 of the Notes to Consolidated Financial Statements in the Annual Report. We provide additional information concerning the interest rate swaps in Note 8. SoCalGas In June 2019, SoCalGas issued $350 million of 3.95 -percent, first mortgage bonds maturing in 2050. We received proceeds of $346 million (net of debt discount, underwriting discounts and debt issuance costs of $4 million ). SoCalGas used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. INTEREST RATE SWAPS In February 2019, Sempra Energy entered into floating-to-fixed interest rate swaps to hedge interest payments on the $850 million of variable rate notes issued in October 2017 and maturing in March 2021, resulting in an all-in fixed rate of 3.069 percent. We discuss our interest rate swaps to hedge cash flows in Note 8.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2019
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 have derivatives that are either (1) cash flow hedges, (2) fair value hedges, 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 OCI (cash flow hedges), on the balance sheet (regulatory offsets), or recognized in earnings (fair value hedges). We classify cash flows from the principal settlements of cross-currency swaps that hedge exposure related to Mexican peso-denominated debt as financing activities and settlements of other 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. 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 natural gas and electricity derivatives, 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 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 and Sempra LNG may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: LNG, natural gas transportation and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Energy-Related Businesses Cost of Sales on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico may also use natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its 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 and GHG allowances. The following table summarizes net energy derivative volumes. NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) Commodity Unit of measure September 30, December 31, Sempra Energy Consolidated: Natural gas MMBtu 30 35 Electricity MWh 2 2 Congestion revenue rights MWh 47 52 SDG&E: Natural gas MMBtu 34 33 Electricity MWh 2 2 Congestion revenue rights MWh 47 52 In addition to the amounts noted above, we 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. The California Utilities, as well as Sempra Energy and its other subsidiaries and JVs, periodically enter into interest rate derivative agreements intended to moderate our exposure to interest rates and to lower our overall costs of borrowing. 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. Separately, Otay Mesa VIE previously entered into interest rate swap agreements, designated as cash flow hedges, to moderate its exposure to interest rate changes. The following table presents the net notional amounts of our interest rate derivatives, excluding JVs. INTEREST RATE DERIVATIVES (Dollars in millions) September 30, 2019 December 31, 2018 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges (1) $ 1,259 2019-2032 $ 594 2019-2032 SDG&E: Cash flow hedge (1) — — 142 2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. On August 14, 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps. FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. 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 JVs 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 JVs, 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; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) September 30, 2019 December 31, 2018 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 306 2019-2023 $ 306 2019-2023 Other foreign currency derivatives 1,242 2019-2021 1,158 2019-2020 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, including the amount of cash collateral receivables that were not offset, as the cash collateral was in excess of liability positions. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2019 Current (1) Other Current liabilities: Deferred Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments $ — $ — $ (12 ) $ (157 ) Derivatives not designated as hedging instruments: Foreign exchange instruments 12 — (3 ) — Associated offsetting foreign exchange instruments (3 ) — 3 — Commodity contracts not subject to rate recovery 31 11 (39 ) (9 ) Associated offsetting commodity contracts (29 ) (1 ) 29 1 Commodity contracts subject to rate recovery 22 245 (48 ) (53 ) Associated offsetting commodity contracts (5 ) (2 ) 5 2 Associated offsetting cash collateral — — 13 2 Net amounts presented on the balance sheet 28 253 (52 ) (214 ) Additional cash collateral for commodity contracts not subject to rate recovery 18 — — — Additional cash collateral for commodity contracts subject to rate recovery 17 — — — Total (2) $ 63 $ 253 $ (52 ) $ (214 ) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 14 $ 245 $ (42 ) $ (53 ) Associated offsetting commodity contracts (3 ) (2 ) 3 2 Associated offsetting cash collateral — — 13 2 Net amounts presented on the balance sheet 11 243 (26 ) (49 ) Additional cash collateral for commodity contracts subject to rate recovery 14 — — — Total (2) $ 25 $ 243 $ (26 ) $ (49 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 8 $ — $ (6 ) $ — Associated offsetting commodity contracts (2 ) — 2 — Net amounts presented on the balance sheet 6 — (4 ) — Additional cash collateral for commodity contracts subject to rate recovery 3 — — — Total $ 9 $ — $ (4 ) $ — (1) Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E. (2) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2018 Current (1) Other Current liabilities: Deferred Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments (2) $ 2 $ — $ (3 ) $ (147 ) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 153 7 (164 ) (6 ) Associated offsetting commodity contracts (133 ) (3 ) 133 3 Commodity contracts subject to rate recovery 64 233 (42 ) (72 ) Associated offsetting commodity contracts (6 ) (2 ) 6 2 Associated offsetting cash collateral — — — 2 Net amounts presented on the balance sheet 80 235 (70 ) (218 ) Additional cash collateral for commodity contracts not subject to rate recovery 19 — — — Additional cash collateral for commodity contracts subject to rate recovery 33 — — — Total (3) $ 132 $ 235 $ (70 ) $ (218 ) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments (2) $ — $ — $ (1 ) $ — Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery 60 233 (37 ) (72 ) Associated offsetting commodity contracts (6 ) (2 ) 6 2 Associated offsetting cash collateral — — — 2 Net amounts presented on the balance sheet 54 231 (32 ) (68 ) Additional cash collateral for commodity contracts subject to rate recovery 28 — — — Total (3) $ 82 $ 231 $ (32 ) $ (68 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ — $ (5 ) $ — Net amounts presented on the balance sheet 4 — (5 ) — Additional cash collateral for commodity contracts subject to rate recovery 5 — — — Total $ 9 $ — $ (5 ) $ — (1) Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E. (2) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (3) Normal purchase contracts previously measured at fair value are excluded. The table below includes the effects of derivative instruments designated as cash flow hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI: CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax (loss) gain recognized in OCI Pretax (loss) gain reclassified from AOCI into earnings Three months ended September 30, Three months ended September 30, 2019 2018 Location 2019 2018 Sempra Energy Consolidated: Interest rate and foreign exchange instruments (1) $ (7 ) $ 16 Interest Expense (1) $ (1 ) $ — Other (Expense) Income, Net (5 ) 11 Interest rate and foreign exchange instruments (62 ) 20 Equity Earnings (2 ) (3 ) Foreign exchange instruments 1 (5 ) Revenues: Energy- Related Businesses — — Total $ (68 ) $ 31 $ (8 ) $ 8 SDG&E: Interest rate instruments (1) $ — $ — Interest Expense (1) $ (1 ) $ (2 ) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1 ) $ — Nine months ended September 30, Nine months ended September 30, 2019 2018 Location 2019 2018 Sempra Energy Consolidated: Interest rate and foreign exchange instruments (1) $ (25 ) $ 57 Interest Expense (1) $ (2 ) $ 1 Other (Expense) Income, Net — 11 Interest rate instruments — — (Loss) Gain on Sale of Assets (10 ) — Interest rate and foreign (222 ) 123 Equity Earnings (3 ) (8 ) Foreign exchange instruments (3 ) (7 ) Revenues: Energy- (1 ) 1 Total $ (250 ) $ 173 $ (16 ) $ 5 SDG&E: Interest rate instruments (1) $ (1 ) $ 1 Interest Expense (1) $ (3 ) $ (6 ) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1 ) $ — (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. For Sempra Energy Consolidated, we expect that net losses of $12 million , which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 12 months as the hedged items affect earnings. SoCalGas expects that $1 million of 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 12 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, 2019 is approximately 13 years for Sempra Energy Consolidated. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 15 years . The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Three months ended Nine months ended Location 2019 2018 2019 2018 Sempra Energy Consolidated: Foreign exchange instruments Other (Expense) Income, Net $ (12 ) $ 28 $ 7 $ 35 Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses (8 ) 9 9 — Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power 18 62 (7 ) 70 Commodity contracts subject to rate recovery Cost of Natural Gas (3 ) (2 ) (1 ) (1 ) Total $ (5 ) $ 97 $ 8 $ 104 SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ 18 $ 62 $ (7 ) $ 70 SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (3 ) $ (2 ) $ (1 ) $ (1 ) CONTINGENT FEATURES For Sempra Energy Consolidated, SDG&E and SoCalGas, 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 at September 30, 2019 and December 31, 2018 was $7 million and $16 million , respectively. For SoCalGas, the total fair value of this group of derivative instruments in a net liability position at September 30, 2019 and December 31, 2018 was $4 million and $5 million , respectively. At September 30, 2019 , if the credit ratings of Sempra Energy or SoCalGas were reduced below investment grade, $8 million and $4 million , respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	9 Months Ended
	Sep. 30, 2019
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, 2019 and December 31, 2018 . 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 valued assets and liabilities, and their placement within the fair value hierarchy. We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2018. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 8 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 in the tables below include the following (other than a $6 million investment at September 30, 2019 measured at net asset value): ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, 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. 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 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 or income 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 in “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, 2019 and December 31, 2018 . RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at September 30, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 465 $ 5 $ — $ 470 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 39 12 — 51 Municipal bonds — 291 — 291 Other securities — 236 — 236 Total debt securities 39 539 — 578 Total nuclear decommissioning trusts (1) 504 544 — 1,048 Interest rate and foreign exchange instruments — 9 — 9 Commodity contracts not subject to rate recovery — 12 — 12 Effect of netting and allocation of collateral (2) 18 — — 18 Commodity contracts subject to rate recovery 1 6 253 260 Effect of netting and allocation of collateral (2) 11 — 6 17 Total $ 534 $ 571 $ 259 $ 1,364 Liabilities: Interest rate and foreign exchange instruments $ — $ 169 $ — $ 169 Commodity contracts not subject to rate recovery — 18 — 18 Commodity contracts subject to rate recovery 15 5 74 94 Effect of netting and allocation of collateral (2) (15 ) — — (15 ) Total $ — $ 192 $ 74 $ 266 Fair value at December 31, 2018 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 407 $ 4 $ — $ 411 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 43 10 — 53 Municipal bonds — 269 — 269 Other securities — 234 — 234 Total debt securities 43 513 — 556 Total nuclear decommissioning trusts (1) 450 517 — 967 Interest rate and foreign exchange instruments — 2 — 2 Commodity contracts not subject to rate recovery — 24 — 24 Effect of netting and allocation of collateral (2) 19 — — 19 Commodity contracts subject to rate recovery 2 9 278 289 Effect of netting and allocation of collateral (2) 28 — 5 33 Total $ 499 $ 552 $ 283 $ 1,334 Liabilities: Interest rate and foreign exchange instruments $ — $ 150 $ — $ 150 Commodity contracts not subject to rate recovery — 34 — 34 Commodity contracts subject to rate recovery 2 5 99 106 Effect of netting and allocation of collateral (2) (2 ) — — (2 ) Total $ — $ 189 $ 99 $ 288 (1) Excludes cash and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at September 30, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 465 $ 5 $ — $ 470 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 39 12 — 51 Municipal bonds — 291 — 291 Other securities — 236 — 236 Total debt securities 39 539 — 578 Total nuclear decommissioning trusts (1) 504 544 — 1,048 Commodity contracts subject to rate recovery — 1 253 254 Effect of netting and allocation of collateral (2) 8 — 6 14 Total $ 512 $ 545 $ 259 $ 1,316 Liabilities: Commodity contracts subject to rate recovery $ 15 $ 1 $ 74 $ 90 Effect of netting and allocation of collateral (2) (15 ) — — (15 ) Total $ — $ 1 $ 74 $ 75 Fair value at December 31, 2018 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 407 $ 4 $ — $ 411 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 43 10 — 53 Municipal bonds — 269 — 269 Other securities — 234 — 234 Total debt securities 43 513 — 556 Total nuclear decommissioning trusts (1) 450 517 — 967 Commodity contracts subject to rate recovery 1 6 278 285 Effect of netting and allocation of collateral (2) 23 — 5 28 Total $ 474 $ 523 $ 283 $ 1,280 Liabilities: Interest rate instruments $ — $ 1 $ — $ 1 Commodity contracts subject to rate recovery 2 — 99 101 Effect of netting and allocation of collateral (2) (2 ) — — (2 ) Total $ — $ 1 $ 99 $ 100 (1) Excludes cash and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at September 30, 2019 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 5 $ — $ 6 Effect of netting and allocation of collateral (1) 3 — — 3 Total $ 4 $ 5 $ — $ 9 Liabilities: Commodity contracts subject to rate recovery $ — $ 4 $ — $ 4 Total $ — $ 4 $ — $ 4 Fair value at December 31, 2018 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 3 $ — $ 4 Effect of netting and allocation of collateral (1) 5 — — 5 Total $ 6 $ 3 $ — $ 9 Liabilities: Commodity contracts subject to rate recovery $ — $ 5 $ — $ 5 Total $ — $ 5 $ — $ 5 (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 table below sets forth reconciliations of changes in the fair value of 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 (1) (Dollars in millions) Three months ended September 30, 2019 2018 Balance at July 1 $ 176 $ (31 ) Realized and unrealized (losses) gains (24 ) 6 Settlements 27 13 Balance at September 30 $ 179 $ (12 ) Change in unrealized gains (losses) relating to instruments still held at September 30 $ 1 $ 6 Nine months ended September 30, 2019 2018 Balance at January 1 $ 179 $ (28 ) Realized and unrealized (losses) gains (32 ) 21 Allocated transmission instruments — 3 Settlements 32 (8 ) Balance at September 30 $ 179 $ (12 ) Change in unrealized gains (losses) relating to instruments still held at September 30 $ 12 $ — (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements. 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 ISO, an objective source. Annual auction prices are published once a year, typically in the middle of November, and are the basis for valuing CRRs settling in the following year. For the CRRs settling from January 1 to December 31, the auction price inputs, at a given location, were in the following ranges for the years indicated below: CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2019 $ (8.57 ) to $ 35.21 $ (2.94 ) 2018 (7.25 ) to 11.99 0.09 The impact associated with discounting is negligible. Because these 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. 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 8. 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. The range and weighted-average price of these inputs at September 30 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2019 $ 21.60 to $ 57.20 $ 38.29 2018 20.40 to 57.70 38.87 A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 8. 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. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Fair Value of Financial Instruments The fair values of certain of our financial instruments (cash, accounts and notes receivable, dividends receivable from discontinued operations, short-term 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. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) September 30, 2019 Carrying Fair value Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates $ 712 $ — $ 735 $ — $ 735 Long-term amounts due to unconsolidated affiliates 39 — 38 — 38 Total long-term debt (1) 21,554 — 23,142 26 23,168 SDG&E: Total long-term debt (2) $ 5,141 $ — $ 5,780 $ — $ 5,780 SoCalGas: Total long-term debt (3) $ 3,809 $ — $ 4,290 $ — $ 4,290 December 31, 2018 Carrying Fair value Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates $ 644 $ — $ 648 $ 4 $ 652 Long-term amounts due to unconsolidated affiliates 37 — 35 — 35 Total long-term debt (4)(5) 21,340 — 20,616 247 20,863 SDG&E: Total long-term debt (4)(6) $ 4,996 $ — $ 4,897 $ 220 $ 5,117 SoCalGas: Total long-term debt (7) $ 3,459 $ — $ 3,505 $ — $ 3,505 (1) Before reductions of unamortized discount and debt issuance costs of $221 million and excluding finance lease obligations of $1,285 million . (2) Before reductions of unamortized discount and debt issuance costs of $49 million and excluding finance lease obligations of $1,270 million . (3) Before reductions of unamortized discount and debt issuance costs of $35 million and excluding finance lease obligations of $15 million . (4) Level 3 instruments include $220 million related to Otay Mesa VIE. (5) Before reductions of unamortized discount and debt issuance costs of $206 million and excluding build-to-suit and capital lease obligations of $1,413 million . (6) Before reductions of unamortized discount and debt issuance costs of $49 million and excluding capital lease obligations of $1,272 million . (7) Before reductions of unamortized discount and debt issuance costs of $32 million and excluding capital lease obligations of $3 million . We provide the fair values for the securities held in the NDT related to SONGS in Note 10 .

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	9 Months Ended
	Sep. 30, 2019
Regulated Operations [Abstract]
San Onofre Nuclear Generating Station	REGULATORY MATTERS We discuss regulatory matters in Note 4 of the Notes to Consolidated Financial Statements in the Annual Report, and provide updates to those discussions and information about new regulatory matters below. REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) September 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ (136 ) $ (150 ) Deferred income taxes refundable in rates (118 ) (236 ) Pension and other postretirement benefit plan obligations 186 186 Removal obligations (1,999 ) (1,848 ) Environmental costs 26 28 Sunrise Powerlink fire mitigation 120 120 Regulatory balancing accounts (1) Commodity – electric 142 (8 ) Gas transportation 17 45 Safety and reliability 76 70 Public purpose programs (117 ) (62 ) 2019 GRC retroactive impacts 81 — Other balancing accounts 46 145 Other regulatory liabilities, net (2) (152 ) (170 ) Total SDG&E (1,828 ) (1,880 ) SoCalGas: Pension and other postretirement benefit plan obligations 452 470 Employee benefit costs 49 49 Removal obligations (754 ) (833 ) Deferred income taxes refundable in rates (214 ) (336 ) Environmental costs 28 28 Regulatory balancing accounts (1) Commodity – gas, including transportation (85 ) 196 Safety and reliability 310 332 Public purpose programs (329 ) (325 ) 2019 GRC retroactive impacts 286 — Other balancing accounts (30 ) (68 ) Other regulatory liabilities, net (2) (115 ) (114 ) Total SoCalGas (402 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 81 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (2,143 ) $ (2,394 ) (1) At September 30, 2019 and December 31, 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $117 million and $78 million , respectively, and for SoCalGas was $475 million and $185 million , respectively. (2) Includes regulatory assets earning a rate of return. CALIFORNIA UTILITIES CPUC General Rate Case The CPUC uses GRC proceedings to set rates designed to allow the California Utilities to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments. 2019 General Rate Case On September 26, 2019, the CPUC issued a final decision in the 2019 GRC approving SDG&E’s and SoCalGas’ test year revenues for 2019 and attrition year adjustments for 2020 and 2021. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD adopts a test year 2019 revenue requirement of $ 1,990 million for SDG&E’s combined operations ($ 1,590 million for its electric operations and $ 400 million for its natural gas operations), which is $ 213 million lower than the $ 2,203 million that SDG&E had requested in its updated application. SDG&E’s adopted 2019 revenue requirement represents an increase of $ 107 million ( 5.70 percent ) over its authorized 2018 revenue requirement. The 2019 GRC FD adopts a test year 2019 revenue requirement of $ 2,770 million for SoCalGas, which is $ 167 million lower than the $ 2,937 million that SoCalGas had requested in its updated application. SoCalGas’ adopted 2019 revenue requirement represents an increase of $ 314 million ( 12.80 percent ) over its authorized 2018 revenue requirement. The 2019 GRC FD retains a three-year GRC cycle for both utilities, specifying the 2020 and 2021 revenue requirement increases. The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00 We expect the adopted revenue requirements associated with the period from January 1, 2019 through September 30, 2019 to be recovered in rates through December 2021. At September 30, 2019 , SDG&E recorded an associated regulatory asset of $ 81 million , with $ 51 million as noncurrent, and SoCalGas recorded an associated regulatory asset of $ 286 million , with $ 179 million as noncurrent. The 2019 GRC FD approves for the California Utilities the establishment of two-way liability insurance premium balancing accounts, including wildfire insurance premium costs based on a specific level of coverage. The 2019 GRC FD also permits the California Utilities to seek recovery of additional liability insurance coverage. As we discuss in Notes 4 and 8 of the Notes to Consolidated Financial Statements in the Annual Report, pursuant to the 2016 GRC FD, SDG&E and SoCalGas each established a two-way income tax expense memorandum account to track, among other items, certain revenue variances resulting from certain differences between the income tax expense forecasted in the GRC and the income tax expense incurred from 2016 through 2018. SDG&E and SoCalGas recorded regulatory liabilities associated with the 2016 through 2018 tracked forecasting differences of $86 million and $88 million , respectively. The 2019 GRC FD clarifies that forecasting differences, which we previously included in this tracked activity, are not subject to tracking in the income tax expense memorandum account. However, its disposition is unclear. Final resolution of the scope of the two-way income tax expense memorandum account for the 2016 through 2018 period could impact the disposition of these regulatory liabilities. The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35 percent. As a result of the TCJA, the federal income tax rate of 21 percent became effective January 1, 2018. Since SDG&E and SoCalGas continued to collect authorized revenues based on a 35 percent tax rate, SDG&E and SoCalGas recorded regulatory liabilities of $88 million and $75 million , respectively. The 2019 GRC FD instructs SDG&E and SoCalGas to refund these balances to customers in future rates. SDG&E also recorded a $79 million regulatory liability at September 30, 2019 , relating to its FERC jurisdictional rates, in anticipation of amounts that will benefit customers in future rates for the decrease in the federal income tax rate. The California Utilities recorded revenues in the first six months of 2019 based on levels authorized for 2018 under the 2016 GRC FD because a final decision in the 2019 GRC was not issued by June 30, 2019. Since the 2019 GRC FD is effective retroactive to January 1, 2019, the California Utilities recorded the retroactive impacts in the third quarter of 2019. For SDG&E and SoCalGas, these amounts include an incremental earnings impact of $92 million ($ 66 million after tax) and $181 million ($ 130 million after tax), respectively, related to the first six months of 2019. CPUC Cost of Capital In April 2019, SDG&E and SoCalGas filed separate applications with the CPUC to update their cost of capital effective January 1, 2020. SDG&E proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent . SDG&E also proposed to increase its authorized ROE from 10.2 percent to 14.3 percent (with the aggregate ROE proposal including a quantified premium for wildfire liability risk), and to increase its authorized return on rate base from 7.55 percent to 10.03 percent . On August 1, 2019, SDG&E filed supplemental testimony to update its ROE request to reflect the impacts of AB 1054 and AB 111. In that supplementary testimony, SDG&E modified its proposal to increase its authorized ROE from 10.2 percent to 12.38 percent , including a revised premium for wildfire liability risk, and its authorized return on rate base from 7.55 percent to 8.95 percent . SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52 percent to 56 percent . SoCalGas also proposed to increase its authorized ROE from 10.05 percent to 10.7 percent and to increase its authorized return on rate base from 7.34 percent to 7.85 percent . Intervenors are proposing a ROE for SDG&E ranging from 8.49 percent to 9.65 percent and for SoCalGas ranging from 8.49 percent to 9.63 percent . Intervenors have also proposed authorized returns on rate base for SDG&E ranging from 6.62 percent to 7.22 percent and for SoCalGas ranging from 6.45 percent to 6.72 percent . Intervenors also propose that the common equity levels remain authorized at 52 percent at both SDG&E and SoCalGas. The schedule for the proceeding indicates a final decision in the fourth quarter of 2019. SDG&E FERC Formulaic Rate Filing In October 2018, SDG&E submitted its TO5 filing to the FERC. This proceeding establishes the transmission revenue requirement, including rate of return, for SDG&E’s FERC-regulated electric transmission operations and assets. SDG&E’s TO5 filing proposed, among other items, an increase to SDG&E’s current authorized FERC ROE from 10.05 percent to 11.2 percent . On December 31, 2018, the FERC issued its order accepting and suspending SDG&E’s TO5 filing and established hearing and settlement procedures. In the order, the FERC suspended the TO5 filing for five months, during which the existing TO4 rates remained in effect. The suspension period ended on June 1, 2019, when the proposed TO5 rates took effect, subject to refund and the outcome of the rate filing. As a result, until a new ROE is authorized, the current ROE of 10.05 percent is the basis of SDG&E’s FERC-related revenue recognition. In July 2019, the settlement judge reported that SDG&E and the parties engaged in settlement negotiations had reached an impasse and directed the matter forward to hearings, which does not preclude continued settlement discussions among SDG&E and settling parties. In September 2019, the settlement judge issued an order suspending the hearing schedule for 60 days in anticipation of a settlement between the parties. In October 2019, SDG&E and settling parties reached an agreement on all issues set for hearing in the proceeding. The agreement provides for a ROE of 10.60 percent , consisting of a base ROE of 10.10 percent plus an additional 50 bps for participation in the California ISO. SDG&E will refund the California ISO additional 50 bps of ROE as of the refund effective date (June 1, 2019) in this proceeding if the FERC issues an order ruling that California IOUs are no longer eligible for the additional California ISO ROE. The agreement also includes the collection of additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. We expect a FERC order on the settlement terms in the first half of 2020. When we receive a final decision, SDG&E expects to record the cumulative earnings effect of retroactive application to June 1, 2019 for any difference between the current ROE and the approved ROE. SOCALGAS Billing Practices OII In May 2017, the CPUC issued an OII to determine whether SoCalGas violated any provisions of the California Public Utilities Code, General Orders, CPUC decisions, or other requirements pertaining to billing practices from 2014 through 2016. The CPUC examined the timeliness of monthly bills, extending the billing period for customers, and issuing estimated bills, including an examination of SoCalGas’ gas tariff rules. In January 2019, the CPUC ordered SoCalGas to pay $8 million in penalties, including $3 million that was paid in July 2019 to California’s general fund and $5 million to be credited to customers that received delayed bills (greater than 45 days) in the form of a $100 bill credit. SoCalGas filed an appeal of the CPUC’s conclusions in the order, which, in April 2019, the CPUC denied. SoCalGas filed a rehearing request on May 28, 2019, which is pending before the CPUC. The CPUC granted SoCalGas’ request to delay distribution of the $100 We provide below updates to ongoing matters related to SONGS, a nuclear generating facility near San Clemente, California that ceased operations in June 2013, and in which SDG&E has a 20 percent ownership interest. We discuss SONGS further in Note 15 of the Notes to Consolidated Financial Statements in the Annual Report. NUCLEAR DECOMMISSIONING AND FUNDING As a result of Edison’s decision to permanently retire SONGS Units 2 and 3, Edison began the decommissioning phase of the plant. The majority of the dismantlement work is expected to take 10 years after receipt of the required permits. The coastal development permit was issued in October 2019 and we expect major decommissioning work to begin in 2020. Decommissioning of Unit 1, removed from service in 1992, is largely complete. The remaining work for Unit 1 will be completed once Units 2 and 3 are dismantled and the spent fuel is removed from the site. The spent fuel is currently being stored on-site, until the DOE identifies a spent fuel storage facility and puts in place a program for the fuel’s disposal, as we discuss below. SDG&E is responsible for approximately 20 percent of the total contract price. In accordance with state and federal requirements and regulations, SDG&E has assets held in the NDT to fund its share of decommissioning costs for SONGS Units 1, 2 and 3. 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 NDT are invested in accordance with CPUC regulations. SDG&E classifies debt and equity securities held in the NDT as available-for-sale. The NDT assets are presented on the Sempra Energy and SDG&E Condensed Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. 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. SDG&E has received authorization from the CPUC to access NDT funds of up to $455 million for 2013 through 2019 (2019 forecasted) SONGS decommissioning costs. This includes up to $93 million authorized by the CPUC in January 2019 to be withdrawn from the NDT for forecasted 2019 SONGS Units 2 and 3 costs as decommissioning costs are incurred. In December 2016, the IRS and the U.S. Department of the Treasury issued proposed regulations that clarify the definition of “nuclear decommissioning costs,” which are costs that may be paid for or reimbursed from a qualified trust fund. The proposed regulations state that costs related to the construction and maintenance of independent spent fuel management installations are included in the definition of “nuclear decommissioning costs.” The proposed regulations will be effective prospectively once they are finalized; however, the IRS has stated that it will not challenge taxpayer positions consistent with the proposed regulations for taxable years ending on or after the date the proposed regulations were issued. SDG&E is awaiting the adoption of, or additional refinement to, the proposed regulations before determining whether the proposed regulations will allow SDG&E to access the NDT funds for reimbursement or payment of the spent fuel management costs incurred in 2017 and subsequent years. Further clarification of the proposed regulations could enable SDG&E to access the NDT to recover spent fuel management costs before Edison reaches final settlement with the DOE regarding the DOE’s reimbursement of these costs. Historically, the DOE’s reimbursements of spent fuel storage costs have not resulted in timely or complete recovery of these costs. We discuss the DOE’s responsibility for spent nuclear fuel below. The IRS held public hearings on the proposed regulations in October 2017. It is unclear when clarification of the proposed regulations might be provided or when the proposed regulations will be finalized. 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 9 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At September 30, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 51 $ — $ — $ 51 Municipal bonds (2) 278 13 — 291 Other securities (3) 228 9 (1 ) 236 Total debt securities 557 22 (1 ) 578 Equity securities 170 309 (9 ) 470 Cash and cash equivalents 1 — — 1 Total $ 728 $ 331 $ (10 ) $ 1,049 At December 31, 2018: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 52 $ 1 $ — $ 53 Municipal bonds 266 4 (1 ) 269 Other securities 238 1 (5 ) 234 Total debt securities 556 6 (6 ) 556 Equity securities 168 253 (10 ) 411 Cash and cash equivalents 7 — — 7 Total $ 731 $ 259 $ (16 ) $ 974 (1) Maturity dates are 2021-2050. (2) Maturity dates are 2020-2056. (3) Maturity dates are 2019-2060. 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 IN THE NDT (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Proceeds from sales $ 231 $ 216 $ 728 $ 703 Gross realized gains 5 3 18 32 Gross realized losses (1 ) (1 ) (4 ) (6 ) Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities 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. ASSET RETIREMENT OBLIGATION AND SPENT NUCLEAR FUEL SDG&E’s ARO related to decommissioning costs for the SONGS units was $614 million at September 30, 2019 . That amount includes the cost to decommission Units 2 and 3, and the remaining cost to complete the decommissioning of Unit 1, which is substantially complete. The ARO for all three units is based on a cost study prepared in 2017 that is pending CPUC approval. The ARO for Units 2 and 3 reflects the acceleration of the start of decommissioning of these units as a result of the early closure of the plant. SDG&E’s share of total decommissioning costs in 2019 dollars is approximately $834 million . U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL Spent nuclear fuel from SONGS is currently stored on-site in an ISFSI licensed by the NRC or temporarily in spent fuel pools. In October 2015, the California Coastal Commission approved Edison’s application for the proposed expansion of the ISFSI at SONGS. The ISFSI expansion began construction in 2016 and the transfer of the spent nuclear fuel from Units 2 and 3 to the ISFSI began in 2018. Edison suspended this transfer in August 2018 due to an incident that was subsequently resolved to the NRC’s satisfaction according to the NRC’s supplemental inspection report released in July 2019. Edison resumed spent fuel transfer operations in July 2019. The ISFSI will operate until 2049, when it is assumed that the DOE will have taken custody of all the SONGS spent fuel. The ISFSI would then be decommissioned, and the site restored to its original environmental state. Until then, SONGS owners are responsible for interim storage of spent nuclear fuel at SONGS. The Nuclear Waste Policy Act of 1982 made the DOE responsible for accepting, transporting, and disposing of spent nuclear fuel. However, it is uncertain when the DOE will begin accepting spent nuclear fuel from SONGS. This delay will lead to increased costs for spent fuel storage. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel. However, it is unclear whether Edison will enter into a new settlement with the DOE or pursue litigation claims for spent fuel management costs incurred on or after January 1, 2017. NUCLEAR INSURANCE SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident. The SONGS owners, including SDG&E, also maintain nuclear property damage insurance at $1.5 billion , with a $500 million property damage sublimit on the ISFSI, which exceeds the minimum federal requirements of $1.06 billion . This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced or eliminated coverage. Insured members as a group are subject to retrospective premium assessments to cover losses sustained by NEIL under all issued policies. SDG&E could be assessed up to $10.4 million of retrospective premiums based on overall member claims. The nuclear property insurance program includes an industry aggregate loss limit for non-certified acts of terrorism (as defined by the Terrorism Risk Insurance Act) of $3.24 billion . This is the maximum amount that will be paid to insured members who suffer losses or damages from these non-certified terrorist acts.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2019
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 reasonably estimate 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, 2019 , loss contingency accruals for legal matters, including associated legal fees, that are probable and estimable were $ 97 million for Sempra Energy Consolidated, including $50 million for SoCalGas. Amounts for Sempra Energy and SoCalGas include $49 million for matters related to the Aliso Canyon natural gas storage facility gas leak, which we discuss below. SDG&E 2007 Wildfire Litigation and Net Cost Recovery Status SDG&E has resolved all civil litigation associated with three wildfires that occurred in October 2007. As a result of a CPUC decision denying SDG&E’s request to recover wildfire costs, SDG&E wrote off the wildfire regulatory asset, resulting in a charge of $351 million ( $208 million after-tax) in the third quarter of 2017. SDG&E applied to the CPUC for rehearing of its decision but, in July 2018, the CPUC denied SDG&E’s rehearing request. In November 2018, the California Court of Appeal denied SDG&E’s petition to reverse the CPUC’s decision. In January 2019, the California Supreme Court denied SDG&E’s petition to reverse the decisions of the CPUC and the California Court of Appeal. In October 2019, the U.S. Supreme Court declined to review the case, effectively ending SDG&E’s efforts to recover the wildfire regulatory asset. 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 in Los Angeles County. The Aliso Canyon natural gas storage facility has been operated by SoCalGas since 1972. SS25 is one of more than 100 injection-and-withdrawal wells at the storage facility. SoCalGas worked closely with several of the world’s leading experts to stop the Leak, and on February 18, 2016, DOGGR confirmed that the well was permanently sealed. As discussed in “Cost Estimates and Accounting Impact” below, SoCalGas incurred significant costs for temporary relocation, to control the well and to stop the Leak, as well as to purchase natural gas to replace that lost through the Leak. As discussed in “Local Community Mitigation Efforts” below, during the Leak and in the months following the sealing of the well, SoCalGas provided support to nearby residents who wished to temporarily relocate as a result of the Leak. These programs ended in July 2016. SoCalGas has additionally incurred significant costs to defend against and, in certain cases, settle, civil and criminal litigation arising from the Leak; to pay the costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis to investigate the technical cause of the Leak; to respond to various government and agency investigations regarding the Leak; and to comply with increased regulation imposed as a result of the Leak. As further described below in “Civil and Criminal Litigation,” “Regulatory Proceedings” and “Governmental Investigations and Orders and Additional Regulation,” these activities are ongoing and SoCalGas anticipates that it will incur additional such costs, which may also be significant. Local Community Mitigation Efforts. Pursuant to a directive by the DPH and orders by the LA Superior Court, SoCalGas provided temporary relocation support to residents in the nearby community who requested it. The DPH issued a second directive generally requiring SoCalGas to professionally clean the homes of Porter Ranch residents (the Directive), which is addressed within the Government Plaintiffs Settlement that we discuss below in “Civil and Criminal Litigation.” The costs incurred to mitigate local community impacts have been significant. If any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant delays in receiving insurance recoveries, or if the insurance recoveries are subject to income taxes while the associated costs are not tax deductible, such amounts could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Civil and Criminal Litigation. As of October 28, 2019, 390 lawsuits, including approximately 36,000 plaintiffs, are pending against SoCalGas, some of which have also named Sempra Energy. All these cases, other than a matter brought by the Los Angeles County District Attorney and the federal securities class action discussed below, are coordinated before a single court in the LA Superior Court for pretrial management. In November 2017, the individuals and business entities asserting tort and Proposition 65 claims filed a Third Amended Consolidated Master 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, loss of consortium, wrongful death and violations of Proposition 65 against SoCalGas, with certain causes also naming Sempra Energy. The consolidated complaint seeks compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, injunctive relief, costs of future medical monitoring, civil penalties (including penalties associated with Proposition 65 claims alleging violation of requirements for warning about certain chemical exposures), and attorneys’ fees. The court has scheduled an initial trial for June 24, 2020 for a small number of randomly selected individual plaintiffs. In January 2017, two consolidated class action complaints were filed against SoCalGas and Sempra Energy, one on behalf of a putative class of persons and businesses who own or lease real property within a five-mile radius of the well (the Property Class Action), and a second on behalf of a putative class of all persons and entities conducting business within five miles of the facility (the Business Class Action). Both complaints assert claims for strict liability for ultra-hazardous activities, negligence and violation of the California Unfair Competition Law. The Property Class Action also asserts claims for negligence per se, trespass, permanent and continuing public and private nuisance, and inverse condemnation. The Business Class Action also asserts a claim for negligent interference with prospective economic advantage. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. In May 2019, the California Supreme Court ruled that the purely economic damages alleged in the Business Class Action are not recoverable under the law, and in September 2019, in accordance with the ruling, the LA Superior Court dismissed the strict liability, negligence and negligent interference with prospective economic advantage causes of action in the Business Class Action complaint. Complaints by property developers were filed in 2017 and 2018 against SoCalGas and Sempra Energy alleging causes of action for strict liability, negligence per se, negligence, continuing nuisance, permanent nuisance and violation of the California Unfair Competition Law, as well as claims for negligence against certain directors of SoCalGas. The complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. In October 2018 and January 2019, complaints were filed on behalf of 51 plaintiffs who are firefighters stationed near the Aliso Canyon natural gas storage facility and allege they were injured by exposure to chemicals released during the Leak. The complaints against SoCalGas and Sempra Energy assert causes of actions 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. The complaints seek compensatory and punitive damages for personal injuries, lost wages and/or lost profits, property damage and diminution in property value, and attorney’s fees. In addition, a federal securities class action alleging violation of the federal securities laws was filed against Sempra Energy and certain of its officers and certain of its directors in the U.S. District Court for the Southern District of California. In March 2018, the court dismissed the action with prejudice. The plaintiffs filed a notice of appeal of the dismissal. Five shareholder derivative actions are also pending alleging breach of fiduciary duties against certain officers and certain directors of Sempra Energy and/or SoCalGas, four of which were joined in a Consolidated Shareholder Derivative Complaint in August 2017. Three actions by public entities were filed, including complaints by the County of Los Angeles, on behalf of itself and the people of the State of California, the California Attorney General, acting in an independent capacity and on behalf of the people of the State of California and the CARB, and the Los Angeles City Attorney alleging public nuisance, unfair competition, and violations of California Health and Safety Code provisions regarding discharge of contaminants, among other things, which sought injunctive relief, abatement, civil penalties and damages. The County of Los Angeles also filed a petition seeking a writ of mandate requiring DOGGR and the State Oil and Gas Supervisor to comply with SB 380 and the California Environmental Quality Act, as well as declaratory and injunctive relief against their authorization allowing SoCalGas to inject natural gas at the facility. In August 2018, SoCalGas entered into a settlement agreement with the Los Angeles City Attorney’s Office, the County of Los Angeles, the California Office of the Attorney General and CARB (collectively, the Government Plaintiffs) to settle these public entity actions and the Directive for payments and funding for environmental projects totaling $120 million , including $21 million in civil penalties (the Government Plaintiffs Settlement). Under the settlement agreement, SoCalGas also agreed to continue its fence-line methane monitoring program, establish a safety committee and hire an independent ombudsman to monitor and report on the safety at the facility. This settlement also fully resolves SoCalGas’ commitment to mitigate the actual natural gas released during the Leak and fulfills the requirements of the Governor’s Order, described below, for SoCalGas to pay for a mitigation program developed by CARB. The Government Plaintiffs Settlement was approved by the LA Superior Court in February 2019. Separately, in February 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. Pursuant to a settlement agreement with the Los Angeles County District Attorney’s Office, SoCalGas agreed to plead 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 $233,500 , and operational commitments estimated to cost approximately $6 million , reimbursements and assessments in exchange for the Los Angeles County District Attorney’s Office moving to dismiss the remaining counts at sentencing and settling the complaint (the District Attorney Settlement). SoCalGas completed the commitments and obligations under the District Attorney Settlement, and in November 2016, the LA Superior Court approved the settlement and entered judgment on the notice charge. Certain individuals who object to the settlement petitioned the Court of Appeal to vacate the judgment, contending they should be granted restitution. In July 2019, the Court of Appeal denied the petition in part, but remanded the matter to the trial court to permit the petitioners to prove damages stemming only from the three-day delay in reporting the Leak. The costs of defending against these civil and criminal lawsuits, and any compensatory, statutory or punitive damages, restitution, and civil, administrative and criminal fines, penalties and other costs, if awarded or imposed, as well as the costs of mitigating the actual natural gas released, could be significant. If any of these costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant delays in receiving insurance recoveries, or if the insurance recoveries are subject to income taxes while the associated costs are not tax deductible, such amounts could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Regulatory Proceedings. In January 2016, DOGGR and the CPUC selected Blade to conduct, under their supervision, an independent analysis of the technical root cause of the Leak, to be funded by SoCalGas. In May 2019, Blade released its report regarding its root cause analysis of the Leak. The report concludes that the Leak occurred on the morning of October 23, 2015, beginning with an axial rupture of the production casing of the well caused by external microbial corrosion as a result of contact with groundwater, followed within hours by the complete separation of the casing. Blade asserts that attempts to stop the Leak were unsuccessful due to insufficient kill fluid density and pump rates. Blade’s report assesses whether SoCalGas complied with gas storage regulations in existence at the time of the Leak, and did not identify any instances of non-compliance by SoCalGas. Blade concludes that SoCalGas’ compliance activities conducted prior to the Leak did not find indications of a casing integrity issue. In Blade’s opinion, however, there were measures, none of which were required by gas storage regulations at the time, that could have been taken to aid in the early identification of corrosion and that, in Blade’s opinion, would have prevented or mitigated the Leak. The report also identified well safety practices and regulations that have since been adopted by DOGGR and implemented by SoCalGas, which address most of the root cause of the Leak identified during Blade’s investigation. In February 2017, the CPUC opened a proceeding pursuant to SB 380 to determine the feasibility of minimizing or eliminating the use of the Aliso Canyon natural gas storage facility, while still maintaining energy and electric reliability for the region. The CPUC indicated it intends to conduct the proceeding in two phases, with Phase 1 undertaking a comprehensive effort to develop the appropriate analyses and scenarios to evaluate the impact of reducing or eliminating the use of the Aliso Canyon natural gas storage facility and Phase 2 using those analyses and scenarios to evaluate the impacts of reducing or eliminating the use of the Aliso Canyon natural gas storage facility. The order establishing the scope of the proceeding expressly excludes issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. In January 2019, the CPUC concluded Phase 1 of the proceeding by establishing a framework for the hydraulic, production cost and economic modeling assumptions for the potential reduction in usage or elimination of the Aliso Canyon natural gas storage facility. Phase 2 of the proceeding, which will evaluate the impacts of reducing or eliminating the Aliso Canyon natural gas storage facility using the established framework and models, began in the first quarter of 2019. The CPUC has indicated that it expects to issue its report in 2020. In June 2019, the CPUC opened an OII to consider penalties against SoCalGas for the Leak. In September 2019, the CPUC issued an order bifurcating the proceeding into two phases and establishing the scope and schedule for the first phase. The issues to be determined in the first phase are whether SoCalGas violated Public Utilities Code section 451 or other laws, CPUC orders or decisions, rules or requirements, whether SoCalGas engaged in unreasonable and/or imprudent practices with respect to its operation and maintenance of the Aliso Canyon natural gas storage facility or its related record-keeping practices, whether SoCalGas cooperated sufficiently with the Safety Enforcement Division and Blade during the pre-formal investigation, and whether any of the mitigation proposed by Blade should be implemented to the extent not already done. The second phase will consider whether SoCalGas should be sanctioned for the Leak and what penalties, if any, should be imposed for any violations proven in the first phase, as well as determine the amounts of various costs incurred by SoCalGas and other parties in connection with the Leak and the ratemaking treatment or other disposition of such costs. The costs to respond to this investigation and any sanctions, fines, penalties or other remedies imposed by the CPUC could be significant and may not be covered completely by insurance (including costs in excess of applicable policy limits). Such amounts could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Governmental Investigations and Orders and Additional Regulation. Various governmental agencies, including DOE, DOGGR, DPH, South Coast Air Quality Management District, CARB, Los Angeles Regional Water Quality Control Board, California Division of Occupational Safety and Health, CPUC, PHMSA, EPA, Los Angeles County District Attorney’s Office and California Attorney General’s Office, have investigated or are investigating this incident. In January 2016, the Governor of the State of California proclaimed a state of emergency in Los Angeles County due to the Leak. The proclamation ordered various actions with respect to the Leak, including: (1) applicable agencies must convene an independent panel of scientific and medical experts to review public health concerns stemming from the Leak and evaluate whether additional measures are needed to protect public health; (2) the CPUC must ensure that SoCalGas covers costs related to the Leak and its response while protecting ratepayers; (3) CARB must develop a program, to be funded by SoCalGas, to fully mitigate the Leak’s emissions of methane; and (4) DOGGR, CPUC, CARB and the CEC must submit to the Governor’s Office a report that assesses the long-term viability of natural gas storage facilities in California. The Government Plaintiffs Settlement described above satisfies the mitigation requirement of the Governor’s emergency proclamation. Cost Estimates and Accounting Impact. At September 30, 2019 , SoCalGas estimates its costs related to the Leak are $1,099 million (the cost estimate), which includes $1,069 million of costs recovered or probable of recovery from insurance. Approximately 52 percent of the cost estimate is for the temporary relocation program (including cleaning costs and certain labor costs). The remaining portion of the cost estimate includes costs incurred to defend litigation, the costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis, efforts to control the well, to mitigate the natural gas released, the cost of replacing the lost gas, the costs of settlements with government entities and other costs. The cost estimate does not include potential additional litigation costs, regulatory-related costs or other costs described below, which could be material. SoCalGas adjusts the cost estimate as additional information becomes available. A substantial portion of the cost estimate has been paid, and $45 million is accrued in Reserve for Aliso Canyon Costs and $9 million is accrued in Deferred Credits and Other as of September 30, 2019 on SoCalGas’ and Sempra Energy’s Condensed Consolidated Balance Sheets. As of September 30, 2019 , we recorded the expected recovery of the cost estimate related to the Leak of $354 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 $715 million of insurance proceeds we received through September 30, 2019 . The Insurance Receivable for Aliso Canyon Costs and insurance proceeds received to date relate to portions of the cost estimate described above, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response including for an independent third party to conduct a root cause analysis, the costs to settle certain claims as described above , the estimated costs to perform obligations pursuant to settlement of some of those claims, legal costs and lost gas. If we were to conclude that this receivable or a portion of it is no longer probable of recovery from insurers, some or all of this receivable would be charged against earnings, which could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. As described in “Civil and Criminal Litigation” above , the actions seek compensatory, statutory and punitive damages, restitution, and civil, administrative and criminal fines, penalties and other costs, which, except for the amounts paid or estimated to settle certain actions as described above , are not included in the cost estimate as it is not possible at this time to predict the outcome of these actions or reasonably estimate the amount of damages, restitution or civil, administrative or criminal fines, penalties or other costs that may be imposed. The recorded amounts above also do not include future legal costs necessary to defend litigation, and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Furthermore, the cost estimate does not include any sanctions, fines, penalties or other costs that may be imposed by the CPUC in connection with the OII opened in June 2019 and certain other costs incurred by Sempra Energy associated with defending against shareholder derivative lawsuits. Insurance. Excluding directors’ and officers’ liability insurance, we have at least four kinds of insurance policies that together we estimate provide between $1.2 billion to $1.4 billion in insurance coverage, depending on the nature of the claims. At September 30, 2019 , SoCalGas’ estimate of costs related to the Leak of $1,099 million include $1,069 million of costs recovered or probable of recovery from insurance. This estimate may rise significantly as more information becomes available. Costs not included in the $1,099 million cost estimate could be material. 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. Subject to various policy limits, exclusions and conditions, based on what we know as of the filing date of this report, we believe that costs in the following categories should be recoverable through insurance: costs incurred for temporary relocation and associated processing costs (including cleaning costs and certain labor costs), costs to address the Leak and stop or reduce emissions, costs of the government-ordered response to the Leak including the costs for an independent third party to conduct a root cause analysis, the value of lost gas, costs incurred to mitigate the actual natural gas released, costs associated with litigation and claims by nearby residents and businesses, and, in some circumstances depending on their nature and manner of assessment, fines and penalties. We have been communicating with our insurance carriers and, as discussed above, we have received insurance payments for portions of the costs described above, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response to the Leak, legal costs and lost gas. 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 additional insurance recovery for these costs. If any costs are not covered by insurance (including any costs in excess of applicable policy limits), if there are significant delays in receiving insurance recoveries, or if the insurance recoveries are subject to income taxes while the associated costs are not tax deductible, such amounts could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Natural Gas Storage Operations and Reliability. Natural gas withdrawn from storage is important for service reliability during peak demand periods, including peak electric generation needs in the summer and heating needs in the winter. The Aliso Canyon natural gas storage facility, with a capacity of 86 Bcf (representing 63 percent of SoCalGas’ natural gas storage capacity), is the largest SoCalGas storage facility and an important element of SoCalGas’ delivery system. As a result of the Leak, SoCalGas suspended injection of natural gas into the Aliso Canyon natural gas storage facility beginning in October 2015, and following a comprehensive safety review and authorization by DOGGR and the CPUC’s Executive Director, resumed limited injection operations in July 2017. During the suspension period, SoCalGas advised the California ISO, CEC, CPUC and PHMSA of its concerns that the inability to inject natural gas into the Aliso Canyon natural gas storage facility posed a risk to energy reliability in Southern California. Following the resumption of injection operations, the CPUC has issued a series of directives to SoCalGas specifying the range of working gas to be maintained in the Aliso Canyon natural gas storage facility to help ensure safety and reliability for the region and just and reasonable rates in California, the most recent of which, issued in July 2018, directed SoCalGas to maintain up to 34 Bcf of working gas. Limited withdrawals of natural gas from the facility were made in 2018 and 2019 to augment natural gas supplies during critical demand periods. In July 2019, the CPUC issued a protocol authorizing withdrawals of natural gas from the facility if gas supply is low in the region, to maintain system reliability and price stability. If the Aliso Canyon natural gas storage facility were to be permanently closed, or if future cash flows were otherwise insufficient to recover its carrying value, it could result in an impairment of the facility and significantly higher than expected operating costs and/or additional capital expenditures, and natural gas reliability and electric generation could be jeopardized. At September 30, 2019 , the Aliso Canyon natural gas storage facility had a net book value of $771 million . Any significant impairment of this asset could have a material adverse effect on SoCalGas’ and Sempra Energy’s results of operations for the period in which it is recorded. Higher operating costs and additional capital expenditures incurred by SoCalGas may not be recoverable in customer rates and could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. Sempra Mexico Property Disputes and Permit Challenges Energía Costa Azul. IEnova has been engaged in a long-running land dispute relating to property adjacent to its ECA LNG terminal near Ensenada, Mexico. A claimant to the adjacent property filed complaints in the federal Agrarian Court challenging the refusal of SEDATU in 2006 to issue a title to him for the disputed property. In November 2013, the federal Agrarian Court ordered that SEDATU issue the requested title and cause it to be registered. Both SEDATU and IEnova challenged the ruling, due to lack of notification of the underlying process. In May 2019, a federal court in Mexico reversed the ruling. IEnova expects additional proceedings regarding the claims. Several administrative challenges are pending in Mexico before the Mexican environmental protection agency and the Federal Tax and Administrative Courts seeking revocation of the environmental impact authorization issued to ECA in 2003. These cases generally allege that the conditions and mitigation measures in the environmental impact authorization are inadequate and challenge findings that the activities of the terminal are consistent with regional development guidelines. Additionally, in August 2018, a claimant filed a challenge in the federal district court in Ensenada, Baja California in relation to the environmental and social impact permits issued to ECA in September 2017 and December 2017, respectively, to allow natural gas liquefaction activities at the ECA LNG terminal. The court issued a provisional injunction on September 28, 2018 and maintained that provisional injunction at an April 11, 2019 hearing. In December 2018, the relevant Mexican regulators approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility at the ECA LNG terminal in two phases. On May 17, 2019, the court canceled the provisional injunction. The claimant has appealed the court’s decision. That appeal and the claimant’s underlying challenge to the permits remain pending. Cases involving t wo parcels of real property have been filed against ECA. In one case, filed in the federal Agrarian Court in 2006, the plaintiffs seek to annul the recorded property title for a parcel on which the ECA LNG terminal is situated and to obtain possession of a different parcel that allegedly sits in the same place. Another civil complaint filed in the state court was served in April 2012 seeking to invalidate the contract by which ECA purchased another of the terminal parcels, on the grounds the purchase price was unfair; the plaintiff filed a second complaint in 2013 in the federal Agrarian Court seeking an order that SEDATU issue title to her. In January 2016, the federal Agrarian Court ruled against the plaintiff, and the plaintiff appealed the ruling. In May 2018, the state court dismissed the civil complaint, and the plaintiff has appealed. IEnova expects further proceedings on these two matters. An unfavorable final decision on these property disputes or permit challenges could materially and adversely affect our existing natural gasification operations and our planned natural gas liquefaction projects currently in development at ECA. Guaymas-El Oro Segment of the Sonora Pipeline. IEnova’s Sonora natural gas pipeline consists of two segments, the Sasabe-Puerto Libertad-Guaymas segment, and the Guaymas-El Oro segment. Each segment has its own service agreement with the CFE. In 2015, the Yaqui tribe, with the exception of some members living in the Bácum community, granted its consent and a right-of-way easement agreement for the construction of the Guaymas-El Oro segment of the Sonora natural gas pipeline that crosses its territory. Representatives of the Bácum community filed a legal challenge in Mexican federal court demanding the right to withhold consent for the project, the stoppage of work in the Yaqui territory and damages. In 2016, the judge granted a suspension order that prohibited the construction of such segment through the Bácum community territory. Because the pipeline does not pass through the Bácum community, IEnova did not believe the 2016 suspension or

SEGMENT INFORMATION

SEGMENT INFORMATION	9 Months Ended
	Sep. 30, 2019
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION At September 30, 2019 , we had five separately managed reportable segments, as follows: ▪ SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. ▪ SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. ▪ Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25 -percent interest in Oncor, a regulated electric transmission and distribution utility serving customers primarily in the north-central, eastern, western and panhandle regions of Texas, and our indirect, 50 -percent interest in Sharyland Holdings, which owns a regulated electric transmission and distribution utility serving customers near the Texas-Mexico border. As we discuss in Note 5, we acquired an indirect, 50 -percent interest in Sharyland Holdings in May 2019. ▪ Sempra Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. ▪ Sempra LNG (previously known as Sempra LNG & Midstream) develops, owns and operates, or holds interests in, terminals for the import and export of LNG and sale of natural gas, natural gas pipelines and marketing operations, all within the U.S. and Mexico. In February 2019, we completed the sale of our natural gas storage assets at Mississippi Hub and Bay Gas. In December 2018, Sempra Renewables completed the sale of all its operating solar assets, solar and battery storage development projects and one wind generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist. The tables below include amounts from Sempra Renewables up until the cessation of the segment. As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment has been reclassified to discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings and cash flows. 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. The cost of common services shared by the business segments is 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 activities of parent organizations and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations. SEGMENT INFORMATION (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 REVENUES SDG&E $ 1,427 $ 1,299 $ 3,666 $ 3,405 SoCalGas 975 802 3,142 2,700 Sempra Mexico 357 410 1,058 1,028 Sempra Renewables — 38 10 103 Sempra LNG 100 147 327 330 All other 1 — 1 — Eliminations and adjustments (2 ) — (3 ) (2 ) Intersegment revenues (1) (100 ) (131 ) (315 ) (288 ) Total $ 2,758 $ 2,565 $ 7,886 $ 7,276 INTEREST EXPENSE SDG&E (2) $ 106 $ 56 $ 311 $ 161 SoCalGas 36 29 104 82 Sempra Mexico 30 30 89 90 Sempra Renewables — 5 3 15 Sempra LNG 11 3 18 18 All other 117 122 336 371 Intercompany eliminations (21 ) (23 ) (64 ) (81 ) Total $ 279 $ 222 $ 797 $ 656 INTEREST INCOME SDG&E $ 1 $ 1 $ 3 $ 3 SoCalGas — — 1 1 Sempra Mexico 20 17 58 48 Sempra Renewables — 2 11 6 Sempra LNG 15 10 45 36 All other 1 1 2 14 Intercompany eliminations (15 ) (12 ) (56 ) (42 ) Total $ 22 $ 19 $ 64 $ 66 DEPRECIATION AND AMORTIZATION SDG&E $ 196 $ 174 $ 571 $ 509 SoCalGas 154 141 449 414 Sempra Mexico 46 45 136 131 Sempra Renewables — — — 27 Sempra LNG 2 2 7 24 All other 4 4 11 10 Total $ 402 $ 366 $ 1,174 $ 1,115 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 71 $ 53 $ 111 $ 151 SoCalGas 35 (7 ) 50 75 Sempra Mexico — 126 116 226 Sempra Renewables — (2 ) 4 (67 ) Sempra LNG (2 ) 6 4 (488 ) All other (43 ) (37 ) (135 ) (118 ) Total $ 61 $ 139 $ 150 $ (221 ) EQUITY EARNINGS (LOSSES) Equity earnings (losses), before income tax: Sempra Texas Utilities $ — $ — $ 1 $ — Sempra Renewables — 12 5 (170 ) Sempra LNG 17 — 19 1 All other — (64 ) (1 ) (67 ) 17 (52 ) 24 (236 ) Equity earnings (losses), net of income tax: Sempra Texas Utilities 212 154 418 283 Sempra Mexico 37 (28 ) 43 2 249 126 461 285 Total $ 266 $ 74 $ 485 $ 49 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 263 $ 205 $ 582 $ 521 SoCalGas 143 (14 ) 437 244 Sempra Texas Utilities 212 154 419 283 Sempra Mexico 84 44 214 161 Sempra Renewables — 34 59 (54 ) Sempra LNG 2 16 13 (764 ) Discontinued operations 248 46 267 115 All other (139 ) (211 ) (383 ) (446 ) Total $ 813 $ 274 $ 1,608 $ 60 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,071 $ 1,194 SoCalGas 1,019 1,127 Sempra Mexico 420 255 Sempra Renewables 2 46 Sempra LNG 74 19 All other 4 13 Total $ 2,590 $ 2,654 September 30, 2019 December 31, 2018 ASSETS SDG&E $ 20,336 $ 19,225 SoCalGas 16,023 15,389 Sempra Texas Utilities 11,248 9,652 Sempra Mexico 9,759 9,165 Sempra Renewables — 2,549 Sempra LNG 3,755 4,060 Discontinued operations 4,115 3,718 All other 1,585 1,070 Intersegment receivables (2,236 ) (4,190 ) Total $ 64,585 $ 60,638 EQUITY METHOD AND OTHER INVESTMENTS Sempra Texas Utilities $ 11,248 $ 9,652 Sempra Mexico 750 747 Sempra Renewables — 291 Sempra LNG 1,216 1,271 All other 7 11 Total $ 13,221 $ 11,972 (1) Revenues for reportable segments include intersegment revenues of $1 million , $16 million , $29 million and $54 million for the three months ended September 30, 2019 ; $4 million , $50 million , $89 million and $172 million for the nine months ended September 30, 2019 ; $1 million , $15 million , $31 million and $84 million for the three months ended September 30, 2018 ; and $3 million , $47 million , $88 million , and $150 million for the nine months ended September 30, 2018 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively. (2) As we discuss in Note 2, in accordance with adoption of the lease standard on January 1, 2019, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Interest Expense.

GENERAL INFORMATION AND OTHER_2

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Policies)	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Energy Sempra Energy’s Condensed Consolidated Financial Statements include the accounts of Sempra Energy, a California-based energy-services holding company, and its consolidated subsidiaries and VIEs. Sempra Global is the holding company for most of our subsidiaries that are not subject to California or Texas utility regulation. Sempra Energy’s businesses were managed within six separate reportable segments until April 2019 and five separate reportable segments thereafter, which we discuss in Note 12. In the first quarter of 2019, our Sempra LNG & Midstream segment was renamed “Sempra LNG.” This segment name change had no impact on our historical position, results of operations, cash flow or segment level results previously reported. All references in these Notes to our reportable segments are not intended to refer to any legal entity with the same or similar name. SDG&E SDG&E’s Condensed Consolidated Financial Statements include its accounts and the accounts of a VIE of which SDG&E was the primary beneficiary until August 23, 2019, at which time SDG&E deconsolidated the VIE, as we discuss below in “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. In this report, we refer to SDG&E and SoCalGas collectively as the California Utilities.
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 (until deconsolidation of the VIE on August 23, 2019); and ▪ the Condensed Financial Statements and related Notes of SoCalGas. We have prepared the Condensed Consolidated Financial Statements in conformity with 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, 2019 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, 2018 balance sheet information in the Condensed Consolidated Financial Statements has been derived from our audited 2018 Consolidated Financial Statements in the Annual Report, which for Sempra Energy has been retrospectively adjusted for discontinued operations, as we discuss below. 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 SEC. We describe our significant accounting policies in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report and the impact of the adoption of new accounting standards on those policies in Note 2 below. 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.
Discontinued Operations	Discontinued Operations On January 25, 2019, our board of directors approved a plan to sell our South American businesses based on our strategic focus on North America. We determined that these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with these businesses, met the held-for-sale criteria. These businesses are presented as discontinued operations, as the planned sales represent a strategic shift that will have a major effect on our operations and financial results. Throughout this report, the financial information for all periods presented has been adjusted to reflect the presentation of these businesses as discontinued operations, which we discuss further in Note 5. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.
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 the right to receive benefits that could be significant to the VIE.
Earnings Per Share Policy	We discuss share-based compensation plans and related awards further in Note 10 of the Notes to Consolidated Financial Statements in the Annual Report. The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we entered into in 2018 is reflected in our diluted EPS calculation using the treasury stock method. We anticipate there will be a dilutive effect on our EPS when the average market price of shares of our common stock is above the applicable adjusted forward sale price, subject to increase or decrease based on the overnight bank funding rate, less a spread, and subject to decrease by amounts related to expected dividends on shares of our common stock during the term of the forward sale agreements. The computation of diluted EPS for both the three months and nine months ended September 30, 2019 excludes zero potentially dilutive shares because to include them would be antidilutive for those periods. The computation of diluted EPS for the three months and nine months ended September 30, 2018 excludes zero and 2,857,143 potentially dilutive shares, respectively, because to include them would be antidilutive for the period. Additionally, if we decide to physically settle or net share settle the forward sale agreements, delivery of our shares to the forward purchasers on any such physical settlement or net share settlement of the forward sale agreements would result in dilution to our EPS. Basic EPS is calculated by dividing earnings attributable to common shares (from both continuing and discontinued operations) 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 ETR anticipated for the full year. Unusual and infrequent items and items that cannot be reliably estimated are recorded in the interim period in which they occur, which can result in variability in the ETR.
Flow-through rate-making treatment tax policy	For SDG&E and SoCalGas, the CPUC requires flow-through rate-making treatment for the current income tax benefit or expense arising from certain property-related and other temporary differences between the treatment for financial reporting and income tax, which will reverse over time. Under the regulatory accounting treatment required for these flow-through temporary differences, deferred income tax assets and liabilities are not recorded to deferred income tax expense, but rather to a regulatory asset or liability, which impacts the ETR. As a result, changes in the relative size of these items compared to pretax income, from period to period, can cause variations in the ETR. The following items are subject to flow-through treatment: ▪ repairs expenditures related to a certain portion of utility plant fixed assets; ▪ the equity portion of AFUDC, which is non-taxable; ▪ 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; and ▪ state income taxes.
New Accounting Standards	NEW ACCOUNTING STANDARDS We describe below recent accounting pronouncements that have had or may have a significant effect on our financial condition, results of operations, cash flows or disclosures. ASU 2016-02, “Leases,” ASU 2018-01, “Land Easement Practical Expedient for Transition to Topic 842,” ASU 2018-10, “Codification Improvements to Topic 842, Leases,” ASU 2018-11, “Leases (Topic 842): Targeted Improvements,” ASU 2018-20, “Narrow-Scope Improvements for Lessors” and ASU 2019-01, “Leases (Topic 842): Codification Improvements” (collectively referred to as the “lease standard”): In 2016, the Financial Accounting Standards Board began issuing the first in a series of ASUs intended to increase transparency and comparability among organizations with leasing activities. The most significant provision of the lease standard is the requirement that lessees recognize operating lease ROU assets and lease liabilities on the balance sheet. We adopted the lease standard on January 1, 2019, using the optional transition method to apply the new guidance prospectively as of January 1, 2019, rather than as of the earliest period presented. We elected the package of practical expedients that permits us to not reassess (a) whether a contract is or contains a lease, (b) lease classification or (c) determination of initial direct costs, which allows us to carry forward accounting conclusions under previous U.S. GAAP on contracts that commenced prior to adoption of the lease standard. We also elected the land easement practical expedient, which allows us to continue to account for pre-existing land easements under our accounting policy that existed before adoption of the lease standard. We did not elect the practical expedient to use hindsight in making judgments when determining the lease term. The adoption of the lease standard did not change our previously reported financial statements. However, in accordance with the lease standard, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Depreciation and Amortization Expense and Interest Expense on Sempra Energy’s and SDG&E’s statements of operations. Additionally, the adoption of the lease standard had a material impact on our balance sheets at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. Our finance leases were already included on our balance sheets prior to adoption of the lease standard, consistent with previous U.S. GAAP for capital leases. The following table shows the initial increases (decreases) on our balance sheets at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Assets held for sale $ 13 $ — $ — Sundry (71 ) — — Property, plant and equipment, net (147 ) — — Right-of-use assets – operating leases 603 130 116 Deferred income tax assets (3 ) — — Other current liabilities 80 20 23 Long-term debt (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — As a result of the adoption of the lease standard, we derecognized our corporate headquarters building lease in accordance with the transition provisions for build-to-suit arrangements. On a prospective basis, we will account for the corporate headquarters building lease as an operating lease. The initial impact is included in the above table. We include additional disclosures about our leases in Note 11. ASU 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13, as amended by subsequently issued ASUs, 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, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2018. The amendments are to be applied using a modified retrospective approach through a cumulative-effect adjustment to retained earnings at the beginning of the first reporting period in the year of adoption. We are currently evaluating the effect of the standard on our ongoing financial reporting. On a prospective basis, the new standard will primarily apply to our accounts receivable balances, amounts due from unconsolidated affiliates and off-balance sheet financial guarantees. We will adopt the standard on January 1, 2020. ASU 2017-04, “Simplifying the Test for Goodwill Impairment”: ASU 2017-04 removes the second step of the goodwill impairment test, which requires a hypothetical purchase price allocation. An entity will be required to apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. For public entities, ASU 2017-04 is effective for annual or interim goodwill impairment tests in fiscal years beginning after December 15, 2019, with early adoption permitted. The amendments are to be applied on a prospective basis. We will adopt the standard on January 1, 2020. ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: ASU 2018-02 contains amendments that allow a reclassification from AOCI to retained earnings for stranded tax effects resulting from the TCJA. Under ASU 2018-02, an entity is required to provide certain disclosures regarding stranded tax effects, including its accounting policy related to releasing the income tax effects from AOCI. The amendments in this update can be applied either as of the beginning of the period of adoption or retrospectively as of the date of enactment of the TCJA and to each period in which the effect of the TCJA is recognized. We adopted ASU 2018-02 on January 1, 2019 and reclassified the income tax effects of the TCJA from AOCI to retained earnings. The impact from adoption of ASU 2018-02 on January 1, 2019 was as follows: ▪ Sempra Energy: increase of $40 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $42 million to Accumulated Other Comprehensive Loss; ▪ SDG&E: increase of $2 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss; and ▪ SoCalGas: increase of $2 million to beginning Retained Earnings, $2 million to noncurrent Regulatory Liabilities and $4 million to Accumulated Other Comprehensive Loss.
Derivative Financial Instruments	FOREIGN CURRENCY DERIVATIVES We utilize cross-currency swaps to hedge exposure related to Mexican peso-denominated debt at our Mexican subsidiaries and JVs. 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 JVs 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 JVs, 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; however, we generally do not hedge our deferred income tax assets and liabilities or for inflation. In addition to the amounts noted above, we 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 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 have derivatives that are either (1) cash flow hedges, (2) fair value hedges, 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 OCI (cash flow hedges), on the balance sheet (regulatory offsets), or recognized in earnings (fair value hedges). We classify cash flows from the principal settlements of cross-currency swaps that hedge exposure related to Mexican peso-denominated debt as financing activities and settlements of other 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. 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 natural gas and electricity derivatives, 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 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 and Sempra LNG may use natural gas and electricity derivatives, as appropriate, to optimize the earnings of their assets which support the following businesses: LNG, natural gas transportation and storage, and power generation. Gains and losses associated with undesignated derivatives are recognized in Energy-Related Businesses Revenues or in Energy-Related Businesses Cost of Sales on the Condensed Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. Sempra Mexico may also use natural gas energy derivatives with the objective of managing price risk and lowering natural gas prices at its 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 and GHG allowances.
Fair Value Measurement Policy	A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 8. 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. Because unrealized gains and losses are recorded as regulatory assets and liabilities, they do not affect earnings. Fair Value of Financial Instruments We have not changed the valuation techniques or types of inputs we use to measure recurring fair value since December 31, 2018. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 8 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 in the tables below include the following (other than a $6 million investment at September 30, 2019 measured at net asset value): ▪ Nuclear decommissioning trusts reflect the assets of SDG&E’s NDT, 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. 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 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 or income 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 in “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, 2019 and December 31, 2018 . The impact associated with discounting is negligible. Because these 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. 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 8. 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.
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 reasonably estimate 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.
Gains and Losses on NDTs	Net unrealized gains and losses, as well as realized gains and losses that are reinvested in the NDT, are included in noncurrent Regulatory Liabilities 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.
Lessee, Leases Policy	Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. In such cases, we recognize short-term lease costs on a straight-line basis over the lease term. Our short-term lease costs for the period reasonably reflect our short-term lease commitments. As of the lease commencement date, we recognize a lease liability for our obligation to make future lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. We also record a ROU asset for our right to use the underlying asset, which is initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. Like other long-lived assets, we test ROU assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of the ROU assets. For our operating leases, our non-regulated entities recognize a single lease cost on a straight-line basis over the lease term in operating expenses. The California Utilities recognize this single lease cost on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations. For our finance leases, the interest expense on the lease liability and amortization of the ROU asset are accounted for separately. Our non-regulated entities use the effective interest rate method to account for the imputed interest on the lease liability and amortize the ROU asset on a straight-line basis over the lease term. The California Utilities recognize amortization of the ROU asset on a basis that is consistent with the recovery of such costs in accordance with U.S. GAAP governing rate-regulated operations.
Lessor, Leases Policy	Generally, we recognize operating lease income on a straight-line basis over the lease term and evaluate the underlying asset for impairment. Certain of our leases contain rate adjustments or are based on foreign currency exchange rates that may result in lease payments received that vary from one period to the next.
Segment Information	At September 30, 2019 , we had five separately managed reportable segments, as follows: ▪ SDG&E provides electric service to San Diego and southern Orange counties and natural gas service to San Diego County. ▪ SoCalGas is a natural gas distribution utility, serving customers throughout most of Southern California and part of central California. ▪ Sempra Texas Utilities holds our investment in Oncor Holdings, which owns an 80.25 -percent interest in Oncor, a regulated electric transmission and distribution utility serving customers primarily in the north-central, eastern, western and panhandle regions of Texas, and our indirect, 50 -percent interest in Sharyland Holdings, which owns a regulated electric transmission and distribution utility serving customers near the Texas-Mexico border. As we discuss in Note 5, we acquired an indirect, 50 -percent interest in Sharyland Holdings in May 2019. ▪ Sempra Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. ▪ Sempra LNG (previously known as Sempra LNG & Midstream) develops, owns and operates, or holds interests in, terminals for the import and export of LNG and sale of natural gas, natural gas pipelines and marketing operations, all within the U.S. and Mexico. In February 2019, we completed the sale of our natural gas storage assets at Mississippi Hub and Bay Gas. In December 2018, Sempra Renewables completed the sale of all its operating solar assets, solar and battery storage development projects and one wind generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Upon completion of this sale, remaining nominal business activities at Sempra Renewables were subsumed into Parent and other and the Sempra Renewables segment ceased to exist. The tables below include amounts from Sempra Renewables up until the cessation of the segment. As we discuss in Note 5, the financial information related to our businesses that constituted the Sempra South American Utilities segment has been reclassified to discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We evaluate each segment’s performance based on its contribution to Sempra Energy’s reported earnings and cash flows. 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. The cost of common services shared by the business segments is 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.

GENERAL INFORMATION AND OTHER_3

GENERAL INFORMATION AND OTHER FINANCIAL DATA (Tables)	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Cash and Cash Equivalents	The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported on the Condensed Consolidated Balance Sheets to the sum of such amounts reported on the Condensed Consolidated Statements of Cash Flows. We provide information about the nature of restricted cash in Note 1 of the Notes to Consolidated Financial Statements in the Annual Report. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) September 30, December 31, 2019 2018 Sempra Energy Consolidated: Cash and cash equivalents $ 106 $ 102 Restricted cash, current 28 35 Restricted cash, noncurrent 3 21 Cash, cash equivalents and restricted cash in discontinued operations 360 88 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 497 $ 246 SDG&E: Cash and cash equivalents $ 24 $ 8 Restricted cash, current — 11 Restricted cash, noncurrent — 18 Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows $ 24 $ 37
Inventory Table	The following table presents the components of inventories by segment. INVENTORY BALANCES (Dollars in millions) Natural gas LNG Materials and supplies Total September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 September 30, 2019 December 31, 2018 SDG&E $ 1 $ — $ — $ — $ 91 $ 102 $ 92 $ 102 SoCalGas 87 92 — — 47 42 134 134 Sempra Mexico — — 6 4 16 15 22 19 Sempra LNG 22 3 — — — — 22 3 Sempra Energy Consolidated $ 110 $ 95 $ 6 $ 4 $ 154 $ 159 $ 270 $ 258
Capitalized Financing Costs Table	The table below summarizes capitalized interest and AFUDC. CAPITALIZED FINANCING COSTS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Sempra Energy Consolidated $ 46 $ 47 $ 144 $ 150 SDG&E 19 20 56 67 SoCalGas 13 10 35 39
Variable Interest Entity Table	The following table summarizes the deconsolidation: DECONSOLIDATION OF OTAY MESA VIE (Dollars in millions) August 23, 2019 Cash and cash equivalents $ 8 Accounts receivable, net 11 Inventories 4 Total current assets 23 Property, plant and equipment, net 272 Other noncurrent assets 27 Total assets $ 322 Accounts payable $ 10 Other 2 Total current liabilities 12 Asset retirement obligations 2 Deferred credits and other 27 Total deferred credits and other liabilities 29 Noncontrolling interest 281 Total liabilities and equity $ 322 AMOUNTS ASSOCIATED WITH TAX EQUITY ARRANGEMENTS (1) (Dollars in millions) Three months ended September 30, Nine months ended 2018 2019 2018 REVENUES Energy-related businesses $ 28 $ 8 $ 77 EXPENSES Operation and maintenance (5 ) (2 ) (13 ) Depreciation and amortization (13 ) (4 ) (36 ) Income before income taxes 10 2 28 Income tax expense (4 ) — (16 ) Net income 6 2 12 Losses (earnings) attributable to noncontrolling interests (2) 9 (1 ) 50 Earnings attributable to common shares $ 15 $ 1 $ 62 ( 1) Amounts for 2019 include activity until deconsolidation of the wind entities in April 2019. Amounts for 2018 include activity until deconsolidation of the solar entities in December 2018 . (2) Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages. The Condensed Consolidated Statements of Operations of Sempra Energy and SDG&E include the following amounts associated with Otay Mesa VIE until its deconsolidation on August 23, 2019. The amounts are net of eliminations of transactions between SDG&E and Otay Mesa VIE. The captions in the table below 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, 2019 (1) 2018 2019 (1) 2018 Operating expenses Cost of electric fuel and purchased power $ (17 ) $ (28 ) $ (52 ) $ (60 ) Operation and maintenance 2 3 10 11 Depreciation and amortization 8 8 23 23 Total operating expenses (7 ) (17 ) (19 ) (26 ) Operating income 7 17 19 26 Interest expense (4 ) (6 ) (12 ) (16 ) Income before income taxes/Net income 3 11 7 10 Earnings attributable to noncontrolling interest (3 ) (11 ) (7 ) (10 ) Earnings attributable to common shares $ — $ — $ — $ — (1) Amounts for 2019 include activity until deconsolidation on August 23, 2019.
Net Periodic Benefit Cost Table	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, 2019 2018 2019 2018 Service cost $ 27 $ 29 $ 4 $ 4 Interest cost 34 35 9 9 Expected return on assets (36 ) (35 ) (17 ) (18 ) Amortization of: Prior service cost 3 3 — — Actuarial loss (gain) 8 6 (3 ) (2 ) Settlement charges 4 9 — — Special termination benefits — — — 5 Net periodic benefit cost (credit) 40 47 (7 ) (2 ) Regulatory adjustments 3 (11 ) 8 2 Total expense recognized $ 43 $ 36 $ 1 $ — Nine months ended September 30, 2019 2018 2019 2018 Service cost $ 82 $ 95 $ 12 $ 15 Interest cost 104 104 27 27 Expected return on assets (108 ) (117 ) (52 ) (53 ) Amortization of: Prior service cost 9 8 — — Actuarial loss (gain) 29 25 (8 ) (4 ) Settlement charges 26 48 — — Special termination benefits — — — 5 Net periodic benefit cost (credit) 142 163 (21 ) (10 ) Regulatory adjustments (30 ) (91 ) 22 11 Total expense recognized $ 112 $ 72 $ 1 $ 1 NET PERIODIC BENEFIT COST – SDG&E (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2019 2018 2019 2018 Service cost $ 7 $ 7 $ 1 $ 1 Interest cost 9 9 1 2 Expected return on assets (9 ) (10 ) (3 ) (3 ) Amortization of: Prior service cost — — 1 — Actuarial loss (gain) 2 — — (1 ) Settlement charges — 1 — — Special termination benefits — — — 3 Net periodic benefit cost 9 7 — 2 Regulatory adjustments (1 ) (7 ) — (2 ) Total expense recognized $ 8 $ — $ — $ — Nine months ended September 30, 2019 2018 2019 2018 Service cost $ 22 $ 23 $ 3 $ 3 Interest cost 26 26 5 5 Expected return on assets (29 ) (35 ) (9 ) (10 ) Amortization of: Prior service cost 2 1 2 2 Actuarial loss (gain) 9 3 (1 ) (2 ) Settlement charges — 17 — — Special termination benefits — — — 3 Net periodic benefit cost 30 35 — 1 Regulatory adjustments (13 ) (34 ) — (1 ) Total expense recognized $ 17 $ 1 $ — $ — NET PERIODIC BENEFIT COST – SOCALGAS (Dollars in millions) Pension benefits Other postretirement benefits Three months ended September 30, 2019 2018 2019 2018 Service cost $ 17 $ 19 $ 3 $ 3 Interest cost 23 23 6 6 Expected return on assets (24 ) (22 ) (14 ) (13 ) Amortization of: Prior service cost (credit) 2 2 (1 ) (1 ) Actuarial loss (gain) 3 3 (2 ) (1 ) Settlement charges — 2 — — Special termination benefits — — — 2 Net periodic benefit cost (credit) 21 27 (8 ) (4 ) Regulatory adjustments 4 (4 ) 8 4 Total expense recognized $ 25 $ 23 $ — $ — Nine months ended September 30, 2019 2018 2019 2018 Service cost $ 51 $ 62 $ 9 $ 11 Interest cost 68 68 20 20 Expected return on assets (71 ) (73 ) (43 ) (41 ) Amortization of: Prior service cost (credit) 6 6 (2 ) (2 ) Actuarial loss (gain) 14 15 (6 ) (2 ) Settlement charges — 25 — — Special termination benefits — — — 2 Net periodic benefit cost (credit) 68 103 (22 ) (12 ) Regulatory adjustments (17 ) (57 ) 22 12 Total expense recognized $ 51 $ 46 $ — $ —
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 2019 . BENEFIT PLAN CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Contributions through September 30, 2019: Pension plans $ 130 $ 17 $ 51 Other postretirement benefit plans 6 — 1 Total expected contributions in 2019: Pension plans $ 280 $ 53 $ 152 Other postretirement benefit plans 8 1 1
Earnings Per Share Computations Table	Basic EPS is calculated by dividing earnings attributable to common shares (from both continuing and discontinued operations) 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 (LOSSES) PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Numerator for continuing operations: Income from continuing operations, net of income tax $ 653 $ 280 $ 1,570 $ 25 (Earnings) losses attributable to noncontrolling interests (52 ) (16 ) (121 ) 10 Mandatory convertible preferred stock dividends (36 ) (36 ) (107 ) (89 ) Preferred dividends of subsidiary — — (1 ) (1 ) Earnings (losses) from continuing operations attributable to common shares for basic EPS 565 228 1,341 (55 ) Add back dividends for dilutive mandatory convertible preferred stock (1) 26 — — — Earnings (losses) from continuing operations attributable to common shares for diluted EPS $ 591 $ 228 $ 1,341 $ (55 ) Numerator for discontinued operations: Income from discontinued operations, net of income tax $ 256 $ 54 $ 292 $ 137 Earnings attributable to noncontrolling interests (8 ) (8 ) (25 ) (22 ) Earnings from discontinued operations attributable to common shares $ 248 $ 46 $ 267 $ 115 Numerator for earnings: Earnings attributable to common shares for basic EPS $ 813 $ 274 $ 1,608 $ 60 Add back dividends for dilutive mandatory convertible preferred stock (1) 26 — — — Earnings attributable to common shares for diluted EPS $ 839 $ 274 $ 1,608 $ 60 Denominator: Weighted-average common shares outstanding for basic EPS (2) 277,360 273,944 275,684 265,963 Dilutive effect of stock options and RSUs (3)(4) 1,636 854 1,381 — Dilutive effect of common shares sold forward (3) 3,555 1,109 2,744 — Dilutive effect of mandatory convertible preferred stock 13,238 — — — Weighted-average common shares outstanding for diluted EPS 295,789 275,907 279,809 265,963 Basic EPS: Earnings (losses) from continuing operations attributable to common shares $ 2.04 $ 0.83 $ 4.86 $ (0.21 ) Earnings from discontinued operations attributable to common shares $ 0.89 $ 0.17 $ 0.97 $ 0.44 Earnings attributable to common shares $ 2.93 $ 1.00 $ 5.83 $ 0.23 Diluted EPS: Earnings (losses) from continuing operations attributable to common shares $ 2.00 $ 0.82 $ 4.79 $ (0.21 ) Earnings from discontinued operations attributable to common shares $ 0.84 $ 0.17 $ 0.95 $ 0.44 Earnings attributable to common shares $ 2.84 $ 0.99 $ 5.74 $ 0.23 (1) In the three months ended September 30, 2019, due to the dilutive effect of the series A preferred stock, the numerator used to calculate diluted EPS includes an add-back of series A preferred stock dividends declared in that quarter. (2) Includes 618 and 645 average fully vested RSUs held in our Deferred Compensation Plan for the three months ended September 30, 2019 and 2018 , respectively, and 615 and 638 of such RSUs for the nine months ended September 30, 2019 and 2018 , respectively. These fully vested RSUs 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. (3) In the nine months ended September 30, 2018 , the total weighted-average potentially dilutive stock options and RSUs of 736 and common stock shares sold forward of 945 were not included in the computation of diluted EPS since to do so would have decreased the losses from continuing operations attributable to common shares. (4) Due to market fluctuations of both Sempra Energy common stock and the comparative indices used to determine the vesting percentage of our total shareholder return performance-based RSUs, which we discuss in Note 10 of the Notes to Consolidated Financial Statements in the Annual Report, dilutive RSUs may vary widely from period-to-period.
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 NCI. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (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, 2019 and 2018 Sempra Energy Consolidated (2) : Balance as of June 30, 2019 $ (518 ) $ (213 ) $ (117 ) $ (848 ) OCI before reclassifications (91 ) (41 ) (7 ) (139 ) Amounts reclassified from AOCI — 4 5 9 Net OCI (91 ) (37 ) (2 ) (130 ) Balance as of September 30, 2019 $ (609 ) $ (250 ) $ (119 ) $ (978 ) Balance as of June 30, 2018 $ (482 ) $ (40 ) $ (79 ) $ (601 ) OCI before reclassifications (16 ) 19 (18 ) (15 ) Amounts reclassified from AOCI — (4 ) 8 4 Net OCI (16 ) 15 (10 ) (11 ) Balance as of September 30, 2018 $ (498 ) $ (25 ) $ (89 ) $ (612 ) SDG&E: Balance as of June 30, 2019 and September 30, 2019 $ (11 ) $ (11 ) Balance as of June 30, 2018 $ (8 ) $ (8 ) OCI before reclassifications (6 ) (6 ) Net OCI (6 ) (6 ) Balance as of September 30, 2018 $ (14 ) $ (14 ) SoCalGas: Balance as of June 30, 2019 $ (14 ) $ (6 ) $ (20 ) Amounts reclassified from AOCI 1 — 1 Net OCI 1 — 1 Balance as of September 30, 2019 $ (13 ) $ (6 ) $ (19 ) Balance as of June 30, 2018 and September 30, 2018 $ (13 ) $ (7 ) $ (20 ) (1) All amounts are net of income tax, if subject to tax, and exclude NCI. (2) Includes discontinued operations. CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT (1) (CONTINUED) (Dollars in millions) Foreign currency translation adjustments Financial instruments Pension and other postretirement benefits Total accumulated other comprehensive income (loss) Nine months ended September 30, 2019 and 2018 Sempra Energy Consolidated (2) : Balance as of December 31, 2018 $ (564 ) $ (82 ) $ (118 ) $ (764 ) Cumulative-effect adjustment from change in accounting principle — (25 ) (17 ) (42 ) OCI before reclassifications (3) (45 ) (153 ) (13 ) (211 ) Amounts reclassified from AOCI (3) — 10 29 39 Net OCI (45 ) (143 ) 16 (172 ) Balance as of September 30, 2019 $ (609 ) $ (250 ) $ (119 ) $ (978 ) Balance as of December 31, 2017 $ (420 ) $ (122 ) $ (84 ) $ (626 ) Cumulative-effect adjustment from change in accounting principle — (3 ) — (3 ) OCI before reclassifications (78 ) 104 (17 ) 9 Amounts reclassified from AOCI — (4 ) 12 8 Net OCI (78 ) 100 (5 ) 17 Balance as of September 30, 2018 $ (498 ) $ (25 ) $ (89 ) $ (612 ) SDG&E: Balance as of December 31, 2018 $ (10 ) $ (10 ) Cumulative-effect adjustment from change in accounting principle (2 ) (2 ) Amounts reclassified from AOCI 1 1 Net OCI 1 1 Balance as of September 30, 2019 $ (11 ) $ (11 ) Balance as of December 31, 2017 $ (8 ) $ (8 ) OCI before reclassifications (6 ) (6 ) Net OCI (6 ) (6 ) Balance as of September 30, 2018 $ (14 ) $ (14 ) SoCalGas: Balance as of December 31, 2018 $ (12 ) $ (8 ) $ (20 ) Cumulative-effect adjustment from change in accounting principle (2 ) (2 ) (4 ) Amounts reclassified from AOCI (3) 1 4 5 Net OCI 1 4 5 Balance as of September 30, 2019 $ (13 ) $ (6 ) $ (19 ) Balance as of December 31, 2017 $ (13 ) $ (8 ) $ (21 ) Amounts reclassified from AOCI — 1 1 Net OCI — 1 1 Balance as of September 30, 2018 $ (13 ) $ (7 ) $ (20 ) (1) All amounts are net of income tax, if subject to tax, and exclude NCI. (2) Includes discontinued operations. (3) Pension and Other Postretirement Benefits and Total AOCI include a $4 million transfer of liabilities from SoCalGas to Sempra Energy related to the nonqualified pension plan.
Reclassifications out of AOCI Table	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated other comprehensive income (loss) components Amounts reclassified Affected line item on Condensed Three months ended September 30, 2019 2018 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments (1) $ 1 $ — Interest Expense 5 (11 ) Other (Expense) Income, Net Interest rate and foreign exchange instruments 2 3 Equity Earnings Total before income tax 8 (8 ) (2 ) 4 Income Tax (Expense) Benefit Net of income tax 6 (4 ) (2 ) — Earnings Attributable to Noncontrolling Interests $ 4 $ (4 ) Pension and other postretirement benefits: Amortization of actuarial loss (2) $ 3 $ 9 Other (Expense) Income, Net Amortization of prior service cost (2) 1 1 Other (Expense) Income, Net Settlement charges (2) 4 — Other (Expense) Income, Net Total before income tax 8 10 (3 ) (2 ) Income Tax (Expense) Benefit Net of income tax $ 5 $ 8 Total reclassifications for the period, net of tax $ 9 $ 4 SDG&E: Financial instruments: Interest rate instruments (1) $ 1 $ 2 Interest Expense (1 ) (2 ) Earnings 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 include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. (2) 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) (CONTINUED) (Dollars in millions) Details about accumulated other Amounts reclassified Affected line item on Condensed Nine months ended September 30, 2019 2018 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments (1) $ 2 $ (1 ) Interest Expense — (11 ) Other (Expense) Income, Net Interest rate instruments 10 — (Loss) Gain on Sale of Assets Interest rate and foreign exchange instruments 3 8 Equity Earnings Foreign exchange instruments 1 (1 ) Revenues: Energy-Related Businesses Total before income tax 16 (5 ) (3 ) 3 Income Tax (Expense) Benefit Net of income tax 13 (2 ) (3 ) (2 ) Earnings Attributable to Noncontrolling Interests $ 10 $ (4 ) Pension and other postretirement benefits: Amortization of actuarial loss (2) $ 7 $ 15 Other (Expense) Income, Net Amortization of prior service cost (2) 2 1 Other (Expense) Income, Net Settlement charges (2) 26 — Other (Expense) Income, Net Total before income tax 35 16 (10 ) (4 ) Income Tax (Expense) Benefit Net of income tax $ 25 $ 12 Total reclassifications for the period, net of tax $ 35 $ 8 SDG&E: Financial instruments: Interest rate instruments (1) $ 3 $ 6 Interest Expense (3 ) (6 ) Earnings Attributable to Noncontrolling Interest $ — $ — Pension and other postretirement benefits: Amortization of prior service cost (2) $ 1 $ — Other Income, Net Total reclassifications for the period, net of tax $ 1 $ — SoCalGas: Financial instruments: Interest rate instruments $ 1 $ — Interest Expense Pension and other postretirement benefits: Amortization of actuarial loss (2) $ — $ 1 Other Income, Net Total reclassifications for the period, net of tax $ 1 $ 1 (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. (2) Amounts are included in the computation of net periodic benefit cost (see “Pension and Other Postretirement Benefits” above).
Ownership Interests Held By Others Table	The following table provides information on noncontrolling ownership interests held by others (not including preferred shareholders) 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 noncontrolling interests Equity (deficit) held by noncontrolling interests September 30, December 31, September 30, December 31, SDG&E: Otay Mesa VIE — % 100 % $ — $ 100 Sempra Mexico: IEnova 33.4 33.5 1,676 1,592 IEnova subsidiaries (1) 10.0 – 46.3 10.0 – 49.0 16 13 Sempra Renewables: Tax equity arrangements – wind (2) — NA — 158 PXiSE Energy Solutions, LLC (3) — 11.1 — 1 Sempra LNG: Bay Gas — 9.1 — 18 Liberty Gas Storage, LLC 24.6 24.6 (13 ) (12 ) ECA LNG proposed liquefaction project 16.7 — 3 — Parent and other: PXiSE Energy Solutions, LLC (3) 20.0 — 1 — Discontinued Operations: Chilquinta Energía subsidiaries (1) 19.7 – 43.4 19.7 – 43.4 23 23 Luz del Sur 16.4 16.4 200 193 Tecsur 9.8 9.8 5 4 Total Sempra Energy $ 1,911 $ 2,090 (1) IEnova and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries. (2) Net income or loss attributable to NCI is computed using the HLBV method and is not based on ownership percentages. (3) In April 2019, PXiSE Energy Solutions, LLC was subsumed into Parent and other.
Transactions with Affiliates Table	We summarize amounts due from and to unconsolidated affiliates at Sempra Energy Consolidated, SDG&E and SoCalGas in the following table. AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES (Dollars in millions) September 30, December 31, Sempra Energy Consolidated: Total due from various unconsolidated affiliates – current $ 40 $ 37 Sempra Mexico (1) : IMG – Note due March 15, 2022 (2) $ 712 $ 641 Energía Sierra Juárez – Note (3) — 3 Total due from unconsolidated affiliates – noncurrent $ 712 $ 644 Total due to various unconsolidated affiliates – current $ (12 ) $ (10 ) Sempra Mexico (1) : Total due to unconsolidated affiliates – noncurrent – TAG – Note due December 20, 2021 (4) $ (39 ) $ (37 ) SDG&E: Total due from unconsolidated affiliates – current – SoCalGas $ 1 $ — Sempra Energy (1)(5) $ (14 ) $ (43 ) SoCalGas — (6 ) Various affiliates (12 ) (12 ) Total due to unconsolidated affiliates – current $ (26 ) $ (61 ) Income taxes due from Sempra Energy (6) $ 5 $ 5 SoCalGas: SDG&E $ — $ 6 Various affiliates — 1 Total due from unconsolidated affiliates – current $ — $ 7 Sempra Energy $ (35 ) $ (34 ) Pacific Enterprises (150 ) — SDG&E (1 ) — Various affiliates (1 ) — Total due to unconsolidated affiliates – current $ (187 ) $ (34 ) Income taxes due to Sempra Energy (6) $ (19 ) $ (4 ) (1) Amounts include principal balances plus accumulated interest outstanding. (2) Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $718 million U.S. dollar-equivalent, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps ( 10.13 percent at September 30, 2019 ), to finance construction of the natural gas marine pipeline. (3) U.S. dollar-denominated loan, at a variable interest rate based on the 30-day LIBOR plus 637.5 bps ( 8.89 percent at December 31, 2018 ). (4) U.S. dollar-denominated loan, at a variable interest rate based on the 6-month LIBOR plus 290 bps ( 4.96 percent at September 30, 2019 ). (5) At September 30, 2019 , net payable includes outstanding advances to Sempra Energy of $25 million at an interest rate of 2.03 percent. (6) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and their respective income tax expense is computed as an amount equal to that which would result from each company having always filed a separate return. The following table summarizes revenues and cost of sales from unconsolidated affiliates. REVENUES AND COST OF SALES FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Revenues: Sempra Energy Consolidated $ 13 $ 17 $ 40 $ 49 SDG&E 2 1 5 4 SoCalGas 16 15 50 47 Cost of Sales: Sempra Energy Consolidated $ 12 $ 9 $ 40 $ 36 SDG&E 16 21 56 56 SoCalGas 2 — 6 —
Other Income and Expense Table	Other (Expense) Income, Net on the Condensed Consolidated Statements of Operations consisted of the following: OTHER (EXPENSE) INCOME, NET (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 25 $ 23 $ 69 $ 79 Investment gains (1) 9 8 46 13 (Losses) gains on interest rate and foreign exchange instruments, net (17 ) 39 7 46 Foreign currency transaction (losses) gains, net (2) (13 ) 28 (2 ) 16 Non-service component of net periodic benefit (cost) credit (13 ) (3 ) (19 ) 37 Penalties related to billing practices OII — — (8 ) — Interest on regulatory balancing accounts, net 4 1 9 2 Sundry, net (2 ) — 1 (1 ) Total $ (7 ) $ 96 $ 103 $ 192 SDG&E: Allowance for equity funds used during construction $ 15 $ 15 $ 42 $ 49 Non-service component of net periodic benefit credit — 8 8 25 Interest on regulatory balancing accounts, net 4 2 10 4 Sundry, net — (1 ) — (1 ) Total $ 19 $ 24 $ 60 $ 77 SoCalGas: Allowance for equity funds used during construction $ 9 $ 8 $ 25 $ 30 Non-service component of net periodic benefit (cost) credit (5 ) (1 ) 9 27 Penalties related to billing practices OII — — (8 ) — Interest on regulatory balancing accounts, net — (1 ) (1 ) (2 ) Sundry, net (3 ) (3 ) (7 ) (6 ) Total $ 1 $ 3 $ 18 $ 49 (1) Represents investment gains on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans, recorded in O&M on the Condensed Consolidated Statements of Operations. (2) Includes losses of $17 million and a negligible amount in the three months and nine months ended September 30, 2019 , respectively, and gains of $33 million and $25 million in the three months and nine months ended September 30, 2018 , respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to the IMG JV, which are offset by corresponding amounts included in Equity Earnings on the Condensed Consolidated Statements of Operations.
Income Tax Expense and Effective Income Tax Rates Table	We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Sempra Energy Consolidated: Income tax expense (benefit) from continuing operations $ 61 $ 139 $ 150 $ (221 ) Income (loss) from continuing operations before income taxes and equity earnings $ 448 $ 345 $ 1,235 $ (245 ) Equity earnings (losses), before income tax (1) 17 (52 ) 24 (236 ) Pretax income (loss) $ 465 $ 293 $ 1,259 $ (481 ) Effective income tax rate 13 % 47 % 12 % 46 % SDG&E: Income tax expense $ 71 $ 53 $ 111 $ 151 Income before income taxes $ 337 $ 269 $ 700 $ 682 Effective income tax rate 21 % 20 % 16 % 22 % SoCalGas: Income tax expense (benefit) $ 35 $ (7 ) $ 50 $ 75 Income (loss) before income taxes $ 178 $ (21 ) $ 488 $ 320 Effective income tax rate 20 % 33 % 10 % 23 % (1) We discuss how we recognize equity earnings in Note 6 of the Notes to Consolidated Financial Statements in the Annual Report.

NEW ACCOUNTING STANDARDS (Table

NEW ACCOUNTING STANDARDS (Tables)	9 Months Ended
	Sep. 30, 2019
Accounting Changes and Error Corrections [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The following table shows the initial increases (decreases) on our balance sheets at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Assets held for sale $ 13 $ — $ — Sundry (71 ) — — Property, plant and equipment, net (147 ) — — Right-of-use assets – operating leases 603 130 116 Deferred income tax assets (3 ) — — Other current liabilities 80 20 23 Long-term debt (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — —

REVENUES (Tables)

REVENUES (Tables)	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Schedule of Disaggregation of Revenue	The following table disaggregates our revenues from contracts with customers by major service line and market and provides a reconciliation to total revenues by segment. The majority of our revenue is recognized over time. DISAGGREGATED REVENUES (Dollars in millions) Three months ended September 30, 2019 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments, Parent & Other Sempra Energy Consolidated By major service line: Utilities $ 1,370 $ 765 $ 14 $ — $ — $ (18 ) $ 2,131 Midstream — — 158 — 48 (39 ) 167 Renewables — — 32 — — 2 34 Other — — 52 — 2 (3 ) 51 Revenues from contracts with customers $ 1,370 $ 765 $ 256 $ — $ 50 $ (58 ) $ 2,383 By market: Gas $ 100 $ 765 $ 171 $ — $ 48 $ (55 ) $ 1,029 Electric 1,270 — 85 — 2 (3 ) 1,354 Revenues from contracts with customers $ 1,370 $ 765 $ 256 $ — $ 50 $ (58 ) $ 2,383 Revenues from contracts with customers $ 1,370 $ 765 $ 256 $ — $ 50 $ (58 ) $ 2,383 Utilities regulatory revenues 57 210 — — — — 267 Other revenues — — 101 — 50 (43 ) 108 Total revenues $ 1,427 $ 975 $ 357 $ — $ 100 $ (101 ) $ 2,758 Nine months ended September 30, 2019 By major service line: Utilities $ 3,604 $ 3,170 $ 56 $ — $ — $ (56 ) $ 6,774 Midstream — — 472 — 134 (109 ) 497 Renewables — — 82 5 — 1 88 Other — — 147 — 5 (5 ) 147 Revenues from contracts with customers $ 3,604 $ 3,170 $ 757 $ 5 $ 139 $ (169 ) $ 7,506 By market: Gas $ 441 $ 3,170 $ 527 $ — $ 134 $ (160 ) $ 4,112 Electric 3,163 — 230 5 5 (9 ) 3,394 Revenues from contracts with customers $ 3,604 $ 3,170 $ 757 $ 5 $ 139 $ (169 ) $ 7,506 Revenues from contracts with customers $ 3,604 $ 3,170 $ 757 $ 5 $ 139 $ (169 ) $ 7,506 Utilities regulatory revenues 62 (28 ) — — — — 34 Other revenues — — 301 5 188 (148 ) 346 Total revenues $ 3,666 $ 3,142 $ 1,058 $ 10 $ 327 $ (317 ) $ 7,886 DISAGGREGATED REVENUES (CONTINUED) (Dollars in millions) Three months ended September 30, 2018 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments Sempra Energy Consolidated By major service line: Utilities $ 1,577 $ 719 $ 17 $ — $ — $ (16 ) $ 2,297 Midstream — — 194 — 82 (71 ) 205 Renewables — — 32 14 1 (1 ) 46 Other — — 71 — 1 (2 ) 70 Revenues from contracts with customers $ 1,577 $ 719 $ 314 $ 14 $ 84 $ (90 ) $ 2,618 By market: Gas $ 91 $ 719 $ 214 $ — $ 82 $ (86 ) $ 1,020 Electric 1,486 — 100 14 2 (4 ) 1,598 Revenues from contracts with customers $ 1,577 $ 719 $ 314 $ 14 $ 84 $ (90 ) $ 2,618 Revenues from contracts with customers $ 1,577 $ 719 $ 314 $ 14 $ 84 $ (90 ) $ 2,618 Utilities regulatory revenues (278 ) 83 — — — — (195 ) Other revenues — — 96 24 63 (41 ) 142 Total revenues $ 1,299 $ 802 $ 410 $ 38 $ 147 $ (131 ) $ 2,565 Nine months ended September 30, 2018 By major service line: Utilities $ 3,707 $ 2,529 $ 58 $ — $ — $ (51 ) $ 6,243 Midstream — — 484 — 171 (105 ) 550 Renewables — — 85 37 2 (1 ) 123 Other — — 142 — 5 (5 ) 142 Revenues from contracts with customers $ 3,707 $ 2,529 $ 769 $ 37 $ 178 $ (162 ) $ 7,058 By market: Gas $ 372 $ 2,529 $ 545 $ — $ 171 $ (153 ) $ 3,464 Electric 3,335 — 224 37 7 (9 ) 3,594 Revenues from contracts with customers $ 3,707 $ 2,529 $ 769 $ 37 $ 178 $ (162 ) $ 7,058 Revenues from contracts with customers $ 3,707 $ 2,529 $ 769 $ 37 $ 178 $ (162 ) $ 7,058 Utilities regulatory revenues (302 ) 171 — — — — (131 ) Other revenues — — 259 66 152 (128 ) 349 Total revenues $ 3,405 $ 2,700 $ 1,028 $ 103 $ 330 $ (290 ) $ 7,276
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at September 30, 2019 , we expect to recognize revenue related to the fixed fee component of the consideration as shown below. SoCalGas did not have any such remaining performance obligations at September 30, 2019 . REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E 2019 (excluding first nine months of 2019) $ 87 $ 1 2020 409 4 2021 401 4 2022 405 4 2023 401 4 Thereafter 4,986 75 Total revenues to be recognized $ 6,689 $ 92 (1) Excludes intercompany transactions.
Schedule of Contract Liabilities	Activities within Sempra Energy’s contract liabilities are presented below. There were no contract liabilities at SDG&E in the nine months ended September 30, 2018 or SoCalGas in the nine months ended September 30, 2019 and 2018 . CONTRACT LIABILITIES (Dollars in millions) Sempra Energy Consolidated SDG&E Balance at January 1, 2019 $ (70 ) $ — Revenue from performance obligations satisfied during reporting period 1 — Payments received in advance (95 ) (92 ) Balance at September 30, 2019 (1) $ (164 ) $ (92 ) Balance at January 1, 2018 $ — Adoption of ASC 606 adjustment (61 ) Revenue from performance obligations satisfied during reporting period 6 Payments received in advance (9 ) Balance at September 30, 2018 $ (64 ) (1) I ncludes $3 million and $3 million in Other Current Liabilities a nd $161 million and $89 million in Deferred Credits and Other on the Sempra Energy and SDG&E Condensed Consolidated Balance Sheets, respectively.
Schedule of Contract Accounts Receivable	The table below shows receivable balances associated with revenues from contracts with customers on our Condensed Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) September 30, 2019 December 31, 2018 Sempra Energy Consolidated: Accounts receivable – trade, net $ 875 $ 1,106 Accounts receivable – other, net 10 11 Due from unconsolidated affiliates – current (1) 6 4 Assets held for sale — 6 Total $ 891 $ 1,127 SDG&E: Accounts receivable – trade, net $ 446 $ 368 Accounts receivable – other, net 7 6 Due from unconsolidated affiliates – current (1) 3 3 Total $ 456 $ 377 SoCalGas: Accounts receivable – trade, net $ 356 $ 634 Accounts receivable – other, net 3 5 Total $ 359 $ 639 (1) A mount is presented net of amounts due to unconsolidated affiliates on the Condensed Consolidated Balance Sheets, when right of offset exists.

REGULATORY MATTERS (Tables)

REGULATORY MATTERS (Tables)	9 Months Ended
	Sep. 30, 2019
Regulated Operations [Abstract]
Schedule Of General Rate Case, Authorized Revenue Increases	The increases include separately authorized components for O&M and capital-related costs, as follows: AUTHORIZED REVENUE REQUIREMENT INCREASES FOR 2020 AND 2021 (Dollars in millions) 2020 increase from 2019 2021 increase from 2020 Revenue increase Percent increase Revenue increase Percent increase SDG&E: O&M $ 20 2.64 % $ 19 2.47 % Capital-related costs 114 9.74 83 6.47 Total increase $ 134 6.74 $ 102 4.83 SoCalGas: O&M $ 36 2.64 % $ 34 2.40 % Capital-related costs 184 14.36 116 7.93 Total increase $ 220 7.92 $ 150 5.00
Schedule of Regulatory Assets	We show the details of regulatory assets and liabilities in the following table. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) September 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ (136 ) $ (150 ) Deferred income taxes refundable in rates (118 ) (236 ) Pension and other postretirement benefit plan obligations 186 186 Removal obligations (1,999 ) (1,848 ) Environmental costs 26 28 Sunrise Powerlink fire mitigation 120 120 Regulatory balancing accounts (1) Commodity – electric 142 (8 ) Gas transportation 17 45 Safety and reliability 76 70 Public purpose programs (117 ) (62 ) 2019 GRC retroactive impacts 81 — Other balancing accounts 46 145 Other regulatory liabilities, net (2) (152 ) (170 ) Total SDG&E (1,828 ) (1,880 ) SoCalGas: Pension and other postretirement benefit plan obligations 452 470 Employee benefit costs 49 49 Removal obligations (754 ) (833 ) Deferred income taxes refundable in rates (214 ) (336 ) Environmental costs 28 28 Regulatory balancing accounts (1) Commodity – gas, including transportation (85 ) 196 Safety and reliability 310 332 Public purpose programs (329 ) (325 ) 2019 GRC retroactive impacts 286 — Other balancing accounts (30 ) (68 ) Other regulatory liabilities, net (2) (115 ) (114 ) Total SoCalGas (402 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 81 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (2,143 ) $ (2,394 ) (1) At September 30, 2019 and December 31, 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $117 million and $78 million , respectively, and for SoCalGas was $475 million and $185 million , respectively. (2) Includes regulatory assets earning a rate of return.
Schedule of Regulatory Liabilities	We show the details of regulatory assets and liabilities in the following table. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) September 30, December 31, SDG&E: Fixed-price contracts and other derivatives $ (136 ) $ (150 ) Deferred income taxes refundable in rates (118 ) (236 ) Pension and other postretirement benefit plan obligations 186 186 Removal obligations (1,999 ) (1,848 ) Environmental costs 26 28 Sunrise Powerlink fire mitigation 120 120 Regulatory balancing accounts (1) Commodity – electric 142 (8 ) Gas transportation 17 45 Safety and reliability 76 70 Public purpose programs (117 ) (62 ) 2019 GRC retroactive impacts 81 — Other balancing accounts 46 145 Other regulatory liabilities, net (2) (152 ) (170 ) Total SDG&E (1,828 ) (1,880 ) SoCalGas: Pension and other postretirement benefit plan obligations 452 470 Employee benefit costs 49 49 Removal obligations (754 ) (833 ) Deferred income taxes refundable in rates (214 ) (336 ) Environmental costs 28 28 Regulatory balancing accounts (1) Commodity – gas, including transportation (85 ) 196 Safety and reliability 310 332 Public purpose programs (329 ) (325 ) 2019 GRC retroactive impacts 286 — Other balancing accounts (30 ) (68 ) Other regulatory liabilities, net (2) (115 ) (114 ) Total SoCalGas (402 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 81 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (2,143 ) $ (2,394 ) (1) At September 30, 2019 and December 31, 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $117 million and $78 million , respectively, and for SoCalGas was $475 million and $185 million , respectively. (2) Includes regulatory assets earning a rate of return.

ACQUISITIONS, DIVESTITURES AN_2

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	9 Months Ended
	Sep. 30, 2019
Business Combinations [Abstract]
Summarized Results from Discontinued Operations	Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Revenues $ 398 $ 375 $ 1,222 $ 1,190 Cost of sales (249 ) (246 ) (765 ) (794 ) Operating expenses (38 ) (41 ) (123 ) (151 ) Interest and other (3 ) (6 ) (12 ) (15 ) Income before income taxes and equity earnings 108 82 322 230 Income tax benefit (expense) 148 (28 ) (32 ) (94 ) Equity earnings — — 2 1 Income from discontinued operations, net of income tax 256 54 292 137 Earnings attributable to noncontrolling interests (8 ) (8 ) (25 ) (22 ) Earnings from discontinued operations attributable to common shares $ 248 $ 46 $ 267 $ 115 The following table summarizes the carrying amounts of the major classes of assets and related liabilities classified as held for sale in discontinued operations. ASSETS HELD FOR SALE IN DISCONTINUED OPERATIONS (Dollars in millions) September 30, December 31, 2018 Cash and cash equivalents $ 359 $ 88 Restricted cash (1) 1 — Accounts receivable, net 290 315 Due from unconsolidated affiliates 2 2 Inventories 44 38 Other current assets 24 16 Current assets $ 720 $ 459 Due from unconsolidated affiliates $ 51 $ 44 Goodwill and other intangible assets 803 819 Property, plant and equipment, net 2,502 2,357 Other noncurrent assets 39 39 Noncurrent assets $ 3,395 $ 3,259 Short-term debt $ 75 $ 55 Accounts payable 165 176 Dividends payable 428 8 Current portion of long-term debt and finance leases 39 29 Other current liabilities 97 100 Current liabilities $ 804 $ 368 Long-term debt and finance leases $ 687 $ 708 Deferred income taxes 274 250 Other noncurrent liabilities 62 55 Noncurrent liabilities $ 1,023 $ 1,013 (1) Primarily represents funds held in accordance with Peruvian tax law.

INVESTMENT IN UNCONSOLIDATED EN

INVESTMENT IN UNCONSOLIDATED ENTITIES (Tables)	9 Months Ended
	Sep. 30, 2019
Investments [Abstract]
Business Acquisition, Results of Operations	We provide summarized income statement information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 March 9 - September 30, 2018 2019 2018 Operating revenues $ 1,211 $ 1,095 $ 3,268 $ 2,352 Operating expense (787 ) (748 ) (2,319 ) (1,663 ) Income from operations 424 347 949 689 Interest expense (97 ) (89 ) (276 ) (198 ) Income tax expense (53 ) (53 ) (106 ) (105 ) Net income 261 191 511 351 Noncontrolling interest held by TTI (52 ) (38 ) (102 ) (70 ) Earnings attributable to Sempra Energy 209 153 409 281

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	PRIMARY U.S. COMMITTED LINES OF CREDIT (Dollars in millions) September 30, 2019 Total facility Commercial paper outstanding (1) Available unused credit Sempra Energy (2) $ 1,250 $ — $ 1,250 Sempra Global (3) 3,185 (2,345 ) 840 SDG&E (4) 1,500 — 1,500 SoCalGas (4) 750 (108 ) 642 Total $ 6,685 $ (2,453 ) $ 4,232 (1) Because the commercial paper programs are supported by these lines, we reflect the amount of commercial paper outstanding as a reduction to the available unused credit. (2) The facility also provides for issuance of $200 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. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra Energy has the right to increase the letter of credit commitment up to $500 million . No letters of credit were outstanding at September 30, 2019 . (3) Commercial paper outstanding is before reductions of unamortized discount of $3 million . Sempra Energy guarantees Sempra Global’s obligations under the credit facility. (4) The facility also provides for issuance of $100 million of letters of credit on behalf of the borrowing utility with the amount of borrowings otherwise available under the facility reduced by the amount of outstanding letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, the borrowing utility has the right to increase the letter of credit commitment up to $250 million . No letters of credit were outstanding at September 30, 2019 .

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Commodity Derivative Volumes Table	The following table summarizes net energy derivative volumes. NET ENERGY DERIVATIVE VOLUMES (Quantities in millions) Commodity Unit of measure September 30, December 31, Sempra Energy Consolidated: Natural gas MMBtu 30 35 Electricity MWh 2 2 Congestion revenue rights MWh 47 52 SDG&E: Natural gas MMBtu 34 33 Electricity MWh 2 2 Congestion revenue rights MWh 47 52
Notional Amounts of Derivatives Table	The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) September 30, 2019 December 31, 2018 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 306 2019-2023 $ 306 2019-2023 Other foreign currency derivatives 1,242 2019-2021 1,158 2019-2020 The following table presents the net notional amounts of our interest rate derivatives, excluding JVs. INTEREST RATE DERIVATIVES (Dollars in millions) September 30, 2019 December 31, 2018 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges (1) $ 1,259 2019-2032 $ 594 2019-2032 SDG&E: Cash flow hedge (1) — — 142 2019 (1) Includes Otay Mesa VIE. All of SDG&E’s interest rate derivatives relate to Otay Mesa VIE. On August 14, 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps.
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, including the amount of cash collateral receivables that were not offset, as the cash collateral was in excess of liability positions. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2019 Current (1) Other Current liabilities: Deferred Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments $ — $ — $ (12 ) $ (157 ) Derivatives not designated as hedging instruments: Foreign exchange instruments 12 — (3 ) — Associated offsetting foreign exchange instruments (3 ) — 3 — Commodity contracts not subject to rate recovery 31 11 (39 ) (9 ) Associated offsetting commodity contracts (29 ) (1 ) 29 1 Commodity contracts subject to rate recovery 22 245 (48 ) (53 ) Associated offsetting commodity contracts (5 ) (2 ) 5 2 Associated offsetting cash collateral — — 13 2 Net amounts presented on the balance sheet 28 253 (52 ) (214 ) Additional cash collateral for commodity contracts not subject to rate recovery 18 — — — Additional cash collateral for commodity contracts subject to rate recovery 17 — — — Total (2) $ 63 $ 253 $ (52 ) $ (214 ) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 14 $ 245 $ (42 ) $ (53 ) Associated offsetting commodity contracts (3 ) (2 ) 3 2 Associated offsetting cash collateral — — 13 2 Net amounts presented on the balance sheet 11 243 (26 ) (49 ) Additional cash collateral for commodity contracts subject to rate recovery 14 — — — Total (2) $ 25 $ 243 $ (26 ) $ (49 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 8 $ — $ (6 ) $ — Associated offsetting commodity contracts (2 ) — 2 — Net amounts presented on the balance sheet 6 — (4 ) — Additional cash collateral for commodity contracts subject to rate recovery 3 — — — Total $ 9 $ — $ (4 ) $ — (1) Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E. (2) Normal purchase contracts previously measured at fair value are excluded. DERIVATIVE INSTRUMENTS ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2018 Current (1) Other Current liabilities: Deferred Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments (2) $ 2 $ — $ (3 ) $ (147 ) Derivatives not designated as hedging instruments: Commodity contracts not subject to rate recovery 153 7 (164 ) (6 ) Associated offsetting commodity contracts (133 ) (3 ) 133 3 Commodity contracts subject to rate recovery 64 233 (42 ) (72 ) Associated offsetting commodity contracts (6 ) (2 ) 6 2 Associated offsetting cash collateral — — — 2 Net amounts presented on the balance sheet 80 235 (70 ) (218 ) Additional cash collateral for commodity contracts not subject to rate recovery 19 — — — Additional cash collateral for commodity contracts subject to rate recovery 33 — — — Total (3) $ 132 $ 235 $ (70 ) $ (218 ) SDG&E: Derivatives designated as hedging instruments: Interest rate instruments (2) $ — $ — $ (1 ) $ — Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery 60 233 (37 ) (72 ) Associated offsetting commodity contracts (6 ) (2 ) 6 2 Associated offsetting cash collateral — — — 2 Net amounts presented on the balance sheet 54 231 (32 ) (68 ) Additional cash collateral for commodity contracts subject to rate recovery 28 — — — Total (3) $ 82 $ 231 $ (32 ) $ (68 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 4 $ — $ (5 ) $ — Net amounts presented on the balance sheet 4 — (5 ) — Additional cash collateral for commodity contracts subject to rate recovery 5 — — — Total $ 9 $ — $ (5 ) $ — (1) Included in Current Assets: Fixed-Price Contracts and Other Derivatives for SDG&E. (2) Includes Otay Mesa VIE. All of SDG&E’s amounts relate to Otay Mesa VIE. (3) Normal purchase contracts previously measured at fair value are excluded.
Cash Flow Hedge Impact on the Condensed Consolidated Statements of Comprehensive Income Table	The table below includes the effects of derivative instruments designated as cash flow hedges on the Condensed Consolidated Statements of Operations and in OCI and AOCI: CASH FLOW HEDGE IMPACTS (Dollars in millions) Pretax (loss) gain recognized in OCI Pretax (loss) gain reclassified from AOCI into earnings Three months ended September 30, Three months ended September 30, 2019 2018 Location 2019 2018 Sempra Energy Consolidated: Interest rate and foreign exchange instruments (1) $ (7 ) $ 16 Interest Expense (1) $ (1 ) $ — Other (Expense) Income, Net (5 ) 11 Interest rate and foreign exchange instruments (62 ) 20 Equity Earnings (2 ) (3 ) Foreign exchange instruments 1 (5 ) Revenues: Energy- Related Businesses — — Total $ (68 ) $ 31 $ (8 ) $ 8 SDG&E: Interest rate instruments (1) $ — $ — Interest Expense (1) $ (1 ) $ (2 ) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1 ) $ — Nine months ended September 30, Nine months ended September 30, 2019 2018 Location 2019 2018 Sempra Energy Consolidated: Interest rate and foreign exchange instruments (1) $ (25 ) $ 57 Interest Expense (1) $ (2 ) $ 1 Other (Expense) Income, Net — 11 Interest rate instruments — — (Loss) Gain on Sale of Assets (10 ) — Interest rate and foreign (222 ) 123 Equity Earnings (3 ) (8 ) Foreign exchange instruments (3 ) (7 ) Revenues: Energy- (1 ) 1 Total $ (250 ) $ 173 $ (16 ) $ 5 SDG&E: Interest rate instruments (1) $ (1 ) $ 1 Interest Expense (1) $ (3 ) $ (6 ) SoCalGas: Interest rate instruments $ — $ — Interest Expense $ (1 ) $ — (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.
Fair Value Hedge Impact on the Condensed Consolidated Statements of Operations Table	The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Condensed Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax (loss) gain on derivatives recognized in earnings Three months ended Nine months ended Location 2019 2018 2019 2018 Sempra Energy Consolidated: Foreign exchange instruments Other (Expense) Income, Net $ (12 ) $ 28 $ 7 $ 35 Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses (8 ) 9 9 — Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power 18 62 (7 ) 70 Commodity contracts subject to rate recovery Cost of Natural Gas (3 ) (2 ) (1 ) (1 ) Total $ (5 ) $ 97 $ 8 $ 104 SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ 18 $ 62 $ (7 ) $ 70 SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (3 ) $ (2 ) $ (1 ) $ (1 )

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at September 30, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 465 $ 5 $ — $ 470 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 39 12 — 51 Municipal bonds — 291 — 291 Other securities — 236 — 236 Total debt securities 39 539 — 578 Total nuclear decommissioning trusts (1) 504 544 — 1,048 Interest rate and foreign exchange instruments — 9 — 9 Commodity contracts not subject to rate recovery — 12 — 12 Effect of netting and allocation of collateral (2) 18 — — 18 Commodity contracts subject to rate recovery 1 6 253 260 Effect of netting and allocation of collateral (2) 11 — 6 17 Total $ 534 $ 571 $ 259 $ 1,364 Liabilities: Interest rate and foreign exchange instruments $ — $ 169 $ — $ 169 Commodity contracts not subject to rate recovery — 18 — 18 Commodity contracts subject to rate recovery 15 5 74 94 Effect of netting and allocation of collateral (2) (15 ) — — (15 ) Total $ — $ 192 $ 74 $ 266 Fair value at December 31, 2018 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 407 $ 4 $ — $ 411 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 43 10 — 53 Municipal bonds — 269 — 269 Other securities — 234 — 234 Total debt securities 43 513 — 556 Total nuclear decommissioning trusts (1) 450 517 — 967 Interest rate and foreign exchange instruments — 2 — 2 Commodity contracts not subject to rate recovery — 24 — 24 Effect of netting and allocation of collateral (2) 19 — — 19 Commodity contracts subject to rate recovery 2 9 278 289 Effect of netting and allocation of collateral (2) 28 — 5 33 Total $ 499 $ 552 $ 283 $ 1,334 Liabilities: Interest rate and foreign exchange instruments $ — $ 150 $ — $ 150 Commodity contracts not subject to rate recovery — 34 — 34 Commodity contracts subject to rate recovery 2 5 99 106 Effect of netting and allocation of collateral (2) (2 ) — — (2 ) Total $ — $ 189 $ 99 $ 288 (1) Excludes cash and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at September 30, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 465 $ 5 $ — $ 470 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 39 12 — 51 Municipal bonds — 291 — 291 Other securities — 236 — 236 Total debt securities 39 539 — 578 Total nuclear decommissioning trusts (1) 504 544 — 1,048 Commodity contracts subject to rate recovery — 1 253 254 Effect of netting and allocation of collateral (2) 8 — 6 14 Total $ 512 $ 545 $ 259 $ 1,316 Liabilities: Commodity contracts subject to rate recovery $ 15 $ 1 $ 74 $ 90 Effect of netting and allocation of collateral (2) (15 ) — — (15 ) Total $ — $ 1 $ 74 $ 75 Fair value at December 31, 2018 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 407 $ 4 $ — $ 411 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 43 10 — 53 Municipal bonds — 269 — 269 Other securities — 234 — 234 Total debt securities 43 513 — 556 Total nuclear decommissioning trusts (1) 450 517 — 967 Commodity contracts subject to rate recovery 1 6 278 285 Effect of netting and allocation of collateral (2) 23 — 5 28 Total $ 474 $ 523 $ 283 $ 1,280 Liabilities: Interest rate instruments $ — $ 1 $ — $ 1 Commodity contracts subject to rate recovery 2 — 99 101 Effect of netting and allocation of collateral (2) (2 ) — — (2 ) Total $ — $ 1 $ 99 $ 100 (1) Excludes cash and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at September 30, 2019 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 5 $ — $ 6 Effect of netting and allocation of collateral (1) 3 — — 3 Total $ 4 $ 5 $ — $ 9 Liabilities: Commodity contracts subject to rate recovery $ — $ 4 $ — $ 4 Total $ — $ 4 $ — $ 4 Fair value at December 31, 2018 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 3 $ — $ 4 Effect of netting and allocation of collateral (1) 5 — — 5 Total $ 6 $ 3 $ — $ 9 Liabilities: Commodity contracts subject to rate recovery $ — $ 5 $ — $ 5 Total $ — $ 5 $ — $ 5 (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 table below sets forth reconciliations of changes in the fair value of 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 (1) (Dollars in millions) Three months ended September 30, 2019 2018 Balance at July 1 $ 176 $ (31 ) Realized and unrealized (losses) gains (24 ) 6 Settlements 27 13 Balance at September 30 $ 179 $ (12 ) Change in unrealized gains (losses) relating to instruments still held at September 30 $ 1 $ 6 Nine months ended September 30, 2019 2018 Balance at January 1 $ 179 $ (28 ) Realized and unrealized (losses) gains (32 ) 21 Allocated transmission instruments — 3 Settlements 32 (8 ) Balance at September 30 $ 179 $ (12 ) Change in unrealized gains (losses) relating to instruments still held at September 30 $ 12 $ — (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements.
Schedule of Fair Value Inputs	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. The range and weighted-average price of these inputs at September 30 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2019 $ 21.60 to $ 57.20 $ 38.29 2018 20.40 to 57.70 38.87 CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2019 $ (8.57 ) to $ 35.21 $ (2.94 ) 2018 (7.25 ) to 11.99 0.09
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. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) September 30, 2019 Carrying Fair value Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates $ 712 $ — $ 735 $ — $ 735 Long-term amounts due to unconsolidated affiliates 39 — 38 — 38 Total long-term debt (1) 21,554 — 23,142 26 23,168 SDG&E: Total long-term debt (2) $ 5,141 $ — $ 5,780 $ — $ 5,780 SoCalGas: Total long-term debt (3) $ 3,809 $ — $ 4,290 $ — $ 4,290 December 31, 2018 Carrying Fair value Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates $ 644 $ — $ 648 $ 4 $ 652 Long-term amounts due to unconsolidated affiliates 37 — 35 — 35 Total long-term debt (4)(5) 21,340 — 20,616 247 20,863 SDG&E: Total long-term debt (4)(6) $ 4,996 $ — $ 4,897 $ 220 $ 5,117 SoCalGas: Total long-term debt (7) $ 3,459 $ — $ 3,505 $ — $ 3,505 (1) Before reductions of unamortized discount and debt issuance costs of $221 million and excluding finance lease obligations of $1,285 million . (2) Before reductions of unamortized discount and debt issuance costs of $49 million and excluding finance lease obligations of $1,270 million . (3) Before reductions of unamortized discount and debt issuance costs of $35 million and excluding finance lease obligations of $15 million . (4) Level 3 instruments include $220 million related to Otay Mesa VIE. (5) Before reductions of unamortized discount and debt issuance costs of $206 million and excluding build-to-suit and capital lease obligations of $1,413 million . (6) Before reductions of unamortized discount and debt issuance costs of $49 million and excluding capital lease obligations of $1,272 million . (7) Before reductions of unamortized discount and debt issuance costs of $32 million and excluding capital lease obligations of $3 million .

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	9 Months Ended
	Sep. 30, 2019
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 9 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At September 30, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 51 $ — $ — $ 51 Municipal bonds (2) 278 13 — 291 Other securities (3) 228 9 (1 ) 236 Total debt securities 557 22 (1 ) 578 Equity securities 170 309 (9 ) 470 Cash and cash equivalents 1 — — 1 Total $ 728 $ 331 $ (10 ) $ 1,049 At December 31, 2018: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 52 $ 1 $ — $ 53 Municipal bonds 266 4 (1 ) 269 Other securities 238 1 (5 ) 234 Total debt securities 556 6 (6 ) 556 Equity securities 168 253 (10 ) 411 Cash and cash equivalents 7 — — 7 Total $ 731 $ 259 $ (16 ) $ 974 (1) Maturity dates are 2021-2050. (2) Maturity dates are 2020-2056. (3) Maturity dates are 2019-2060.
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 IN THE NDT (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Proceeds from sales $ 231 $ 216 $ 728 $ 703 Gross realized gains 5 3 18 32 Gross realized losses (1 ) (1 ) (4 ) (6 )

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Schedule of Leases Statement of Financial Position	Classification of ROU assets and lease liabilities and the weighted-average remaining lease term and discount rate associated with operating and finance leases are summarized in the table below. LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED BALANCE SHEETS (Dollars in millions) September 30, 2019 Sempra Energy Consolidated SDG&E SoCalGas Right-of-use assets: Operating leases: Right-of-use assets $ 595 $ 126 $ 99 Finance leases: Property, plant and equipment 1,342 1,322 20 Accumulated depreciation (57 ) (52 ) (5 ) Property, plant and equipment, net 1,285 1,270 15 Total right-of-use assets $ 1,880 $ 1,396 $ 114 Lease liabilities: Operating leases: Other current liabilities $ 47 $ 22 $ 19 Deferred credits and other 447 102 79 494 124 98 Finance leases: Current portion of long-term debt and finance leases 24 19 5 Long-term debt and finance leases 1,261 1,251 10 1,285 1,270 15 Total lease liabilities $ 1,779 $ 1,394 $ 113 Weighted-average remaining lease term (in years): Operating leases 14 7 6 Finance leases 20 20 6 Weighted-average discount rate: Operating leases 6.02 % 3.69 % 3.75 % Finance leases 14.81 % 14.86 % 3.41 %
Schedule of Lease Cost	The components of lease costs were as follows: LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (1) (Dollars in millions) Three months ended September 30, 2019 Nine months ended September 30, 2019 Sempra Energy Consolidated SDG&E SoCalGas Sempra Energy Consolidated SDG&E SoCalGas Operating lease costs $ 23 $ 8 $ 7 $ 72 $ 25 $ 21 Finance lease costs: Amortization of ROU assets 6 4 2 17 13 4 Interest on lease liabilities 47 47 — 141 141 — Total finance lease costs 53 51 2 158 154 4 Short-term lease costs (2) 3 1 — 5 1 — Variable lease costs (2) 156 155 1 396 389 7 Total lease costs $ 235 $ 215 $ 10 $ 631 $ 569 $ 32 (1) Includes costs capitalized in PP&E. (2) Short-term leases with variable lease costs are recorded and presented as variable lease costs.
Schedule of Lease Cash Flow Activity [Table Text Block]	Cash paid for amounts included in the measurement of lease liabilities was as follows: LESSEE INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Dollars in millions) Nine months ended September 30, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating activities: Cash paid for operating leases $ 81 $ 25 $ 21 Cash paid for finance leases 130 130 — Financing activities: Cash paid for finance leases 17 13 4 Increase in operating lease obligations for right-of-use assets 571 147 117 Increase in finance lease obligations for investment in PP&E 27 12 15
Schedule of Operating Lease Maturity Payments	The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) September 30, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating leases Finance leases Operating leases Finance leases Operating leases Finance leases 2019 (excluding first nine months of 2019) $ 17 $ 50 $ 7 $ 48 $ 6 $ 2 2020 72 195 26 191 23 4 2021 69 192 26 190 20 2 2022 62 191 22 189 17 2 2023 53 191 17 189 13 2 Thereafter 494 2,811 43 2,807 30 4 Total undiscounted lease payments 767 3,630 141 3,614 109 16 Less: imputed interest (273 ) (2,345 ) (17 ) (2,344 ) (11 ) (1 ) Total lease liabilities 494 1,285 124 1,270 98 15 Less: current lease liabilities (47 ) (24 ) (22 ) (19 ) (19 ) (5 ) Long-term lease liabilities $ 447 $ 1,261 $ 102 $ 1,251 $ 79 $ 10 The table below presents the future minimum lease payments under previous U.S. GAAP: FUTURE MINIMUM LEASE PAYMENTS (Dollars in millions) December 31, 2018 Sempra Energy Consolidated SDG&E SoCalGas Build-to-suit lease Operating leases Capital leases Operating leases Capital leases Operating leases Capital leases 2019 $ 10 $ 77 $ 215 $ 23 $ 212 $ 26 $ 3 2020 11 55 210 22 210 22 — 2021 11 53 211 22 211 21 — 2022 11 50 211 21 211 20 — 2023 11 42 211 17 211 16 — Thereafter 217 253 3,196 48 3,196 28 — Total undiscounted lease payments $ 271 $ 530 4,254 $ 153 4,251 $ 133 3 Less: estimated executory costs (480 ) (480 ) — Less: imputed interest (2,483 ) (2,483 ) — Total future minimum lease payments $ 1,291 $ 1,288 $ 3
Schedule of Finance Lease Maturity Payments	The table below presents the future minimum lease payments under previous U.S. GAAP: FUTURE MINIMUM LEASE PAYMENTS (Dollars in millions) December 31, 2018 Sempra Energy Consolidated SDG&E SoCalGas Build-to-suit lease Operating leases Capital leases Operating leases Capital leases Operating leases Capital leases 2019 $ 10 $ 77 $ 215 $ 23 $ 212 $ 26 $ 3 2020 11 55 210 22 210 22 — 2021 11 53 211 22 211 21 — 2022 11 50 211 21 211 20 — 2023 11 42 211 17 211 16 — Thereafter 217 253 3,196 48 3,196 28 — Total undiscounted lease payments $ 271 $ 530 4,254 $ 153 4,251 $ 133 3 Less: estimated executory costs (480 ) (480 ) — Less: imputed interest (2,483 ) (2,483 ) — Total future minimum lease payments $ 1,291 $ 1,288 $ 3 The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities: LESSEE MATURITY ANALYSIS OF LIABILITIES (Dollars in millions) September 30, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating leases Finance leases Operating leases Finance leases Operating leases Finance leases 2019 (excluding first nine months of 2019) $ 17 $ 50 $ 7 $ 48 $ 6 $ 2 2020 72 195 26 191 23 4 2021 69 192 26 190 20 2 2022 62 191 22 189 17 2 2023 53 191 17 189 13 2 Thereafter 494 2,811 43 2,807 30 4 Total undiscounted lease payments 767 3,630 141 3,614 109 16 Less: imputed interest (273 ) (2,345 ) (17 ) (2,344 ) (11 ) (1 ) Total lease liabilities 494 1,285 124 1,270 98 15 Less: current lease liabilities (47 ) (24 ) (22 ) (19 ) (19 ) (5 ) Long-term lease liabilities $ 447 $ 1,261 $ 102 $ 1,251 $ 79 $ 10
Schedule of Operating Lease Payments to Be Received	We provide information below for leases for which we are the lessor. LESSOR INFORMATION – SEMPRA ENERGY (Dollars in millions) September 30, 2019 Assets subject to operating leases: Property, plant and equipment (1) $ 1,112 Accumulated depreciation (181 ) Property, plant and equipment, net $ 931 Maturity analysis of operating lease payments: 2019 (excluding first nine months of 2019) $ 50 2020 199 2021 199 2022 199 2023 199 Thereafter 2,588 Total undiscounted cash flows $ 3,434 (1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.
Schedule of Operating Lease Payments Received, Lease Income [Table Text Block]	LESSOR INFORMATION ON THE CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA ENERGY (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 Minimum lease payments $ 51 $ 47 $ 150 $ 143 Variable lease payments — 26 6 63 Total revenues from operating leases $ 51 $ 73 $ 156 $ 206 Depreciation expense $ 10 $ 19 $ 29 $ 55

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2019
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 activities of parent organizations and include certain nominal amounts from our South American businesses that did not qualify for treatment as discontinued operations. SEGMENT INFORMATION (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 REVENUES SDG&E $ 1,427 $ 1,299 $ 3,666 $ 3,405 SoCalGas 975 802 3,142 2,700 Sempra Mexico 357 410 1,058 1,028 Sempra Renewables — 38 10 103 Sempra LNG 100 147 327 330 All other 1 — 1 — Eliminations and adjustments (2 ) — (3 ) (2 ) Intersegment revenues (1) (100 ) (131 ) (315 ) (288 ) Total $ 2,758 $ 2,565 $ 7,886 $ 7,276 INTEREST EXPENSE SDG&E (2) $ 106 $ 56 $ 311 $ 161 SoCalGas 36 29 104 82 Sempra Mexico 30 30 89 90 Sempra Renewables — 5 3 15 Sempra LNG 11 3 18 18 All other 117 122 336 371 Intercompany eliminations (21 ) (23 ) (64 ) (81 ) Total $ 279 $ 222 $ 797 $ 656 INTEREST INCOME SDG&E $ 1 $ 1 $ 3 $ 3 SoCalGas — — 1 1 Sempra Mexico 20 17 58 48 Sempra Renewables — 2 11 6 Sempra LNG 15 10 45 36 All other 1 1 2 14 Intercompany eliminations (15 ) (12 ) (56 ) (42 ) Total $ 22 $ 19 $ 64 $ 66 DEPRECIATION AND AMORTIZATION SDG&E $ 196 $ 174 $ 571 $ 509 SoCalGas 154 141 449 414 Sempra Mexico 46 45 136 131 Sempra Renewables — — — 27 Sempra LNG 2 2 7 24 All other 4 4 11 10 Total $ 402 $ 366 $ 1,174 $ 1,115 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 71 $ 53 $ 111 $ 151 SoCalGas 35 (7 ) 50 75 Sempra Mexico — 126 116 226 Sempra Renewables — (2 ) 4 (67 ) Sempra LNG (2 ) 6 4 (488 ) All other (43 ) (37 ) (135 ) (118 ) Total $ 61 $ 139 $ 150 $ (221 ) EQUITY EARNINGS (LOSSES) Equity earnings (losses), before income tax: Sempra Texas Utilities $ — $ — $ 1 $ — Sempra Renewables — 12 5 (170 ) Sempra LNG 17 — 19 1 All other — (64 ) (1 ) (67 ) 17 (52 ) 24 (236 ) Equity earnings (losses), net of income tax: Sempra Texas Utilities 212 154 418 283 Sempra Mexico 37 (28 ) 43 2 249 126 461 285 Total $ 266 $ 74 $ 485 $ 49 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Three months ended September 30, Nine months ended September 30, 2019 2018 2019 2018 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 263 $ 205 $ 582 $ 521 SoCalGas 143 (14 ) 437 244 Sempra Texas Utilities 212 154 419 283 Sempra Mexico 84 44 214 161 Sempra Renewables — 34 59 (54 ) Sempra LNG 2 16 13 (764 ) Discontinued operations 248 46 267 115 All other (139 ) (211 ) (383 ) (446 ) Total $ 813 $ 274 $ 1,608 $ 60 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,071 $ 1,194 SoCalGas 1,019 1,127 Sempra Mexico 420 255 Sempra Renewables 2 46 Sempra LNG 74 19 All other 4 13 Total $ 2,590 $ 2,654 September 30, 2019 December 31, 2018 ASSETS SDG&E $ 20,336 $ 19,225 SoCalGas 16,023 15,389 Sempra Texas Utilities 11,248 9,652 Sempra Mexico 9,759 9,165 Sempra Renewables — 2,549 Sempra LNG 3,755 4,060 Discontinued operations 4,115 3,718 All other 1,585 1,070 Intersegment receivables (2,236 ) (4,190 ) Total $ 64,585 $ 60,638 EQUITY METHOD AND OTHER INVESTMENTS Sempra Texas Utilities $ 11,248 $ 9,652 Sempra Mexico 750 747 Sempra Renewables — 291 Sempra LNG 1,216 1,271 All other 7 11 Total $ 13,221 $ 11,972 (1) Revenues for reportable segments include intersegment revenues of $1 million , $16 million , $29 million and $54 million for the three months ended September 30, 2019 ; $4 million , $50 million , $89 million and $172 million for the nine months ended September 30, 2019 ; $1 million , $15 million , $31 million and $84 million for the three months ended September 30, 2018 ; and $3 million , $47 million , $88 million , and $150 million for the nine months ended September 30, 2018 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively. (2) As we discuss in Note 2, in accordance with adoption of the lease standard on January 1, 2019, on a prospective basis, a significant portion of finance lease costs for PPAs that have historically been presented in Cost of Electric Fuel and Purchased Power are now presented in Interest Expense.

GENERAL INFORMATION AND OTHER_4

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details) - segment	3 Months Ended		6 Months Ended
	Sep. 30, 2019	Mar. 31, 2019	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	5	6	5

GENERAL INFORMATION AND OTHER_5

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents	$ 106	$ 102	[1]
Restricted cash, current	28	35	[1]
Restricted cash, noncurrent	3	21	[1]
Cash and cash equivalents	360	88
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	497	246
San Diego Gas and Electric Company [Member]
Cash and Cash Equivalents [Line Items]
Cash and cash equivalents	24	8	[1]
Restricted cash, current	0	11	[1]
Restricted cash, noncurrent	0	18	[1]
Total cash, cash equivalents and restricted cash on the Condensed Consolidated Statements of Cash Flows	$ 24	$ 37
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_6

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Inventory [Line Items]
Natural gas	$ 110	$ 95
LNG	6	4
Materials and supplies	154	159
Inventory	270	258	[1]
SDG&E [Member]
Inventory [Line Items]
Natural gas	1	0
LNG	0	0
Materials and supplies	91	102
Inventory	92	102
SoCalGas [Member]
Inventory [Line Items]
Natural gas	87	92
LNG	0	0
Materials and supplies	47	42
Inventory	134	134
Sempra Mexico [Member]
Inventory [Line Items]
Natural gas	0	0
LNG	6	4
Materials and supplies	16	15
Inventory	22	19
Sempra LNG [Member]
Inventory [Line Items]
Natural gas	22	3
LNG	0	0
Materials and supplies	0	0
Inventory	$ 22	$ 3
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_7

GENERAL INFORMATION AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details) - USD ($)	Jul. 12, 2019	Aug. 31, 2019	Sep. 30, 2019	Jul. 25, 2019	Dec. 31, 2018	[1]
Loss Contingencies [Line Items]
Potential initial funded amount by loan	$ 10,500,000,000
Initial shareholder contributions	7,500,000,000
Aggregate value of annual shareholder contributions	$ 3,000,000,000
Period of annual contributions	10 years
Noncurrent portion of the Wildfire Fund asset			$ 381,000,000		$ 0
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Wildfire fund, threshold amount to seek payment	$ 1,000,000,000
Wildfire fund, threshold percentage of equity portion of electric transmission and distribution rate base	20.00%
initial liability cap	$ 825,000,000
Initial shareholder contributions	322,500,000
Aggregate value of annual shareholder contributions	129,000,000
Period of annual contributions			10 years
Wildfire Fund asset				$ 451,500,000
Current portion of the Wildfire Fund asset			$ 43,000,000
Estimated period of benefit			10 years
Noncurrent portion of the Wildfire Fund asset			$ 381,000,000		$ 0
Wildfire Fund obligation				$ 451,500,000
Additional annual contributions			12,900,000
Wildfire Fund obligation in other current liabilities			12,900,000
Wildfire Fund obligation in deferred credits and other			$ 97,000,000
Wildfire Fund [Member]
Loss Contingencies [Line Items]
Potential initial funded amount by loan	10,500,000,000
Loan proceeds received		$ 2,000,000,000
PG&E [Member]
Loss Contingencies [Line Items]
Initial shareholder contributions	4,800,000,000
Aggregate value of annual shareholder contributions	1,900,000,000
Edison [Member]
Loss Contingencies [Line Items]
Initial shareholder contributions	2,400,000,000
Aggregate value of annual shareholder contributions	945,000,000
SDG&E and Edison [Member]
Loss Contingencies [Line Items]
Total Shareholder Contribution	3,800,000,000
Minimum [Member] | San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Fire risk mitigation capital improvements	$ 215,000,000
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHER_8

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 46	$ 47	$ 144	$ 150
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	19	20	56	67
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 13	$ 10	$ 35	$ 39

GENERAL INFORMATION AND OTHER_9

GENERAL INFORMATION AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details)	Aug. 23, 2019USD ($)	Mar. 09, 2018	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)MW	Sep. 30, 2018USD ($)	Dec. 31, 2018USD ($)
Variable Interest Entities [Line Items]
Cash and cash equivalents			$ 106,000,000		$ 106,000,000		$ 102,000,000	[1]
Inventories			270,000,000		270,000,000		258,000,000	[1]
Total current assets			3,666,000,000		3,666,000,000		3,645,000,000	[1]
Property, plant and equipment, net			35,520,000,000		35,520,000,000		34,439,000,000	[1]
Other noncurrent assets			850,000,000		850,000,000		962,000,000	[1]
Total assets			64,585,000,000		64,585,000,000		60,638,000,000	[1]
Other			914,000,000		914,000,000		935,000,000	[1]
Total current liabilities			9,498,000,000		9,498,000,000		7,523,000,000	[1]
Deferred credits and other			2,049,000,000		2,049,000,000		1,493,000,000	[1]
Other noncontrolling interests			1,911,000,000		1,911,000,000		2,090,000,000	[1]
Total liabilities and equity			64,585,000,000		64,585,000,000		60,638,000,000	[1]
Energy-related businesses			360,000,000	$ 463,000,000	1,078,000,000	$ 1,164,000,000
Interest expense			(279,000,000)	(222,000,000)	(797,000,000)	(656,000,000)
Operation and maintenance			(845,000,000)	(792,000,000)	(2,515,000,000)	(2,275,000,000)
Depreciation and amortization			(402,000,000)	(366,000,000)	(1,174,000,000)	(1,115,000,000)
Income (loss) from continuing operations before income taxes and equity earnings			448,000,000	345,000,000	1,235,000,000	(245,000,000)
Income tax expense			(61,000,000)	(139,000,000)	(150,000,000)	221,000,000
Net income			909,000,000	334,000,000	1,862,000,000	162,000,000
Earnings attributable to noncontrolling interests			(60,000,000)	(24,000,000)	(146,000,000)	(12,000,000)
Equity method investment			11,145,000,000		11,145,000,000		9,652,000,000	[1]
Variable Interest Entity, Primary Beneficiary
Variable Interest Entities [Line Items]
Assets of VIEs			779,000,000		779,000,000		286,000,000
Sempra Texas Utilities [Member] | Oncor Holdings [Member]
Variable Interest Entities [Line Items]
Equity method investment			11,145,000,000		11,145,000,000		9,652,000,000
Sempra Renewables [Member] | Tax Equity Investors [Member]
Variable Interest Entities [Line Items]
Energy-related businesses				28,000,000	8,000,000	77,000,000
Operation and maintenance				(5,000,000)	(2,000,000)	(13,000,000)
Depreciation and amortization				(13,000,000)	(4,000,000)	(36,000,000)
Income (loss) from continuing operations before income taxes and equity earnings				10,000,000	2,000,000	28,000,000
Income tax expense				(4,000,000)	0	(16,000,000)
Net income				6,000,000	2,000,000	12,000,000
Earnings attributable to noncontrolling interests				9,000,000	(1,000,000)	50,000,000
Earnings attributable to common shares				15,000,000	1,000,000	62,000,000
Equity							158,000,000
Sempra Natural Gas [Member] | Cameron LNG Holdings [Member]
Variable Interest Entities [Line Items]
Equity method investment			1,216,000,000		1,216,000,000		1,271,000,000
San Diego Gas and Electric Company [Member]
Variable Interest Entities [Line Items]
Cash and cash equivalents			24,000,000		24,000,000		8,000,000	[1]
Inventories			92,000,000		92,000,000		102,000,000	[1]
Total current assets			1,066,000,000		1,066,000,000		894,000,000	[1]
Property, plant and equipment, net			16,611,000,000		16,611,000,000		16,310,000,000	[1]
Other noncurrent assets			390,000,000		390,000,000		420,000,000	[1]
Total assets			20,336,000,000		20,336,000,000		19,225,000,000	[1]
Accounts payable			444,000,000		444,000,000		439,000,000	[1]
Other			268,000,000		268,000,000		141,000,000	[1]
Total current liabilities			1,245,000,000		1,245,000,000		1,428,000,000	[1]
Deferred credits and other			686,000,000		686,000,000		488,000,000	[1]
Other noncontrolling interests			0		0		100,000,000	[1]
Total liabilities and equity			20,336,000,000		20,336,000,000		19,225,000,000	[1]
Operation and maintenance			295,000,000	262,000,000	857,000,000	761,000,000
Depreciation and amortization			196,000,000	174,000,000	571,000,000	509,000,000
Operating income			423,000,000	300,000,000	948,000,000	763,000,000
Interest expense			(106,000,000)	(56,000,000)	(311,000,000)	(161,000,000)
Income (loss) from continuing operations before income taxes and equity earnings			337,000,000	269,000,000	700,000,000	682,000,000
Income tax expense			(71,000,000)	(53,000,000)	(111,000,000)	(151,000,000)
Net income			266,000,000	216,000,000	589,000,000	531,000,000
Earnings attributable to noncontrolling interests			(3,000,000)	(11,000,000)	$ (7,000,000)	(10,000,000)
San Diego Gas and Electric Company [Member] | Variable Interest Entity, Primary Beneficiary
Variable Interest Entities [Line Items]
Equity of variable interest entity							$ 100,000,000
Oncor Electric Delivery Company LLC. [Member]
Variable Interest Entities [Line Items]
Acquired percentage interest		80.25%
Sempra Texas Holdings Corp [Member] | Oncor Holdings [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Variable Interest Entities [Line Items]
Ownership percentage in consolidated entity		100.00%
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC. [Member]
Variable Interest Entities [Line Items]
Acquired percentage interest		80.03%
Otay Mesa VIE [Member] | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entities [Line Items]
Cash and cash equivalents	$ 8,000,000
Accounts receivable, net	11,000,000
Inventories	4,000,000
Total current assets	23,000,000
Property, plant and equipment, net	272,000,000
Other noncurrent assets	27,000,000
Total assets	322,000,000
Accounts payable	10,000,000
Other	2,000,000
Total current liabilities	12,000,000
Asset retirement obligations	2,000,000
Deferred credits and other	27,000,000
Asset Retirement Obligations And Deferred Credits And Other Liabilities	29,000,000
Other noncontrolling interests	281,000,000
Total liabilities and equity	322,000,000
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member] | Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entities [Line Items]
Gain recognized upon deconsolidation	$ 0
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member] | Variable Interest Entity, Primary Beneficiary
Variable Interest Entities [Line Items]
Generating capacity | MW					605
Conditional purchase obligation			280,000,000		$ 280,000,000
Cost of electric fuel and purchased power			(17,000,000)	(28,000,000)	(52,000,000)	(60,000,000)
Operation and maintenance			2,000,000	3,000,000	10,000,000	11,000,000
Depreciation and amortization			8,000,000	8,000,000	23,000,000	23,000,000
Total operating expenses			(7,000,000)	(17,000,000)	(19,000,000)	(26,000,000)
Operating income			7,000,000	17,000,000	19,000,000	26,000,000
Interest expense			(4,000,000)	(6,000,000)	(12,000,000)	(16,000,000)
Net income			3,000,000	11,000,000	7,000,000	10,000,000
Earnings attributable to noncontrolling interests			(3,000,000)	(11,000,000)	(7,000,000)	(10,000,000)
Earnings attributable to common shares			$ 0	$ 0	$ 0	$ 0
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_10

GENERAL INFORMATION AND OTHER FINANCIAL DATA - PENSION AND OTHER POSTRETIREMENT BENEFITS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Pension benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 27	$ 29	$ 82	$ 95
Interest cost	34	35	104	104
Expected return on assets	(36)	(35)	(108)	(117)
Amortization of:
Prior service cost (credit)	3	3	9	8
Actuarial loss (gain)	8	6	29	25
Settlement charges	4	9	26	48
Special termination benefits	0	0	0	0
Net periodic benefit cost (credit)	40	47	142	163
Regulatory adjustments	3	(11)	(30)	(91)
Total expense recognized	43	36	112	72
Contributions by employer			130
Expected contributions in current fiscal year	280		280
Pension benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	7	7	22	23
Interest cost	9	9	26	26
Expected return on assets	(9)	(10)	(29)	(35)
Amortization of:
Prior service cost (credit)	0	0	2	1
Actuarial loss (gain)	2	0	9	3
Settlement charges	0	1	0	17
Special termination benefits	0	0	0	0
Net periodic benefit cost (credit)	9	7	30	35
Regulatory adjustments	(1)	(7)	(13)	(34)
Total expense recognized	8	0	17	1
Contributions by employer			17
Expected contributions in current fiscal year	53		53
Pension benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	17	19	51	62
Interest cost	23	23	68	68
Expected return on assets	(24)	(22)	(71)	(73)
Amortization of:
Prior service cost (credit)	2	2	6	6
Actuarial loss (gain)	3	3	14	15
Settlement charges	0	2	0	25
Special termination benefits	0	0	0	0
Net periodic benefit cost (credit)	21	27	68	103
Regulatory adjustments	4	(4)	(17)	(57)
Total expense recognized	25	23	51	46
Contributions by employer			51
Expected contributions in current fiscal year	152		152
Other postretirement benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	4	4	12	15
Interest cost	9	9	27	27
Expected return on assets	(17)	(18)	(52)	(53)
Amortization of:
Prior service cost (credit)	0	0	0	0
Actuarial loss (gain)	(3)	(2)	(8)	(4)
Settlement charges	0	0	0	0
Special termination benefits	0	5	0	5
Net periodic benefit cost (credit)	(7)	(2)	(21)	(10)
Regulatory adjustments	8	2	22	11
Total expense recognized	1	0	1	1
Contributions by employer			6
Expected contributions in current fiscal year	8		8
Other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	1	1	3	3
Interest cost	1	2	5	5
Expected return on assets	(3)	(3)	(9)	(10)
Amortization of:
Prior service cost (credit)	1	0	2	2
Actuarial loss (gain)	0	(1)	(1)	(2)
Settlement charges	0	0	0	0
Special termination benefits	0	3	0	3
Net periodic benefit cost (credit)	0	2	0	1
Regulatory adjustments	0	(2)	0	(1)
Total expense recognized	0	0	0	0
Contributions by employer			0
Expected contributions in current fiscal year	1		1
Other postretirement benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	3	3	9	11
Interest cost	6	6	20	20
Expected return on assets	(14)	(13)	(43)	(41)
Amortization of:
Prior service cost (credit)	(1)	(1)	(2)	(2)
Actuarial loss (gain)	(2)	(1)	(6)	(2)
Settlement charges	0	0	0	0
Special termination benefits	0	2	0	2
Net periodic benefit cost (credit)	(8)	(4)	(22)	(12)
Regulatory adjustments	8	4	22	12
Total expense recognized	0	0	0	0
Contributions by employer			1
Expected contributions in current fiscal year	$ 1		1
Nonqualified Plan [Member] | Pension benefits [Member]
Amortization of:
Settlement charges			$ 22
Qualified Plan [Member] | Pension benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Reduction in plan assets due to settlement				300
Amortization of:
Settlement charges		3		42
Qualified Plan [Member] | Pension benefits [Member] | San Diego Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Reduction in plan assets due to settlement				108
Amortization of:
Settlement charges		1		17
Qualified Plan [Member] | Pension benefits [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Reduction in plan assets due to settlement				192
Amortization of:
Settlement charges		$ 2		$ 25

GENERAL INFORMATION AND OTHE_11

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RABBI TRUST (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Rabbi trust	$ 439	$ 416	[1]
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_12

GENERAL INFORMATION AND OTHER FINANCIAL DATA - EARNINGS PER SHARE (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Income from continuing operations, net of income tax	$ 653	$ 280	$ 1,570	$ 25
(Earnings) losses attributable to noncontrolling interests	(52)	(16)	(121)	10
Mandatory convertible preferred stock dividends	(36)	(36)	(107)	(89)
Preferred dividends of subsidiary	0	0	1	1
Earnings (losses) from continuing operations attributable to common shares for basic EPS	565	228	1,341	(55)
Earnings (losses) from continuing operations attributable to common shares for diluted EPS	591	228	1,341	(55)
Income from discontinued operations, net of income tax	256	54	292	137
Earnings attributable to noncontrolling interests	(8)	(8)	(25)	(22)
Earnings from discontinued operations attributable to common shares	248	46	267	115
Earnings attributable to common shares for basic EPS	813	274	1,608	60
Add back dividends for dilutive mandatory convertible preferred stock	26	0	0	0
Earnings attributable to common shares	$ 839	$ 274	$ 1,608	$ 60
Weighted-average common shares outstanding for basic EPS	277,360,000	273,944,000	275,684,000	265,963,000
Dilutive effect of stock options, RSAs and RSUs (in shares)	1,636,000	854,000	1,381,000	0
Dilutive effect of common stock forward shares (in shares)	3,555,000	1,109,000	2,744,000	0
Dilutive effect of mandatory convertible preferred stock (in shares)	13,238,000	0	0	0
Weighted-average common shares outstanding for diluted EPS (in shares)	295,789,000	275,907,000	279,809,000	265,963,000
Earnings (losses) from continuing operations attributable to common shares (in usd per share)	$ 2.04	$ 0.83	$ 4.86	$ (0.21)
Earnings from discontinued operations attributable to common shares (in usd per share)	0.89	0.17	0.97	0.44
Earnings attributable to common shares (in usd per share)	2.93	1	5.83	0.23
Earnings (losses) from continuing operations attributable to common shares (in usd per share)	2	0.82	4.79	(0.21)
Earnings from discontinued operations attributable to common shares (in usd per share)	0.84	0.17	0.95	0.44
Earnings from continuing operations attributable to common shares (n usd per share)	$ 2.84	$ 0.99	$ 5.74	$ 0.23
Vested RSUs included in basic WASO (in shares)	618,000	645,000	615,000	638,000
Non-qualified stock options granted (in shares)			261,075
Convertible Preferred Stock [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	4,219,350	19,152,109	17,457,000	15,863,530
Common Stock Forward Sales [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	0	0	0	2,857,143
Share-based Payment Arrangement, Option [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Exercisable period			3 years
Performance-based RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			389,825
Service-based RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Equity awards, granted (in shares)			260,594
Stock Options and RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)				736,000
Common Stock [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)				945,000
Stock options, RSAs and RSUs [Member]
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items]
Antidilutive securities excluded from earnings per share (in shares)	0	508	107,042	1,552

GENERAL INFORMATION AND OTHE_13

GENERAL INFORMATION AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			$ 17,138
OCI before reclassifications		$ (139)	$ (15)	(211)	$ 9
Amounts reclassified from AOCI		9	4	39	8
Net OCI		(130)	(11)	(172)	17
Ending balance		18,620		18,620
Foreign currency translation adjustments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(518)	(482)	(564)	(420)
Cumulative-effect adjustment from change in accounting principle				0	0
OCI before reclassifications		(91)	(16)	(45)	(78)
Amounts reclassified from AOCI		0	0	0	0
Net OCI		(91)	(16)	(45)	(78)
Ending balance		(609)	(498)	(609)	(498)
Financial instruments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(213)	(40)	(82)	(122)
Cumulative-effect adjustment from change in accounting principle				(25)	(3)
OCI before reclassifications		(41)	19	(153)	104
Amounts reclassified from AOCI		4	(4)	10	(4)
Net OCI		(37)	15	(143)	100
Ending balance		(250)	(25)	(250)	(25)
Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(117)	(79)	(118)	(84)
Cumulative-effect adjustment from change in accounting principle				(17)	0
OCI before reclassifications		(7)	(18)	(13)	(17)
Amounts reclassified from AOCI		5	8	29	12
Net OCI		(2)	(10)	16	(5)
Ending balance		(119)	(89)	(119)	(89)
Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(848)	(601)	(764)	(626)
Cumulative-effect adjustment from change in accounting principle				(42)	(3)
Ending balance		(978)	(612)	(978)	(612)
San Diego Gas and Electric Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			6,015
OCI before reclassifications			(6)		(6)
Amounts reclassified from AOCI				1
Net OCI			(6)	1	(6)
Ending balance		6,920		6,920
San Diego Gas and Electric Company [Member] | Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(11)	(8)	(10)	(8)
Cumulative-effect adjustment from change in accounting principle				(2)
OCI before reclassifications			(6)		(6)
Amounts reclassified from AOCI				1
Net OCI			(6)	1	(6)
Ending balance		(11)	(14)	(11)	(14)
San Diego Gas and Electric Company [Member] | Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(11)	(8)	(10)	(8)
Cumulative-effect adjustment from change in accounting principle				(2)
Ending balance		(11)	(14)	(11)	(14)
Southern California Gas Company [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance	[1]			4,258
Amounts reclassified from AOCI		1		5	1
Net OCI		1		5	1
Ending balance		4,548		4,548
Southern California Gas Company [Member] | Financial instruments [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(14)	(13)	(12)	(13)
Cumulative-effect adjustment from change in accounting principle				(2)
Amounts reclassified from AOCI		1		1	0
Net OCI		1		1	0
Ending balance		(13)	(13)	(13)	(13)
Southern California Gas Company [Member] | Pension and other postretirement benefits [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(6)	(7)	(8)	(8)
Cumulative-effect adjustment from change in accounting principle				(2)
Amounts reclassified from AOCI		0		4	1
Net OCI		0		4	1
Ending balance		(6)	(7)	(6)	(7)
Southern California Gas Company [Member] | Total accumulated other comprehensive income (loss) [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning balance		(20)	(20)	(20)	(21)
Cumulative-effect adjustment from change in accounting principle				(4)
Ending balance		$ (19)	$ (20)	$ (19)	$ (20)
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_14

GENERAL INFORMATION AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	$ (279)	$ (222)	$ (797)	$ (656)
Other (Expense) Income, Net	7	(96)	(103)	(192)
(Loss) gain on sale of assets	(3)	0	63	0
Equity earnings	266	74	485	49
Energy-related businesses	360	463	1,078	1,164
Income (loss) from continuing operations before income taxes and equity earnings	448	345	1,235	(245)
Income tax (expense) benefit	(61)	(139)	(150)	221
Net income	(909)	(334)	(1,862)	(162)
Earnings attributable to noncontrolling interest	(60)	(24)	(146)	(12)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	9	4	35	8
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 (loss) from continuing operations before income taxes and equity earnings	8	(8)	16	(5)
Income tax (expense) benefit	(2)	4	(3)	3
Net income	6	(4)	13	(2)
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	1	0	2	(1)
Other (Expense) Income, Net	5	(11)	0	(11)
Equity earnings	2	3	3	8
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]
(Loss) gain on sale of assets			10	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gains (Losses) on Cash Flow hedges [Member] | Foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Energy-related businesses			1	(1)
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 interest	(2)	0	(3)	(2)
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 attributable to common shares	4	(4)	10	(4)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Gain (Loss) on Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (Expense) Income, Net	3	9	7	15
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (Expense) Income, Net	1	1	2	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Settlements Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (Expense) Income, Net	4	0	26	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from continuing operations before income taxes and equity earnings	8	10	35	16
Income tax (expense) benefit	(3)	(2)	(10)	(4)
Net income	5	8	25	12
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(106)	(56)	(311)	(161)
Other (Expense) Income, Net	(19)	(24)	(60)	(77)
Income (loss) from continuing operations before income taxes and equity earnings	337	269	700	682
Income tax (expense) benefit	(71)	(53)	(111)	(151)
Net income	(266)	(216)	(589)	(531)
Earnings attributable to noncontrolling interest	(3)	(11)	(7)	(10)
San Diego Gas and Electric Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	0	0	1	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	1	2	3	6
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 interest	(1)	(2)	(3)	(6)
San Diego Gas and Electric Company [Member] | 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 attributable to common shares			0	0
San Diego Gas and Electric Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (Expense) Income, Net			1	0
Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	(36)	(29)	(104)	(82)
Other (Expense) Income, Net	(1)	(3)	(18)	(49)
Income (loss) from continuing operations before income taxes and equity earnings	178	(21)	488	320
Income tax (expense) benefit	(35)	7	(50)	(75)
Net income	(143)	14	(438)	(245)
Southern California Gas Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares	1	0	1	1
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
Southern California Gas Company [Member] | Reclassification out of Accumulated Other Comprehensive Income [Member] | Gain (Loss) on Pension and Other Postretirement Benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (Expense) Income, Net			$ 0	$ 1

GENERAL INFORMATION AND OTHE_15

GENERAL INFORMATION AND OTHER FINANCIAL DATA - SHAREHOLDER'S EQUITY AND NONCONTROLLING INTEREST (Details) - USD ($) $ / shares in Units, $ in Millions	Nov. 01, 2019	Feb. 07, 2019	Jul. 31, 2018	Jan. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Dec. 31, 2018	Jul. 13, 2018	Jan. 09, 2018
Subsidiary, Sale of Stock [Line Items]
Proceeds from issuance									$ 0	$ 2,259
Proceeds from issuance									757	2,261
Repurchases of common stock					$ 5				$ 23	$ 20
Public Offering [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued (in shares)			11,212,500	26,869,158
Shares issued (in usd per share)			$ 113.75	$ 107
Shares issued net of underwriting discount (in usd per share)			$ 111.87	$ 105.07
Proceeds from issuance											$ 2,800
Over-Allotment Option [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued (in shares)						1,462,500		3,504,672
Proceeds from issuance						$ 164		$ 367
Underwriting discounts and equity issuance costs						$ 3		$ 8
Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued (in shares)					7,156,185		7,651,671	8,556,630
Proceeds from issuance					$ 728		$ 800	$ 900
Underwriting discounts and equity issuance costs					$ 13		$ 14	$ 16
Sempra Energy [Member] | Series A Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued (in shares)				17,250,000
Proceeds from issuance				$ 1,690
Liquidation price (in usd per share)														$ 100
Sempra Energy [Member] | Series B Preferred Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issued (in shares)			5,750,000
Proceeds from issuance			$ 565
Liquidation price (in usd per share)													$ 100
Infraestructura Energética Nova [Member]
Subsidiary, Sale of Stock [Line Items]
Common stock repurchased (in shares)									2,620,000
Repurchases of common stock									$ 10
Subsequent Event [Member] | Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Subsidiary, Sale of Stock [Line Items]
Shares issuable under forward contracts	9,750,000
Infraestructura Energética Nova [Member]
Subsidiary, Sale of Stock [Line Items]
Ownership interest					66.60%				66.60%		66.60%	66.50%
Bay Gas [Member] | Sempra LNG [Member]
Subsidiary, Sale of Stock [Line Items]
Payment to acquire remaining interest in Bay Gas		$ 20
Sale of interest		100.00%
Sempra LNG [Member] | Ownership Interests Held By Others, Bay Gas Storage Company [Member]
Subsidiary, Sale of Stock [Line Items]
Percent ownership held by noncontrolling interests					0.00%				0.00%		0.00%	9.10%

GENERAL INFORMATION AND OTHE_16

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 1,911	$ 2,090	[1]
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	0.00%	100.00%
Other noncontrolling interests	$ 0	$ 100
IEnova [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	33.40%	33.50%
Other noncontrolling interests	$ 1,676	$ 1,592
IEnova subsidiaries [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 16	$ 13
IEnova subsidiaries [Member] | Sempra Mexico [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	10.00%	10.00%
IEnova subsidiaries [Member] | Sempra Mexico [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	46.30%	49.00%
Tax equity arrangement – wind [Member] | Sempra Renewables [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	0.00%
Other noncontrolling interests	$ 0	$ 158
PXISE Energy Solutions LLC [Member] | Sempra Renewables [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	0.00%	11.10%
Other noncontrolling interests	$ 0	$ 1
PXISE Energy Solutions LLC [Member] | Parent and Other [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	20.00%
Other noncontrolling interests	$ 1
Bay Gas Storage Company, Ltd. [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	0.00%	9.10%
Other noncontrolling interests	$ 0	$ 18
Liberty Gas Storage, LLC [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	24.60%	24.60%
Other noncontrolling interests	$ (13)	$ (12)
ECA LNG Proposed Liquefaction Project [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	16.70%	0.00%
Other noncontrolling interests	$ 3	$ 0
Discontinued Operations, Held-for-sale [Member] | Chilquinta Energía subsidiaries [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 23	$ 23
Discontinued Operations, Held-for-sale [Member] | Chilquinta Energía subsidiaries [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	19.70%	19.70%
Discontinued Operations, Held-for-sale [Member] | Chilquinta Energía subsidiaries [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	43.40%	43.40%
Discontinued Operations, Held-for-sale [Member] | Luz del Sur [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	16.40%	16.40%
Other noncontrolling interests	$ 200	$ 193
Discontinued Operations, Held-for-sale [Member] | Tecsur [Member]
Noncontrolling Interest [Line Items]
Percent ownership held by noncontrolling interests	9.80%	9.80%
Other noncontrolling interests	$ 5	$ 4
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_17

GENERAL INFORMATION AND OTHER FINANCIAL DATA - DUE TO DUE FROM AFFILIATES (Details) $ in Millions, $ in Billions	9 Months Ended	12 Months Ended
	Sep. 30, 2019USD ($)	Dec. 31, 2018USD ($)		Sep. 30, 2019MXN ($)	May 17, 2019USD ($)	May 16, 2019USD ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 40	$ 37	[1]
Due from unconsolidated affiliates - noncurrent	712	644	[1]
Due to unconsolidated affiliates, current	(12)	(10)	[1]
Due to unconsolidated affiliates - noncurrent	$ (39)	$ (37)	[1]
ESJ joint venture [Member]
Related Party Transaction [Line Items]
Interest rate on due from affiliate, noncurrent		8.89%
ESJ joint venture [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate	6.375%	6.375%
TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Interest rate on due from affiliate, noncurrent	4.96%
TAG Pipeline Norte [Member] | LIBOR [Member]
Related Party Transaction [Line Items]
Spread on variable rate	2.90%	2.90%
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 1	$ 0	[1]
Due to unconsolidated affiliates, current	(26)	(61)	[1]
Maximum borrowing capacity	1,500				$ 1,500	$ 750
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	1	0
Due to unconsolidated affiliates, current	0	(6)
San Diego Gas and Electric Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(14)	(43)
Income taxes due (to) from Sempra Energy	$ 5	5
Interest rate on due from affiliate, noncurrent	2.03%
Advances to Affiliate	$ 25
San Diego Gas and Electric Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(12)	(12)
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	0	7	[1]
Due to unconsolidated affiliates, current	(187)	(34)	[1]
Maximum borrowing capacity	750				$ 750	$ 750
Southern California Gas Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(35)	(34)
Income taxes due (to) from Sempra Energy	(19)	(4)
Southern California Gas Company [Member] | Due to/from Other affiliates [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	0	1
Due to unconsolidated affiliates, current	(1)	0
Southern California Gas Company [Member] | Due to/from SDG&E
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	0	6
Due to unconsolidated affiliates, current	(1)	0
Southern California Gas Company [Member] | Pacific Enterprises [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, current	(150)	0
Sempra Mexico [Member] | IMG [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	712	$ 641
Maximum borrowing capacity	$ 718			$ 14.2
Sempra Mexico [Member] | IMG [Member] | Interbank Equilibrium Rate [Member]
Related Party Transaction [Line Items]
Spread on variable rate	2.20%	2.20%
Interest rate on due from affiliate, noncurrent	10.13%
Sempra Mexico [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	$ 0	$ 3
Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - noncurrent	$ (39)	$ (37)
[1]	Derived from audited financial statements.

GENERAL INFORMATION AND OTHE_18

GENERAL INFORMATION AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Related Party Transaction [Line Items]
Revenue from related parties	$ 13	$ 17	$ 40	$ 49
Costs of sales to related parties	12	9	40	36
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	2	1	5	4
Costs of sales to related parties	16	21	56	56
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Revenue from related parties	16	15	50	47
Costs of sales to related parties	$ 2	$ 0	$ 6	$ 0

GENERAL INFORMATION AND OTHE_19

GENERAL INFORMATION AND OTHER FINANCIAL DATA - OTHER (EXPENSE) INCOME, NET (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		9 Months Ended
	Jan. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Other Income [Line Items]
Allowance for equity funds used during construction		$ 25	$ 23	$ 69	$ 79
Investment gains		9	8	46	13
(Losses) gains on interest rate and foreign exchange instruments, net		(17)	39	7	46
Foreign currency transaction gains (losses), net		(13)	28	(2)	16
Non-service component of net periodic benefit (cost) credit		(13)	(3)	(19)	37
Penalties related to billing practices OII		0	0	(8)	0
Interest on regulatory balancing accounts, net		4	1	9	2
Sundry, net		(2)	0	1	(1)
Total		(7)	96	103	192
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		15	15	42	49
Non-service component of net periodic benefit (cost) credit		0	8	8	25
Interest on regulatory balancing accounts, net		4	2	10	4
Sundry, net		0	(1)	0	(1)
Total		19	24	60	77
Southern California Gas Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		9	8	25	30
Non-service component of net periodic benefit (cost) credit		(5)	(1)	9	27
Penalties related to billing practices OII	$ (8)	0	0	(8)	0
Interest on regulatory balancing accounts, net		0	(1)	(1)	(2)
Sundry, net		(3)	(3)	(7)	(6)
Total		1	3	18	49
Sempra Mexico [Member] | IMG [Member]
Other Income [Line Items]
Foreign Currency Transaction Gain, before Tax			$ 33		$ 25
Foreign Currency Transaction Loss, before Tax		$ 17		$ 0

GENERAL INFORMATION AND OTHE_20

GENERAL INFORMATION AND OTHER FINANCIAL DATA - INCOME TAXES (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2019	Mar. 31, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit) from continuing operations	$ 61		$ 139	$ 150	$ (221)
Income (loss) from continuing operations before income taxes and equity earnings	448		345	1,235	(245)
Equity earnings (losses), before income tax	17		(52)	24	(236)
Pretax income (loss)	$ 465		$ 293	$ 1,259	$ (481)
Effective income tax rate	13.00%		47.00%	12.00%	46.00%
Income tax expense (benefit) related to outside basis differences existing prior to the January 25, 2019 approval of our plan to sell our South American businesses	$ (192)	$ 103		$ (89)
Income tax expense related to the increase in outside basis differences from 2019 earnings since January 25, 2019				32
San Diego Gas and Electric Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit) from continuing operations	71		$ 53	111	$ 151
Income (loss) from continuing operations before income taxes and equity earnings	$ 337		$ 269	$ 700	$ 682
Effective income tax rate	21.00%		20.00%	16.00%	22.00%
Income tax benefit for release of a regulatory liability				$ 31
Southern California Gas Company [Member]
Income Tax Expense And Effective Income Tax Rates Disclosure [Line Items]
Income tax expense (benefit) from continuing operations	$ 35		$ (7)	50	$ 75
Income (loss) from continuing operations before income taxes and equity earnings	$ 178		$ (21)	$ 488	$ 320
Effective income tax rate	20.00%		33.00%	10.00%	23.00%
Income tax benefit for release of a regulatory liability				$ 38

NEW ACCOUNTING STANDARDS (Detai

NEW ACCOUNTING STANDARDS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Jan. 01, 2019	Dec. 31, 2018	[1]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry	$ 309		$ 249
Property, plant and equipment, net	35,520		34,439
Right-of-use assets – operating leases	595
Deferred income tax assets	157		141
Other current liabilities	914		935
Deferred credits and other	2,049		1,493
Retained earnings	10,966		10,104
Regulatory liabilities	3,823		4,016
Accumulated other comprehensive income (loss)	(978)		(764)
Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry		$ (71)
Property, plant and equipment, net		(147)
Right-of-use assets – operating leases		603
Deferred income tax assets		(3)
Other current liabilities		80
Long-term debt		(138)
Deferred credits and other		436
Retained earnings		17
Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		40
Regulatory liabilities		2
Accumulated other comprehensive income (loss)		42
San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry	25		5
Property, plant and equipment, net	16,611		16,310
Right-of-use assets – operating leases	126
Other current liabilities	268		141
Deferred credits and other	686		488
Retained earnings	5,271		4,687
Regulatory liabilities	2,400		2,404
Accumulated other comprehensive income (loss)	(11)		(10)
San Diego Gas and Electric Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry		0
Property, plant and equipment, net		0
Right-of-use assets – operating leases		130
Deferred income tax assets		0
Other current liabilities		20
Long-term debt		0
Deferred credits and other		110
Retained earnings		0
San Diego Gas and Electric Company [Member] | Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		2
Accumulated other comprehensive income (loss)		2
Southern California Gas Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry	39		31
Property, plant and equipment, net	12,963		12,439
Right-of-use assets – operating leases	99
Other current liabilities	223		217
Deferred credits and other	422		330
Retained earnings	3,679		3,390
Regulatory liabilities	1,423		1,612
Accumulated other comprehensive income (loss)	$ (19)		$ (20)
Southern California Gas Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Sundry		0
Property, plant and equipment, net		0
Right-of-use assets – operating leases		116
Deferred income tax assets		0
Other current liabilities		23
Long-term debt		0
Deferred credits and other		93
Retained earnings		0
Southern California Gas Company [Member] | Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		2
Regulatory liabilities		2
Accumulated other comprehensive income (loss)		4
Disposal Group Held-for-sale [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets held for sale		13
Disposal Group Held-for-sale [Member] | San Diego Gas and Electric Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets held for sale		0
Disposal Group Held-for-sale [Member] | Southern California Gas Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets held for sale		$ 0
[1]	Derived from audited financial statements.

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 2,383	$ 2,618	$ 7,506	$ 7,058
Utilities regulatory revenues	267	(195)	34	(131)
Other revenues	108	142	346	349
Total revenues	2,758	2,565	7,886	7,276
Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2,131	2,297	6,774	6,243
Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	167	205	497	550
Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	34	46	88	123
Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	51	70	147	142
Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,029	1,020	4,112	3,464
Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,354	1,598	3,394	3,594
Operating Segments [Member] | San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,370	1,577	3,604	3,707
Utilities regulatory revenues	57	(278)	62	(302)
Other revenues	0	0	0	0
Total revenues	1,427	1,299	3,666	3,405
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,370	1,577	3,604	3,707
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	100	91	441	372
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,270	1,486	3,163	3,335
Operating Segments [Member] | Southern California Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	765	719	3,170	2,529
Utilities regulatory revenues	210	83	(28)	171
Other revenues	0	0	0	0
Total revenues	975	802	3,142	2,700
Operating Segments [Member] | Southern California Gas Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	765	719	3,170	2,529
Operating Segments [Member] | Southern California Gas Company [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	765	719	3,170	2,529
Operating Segments [Member] | Southern California Gas Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra Mexico [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	256	314	757	769
Utilities regulatory revenues	0	0	0	0
Other revenues	101	96	301	259
Total revenues	357	410	1,058	1,028
Operating Segments [Member] | Sempra Mexico [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	14	17	56	58
Operating Segments [Member] | Sempra Mexico [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	158	194	472	484
Operating Segments [Member] | Sempra Mexico [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	32	32	82	85
Operating Segments [Member] | Sempra Mexico [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	52	71	147	142
Operating Segments [Member] | Sempra Mexico [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	171	214	527	545
Operating Segments [Member] | Sempra Mexico [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	85	100	230	224
Operating Segments [Member] | Sempra Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	14	5	37
Utilities regulatory revenues	0	0	0	0
Other revenues	0	24	5	66
Total revenues	0	38	10	103
Operating Segments [Member] | Sempra Renewables [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	14	5	37
Operating Segments [Member] | Sempra Renewables [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	14	5	37
Operating Segments [Member] | Sempra LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	50	84	139	178
Utilities regulatory revenues	0	0	0	0
Other revenues	50	63	188	152
Total revenues	100	147	327	330
Operating Segments [Member] | Sempra LNG [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0	0
Operating Segments [Member] | Sempra LNG [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	48	82	134	171
Operating Segments [Member] | Sempra LNG [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	1	0	2
Operating Segments [Member] | Sempra LNG [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	1	5	5
Operating Segments [Member] | Sempra LNG [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	48	82	134	171
Operating Segments [Member] | Sempra LNG [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	2	5	7
Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(58)	(90)	(169)	(162)
Utilities regulatory revenues	0	0	0	0
Other revenues	(43)	(41)	(148)	(128)
Total revenues	(101)	(131)	(317)	(290)
Consolidation, Eliminations [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(18)	(16)	(56)	(51)
Consolidation, Eliminations [Member] | Midstream service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(39)	(71)	(109)	(105)
Consolidation, Eliminations [Member] | Renewables service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	2	(1)	1	(1)
Consolidation, Eliminations [Member] | Other service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(3)	(2)	(5)	(5)
Consolidation, Eliminations [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(55)	(86)	(160)	(153)
Consolidation, Eliminations [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (3)	$ (4)	$ (9)	$ (9)

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Sep. 30, 2019USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 87
Revenues to be recognized, period of recognition	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 409
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 401
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 405
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 401
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4,986
Revenues to be recognized, period of recognition
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 6,689
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-10-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 1
Revenues to be recognized, period of recognition	3 months
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4
Revenues to be recognized, period of recognition	1 year
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 75
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 92

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	$ (70)	$ 0
Adoption of ASC 606 adjustment		(61)
Revenue from performance obligations satisfied during reporting period	1	6
Payments received in advance	(95)	(9)
Contract liabilities, closing balance	(164)	(64)
Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(161)
San Diego Gas and Electric Company [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, opening balance	0
Revenue from performance obligations satisfied during reporting period	0
Payments received in advance	(92)
Contract liabilities, closing balance	(92)	0
San Diego Gas and Electric Company [Member] | Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(3)
San Diego Gas and Electric Company [Member] | Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	(89)
Southern California Gas Company [Member]
Contract with Customer, Liability [Roll Forward]
Contract liabilities, closing balance	$ 0	$ 0

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 891	$ 1,127
Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	875	1,106
Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	10	11
Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	6	4
Assets held-for-sale [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	0	6
San Diego Gas and Electric Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	456	377
San Diego Gas and Electric Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	446	368
San Diego Gas and Electric Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	7	6
San Diego Gas and Electric Company [Member] | Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	3	3
Southern California Gas Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	359	639
Southern California Gas Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	356	634
Southern California Gas Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 3	$ 5

REGULATORY MATTERS - REGULATORY

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (2,143)	$ (2,394)
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	117	78
San Diego Gas and Electric Company [Member] | Fixed-price contracts and other derivatives [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(136)	(150)
San Diego Gas and Electric Company [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(118)	(236)
San Diego Gas and Electric Company [Member] | Pension and other postretirement benefit plan obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	186	186
San Diego Gas and Electric Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,999)	(1,848)
San Diego Gas and Electric Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	26	28
San Diego Gas and Electric Company [Member] | Sunrise Powerlink fire mitigation [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	120	120
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Commodity – electric [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	142	(8)
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Gas transportation [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	17	45
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	76	70
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Public purpose programs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(117)	(62)
San Diego Gas and Electric Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	81	0
San Diego Gas and Electric Company [Member] | Regulatory Balancing Accounts, Other balancing accounts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	46	145
San Diego Gas and Electric Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(152)	(170)
San Diego Gas and Electric Company [Member] | Net Regulatory Assets (Liabilities) SDGE [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,828)	(1,880)
Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	475	185
Southern California Gas Company [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(214)	(336)
Southern California Gas Company [Member] | Pension and other postretirement benefit plan obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	452	470
Southern California Gas Company [Member] | Employee benefit costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	49	49
Southern California Gas Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(754)	(833)
Southern California Gas Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	28	28
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Commodity - gas including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(85)	196
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	310	332
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Public purpose programs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(329)	(325)
Southern California Gas Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	286	0
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Other balancing accounts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(30)	(68)
Southern California Gas Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(115)	(114)
Southern California Gas Company [Member] | Net Regulatory Assets (Liabilities) SoCalGas [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(402)	(601)
Sempra Mexico [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	81	81
Sempra Mexico [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 6	$ 6

REGULATORY MATTERS - GENERAL RA

REGULATORY MATTERS - GENERAL RATE CASE (Details) - USD ($) $ in Millions	Sep. 26, 2019	Oct. 06, 2017	Sep. 30, 2019	Dec. 31, 2018	[1]
General Rate Case [Line Items]
Regulatory assets, noncurrent			$ 1,942	$ 1,589
San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Regulatory assets, noncurrent			519	454
GRC requested revenue requirement		$ 2,203
General Rate Case, Retroactive Impact, Incremental Earnings			(92)
General Rate Case, Retroactive Impact, Incremental Earnings, Net Of Tax			66
San Diego Gas and Electric Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability			86
San Diego Gas and Electric Company [Member] | Future Refund of Rates to Customers [Member]
General Rate Case [Line Items]
Regulatory liability			88
San Diego Gas and Electric Company [Member] | Future Refund of Rates to Customers - FERC [Member]
General Rate Case [Line Items]
Regulatory liability			79
Southern California Gas Company [Member]
General Rate Case [Line Items]
Regulatory assets, noncurrent			1,341	$ 1,051
GRC requested revenue requirement		$ 2,937
General Rate Case, Retroactive Impact, Incremental Earnings			(181)
General Rate Case, Retroactive Impact, Incremental Earnings, Net Of Tax			130
Southern California Gas Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability			88
Southern California Gas Company [Member] | Future Refund of Rates to Customers [Member]
General Rate Case [Line Items]
Regulatory liability			75
2019 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Regulatory assets			81
Regulatory assets, noncurrent			51
GRC requested revenue requirement	$ 1,990
Difference from requested amount	213
Revenue increase	$ 107
Percent increase	5.70%
2019 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Regulatory assets			286
Regulatory assets, noncurrent			$ 179
GRC requested revenue requirement	$ 2,770
Difference from requested amount	167
Revenue increase	$ 314
Percent increase	12.80%
2019 GRC FD [Member] | Electric market [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement	$ 1,590
2019 GRC FD [Member] | Gas market [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement	$ 400
[1]	Derived from audited financial statements.

REGULATORY MATTERS - SCHEDULE O

REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE AUTHORIZED REVENUE INCREASES (Details) $ in Millions	Sep. 26, 2019USD ($)
2020 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 134
Percent increase	6.74%
2020 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 220
Percent increase	7.92%
2021 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 102
Percent increase	4.83%
2021 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 150
Percent increase	5.00%
O&M [Member] | 2020 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 20
Percent increase	2.64%
O&M [Member] | 2020 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 36
Percent increase	2.64%
O&M [Member] | 2021 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 19
Percent increase	2.47%
O&M [Member] | 2021 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 34
Percent increase	2.40%
Capital-related Costs [Member] | 2020 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 114
Percent increase	9.74%
Capital-related Costs [Member] | 2020 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 184
Percent increase	14.36%
Capital-related Costs [Member] | 2021 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 83
Percent increase	6.47%
Capital-related Costs [Member] | 2021 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 116
Percent increase	7.93%

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL (Details) - Forecast [Member] - California Public Utilities Commission [Member]	Jan. 01, 2020	Dec. 31, 2019
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base	10.03%	7.55%
Return on rate base, revised	8.95%
San Diego Gas and Electric Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting	56.00%	52.00%
Return on rate base	14.30%	10.20%
Return on rate base, revised	12.38%
Authorized weighting, proposed		52.00%
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base	7.85%	7.34%
Southern California Gas Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting	56.00%	52.00%
Return on rate base	10.70%	10.05%
Authorized weighting, proposed		52.00%
Minimum [Member] | San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base, proposed		6.62%
Minimum [Member] | San Diego Gas and Electric Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate, proposed		8.49%
Minimum [Member] | Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base, proposed		6.45%
Minimum [Member] | Southern California Gas Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate, proposed		8.49%
Maximum [Member] | San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base, proposed		7.22%
Maximum [Member] | San Diego Gas and Electric Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate, proposed		9.65%
Maximum [Member] | Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base, proposed		6.72%
Maximum [Member] | Southern California Gas Company [Member] | Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate, proposed		9.63%

REGULATORY MATTERS - BILLING PR

REGULATORY MATTERS - BILLING PRACTICES (Details) - USD ($)	1 Months Ended		3 Months Ended		9 Months Ended
	Oct. 31, 2019	Jan. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Jan. 01, 2019	Dec. 31, 2018
Public Utilities, General Disclosures [Line Items]
Penalties related to billing practices OII			$ 0	$ 0	$ 8,000,000	$ 0
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
FERC Requirement To Maintain Common Equity Ratio At Or Above							11.20%	10.05%
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Penalties related to billing practices OII		$ 8,000,000	$ 0	$ 0	$ 8,000,000	$ 0
Penalties related to billing practives, payable to general fund		3,000,000
Total amount penalties credited to customers		$ 5,000,000
Number of days that customers bills were delayed		45 days
Penalty credit per customer		$ 100
Subsequent Event [Member] | San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
FERC Requirement To Maintain Common Equity Ratio At Or Above	10.60%
Base ROE	10.10%
Additional Bps	0.50%
Additional FERC revenues	$ 17,000,000

ACQUISITIONS, DIVESTITURES AN_3

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - ACQUISITION ACTIVITY (Details) - USD ($) $ / shares in Units, $ in Millions	May 17, 2019	May 16, 2019	Dec. 18, 2018	Mar. 09, 2018
Oncor Holdings [Member]
Business Acquisition [Line Items]
Capital contributions		$ 1,330
Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Acquired percentage interest				80.25%
Compania Transmisora del Norte Grande S.A. [Member]
Business Acquisition [Line Items]
Cash consideration			$ 208
Consideration			226
Cash acquired			$ 18
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Acquired percentage interest				80.03%
Sempra Texas Holdings Corp [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity				100.00%
Sempra Texas Holdings Corp [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Cash consideration				$ 9,450
Adjustment for dividends				$ 31
Sempra Texas Holdings Corp [Member] | Texas Transmission Investment LLC [Member] | Oncor Electric Delivery Company LLC. [Member]
Business Acquisition [Line Items]
Ownership percentage held by noncontrolling owners				19.75%
Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Cash consideration				$ 26
Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Oncor Electric Delivery Company LLC. [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Acquired percentage interest				0.22%
InfraREIT Acquisition [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Acquired percentage interest		100.00%
Consideration		$ 1,275
Acquisition price per share acquired		$ 21
Management agreement termination fee paid		$ 40
Debt assumed	$ 953
Repayments of assumed debt	602
Repayments of secured debt	$ 351
InfraREIT Partners [Member] | Oncor Holdings [Member]
Business Acquisition [Line Items]
Acquired percentage interest		100.00%
Sharyland Holdings, LP [Member]
Business Acquisition [Line Items]
Acquired percentage interest		50.00%
Consideration		$ 102
Sharyland Holdings, LP [Member] | Sharyland Holdings, LP [Member] | Sharyland Utilities [Member]
Business Acquisition [Line Items]
Acquired percentage interest		100.00%
Compania Transmisora del Norte Grande S.A. [Member] | Sempra South American Utilities [Member] | Compania Transmisora del Norte Grande S.A. [Member]
Business Acquisition [Line Items]
Acquired percentage interest			100.00%

ACQUISITIONS, DIVESTITURES AN_4

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - DIVESTITURES (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended		9 Months Ended
	Apr. 30, 2019	Jun. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Feb. 07, 2019	Jan. 31, 2019
Business Acquisition [Line Items]
Gain on sale of assets			$ (3)	$ 0	$ 63	$ 0
Disposal Group Held-for-sale [Member]
Business Acquisition [Line Items]
Impairment charges		$ 1,500
Impairment charges net of taxes and noncontrolling interests		900
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Mississippi Hub And Bay Gas [Member] | Sempra LNG [Member]
Business Acquisition [Line Items]
Consideration to be received							$ 322
Disposal Group, Disposed of by Sale, Not Discontinued Operations [Member] | Other Non-Utility assets [Member] | Sempra LNG [Member]
Business Acquisition [Line Items]
Consideration to be received								$ 5
Sempra LNG [Member] | Disposal Group Held-for-sale [Member]
Business Acquisition [Line Items]
Impairment charges		1,300
Impairment charges net of taxes and noncontrolling interests		755
Sempra Renewables [Member] | Disposal Group Held-for-sale [Member]
Business Acquisition [Line Items]
Impairment charges		200
Impairment charges net of taxes and noncontrolling interests		$ 145
Sempra Renewables [Member] | Disposal Group Held-for-sale [Member] | Wind Facilities [Member]
Business Acquisition [Line Items]
Consideration to be received	$ 569
Gain on sale of assets	61
Gain on sale of assets after tax and NCI	$ 45

ACQUISITIONS, DIVESTITURES AN_5

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - DISCONTINUED OPERATIONS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Oct. 12, 2019	Sep. 27, 2019	Dec. 31, 2018
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from discontinued operations, net of income tax	$ 256	$ 54	$ 292	$ 137
Earnings attributable to noncontrolling interests	(8)	(8)	(25)	(22)
Earnings from discontinued operations attributable to common shares	248	46	267	115
Cash and cash equivalents	360		360				$ 88
Noncurrent assets	3,395		3,395				3,259	[1]
Current liabilities	804		804				368	[1]
Noncurrent liabilities	1,023		1,023				1,013	[1]
Discontinued Operations, Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Current assets	720		720				459	[1]
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	398	375	1,222	1,190
Cost of sales	(249)	(246)	(765)	(794)
Operating expenses	(38)	(41)	(123)	(151)
Interest and other	(3)	(6)	(12)	(15)
Income before income taxes and equity earnings	108	82	322	230
Income tax benefit (expense)	148	(28)	(32)	(94)
Equity earnings	0	0	2	1
Income from discontinued operations, net of income tax	256	54	292	137
Earnings from discontinued operations attributable to common shares	248	$ 46	267	$ 115
Cash and cash equivalents	359		359				88
Restricted cash	1		1				0
Accounts receivable, net	290		290				315
Due from unconsolidated affiliates	2		2				2
Inventories	44		44				38
Other current assets	24		24				16
Current assets	720		720				459
Due from unconsolidated affiliates	51		51				44
Goodwill and other intangible assets	803		803				819
Property, plant and equipment, net	2,502		2,502				2,357
Other noncurrent assets	39		39				39
Noncurrent assets	3,395		3,395				3,259
Short-term debt	75		75				55
Accounts payable	165		165				176
Dividends payable	428		428				8
Current portion of long-term debt and finance leases	39		39				29
Other current liabilities	97		97				100
Current liabilities	804		804				368
Long-term debt and finance leases	687		687				708
Deferred income taxes	274		274				250
Other noncurrent liabilities	62		62				55
Noncurrent liabilities	1,023		1,023				1,013
Cumulative foreign translation adjustments	$ 549		$ 549				$ 506
Discontinued Operations, Held-for-sale [Member] | Chilquinta Energia [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest	100.00%		100.00%
Discontinued Operations, Held-for-sale [Member] | Luz Del Sur [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest	83.60%		83.60%			83.60%
Consideration to be received						$ 3,590
Subsequent Event [Member] | Discontinued Operations, Held-for-sale [Member] | Chilquinta Energia [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest					100.00%
Consideration to be received					$ 2,230
Subsequent Event [Member] | Discontinued Operations, Held-for-sale [Member] | Eletrans [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest					50.00%
Chilquinta Energia [Member] | Subsequent Event [Member] | Discontinued Operations, Held-for-sale [Member] | Eletrans [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest					50.00%
State Grid International Development Limited [Member] | Subsequent Event [Member] | Discontinued Operations, Held-for-sale [Member] | Eletrans [Member] | Sempra South American Utilities [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest					100.00%
[1]	Derived from audited financial statements.

INVESTMENTS IN UNCONSOLIDATED_2

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) - USD ($) $ in Millions	May 16, 2019	Jun. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Schedule of Equity Method Investments [Line Items]
Equity earnings (losses), before income tax:			$ 17	$ (52)	$ 24	$ (236)
Maximum exposure under guarantor obligations			3,900		3,900
Oncor Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Contribution			1,236	$ 117	1,236	117
Commitment to invest			$ 1,067		1,067
R B S Sempra Commodities [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings (losses), before income tax:						65
Corporate Joint Venture [Member] | Sempra Mexico [Member] | IMG [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period						45
Corporate Joint Venture [Member] | Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Investments made during period					77	149
Capitalized interest					32	34
Wind Investments [Member] | Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Other-than-temporary impairment		$ 200
Sempra Energy [Member] | Oncor Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Dividends					162	9
Tax sharing payments					$ 9	$ 15
Sharyland Holdings, LP [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest	50.00%
Investments made during period	$ 102

INVESTMENTS IN UNCONSOLIDATED_3

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - Oncor Holdings [Member] - USD ($) $ in Millions	3 Months Ended		4 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018	Sep. 30, 2019
Schedule of Equity Method Investments [Line Items]
Operating revenues	$ 1,211	$ 1,095	$ 2,352	$ 3,268
Operating expense	(787)	(748)	(1,663)	(2,319)
Income from operations	424	347	689	949
Interest expense	(97)	(89)	(198)	(276)
Income tax expense	(53)	(53)	(105)	(106)
Net income / Earnings	261	191	351	511
Noncontrolling interest held by TTI	(52)	(38)	(70)	(102)
Earnings attributable to Sempra Energy	$ 209	$ 153	$ 281	$ 409

DEBT AND CREDIT FACILITIES - LI

DEBT AND CREDIT FACILITIES - LINES OF CREDIT (Details)	Sep. 23, 2019USD ($)	May 17, 2019USD ($)lender	Apr. 11, 2019USD ($)	Feb. 28, 2019USD ($)lender	Dec. 31, 2018USD ($)lender	Sep. 30, 2019USD ($)	May 16, 2019USD ($)
Line of Credit Facility [Line Items]
Standby letters of credit outstanding						$ 648,000,000
Sempra Energy [Member]
Line of Credit Facility [Line Items]
Term of debt instrument		5 years
Maximum borrowing capacity		$ 1,250,000,000				1,250,000,000	$ 1,250,000,000
Number of lenders | lender		23
Lender maximum share of debt, percent		6.00%
Available unused credit						1,250,000,000
Capacity for issuance of letters of credit						200,000,000
Option to request						500,000,000
Sempra Global [Member]
Line of Credit Facility [Line Items]
Term of debt instrument		5 years
Maximum borrowing capacity		$ 3,190,000,000				3,185,000,000	3,190,000,000
Number of lenders | lender		23
Lender maximum share of debt, percent		6.00%
Available unused credit						840,000,000
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 1,500,000,000				1,500,000,000	750,000,000
Number of lenders | lender		23
Lender maximum share of debt, percent		6.00%
Available unused credit						1,500,000,000
Capacity for issuance of letters of credit						100,000,000
Option to request						$ 250,000,000
Maximum ratio of indebtedness to total capitalization						65.00%
California Utilities Combined [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity							1,000,000,000
Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 750,000,000				$ 750,000,000	$ 750,000,000
Number of lenders | lender		23
Lender maximum share of debt, percent		6.00%
Available unused credit						642,000,000
Capacity for issuance of letters of credit						100,000,000
Option to request						$ 250,000,000
Maximum ratio of indebtedness to total capitalization						65.00%
Sempra U.S. Businesses [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity						$ 6,685,000,000
Available unused credit						$ 4,232,000,000
Maximum ratio of indebtedness to total capitalization						65.00%
Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Term of debt instrument				5 years
Maximum borrowing capacity				$ 1,500,000,000	$ 1,170,000,000
Number of lenders | lender				10	8
Available unused credit						$ 642,000,000
Commercial Paper [Member] | Sempra Energy [Member]
Line of Credit Facility [Line Items]
Amount outstanding						0
Commercial Paper [Member] | Sempra Global [Member]
Line of Credit Facility [Line Items]
Amount outstanding						(2,345,000,000)
Unamortized debt discount						3,000,000
Commercial Paper [Member] | San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Amount outstanding						0
Commercial Paper [Member] | Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Amount outstanding						(108,000,000)
Commercial Paper [Member] | Sempra U.S. Businesses [Member]
Line of Credit Facility [Line Items]
Amount outstanding						(2,453,000,000)
Additional Line of Credit [Member] | Sempra Mexico [Member]
Line of Credit Facility [Line Items]
Term of debt instrument	2 years		3 years
Maximum borrowing capacity	$ 280,000,000		$ 100,000,000
Amount outstanding						0
Available unused credit						$ 100,000,000

DEBT AND CREDIT FACILITIES - WE

DEBT AND CREDIT FACILITIES - WEIGHTED-AVERAGE INTEREST RATES AND INTEREST RATE SWAPS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Feb. 28, 2019	Dec. 31, 2018
Sempra Energy Consolidated [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	2.62%		2.99%
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding			2.97%
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding	2.06%		2.58%
Interest Rate Swap, maturing in March 2021 [Member]
Debt Instrument [Line Items]
Notional amount of derivative		$ 850
Fixed interest rate		3.069%

DEBT AND CREDIT FACILITIES - LO

DEBT AND CREDIT FACILITIES - LONG-TERM DEBT (Details) - USD ($)	Aug. 14, 2019	Jun. 30, 2019	May 31, 2019	Sep. 30, 2019
Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Par value of each note		$ 25
Otay Mesa VIE [Member] | Variable-Rate Loan. Due August 2024 [Member]
Debt Instrument [Line Items]
Repayments of variable-rate loan	$ 211,000,000
Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Stated rate of debt		3.95%		3.95%
Junior Subordinated Debt [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Debt amount		$ 758,000,000
Stated rate of debt		5.75%		5.75%
Net proceeds of debt		$ 735,000,000
Debt issuance costs		$ 23,000,000
Junior Subordinated Debt [Member] | On Or After October 1, 2024 [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Redemption price		100.00%
Junior Subordinated Debt [Member] | Before October 1, 2024, Amended Tax Regulations [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Redemption price		100.00%
Junior Subordinated Debt [Member] | Before October 1, 2024, Equity Credit Methodology Update [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Redemption price		102.00%
Bonds [Member] | San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due June 2049 [Member]
Debt Instrument [Line Items]
Debt amount			$ 400,000,000
Stated rate of debt			4.10%
Net proceeds of debt			$ 396,000,000
Debt issuance costs				$ 4,000,000
Bonds [Member] | Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Debt amount		$ 350,000,000
Net proceeds of debt		346,000,000
Debt issuance costs		$ 4,000,000

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE COMMODITY VOLUMES (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2019MWhMMBTU	Dec. 31, 2018MWhMMBTU
Natural Gas Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	30	35
Electric Energy Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	2	2
Congestion Revenue Rights Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	47	52
SDG&E [Member] | Natural Gas Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount | MMBTU	34	33
SDG&E [Member] | Electric Energy Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	2	2
SDG&E [Member] | Congestion Revenue Rights Derivative [Member]
Derivative [Line Items]
Derivative, nonmonetary notional amount	47	52

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE NOTIONALS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Notional amount of derivative	$ 306	$ 306
Foreign Exchange [Member]
Derivative [Line Items]
Notional amount of derivative	1,242	1,158
Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Notional amount of derivative	1,259	594
San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Notional amount of derivative	$ 0	$ 142

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS ON THE CONDENSED BALANCE SHEET (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	$ 28	$ 80
Additional cash collateral for commodity contracts not subject to rate recovery	18	19
Additional cash collateral for commodity contracts subject to rate recovery	17	33
Total	63	132
Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	253	235
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	253	235
Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(52)	(70)
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	(52)	(70)
Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(214)	(218)
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	(214)	(218)
Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	0	2
Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	0	0
Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(12)	(3)
Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives designated as hedging instruments:
Interest rate and foreign exchange instruments	(157)	(147)
Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	12
Associated offsetting foreign exchange instruments	(3)
Commodity contracts not subject to rate recovery	31	153
Associated offsetting commodity contracts	(29)	(133)
Commodity contracts subject to rate recovery	22	64
Associated offsetting commodity contracts	(5)	(6)
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
Associated offsetting foreign exchange instruments	0
Commodity contracts not subject to rate recovery	11	7
Associated offsetting commodity contracts	(1)	(3)
Commodity contracts subject to rate recovery	245	233
Associated offsetting commodity contracts	(2)	(2)
Associated offsetting cash collateral	0	0
Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	(3)
Associated offsetting foreign exchange instruments	3
Commodity contracts not subject to rate recovery	(39)	(164)
Associated offsetting commodity contracts	29	133
Commodity contracts subject to rate recovery	(48)	(42)
Associated offsetting commodity contracts	5	6
Associated offsetting cash collateral	13	0
Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Foreign exchange instruments	0
Associated offsetting foreign exchange instruments	0
Commodity contracts not subject to rate recovery	(9)	(6)
Associated offsetting commodity contracts	1	3
Commodity contracts subject to rate recovery	(53)	(72)
Associated offsetting commodity contracts	2	2
Associated offsetting cash collateral	2	2
San Diego Gas and Electric Company [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	11	54
Additional cash collateral for commodity contracts subject to rate recovery	14	28
Total	25	82
San Diego Gas and Electric Company [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	243	231
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	243	231
San Diego Gas and Electric Company [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(26)	(32)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(26)	(32)
San Diego Gas and Electric Company [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(49)	(68)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(49)	(68)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		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
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		(1)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives designated as hedging instruments:
Interest rate instruments		0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	14	60
Associated offsetting commodity contracts	(3)	(6)
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 subject to rate recovery	245	233
Associated offsetting commodity contracts	(2)	(2)
Associated offsetting cash collateral	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(42)	(37)
Associated offsetting commodity contracts	3	6
Associated offsetting cash collateral	13	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(53)	(72)
Associated offsetting commodity contracts	2	2
Associated offsetting cash collateral	2	2
Southern California Gas Company [Member] | Current assets: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	6	4
Additional cash collateral for commodity contracts subject to rate recovery	3	5
Total	9	9
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 subject to rate recovery	0	0
Total	0	0
Southern California Gas Company [Member] | Current liabilities: Other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	(4)	(5)
Additional cash collateral for commodity contracts subject to rate recovery	0	0
Total	(4)	(5)
Southern California Gas Company [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Net amounts presented on the balance sheet	0	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: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	8	4
Associated offsetting commodity contracts	(2)
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Sundry [Member]
Derivatives not designated as hedging instruments:
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: Other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	(6)	(5)
Associated offsetting commodity contracts	2
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivatives not designated as hedging instruments:
Commodity contracts subject to rate recovery	0	$ 0
Associated offsetting commodity contracts	$ 0

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE IMPACT ON INCOME (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings			$ 12	$ 44
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	$ (68)	$ 31	(250)	173
Pretax (loss) gain reclassified from AOCI into earnings	(8)	8	(16)	5
Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(7)	16	(25)	57
Pretax (loss) gain reclassified from AOCI into earnings	(1)	0	(2)	1
Designated as Hedging Instrument [Member] | Other (Expense) Income, Net [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Pretax (loss) gain reclassified from AOCI into earnings	(5)	11	0	11
Designated as Hedging Instrument [Member] | Gain (Loss) On Sale Of Assets [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI			0	0
Pretax (loss) gain reclassified from AOCI into earnings			(10)	0
Designated as Hedging Instrument [Member] | Equity Earnings [Member] | Cash Flow Hedging [Member] | Interest rate and foreign exchange instruments [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	(62)	20	(222)	123
Pretax (loss) gain reclassified from AOCI into earnings	(2)	(3)	(3)	(8)
Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Cash Flow Hedging [Member] | Foreign Exchange Instruments [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	1	(5)	(3)	(7)
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(1)	1
Not Designated as Hedging Instrument [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(5)	97	8	104
Not Designated as Hedging Instrument [Member] | Other (Expense) Income, Net [Member] | Foreign Exchange Instruments [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(12)	28	7	35
Not Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Commodity Contracts not subject to rate recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(8)	9	9	0
Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	18	62	(7)	70
Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity Contracts Subject To Rate Recovery [Member]
Derivative [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	(3)	(2)	(1)	(1)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	0	0	(1)	1
Pretax (loss) gain reclassified from AOCI into earnings	(1)	(2)	(3)	(6)
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 [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	18	62	(7)	70
Southern California Gas Company [Member] | Designated as Hedging Instrument [Member] | Interest Expense [Member] | Cash Flow Hedging [Member] | Interest Rate Contract [Member]
Derivative [Line Items]
Pretax (loss) gain recognized in OCI	0	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	(1)	0	(1)	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 [Line Items]
Pretax (loss) gain on derivatives recognized in earnings	$ (3)	$ (2)	$ (1)	$ (1)

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (12)
Term of interest rate cash flow hedge	13 years
Southern California Gas Company [Member]
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified	$ (1)
Equity Method Investee [Member]
Derivative [Line Items]
Term of interest rate cash flow hedge	15 years

DERIVATIVE FINANCIAL INSTRUME_8

DERIVATIVE FINANCIAL INSTRUMENTS - DERIVATIVE INSTRUMENTS WITH CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Derivative [Line Items]
Derivative fair value	$ 7	$ 16
Collateral	8
Southern California Gas Company [Member]
Derivative [Line Items]
Derivative fair value	4	$ 5
Collateral	$ 4

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($)	Sep. 30, 2019	Dec. 31, 2018
Fair Value Measured at Net Asset Value Per Share [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investments at NAV	$ 6,000,000
Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	470,000,000	$ 411,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	51,000,000	53,000,000
Nuclear decommissioning trusts - Municipal bonds	291,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	236,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	578,000,000	556,000,000
Total nuclear decommissioning trusts	1,048,000,000	967,000,000
Total Assets Measured at Fair Value	1,364,000,000	1,334,000,000
Total Liabilities Measured at Fair Value	266,000,000	288,000,000
Recurring [Member] | Interest rate and foreign exchange instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	9,000,000	2,000,000
Derivative liabilities	169,000,000	150,000,000
Recurring [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	12,000,000	24,000,000
Effect of netting and allocation of collateral	18,000,000	19,000,000
Derivative liabilities	18,000,000	34,000,000
Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	260,000,000	289,000,000
Effect of netting and allocation of collateral	17,000,000	33,000,000
Derivative liabilities	94,000,000	106,000,000
Effect of netting and allocation of collateral	(15,000,000)	(2,000,000)
Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	465,000,000	407,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	39,000,000	43,000,000
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	39,000,000	43,000,000
Total nuclear decommissioning trusts	504,000,000	450,000,000
Total Assets Measured at Fair Value	534,000,000	499,000,000
Total Liabilities Measured at Fair Value	0	0
Recurring [Member] | 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
Recurring [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
Effect of netting and allocation of collateral	18,000,000	19,000,000
Derivative liabilities	0	0
Recurring [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	1,000,000	2,000,000
Effect of netting and allocation of collateral	11,000,000	28,000,000
Derivative liabilities	15,000,000	2,000,000
Effect of netting and allocation of collateral	(15,000,000)	(2,000,000)
Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	5,000,000	4,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	12,000,000	10,000,000
Nuclear decommissioning trusts - Municipal bonds	291,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	236,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	539,000,000	513,000,000
Total nuclear decommissioning trusts	544,000,000	517,000,000
Total Assets Measured at Fair Value	571,000,000	552,000,000
Total Liabilities Measured at Fair Value	192,000,000	189,000,000
Recurring [Member] | 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	9,000,000	2,000,000
Derivative liabilities	169,000,000	150,000,000
Recurring [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	12,000,000	24,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	18,000,000	34,000,000
Recurring [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	6,000,000	9,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	5,000,000	5,000,000
Effect of netting and allocation of collateral	0	0
Recurring [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 Assets Measured at Fair Value	259,000,000	283,000,000
Total Liabilities Measured at Fair Value	74,000,000	99,000,000
Recurring [Member] | 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
Recurring [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
Effect of netting and allocation of collateral	0	0
Derivative liabilities	0	0
Recurring [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	253,000,000	278,000,000
Effect of netting and allocation of collateral	6,000,000	5,000,000
Derivative liabilities	74,000,000	99,000,000
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	470,000,000	411,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	51,000,000	53,000,000
Nuclear decommissioning trusts - Municipal bonds	291,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	236,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	578,000,000	556,000,000
Total nuclear decommissioning trusts	1,048,000,000	967,000,000
Total Assets Measured at Fair Value	1,316,000,000	1,280,000,000
Total Liabilities Measured at Fair Value	75,000,000	100,000,000
San Diego Gas and Electric Company [Member] | Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	254,000,000	285,000,000
Effect of netting and allocation of collateral	14,000,000	28,000,000
Derivative liabilities	90,000,000	101,000,000
Effect of netting and allocation of collateral	(15,000,000)	(2,000,000)
San Diego Gas and Electric Company [Member] | Recurring [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		1,000,000
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	465,000,000	407,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	39,000,000	43,000,000
Nuclear decommissioning trusts - Municipal bonds	0	0
Nuclear decommissioning trusts - Other securities	0	0
Nuclear decommissioning trusts - Total debt securities	39,000,000	43,000,000
Total nuclear decommissioning trusts	504,000,000	450,000,000
Total Assets Measured at Fair Value	512,000,000	474,000,000
Total Liabilities Measured at Fair Value	0	0
San Diego Gas and Electric Company [Member] | Recurring [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	1,000,000
Effect of netting and allocation of collateral	8,000,000	23,000,000
Derivative liabilities	15,000,000	2,000,000
Effect of netting and allocation of collateral	(15,000,000)	(2,000,000)
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 1 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	5,000,000	4,000,000
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	12,000,000	10,000,000
Nuclear decommissioning trusts - Municipal bonds	291,000,000	269,000,000
Nuclear decommissioning trusts - Other securities	236,000,000	234,000,000
Nuclear decommissioning trusts - Total debt securities	539,000,000	513,000,000
Total nuclear decommissioning trusts	544,000,000	517,000,000
Total Assets Measured at Fair Value	545,000,000	523,000,000
Total Liabilities Measured at Fair Value	1,000,000	1,000,000
San Diego Gas and Electric Company [Member] | Recurring [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	6,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	1,000,000	0
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 2 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		1,000,000
San Diego Gas and Electric Company [Member] | Recurring [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 Assets Measured at Fair Value	259,000,000	283,000,000
Total Liabilities Measured at Fair Value	74,000,000	99,000,000
San Diego Gas and Electric Company [Member] | Recurring [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	253,000,000	278,000,000
Effect of netting and allocation of collateral	6,000,000	5,000,000
Derivative liabilities	74,000,000	99,000,000
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Recurring [Member] | Level 3 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liabilities		0
Southern California Gas Company [Member] | Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	9,000,000	9,000,000
Total Liabilities Measured at Fair Value	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets	6,000,000	4,000,000
Effect of netting and allocation of collateral	3,000,000	5,000,000
Derivative liabilities	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	4,000,000	6,000,000
Total Liabilities Measured at Fair Value	0	0
Southern California Gas Company [Member] | Recurring [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	1,000,000	1,000,000
Effect of netting and allocation of collateral	3,000,000	5,000,000
Derivative liabilities	0	0
Southern California Gas Company [Member] | Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	5,000,000	3,000,000
Total Liabilities Measured at Fair Value	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [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	5,000,000	3,000,000
Effect of netting and allocation of collateral	0	0
Derivative liabilities	4,000,000	5,000,000
Southern California Gas Company [Member] | Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Assets Measured at Fair Value	0	0
Total Liabilities Measured at Fair Value	0	0
Southern California Gas Company [Member] | Recurring [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
Effect of netting and allocation of collateral	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		12 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at July 1	$ 176,000,000	$ (31,000,000)	$ 179,000,000	$ (28,000,000)	$ 179,000,000	$ (28,000,000)
Realized and unrealized (losses) gains	(24,000,000)	6,000,000	(32,000,000)	21,000,000
Allocated transmission instruments			0	3,000,000
Settlements	27,000,000	13,000,000	32,000,000	(8,000,000)
Balance at September 30	179,000,000	(12,000,000)	179,000,000	(12,000,000)		179,000,000
Change in unrealized gains (losses) relating to instruments still held at the end of the period	$ 1,000,000	$ 6,000,000	$ 12,000,000	$ 0
San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH)						(7.25)
San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH)						11.99
San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH)						0.09
Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH)					(8.57)
Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH)					35.21
Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH)					(2.94)
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs ( in dollars per MWH)						20.40
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs ( in dollars per MWH)						57.70
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs ( in dollars per MWH)						$ 38.87
Level 3 [Member] | Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs ( in dollars per MWH)					21.60
Level 3 [Member] | Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs ( in dollars per MWH)					57.20
Level 3 [Member] | Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs ( in dollars per MWH)					$ 38.29

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Sep. 30, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	$ 221	$ 206
Finance lease obligations	1,285
Build-to-suit and capital lease obligations		1,413
Level 3 [Member] | Otay Mesa VIE [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt		220
Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	712	644
Long-term amounts due to unconsolidated affiliate	39	37
Total long-term debt	21,554	21,340
Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	735	652
Long-term amounts due to unconsolidated affiliate	38	35
Total long-term debt	23,168	20,863
Fair value [Member] | Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	0	0
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	0	0
Fair value [Member] | Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	735	648
Long-term amounts due to unconsolidated affiliate	38	35
Total long-term debt	23,142	20,616
Fair value [Member] | Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	0	4
Long-term amounts due to unconsolidated affiliate	0	0
Total long-term debt	26	247
San Diego Gas and Electric Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	49	49
Finance lease obligations	1,270
Capital lease obligations		1,272
San Diego Gas and Electric Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,141	4,996
San Diego Gas and Electric Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,780	5,117
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	5,780	4,897
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	0	220
Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	35	32
Finance lease obligations	15
Capital lease obligations		3
Southern California Gas Company [Member] | Carrying amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	3,809	3,459
Southern California Gas Company [Member] | Fair value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,290	3,505
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
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	4,290	3,505
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

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Jan. 31, 2019
Jointly Owned Utility Plant Interests [Line Items]
Anticipated term of dismantlement work	10 years
San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Percent of dismantlement work expense	20.00%
Nuclear decommissioning trust authorized withdrawal amount	$ 455	$ 93
ARO related to decommissioning costs	614
Cost study estimate decommissioning escalated	$ 834
Jointly Owned Nuclear Power Plant [Member] | San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, proportionate ownership share	20.00%

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Cost	$ 728		$ 728		$ 731
Gross unrealized gains	331		331		259
Gross unrealized losses	(10)		(10)		(16)
Estimated fair value	1,049		1,049		974
Proceeds from sales	231	$ 216	728	$ 703
Gross realized gains	5	3	18	32
Gross realized losses	(1)	$ (1)	(4)	$ (6)
Total debt securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	557		557		556
Gross unrealized gains	22		22		6
Gross unrealized losses	(1)		(1)		(6)
Estimated fair value	578		578		556
U.S. government corporations and agencies [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	51		51		52
Gross unrealized gains	0		0		1
Gross unrealized losses	0		0		0
Estimated fair value	51		51		53
Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	278		278		266
Gross unrealized gains	13		13		4
Gross unrealized losses	0		0		(1)
Estimated fair value	291		291		269
Other securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	228		228		238
Gross unrealized gains	9		9		1
Gross unrealized losses	(1)		(1)		(5)
Estimated fair value	236		236		234
Equity securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	170		170		168
Gross unrealized gains	309		309		253
Gross unrealized losses	(9)		(9)		(10)
Estimated fair value	470		470		411
Cash and cash equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	1		1		7
Gross unrealized gains	0		0		0
Gross unrealized losses	0		0		0
Estimated fair value	$ 1		$ 1		$ 7

SAN ONOFRE NUCLEAR GENERATING_5

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	Sep. 30, 2019USD ($)
Schedule Of Nuclear Insurance [Line Items]
Maximum nuclear liability insurance coverage	$ 450
Maximum secondary financial protection	110
Maximum nuclear liability loss coverage per incident	560
Nuclear property damage insurance	1,500
Spent nuclear fuel storage insurance	500
Federal nuclear property damage insurance, minimum required	1,060
Maximum premium assessment under nuclear property damage insurance	10.4
Maximum nuclear property insurance terrorism coverage	$ 3,240

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details)	Oct. 28, 2019plaintifflawsuit	Aug. 31, 2018USD ($)	Jan. 31, 2017lawsuit	Feb. 29, 2016USD ($)	Sep. 30, 2019USD ($)Bcflawsuit	Sep. 30, 2017USD ($)	Jan. 31, 2019plaintiff	Sep. 30, 2019USD ($)Bcf	Dec. 31, 2018USD ($)	[1]
Loss Contingencies [Line Items]
Liability for legal proceedings					$ 97,000,000			$ 97,000,000
Reserve for Aliso Canyon costs					$ 45,000,000			45,000,000	$ 160,000,000
Consolidated Class Action Complaints [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit			2
Property Class Action [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit			1
Complaints Filed by Public Entities [Member]
Loss Contingencies [Line Items]
Number of lawsuits filed | lawsuit					3
Southern California Gas Company [Member]
Loss Contingencies [Line Items]
Liability for legal proceedings					$ 50,000,000			50,000,000
Insurance settlements receivable					1,069,000,000			1,069,000,000
Reserve for Aliso Canyon costs					45,000,000			45,000,000	$ 160,000,000
Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Liability for legal proceedings					49,000,000			49,000,000
Loss contingency accrual					$ 1,099,000,000			$ 1,099,000,000
Percent of loss accrual allocated to temporary relocation program					52.00%			52.00%
Receivable related to natural gas leak					$ 354,000,000			$ 354,000,000
Reserve for Aliso Canyon costs					45,000,000			45,000,000
Payable related to natural gas leak, noncurrent					$ 9,000,000			9,000,000
Insurance proceeds								$ 715,000,000
Storage facility capacity | Bcf					86			86
Proportion of total gas storage capacity (percentage)					63.00%			63.00%
Working gas target | Bcf					34			34
Net book value of Aliso Canyon facility					$ 771,000,000			$ 771,000,000
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
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
Southern California Gas Company [Member] | Damages from Product Defects [Member]
Loss Contingencies [Line Items]
Maximum occupational safety and health fines				$ 75,000
Penalty assessments				233,500
Maximum other assessments in settlement of criminal complaint				$ 6,000,000
Southern California Gas Company [Member] | Complaints Filed by Firefighters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff							51
Southern California Gas Company [Member] | Complaints Filed by Public Entities [Member] | Funding for Environmental Projects [Member]
Loss Contingencies [Line Items]
Settlement amount payable		$ 120,000,000
Southern California Gas Company [Member] | Complaints Filed by Public Entities [Member] | Civil Penalties [Member]
Loss Contingencies [Line Items]
Settlement amount payable		$ 21,000,000
San Diego Gas and Electric Company [Member] | Wildfire [Member]
Loss Contingencies [Line Items]
Write-off of wildfire regulatory asset						$ 351,000,000
After-tax charge for nonrecovery of CPUC regulatory assets						$ 208,000,000
Sempra Energy [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Reserve for Aliso Canyon costs					45,000,000			45,000,000
Payable related to natural gas leak, noncurrent					$ 9,000,000			$ 9,000,000
IMG [Member] | Corporate Joint Venture [Member] | Sempra Mexico [Member]
Loss Contingencies [Line Items]
Interest percentage					40.00%			40.00%
Service agreement term								25 years
Subsequent Event [Member] | Southern California Gas Company [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit	390
Number of plaintiffs | plaintiff	36,000
Subsequent Event [Member] | Energy Future Holdings Corp. [Member]
Loss Contingencies [Line Items]
Number of lawsuits | lawsuit	103
Number of lawsuits filed | lawsuit	1,608
[1]	Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - OTHER LITIGATION (Details) proof_of_claim in Thousands, £ in Millions, $ in Millions	Oct. 28, 2019lawsuit	Sep. 30, 2019USD ($)proof_of_claim	Sep. 30, 2019GBP (£)proof_of_claim	Sep. 30, 2018USD ($)	Oct. 01, 2014USD ($)	Oct. 01, 2014GBP (£)
R B S Sempra Commodities [Member]
Loss Contingencies [Line Items]
Investment in RBS Sempra Commodities LLP | $				$ 65
R B S Sempra Commodities [Member] | HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT tax claim paid upon appeal					$ 138	£ 86
Plaintiffs [Member] | HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
Filed claims amount		$ 88	£ 71.5
Energy Future Holdings Corp. [Member]
Loss Contingencies [Line Items]
Number of proof of claims | proof_of_claim		28	28
Energy Future Holdings Corp. [Member] | Subsequent Event [Member]
Loss Contingencies [Line Items]
Number of lawsuits	103
Number of lawsuits filed	1,608

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - LEASES (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)facility
Lessee, Lease, Description [Line Items]
Lease term	12 months
Number of battery storage facilities | facility	3
Leases not yet commenced, future minimum lease payments, 2020 - 2024	$ 1
Leases not yet commenced, future minimum lease payments, thereafter	18
Aggregate maximum lease limit	180
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Aggregate maximum lease limit, utilized	53
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Aggregate maximum lease limit, utilized	$ 74
Maximum [Member]
Lessee, Lease, Description [Line Items]
Option to extend terms	25 years
Annual increase in rent	5.00%
Minimum [Member]
Lessee, Lease, Description [Line Items]
Termination period	1 year
Annual increase in rent	2.00%

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - LESSEE BALANCE SHEET INFORMATION (Details) $ in Millions	Sep. 30, 2019USD ($)
Operating leases:
Operating Lease, Right-of-Use Asset	$ 595
Finance leases:
Property, plant and equipment	1,342
Accumulated depreciation	(57)
Property, plant and equipment, net	1,285
Total right-of-use assets	1,880
Operating leases:
Other current liabilities	47
Long-term lease liabilities	447
Total operating lease liabilities	494
Finance Lease, Finance Leases [Abstract]
Current portion of long-term debt and finance leases	24
Long-term debt and finance leases	1,261
Total finance lease liabilities	1,285
Total lease liabilities	$ 1,779
Weighted-average remaining lease term (in years):
Operating leases, Weighted-average remaining lease term (in years)	14 years
Finance leases, Weighted-average remaining lease term (in years)	20 years
Weighted-average discount rate:
Operating leases, Weighted-average discount rate	6.02%
Finance leases, Weighted-average discount rate	14.81%
San Diego Gas and Electric Company [Member]
Operating leases:
Operating Lease, Right-of-Use Asset	$ 126
Finance leases:
Property, plant and equipment	1,322
Accumulated depreciation	(52)
Property, plant and equipment, net	1,270
Total right-of-use assets	1,396
Operating leases:
Other current liabilities	22
Long-term lease liabilities	102
Total operating lease liabilities	124
Finance Lease, Finance Leases [Abstract]
Current portion of long-term debt and finance leases	19
Long-term debt and finance leases	1,251
Total finance lease liabilities	1,270
Total lease liabilities	$ 1,394
Weighted-average remaining lease term (in years):
Operating leases, Weighted-average remaining lease term (in years)	7 years
Finance leases, Weighted-average remaining lease term (in years)	20 years
Weighted-average discount rate:
Operating leases, Weighted-average discount rate	3.69%
Finance leases, Weighted-average discount rate	14.86%
Southern California Gas Company [Member]
Operating leases:
Operating Lease, Right-of-Use Asset	$ 99
Finance leases:
Property, plant and equipment	20
Accumulated depreciation	(5)
Property, plant and equipment, net	15
Total right-of-use assets	114
Operating leases:
Other current liabilities	19
Long-term lease liabilities	79
Total operating lease liabilities	98
Finance Lease, Finance Leases [Abstract]
Current portion of long-term debt and finance leases	5
Long-term debt and finance leases	10
Total finance lease liabilities	15
Total lease liabilities	$ 113
Weighted-average remaining lease term (in years):
Operating leases, Weighted-average remaining lease term (in years)	6 years
Finance leases, Weighted-average remaining lease term (in years)	6 years
Weighted-average discount rate:
Operating leases, Weighted-average discount rate	3.75%
Finance leases, Weighted-average discount rate	3.41%

COMMITMENTS AND CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - LESSEE STATEMENT OF OPERATIONS INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 23	$ 72
Finance lease costs:
Amortization of ROU assets	6	17
Interest on lease liabilities	47	141
Total finance lease costs	53	158
Short-term lease costs	3	5
Variable lease costs	156	396
Total lease costs	235	631
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	7	21
Finance lease costs:
Amortization of ROU assets	2	4
Interest on lease liabilities	0	0
Total finance lease costs	2	4
Short-term lease costs	0	0
Variable lease costs	1	7
Total lease costs	10	32
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	8	25
Finance lease costs:
Amortization of ROU assets	4	13
Interest on lease liabilities	47	141
Total finance lease costs	51	154
Short-term lease costs	1	1
Variable lease costs	155	389
Total lease costs	$ 215	$ 569

COMMITMENTS AND CONTINGENCIES_6

COMMITMENTS AND CONTINGENCIES - LESSEE CASH FLOW INFORMATION (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Operating activities:
Cash paid for operating leases	$ 81
Cash paid for finance leases - operating	130
Financing activities:
Cash paid for finance leases - financing	17
Increase in operating lease obligations for right-of-use assets	571
Increase in finance lease obligations for investment in PP&E	27	$ 7
Southern California Gas Company [Member]
Operating activities:
Cash paid for operating leases	21
Cash paid for finance leases - operating	0
Financing activities:
Cash paid for finance leases - financing	4
Increase in operating lease obligations for right-of-use assets	117
Increase in finance lease obligations for investment in PP&E	15	7
San Diego Gas and Electric Company [Member]
Operating activities:
Cash paid for operating leases	25
Cash paid for finance leases - operating	130
Financing activities:
Cash paid for finance leases - financing	13
Increase in operating lease obligations for right-of-use assets	147
Increase in finance lease obligations for investment in PP&E	$ 12	$ 0

COMMITMENTS AND CONTINGENCIES_7

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY OF LEASE LIABILITIES (Details) $ in Millions	Sep. 30, 2019USD ($)
Operating leases
2019 (excluding first nine months of 2019)	$ 17
2020	72
2021	69
2022	62
2023	53
Thereafter	494
Total undiscounted lease payments	767
Less: imputed interest	(273)
Total operating lease liabilities	494
Less: current lease liabilities	(47)
Long-term lease liabilities	447
Finance leases
2019 (excluding first nine months of 2019)	50
2020	195
2021	192
2022	191
2023	191
Thereafter	2,811
Total undiscounted lease payments	3,630
Less: imputed interest	(2,345)
Total finance lease liabilities	1,285
Less: current lease liabilities	(24)
Long-term lease liabilities	1,261
Southern California Gas Company [Member]
Operating leases
2019 (excluding first nine months of 2019)	6
2020	23
2021	20
2022	17
2023	13
Thereafter	30
Total undiscounted lease payments	109
Less: imputed interest	(11)
Total operating lease liabilities	98
Less: current lease liabilities	(19)
Long-term lease liabilities	79
Finance leases
2019 (excluding first nine months of 2019)	2
2020	4
2021	2
2022	2
2023	2
Thereafter	4
Total undiscounted lease payments	16
Less: imputed interest	(1)
Total finance lease liabilities	15
Less: current lease liabilities	(5)
Long-term lease liabilities	10
San Diego Gas and Electric Company [Member]
Operating leases
2019 (excluding first nine months of 2019)	7
2020	26
2021	26
2022	22
2023	17
Thereafter	43
Total undiscounted lease payments	141
Less: imputed interest	(17)
Total operating lease liabilities	124
Less: current lease liabilities	(22)
Long-term lease liabilities	102
Finance leases
2019 (excluding first nine months of 2019)	48
2020	191
2021	190
2022	189
2023	189
Thereafter	2,807
Total undiscounted lease payments	3,614
Less: imputed interest	(2,344)
Total finance lease liabilities	1,270
Less: current lease liabilities	(19)
Long-term lease liabilities	$ 1,251

COMMITMENTS AND CONTINGENCIES_8

COMMITMENTS AND CONTINGENCIES - FUTURE MINIMUM LEASE PAYMENTS UNDER TOPIC 840 (Details) $ in Millions	Dec. 31, 2018USD ($)
Capital Leases [Abstract]
2019	$ 215
2020	210
2021	211
2022	211
2023	211
Thereafter	3,196
Total undiscounted lease payments	4,254
Less: estimated executory costs	(480)
Less: imputed interest	(2,483)
Total future minimum lease payments	1,291
Leases, Operating [Abstract]
2019	77
2020	55
2021	53
2022	50
2023	42
Thereafter	253
Total undiscounted lease payments	530
HQ Build To Suit Lease [Member]
Capital Leases [Abstract]
2019	10
2020	11
2021	11
2022	11
2023	11
Thereafter	217
Total undiscounted lease payments	271
San Diego Gas and Electric Company [Member]
Capital Leases [Abstract]
2019	212
2020	210
2021	211
2022	211
2023	211
Thereafter	3,196
Total undiscounted lease payments	4,251
Less: estimated executory costs	(480)
Less: imputed interest	(2,483)
Total future minimum lease payments	1,288
Leases, Operating [Abstract]
2019	23
2020	22
2021	22
2022	21
2023	17
Thereafter	48
Total undiscounted lease payments	153
Southern California Gas Company [Member]
Capital Leases [Abstract]
2019	3
2020	0
2021	0
2022	0
2023	0
Thereafter	0
Total undiscounted lease payments	3
Less: estimated executory costs	0
Less: imputed interest	0
Total future minimum lease payments	3
Leases, Operating [Abstract]
2019	26
2020	22
2021	21
2022	20
2023	16
Thereafter	28
Total undiscounted lease payments	$ 133

COMMITMENTS AND CONTINGENCIES_9

COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	[1]
Lessee, Lease, Description [Line Items]
Property, plant and equipment	$ 48,139		$ 48,139		$ 46,615
Accumulated depreciation	(12,619)		(12,619)		(12,176)
Property, plant and equipment, net	35,520		35,520		$ 34,439
Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]
2019 (excluding first nine months of 2019)	50		50
2020	199		199
2021	199		199
2022	199		199
2023	199		199
Thereafter	2,588		2,588
Total undiscounted cash flows	3,434		3,434
Minimum lease payments	51	$ 47	150	$ 143
Variable lease payments	0	26	6	63
Total revenues from operating leases	51	73	156	206
Assets Leased to Others [Member]
Lessee, Lease, Description [Line Items]
Property, plant and equipment	1,112		1,112
Accumulated depreciation	(181)		(181)
Property, plant and equipment, net	931		931
Lessor, Operating Lease, Payments, Fiscal Year Maturity [Abstract]
Depreciation	$ 10	$ 19	$ 29	$ 55
[1]	Derived from audited financial statements.

COMMITMENTS AND CONTINGENCIE_10

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) $ in Millions	9 Months Ended
	Sep. 30, 2019USD ($)
Sempra LNG [Member] | Liquefied Natural Gas Contracts [Member]
Loss Contingencies [Line Items]
Change in 2019	$ (281)
Change in 2020	(9)
Change in 2021	(16)
Change in 2022	(8)
Change in 2023	(1)
Change thereafter	(24)
San Diego Gas and Electric Company [Member] | Purchased-Power Contracts [Member]
Loss Contingencies [Line Items]
Change in 2019	13
Change in 2020	45
Change in 2021	52
Change in 2022	69
Change in 2023	74
Change thereafter	119
Increase purchase-power contracts	372
OMEC LLC [Member] | San Diego Gas and Electric Company [Member] | Purchased-Power Contracts [Member]
Loss Contingencies [Line Items]
Increase purchase-power contracts	$ 262

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)segment	Mar. 31, 2019segment	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)segment	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	May 16, 2019	Dec. 31, 2018USD ($)		Mar. 09, 2018
Segment Reporting Information [Line Items]
Number of reportable segments | segment	5	6		5
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 2,758		$ 2,565		$ 7,886	$ 7,276
INTEREST EXPENSE	279		222		797	656
INTEREST INCOME	22		19		64	66
DEPRECIATION AND AMORTIZATION	402		366		1,174	1,115
Income tax expense (benefit) from continuing operations	61		139		150	(221)
Equity earnings (losses), before income tax:	17		(52)		24	(236)
Equity earnings (losses), net of income tax:	249		126		461	285
Equity earnings	266		74		485	49
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	813		274		1,608	60
Discontinued operations	248		46		267	115
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					2,590	2,654
ASSETS	64,585			$ 64,585	64,585			$ 60,638	[1]
EQUITY METHOD AND OTHER INVESTMENTS	13,221			13,221	13,221			11,972
Operating Segments [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,427		1,299		3,666	3,405
INTEREST EXPENSE	106		56		311	161
INTEREST INCOME	1		1		3	3
DEPRECIATION AND AMORTIZATION	196		174		571	509
Income tax expense (benefit) from continuing operations	71		53		111	151
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	263		205		582	521
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					1,071	1,194
ASSETS	20,336			20,336	20,336			19,225
Operating Segments [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	975		802		3,142	2,700
INTEREST EXPENSE	36		29		104	82
INTEREST INCOME	0		0		1	1
DEPRECIATION AND AMORTIZATION	154		141		449	414
Income tax expense (benefit) from continuing operations	35		(7)		50	75
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	143		(14)		437	244
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					1,019	1,127
ASSETS	16,023			16,023	16,023			15,389
Operating Segments [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Equity earnings (losses), before income tax:	0		0		1	0
Equity earnings (losses), net of income tax:	212		154		418	283
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	212		154		419	283
Segment Reporting Information, Additional Information [Abstract]
ASSETS	11,248			11,248	11,248			9,652
EQUITY METHOD AND OTHER INVESTMENTS	11,248			11,248	11,248			9,652
Operating Segments [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	357		410		1,058	1,028
INTEREST EXPENSE	30		30		89	90
INTEREST INCOME	20		17		58	48
DEPRECIATION AND AMORTIZATION	46		45		136	131
Income tax expense (benefit) from continuing operations	0		126		116	226
Equity earnings (losses), net of income tax:	37		(28)		43	2
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	84		44		214	161
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					420	255
ASSETS	9,759			9,759	9,759			9,165
EQUITY METHOD AND OTHER INVESTMENTS	750			750	750			747
Operating Segments [Member] | Sempra Renewables [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	0		38		10	103
INTEREST EXPENSE	0		5		3	15
INTEREST INCOME	0		2		11	6
DEPRECIATION AND AMORTIZATION	0		0		0	27
Income tax expense (benefit) from continuing operations	0		(2)		4	(67)
Equity earnings (losses), before income tax:	0		12		5	(170)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	0		34		59	(54)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					2	46
ASSETS	0			0	0			2,549
EQUITY METHOD AND OTHER INVESTMENTS	0			0	0			291
Operating Segments [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	100		147		327	330
INTEREST EXPENSE	11		3		18	18
INTEREST INCOME	15		10		45	36
DEPRECIATION AND AMORTIZATION	2		2		7	24
Income tax expense (benefit) from continuing operations	(2)		6		4	(488)
Equity earnings (losses), before income tax:	17		0		19	1
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	2		16		13	(764)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					74	19
ASSETS	3,755			3,755	3,755			4,060
EQUITY METHOD AND OTHER INVESTMENTS	1,216			1,216	1,216			1,271
Corporate, Non-Segment [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1		0		1	0
INTEREST EXPENSE	117		122		336	371
INTEREST INCOME	1		1		2	14
DEPRECIATION AND AMORTIZATION	4		4		11	10
Income tax expense (benefit) from continuing operations	(43)		(37)		(135)	(118)
Equity earnings (losses), before income tax:	0		(64)		(1)	(67)
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES	(139)		(211)		(383)	(446)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT					4	13
ASSETS	1,585			1,585	1,585			1,070
EQUITY METHOD AND OTHER INVESTMENTS	7			7	7			11
Segment Reconciling Items [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(2)		0		(3)	(2)
Discontinued operations	248		46		267	115
Segment Reporting Information, Additional Information [Abstract]
Discontinued operations	4,115			4,115	4,115			3,718
Intersegment eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(100)		(131)		(315)	(288)
INTEREST EXPENSE	(21)		(23)		(64)	(81)
INTEREST INCOME	(15)		(12)		(56)	(42)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(2,236)			$ (2,236)	(2,236)			$ (4,190)
Intersegment eliminations [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1		1		4	3
Intersegment eliminations [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	16		15		50	47
Intersegment eliminations [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	29		31		89	88
Intersegment eliminations [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 54		$ 84		$ 172	$ 150
Oncor Electric Delivery Company LLC. [Member]
Segment Reporting Information [Line Items]
Acquired percentage interest										80.25%
Oncor Electric Delivery Company LLC. [Member] | Oncor Holdings [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information [Line Items]
Ownership interest	80.25%			80.25%	80.25%
Sharyland Holdings, LP [Member]
Segment Reporting Information [Line Items]
Acquired percentage interest							50.00%
Sharyland Holdings, LP [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information [Line Items]
Acquired percentage interest							50.00%
[1]	Derived from audited financial statements.