Southern California Gas Company PFD 6% (SOCGM) 10-K 27 Feb 20 2019 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Dec. 31, 2019	Feb. 21, 2020	Jun. 30, 2019
Document And Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 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 Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
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 Public Float			$ 37,700,000,000
Entity Common Stock, Shares Outstanding		292,276,007
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE: Portions of the Sempra Energy Proxy Statement to be filed for its May 2020 annual meeting of shareholders are incorporated by reference into Part III of this annual report on Form 10-K. Portions of the Southern California Gas Company Information Statement to be filed for its May 2020 annual meeting of shareholders are incorporated by reference into Part III of this annual report on Form 10-K.
Entity Central Index Key	0001032208
Amendment Flag	false
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
San Diego Gas and Electric Company [Member]
Document And Entity 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 Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			0
Entity Central Index Key	0000086521
Southern California Gas Company [Member]
Document And Entity 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 Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Public Float			$ 0
Entity Central Index Key	0000092108
Common Stock [Member]
Document And Entity Information [Line Items]
Title of 12(b) Security	Common Stock, without par value
Trading Symbol	SRE
Security Exchange Name	NYSE
Convertible Preferred Stock Series A [Member]
Document And Entity Information [Line Items]
Title of 12(b) Security	6% Mandatory Convertible Preferred Stock, Series A, $100 liquidation preference
Trading Symbol	SREPRA
Security Exchange Name	NYSE
Convertible Preferred Stock Series B [Member]
Document And Entity Information [Line Items]
Title of 12(b) Security	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 And Entity Information [Line Items]
Title of 12(b) Security	5.75% Junior Subordinated Notes Due 2079, $25 par value
Trading Symbol	SREA
Security Exchange Name	NYSE
Preferred Stock [Member] | Southern California Gas Company [Member]
Document And Entity Information [Line Items]
Title of 12(g) Security	6% Preferred Stock, $25 par value
Preferred Stock Series A [Member] | Southern California Gas Company [Member]
Document And Entity Information [Line Items]
Title of 12(g) Security	6% Preferred Stock, Series A, $25 par value

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Revenues
Energy-related businesses	$ 1,381	$ 1,563	$ 1,350
Utilities	9,448	8,539	8,290
Total revenues	10,829	10,102	9,640
Operating expenses
Operation and maintenance	(3,466)	(3,150)	(2,947)
Depreciation and amortization	(1,569)	(1,491)	(1,436)
Franchise fees and other taxes	(496)	(472)	(436)
Write-off of wildfire regulatory asset	0	0	(351)
Impairment losses	(43)	(1,122)	(72)
Gain on sale of assets	63	513	2
Other Income, net	77	58	220
Operating expenses
Impairment losses	43	1,122	72
Write-off of wildfire regulatory asset	0	0	351
Interest income	87	85	24
Interest expense	(1,077)	(886)	(622)
Income before income taxes	1,734	714	1,248
Income tax (expense) benefit	(315)	49	(938)
Equity earnings	580	175	72
Net of income tax	1,999	938	382
Income (loss) from discontinued operations, net of income tax	363	188	(31)
Net income	2,362	1,126	351
Earnings attributable to noncontrolling interest	(164)	(76)	(94)
Preferred dividends of subsidiary	(1)	(1)	(1)
Mandatory convertible preferred stock dividends	(142)	(125)	0
Earnings attributable to common shares	$ 2,055	$ 924	$ 256
Earnings Per Share, Basic [Abstract]
Earnings from continuing operations attributable to common shares	$ 6.22	$ 2.86	$ 1.25
Earnings (losses) from discontinued operations attributable to common shares	1.18	0.59	(0.23)
Basic earnings per common share (in shares)	$ 7.40	$ 3.45	$ 1.02
Weighted-average number of shares outstanding, basic (in shares)	277,904	268,072	251,545
Earnings Per Share, Diluted [Abstract]
Earnings from continuing operations (in dollars per share)	$ 6.13	$ 2.84	$ 1.24
Earnings (losses) from discontinued operations (in dollars per share)	1.16	0.58	(0.23)
Diluted earnings per common share (in dollars per share)	$ 7.29	$ 3.42	$ 1.01
Weighted-average number of shares outstanding, diluted (in shares)	282,033	269,852	252,300
San Diego Gas and Electric Company [Member]
Revenues
Electric	$ 4,267	$ 4,003	$ 3,935
Natural Gas	658	565	541
Utilities	4,925	4,568	4,476
Operating expenses
Write-off of wildfire regulatory asset	0	0	(351)
Other Income, net	39	56	70
Operating expenses
Cost of electric fuel and purchased power	1,194	1,370	1,293
Cost of natural gas	176	152	164
Operation and maintenance	1,181	1,058	1,024
Depreciation and amortization	760	688	670
Franchise fees and other taxes	301	290	265
Write-off of wildfire regulatory asset	0	0	351
Total operating expenses	3,612	3,558	3,767
Operating income	1,313	1,010	709
Interest income	4	4	0
Interest expense	(411)	(221)	(203)
Income before income taxes	945	849	576
Income tax (expense) benefit	(171)	(173)	(155)
Net income	774	676	421
Earnings attributable to noncontrolling interest	(7)	(7)	(14)
Earnings attributable to common shares	767	669	407
Southern California Gas Company [Member]
Revenues
Utilities	4,525	3,962	3,785
Operating expenses
Impairment losses	(37)	0	0
Other Income, net	(55)	15	31
Operating expenses
Cost of natural gas	977	1,048	1,025
Operation and maintenance	1,780	1,613	1,474
Depreciation and amortization	602	556	515
Franchise fees and other taxes	173	154	144
Impairment losses	37	0	0
Total operating expenses	3,569	3,371	3,158
Operating income	956	591	627
Interest income	2	2	1
Interest expense	(141)	(115)	(102)
Income before income taxes	762	493	557
Income tax (expense) benefit	(120)	(92)	(160)
Net income	642	401	397
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings attributable to common shares	641	400	396
Cost of natural gas [Member]
Operating expenses
Operating expenses	(1,139)	(1,208)	(1,190)
Cost of electric fuel and purchased power [Member]
Operating expenses
Operating expenses	(1,188)	(1,358)	(1,293)
Energy-related businesses cost of sales [Member]
Operating expenses
Operating expenses	$ (344)	$ (357)	$ (291)

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Net income	$ 2,362	$ 1,126	$ 351
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Total other comprehensive (loss) income	(140)	(133)	142
Preferred dividends of subsidiary	(1)	(1)	(1)
Pretax amount [Member]
Net income	2,585	1,146	1,533
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	(161)
Foreign currency translation adjustments	(43)	(144)	107
Financial instruments		64	2
Pension and other postretirement benefits	25	(38)	20
Total other comprehensive (loss) income	(179)	(118)	129
Comprehensive income	2,406	1,028	1,662
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	2,405	1,027	1,661
Income tax (expense) benefit [Member]
Net income	(387)	(96)	(1,276)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	53
Foreign currency translation adjustments	0	0	0
Financial instruments		(21)	1
Pension and other postretirement benefits	(7)	4	(8)
Total other comprehensive (loss) income	46	(17)	(7)
Comprehensive income	(341)	(113)	(1,283)
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	(341)	(113)	(1,283)
Net-of-tax amount [Member]
Net income	2,198	1,050	257
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	(108)
Foreign currency translation adjustments	(43)	(144)	107
Financial instruments		43	3
Pension and other postretirement benefits	18	(34)	12
Total other comprehensive (loss) income	(133)	(135)	122
Comprehensive income	2,065	915	379
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	2,064	914	378
Noncontrolling interests (after-tax) [Member]
Net income	164	76	94
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	(10)
Foreign currency translation adjustments	3	(11)	8
Financial instruments		13	12
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	(7)	2	20
Comprehensive income	157	78	114
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	157	78	114
Total [Member]
Net income	2,362	1,126	351
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	(118)
Foreign currency translation adjustments	(40)	(155)	115
Financial instruments		56	15
Pension and other postretirement benefits	18	(34)	12
Total other comprehensive (loss) income	(140)	(133)	142
Comprehensive income	2,222	993	493
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	2,221	992	492
San Diego Gas and Electric Company [Member]
Net income	774	676	421
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Total other comprehensive (loss) income	(2)	6	11
San Diego Gas and Electric Company [Member] | Pretax amount [Member]
Net income	938	842	562
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	0
Financial instruments		0	0
Pension and other postretirement benefits	(6)	(2)	(1)
Total other comprehensive (loss) income	(6)	(2)	(1)
Comprehensive income	932	840	561
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit [Member]
Net income	(171)	(173)	(155)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	0
Financial instruments		0	0
Pension and other postretirement benefits	2	0	1
Total other comprehensive (loss) income	2	0	1
Comprehensive income	(169)	(173)	(154)
San Diego Gas and Electric Company [Member] | Net-of-tax amount [Member]
Net income	767	669	407
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	0
Financial instruments		0	0
Pension and other postretirement benefits	(4)	(2)	0
Total other comprehensive (loss) income	(4)	(2)	0
Comprehensive income	763	667	407
San Diego Gas and Electric Company [Member] | Noncontrolling interests (after-tax) [Member]
Net income	7	7	14
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	2
Financial instruments		8	11
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	2	8	11
Comprehensive income	9	15	25
San Diego Gas and Electric Company [Member] | Total [Member]
Net income	774	676	421
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	2
Financial instruments		8	11
Pension and other postretirement benefits	(4)	(2)	0
Total other comprehensive (loss) income	(2)	6	11
Comprehensive income	772	682	432
Southern California Gas Company [Member]
Net income	642	401	397
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Total other comprehensive (loss) income	1	1	1
Southern California Gas Company [Member] | Pretax amount [Member]
Net income	762	493	557
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	1
Financial instruments		1
Pension and other postretirement benefits	1		1
Total other comprehensive (loss) income	2	1	1
Comprehensive income	764	494	558
Southern California Gas Company [Member] | Income tax (expense) benefit [Member]
Net income	(120)	(92)	(160)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	0
Financial instruments		0
Pension and other postretirement benefits	(1)		0
Total other comprehensive (loss) income	(1)	0	0
Comprehensive income	(121)	(92)	(160)
Southern California Gas Company [Member] | Net-of-tax amount [Member]
Net income	642	401	397
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments	1
Financial instruments		1
Pension and other postretirement benefits	0		1
Total other comprehensive (loss) income	1	1	1
Comprehensive income	$ 643	$ 402	$ 398

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 108	$ 102
Restricted cash	31	35
Accounts receivable – trade, net	1,261	1,215
Accounts receivable – other, net	455	320
Due from unconsolidated affiliates	32	37
Income taxes receivable	112	60
Inventories	277	258
Regulatory assets	222	138
Greenhouse gas allowances	72	59
Other current assets	324	249
Total current assets	3,339	3,645
Other assets:
Restricted cash	3	21
Due from unconsolidated affiliates	742	644
Regulatory assets	1,930	1,589
Nuclear decommissioning trusts	1,082	974
Investment in Oncor Holdings	11,519	9,652
Other investments	2,103	2,320
Goodwill	1,602	1,602
Other intangible assets	213	224
Dedicated assets in support of certain benefit plans	488	416
Insurance receivable for Aliso Canyon costs	339	461
Deferred income taxes	155	141
Greenhouse gas allowances	470	289
Right-of-use assets – operating leases	591
Prepaid Insurance Fund Asset, Noncurrent	392	0
Assets held for sale in discontinued operations	3,513	3,259
Other long-term assets	732	962
Total other assets	25,874	22,554
Property, plant and equipment:
Property, plant and equipment	49,329	46,615
Less accumulated depreciation and amortization	(12,877)	(12,176)
Property, plant and equipment, net	36,452	34,439
Total assets	65,665	60,638
Liabilities, Current [Abstract]
Short-term debt	3,505	2,024
Accounts payable – trade	1,234	1,160
Accounts payable – other	179	138
Due to unconsolidated affiliates	5	10
Dividends and interest payable	515	480
Accrued compensation and benefits	476	440
Regulatory liabilities	319	105
Current portion of long-term debt and finance leases	1,526	1,644
Reserve for Aliso Canyon costs	9	160
Greenhouse gas obligations	72	59
Liabilities held for sale in discontinued operations	444	368
Other current liabilities	866	935
Total current liabilities	9,150	7,523
Long-term debt and finance leases	20,785	20,903
Deferred Credits and Other Liabilities [Abstract]
Due to unconsolidated affiliates	195	37
Pension and other postretirement benefit plan obligations, net of plan assets	1,067	1,143
Deferred income taxes	2,577	2,321
Deferred investment tax credits	21	24
Regulatory liabilities	3,741	4,016
Asset retirement obligations	2,923	2,786
Greenhouse gas obligations	301	131
Liabilities held for sale in discontinued operations	1,052	1,013
Deferred credits and other	2,048	1,493
Total deferred credits and other liabilities	13,925	12,964
Commitments and contingencies (Note 16)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Common stock	7,480	5,540
Retained earnings	11,130	10,104
Accumulated other comprehensive income (loss)	(939)	(764)
Total shareholders’ equity	19,929	17,138
Preferred stock of subsidiary	20	20
Other noncontrolling interests	1,856	2,090
Total equity	21,805	19,248
Total liabilities and equity	65,665	60,638
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	10	8
Restricted cash	0	11
Accounts receivable – trade, net	398	368
Accounts receivable – other, net	119	106
Income taxes receivable	128	0
Inventories	94	102
Prepaid expenses	120	74
Regulatory assets	209	123
Fixed-price contracts and other derivatives	43	82
Greenhouse gas allowances	13	15
Other current assets	24	5
Total current assets	1,158	894
Other assets:
Restricted cash	0	18
Regulatory assets	440	454
Nuclear decommissioning trusts	1,082	974
Greenhouse gas allowances	189	155
Right-of-use assets – operating leases	130
Prepaid Insurance Fund Asset, Noncurrent	392	0
Other long-term assets	202	420
Total other assets	2,435	2,021
Property, plant and equipment:
Property, plant and equipment	22,504	21,662
Less accumulated depreciation and amortization	(5,537)	(5,352)
Property, plant and equipment, net	16,967	16,310
Total assets	20,560	19,225
Liabilities, Current [Abstract]
Short-term debt	80	291
Accounts payable – trade	496	439
Due to unconsolidated affiliates	53	61
Accrued compensation and benefits	138	117
Regulatory liabilities	76	53
Accrued franchise fees	53	64
Current portion of long-term debt and finance leases	56	81
Contract with Customer, Liability, Current	74	70
Asset retirement obligations	95	96
Greenhouse gas obligations	13	15
Other current liabilities	176	141
Total current liabilities	1,310	1,428
Long-term debt and finance leases	6,306	6,138
Deferred Credits and Other Liabilities [Abstract]
Pension and other postretirement benefit plan obligations, net of plan assets	153	212
Deferred income taxes	1,848	1,616
Deferred investment tax credits	14	16
Regulatory liabilities	2,319	2,404
Asset retirement obligations	771	778
Greenhouse gas obligations	62	30
Deferred credits and other	677	488
Total deferred credits and other liabilities	5,844	5,544
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	0	0
Common stock	1,660	1,338
Retained earnings	5,456	4,687
Accumulated other comprehensive income (loss)	(16)	(10)
Total shareholders’ equity	7,100	6,015
Other noncontrolling interests	0	100
Total equity	7,100	6,115
Total liabilities and equity	20,560	19,225
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	10	18
Accounts receivable – trade, net	710	634
Accounts receivable – other, net	87	97
Due from unconsolidated affiliates	11	7
Income taxes receivable	161	2
Inventories	136	134
Regulatory assets	7	12
Greenhouse gas allowances	52	37
Other current assets	44	29
Total current assets	1,218	970
Other assets:
Regulatory assets	1,407	1,051
Insurance receivable for Aliso Canyon costs	339	461
Greenhouse gas allowances	248	116
Right-of-use assets – operating leases	94
Other long-term assets	447	352
Total other assets	2,535	1,980
Property, plant and equipment:
Property, plant and equipment	19,362	18,138
Less accumulated depreciation and amortization	(6,038)	(5,699)
Property, plant and equipment, net	13,324	12,439
Total assets	17,077	15,389
Liabilities, Current [Abstract]
Short-term debt	630	256
Accounts payable – trade	545	556
Accounts payable – other	110	93
Due to unconsolidated affiliates	47	34
Accrued compensation and benefits	182	159
Regulatory liabilities	243	52
Current portion of long-term debt and finance leases	6	3
Contract with Customer, Liability, Current	71	101
Asset retirement obligations	65	90
Reserve for Aliso Canyon costs	9	160
Greenhouse gas obligations	52	37
Other current liabilities	222	217
Total current liabilities	2,182	1,758
Long-term debt and finance leases	3,788	3,427
Deferred Credits and Other Liabilities [Abstract]
Pension obligation, net of plan assets	785	760
Deferred income taxes	1,403	1,177
Deferred investment tax credits	7	8
Regulatory liabilities	1,422	1,612
Asset retirement obligations	2,112	1,973
Greenhouse gas obligations	208	86
Deferred credits and other	422	330
Total deferred credits and other liabilities	6,359	5,946
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	22	22
Common stock	866	866
Retained earnings	3,883	3,390
Accumulated other comprehensive income (loss)	(23)	(20)
Total shareholders’ equity	4,748	4,258
Total equity	4,748	4,258
Total liabilities and equity	17,077	15,389
Series A Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	1,693	1,693
Series B Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	565	565
Disposal Group, Not Discontinued Operations [Member]
Current assets:
Assets held for sale	0	713
Discontinued Operations, Held-for-sale [Member]
Current assets:
Assets held for sale	$ 445	$ 459

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parentheticals) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Current portion of long-term debt and finance leases	$ 1,526	$ 1,644
Long-term debt, VIE		$ 190
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)	291,712,925	273,769,513
San Diego Gas and Electric Company [Member]
Property, plant and equipment, net related to VIE		$ 295
Current portion of long-term debt and finance leases	$ 56	81
Long-term debt, VIE		$ 190
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares outstanding (in shares)	0	0
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
Southern California Gas Company [Member]
Current portion of long-term debt and finance leases	$ 6	$ 3
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	11,000,000	11,000,000
Preferred stock, shares outstanding (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
Otay Mesa VIE [Member]
Current portion of long-term debt and finance leases		$ 28
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member]
Current portion of long-term debt and finance leases		$ 28
Series A Preferred Stock [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, percent	6.00%
Preferred stock, shares outstanding (in shares)	17,250,000
Preferred stock, shares issued (in shares)	17,250,000
Series B Preferred Stock [Member]
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, percent	6.75%
Preferred stock, shares outstanding (in shares)	5,750,000
Preferred stock, shares issued (in shares)	5,750,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 2,362	$ 1,126	$ 351
Less: (Income) loss from discontinued operations, net of income tax	(363)	(188)	31
Income from continuing operations, net of income tax	1,999	938	382
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,569	1,491	1,436
Deferred income taxes and investment tax credits	189	(242)	889
Write-off of wildfire regulatory asset	0	0	351
Impairment losses	43	1,122	72
Gain on sale of assets	(63)	(513)	(2)
Equity earnings	(580)	(175)	(72)
Share-based compensation expense	75	83	82
Other	26	112	22
Net change in other working capital components:
Accounts receivable	(91)	(145)	29
Income taxes receivable/payable, net	(166)	88	(78)
Inventories	(22)	32	(42)
Other current assets	(88)	(79)	(6)
Accounts payable	12	96	84
Regulatory balancing accounts	13	263	108
Reserve for Aliso Canyon costs	(144)	56	31
Other current liabilities	(99)	52	(19)
Intercompany activities with discontinued operations, net	378	70	8
Insurance receivable for Aliso Canyon costs	122	(43)	188
Wildfire fund, current and noncurrent	(323)	0	0
Changes in other noncurrent assets and liabilities, net	(152)	14	(124)
Net cash provided by continuing operations	2,698	3,220	3,339
Net cash provided by discontinued operations	390	296	286
Net cash provided by operating activities	3,088	3,516	3,625
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(3,708)	(3,544)	(3,705)
Expenditures for investments and acquisitions, net of cash and cash equivalents acquired	(1,797)	(10,168)	(269)
Proceeds from sale of assets	899	1,580	15
Purchases of nuclear decommissioning trust assets	(914)	(890)	(1,314)
Proceeds from sales of nuclear decommissioning trust assets	914	890	1,314
Increase (decrease) in loans from affiliates, net	(16)	(95)	(505)
Repayments of advances to unconsolidated affiliates	3	3	9
Intercompany activities with discontinued operations, net	8	(22)	(18)
Other	30	41	24
Net cash used in continuing operations	(4,581)	(12,205)	(4,449)
Net cash used in discontinued operations	(12)	(265)	(436)
Net cash used in investing activities	(4,593)	(12,470)	(4,885)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(993)	(877)	(755)
Preferred dividends paid	(142)	(89)	0
Issuances of mandatory convertible preferred stock, net	0	2,258	0
Issuances of common stock, net	1,830	2,272	47
Repurchases of common stock	(26)	(21)	(15)
Issuances of debt (maturities greater than 90 days)	4,296	8,927	4,260
Payments on debt (maturities greater than 90 days) and finance leases	(3,667)	(3,342)	(2,587)
Increase (decrease) in short-term debt, net	656	(84)	(39)
Advances from unconsolidated affiliates	155	0	35
Proceeds from sale of noncontrolling interests, net	5	90	196
Payments To Acquire Noncontrolling Interest	30	7	0
Distributions to noncontrolling interest, net		(26)	(114)
Contributions from noncontrolling interests, net	98
Intercompany activities with discontinued operations, net	(266)	(109)	167
Other	(49)	(117)	(43)
Net cash provided by continuing operations	1,867	8,875	1,152
Net cash (used in) provided by discontinued operations	(392)	(25)	40
Net cash provided by financing activities	1,475	8,850	1,192
Effect of exchange rate changes on cash, cash equivalents and restricted cash	0	(2)	(2)
Effect of exchange rate changes in discontinued operations	1	(12)	9
Effect of exchange rate changes on cash, cash equivalents and restricted cash	1	(14)	7
Decrease in cash, cash equivalents and restricted cash, including discontinued operations	(29)	(118)	(61)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	246	364	425
Cash, cash equivalents and restricted cash, including discontinued operations, December 31	217	246	364
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	1,051	773	599
Income tax payments (refunds), net	254	107	122
Noncash acquisition of businesses:
Assets acquired, net of cash and cash equivalents acquired	0	9,670	436
Value of equity method investment immediately prior to acquisition	0	0	(28)
Liabilities assumed	0	(102)	(261)
Cash paid, net of cash and cash equivalents acquired	0	(9,568)	(147)
Other Noncash Investing and Financing Items [Abstract]
Accrued interest receivable from unconsolidated affiliate	55	62	22
Accrued capital expenditures	515	425	520
Accrued commercial paper proceeds	67	0	0
Increase in finance lease obligations for investment in property, plant and equipment	38	556	503
Common dividends issued in stock	55	54	53
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	774	676	421
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	760	688	670
Deferred income taxes and investment tax credits	105	39	(10)
Write-off of wildfire regulatory asset	0	0	351
Other	13	(17)	(24)
Net change in other working capital components:
Accounts receivable	(15)	30	(76)
Due to/from affiliates, net	(8)	(2)	(10)
Income taxes receivable/payable, net	126	(23)	(136)
Inventories	4	3	(25)
Other current assets	(19)	(6)	9
Accounts payable	32	(1)	75
Regulatory balancing accounts	(101)	138	56
Other current liabilities	4	4	4
Wildfire fund, current and noncurrent	(323)	0	0
Changes in other noncurrent assets and liabilities, net	(10)	9	(30)
Net cash provided by operating activities	1,090	1,584	1,547
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,522)	(1,542)	(1,555)
Decrease in cash from deconsolidation of Otay Mesa VIE	(8)	0	0
Purchases of nuclear decommissioning trust assets	(914)	(890)	(1,314)
Proceeds from sales of nuclear decommissioning trust assets	914	890	1,314
Decrease in loans to affiliate, net	0	0	31
Other	8	0	9
Net cash used in investing activities	(1,522)	(1,542)	(1,515)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	0	(250)	(450)
Equity contribution from Sempra Energy	322	0	0
Issuances of debt (maturities greater than 90 days)	400	618	398
Payments on debt (maturities greater than 90 days) and finance leases	(274)	(492)	(186)
Increase (decrease) in short-term debt, net	(211)	38	253
Distributions to noncontrolling interest, net			(34)
Contributions from noncontrolling interests, net	172	57
Debt issuance costs	(4)	(5)	(4)
Net cash provided by financing activities	405	(34)	(23)
Decrease in cash, cash equivalents and restricted cash, including discontinued operations	(27)	8	9
Cash, cash equivalents and restricted cash, January 1	37	29	20
Cash, cash equivalents and restricted cash, December 31	10	37	29
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	405	214	195
Income tax payments (refunds), net	191	112	27
Other Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	174	159	217
Increase in finance lease obligations for investment in property, plant and equipment	16	550	500
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	642	401	397
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	602	556	515
Deferred income taxes and investment tax credits	88	78	137
Impairment losses	37	0	0
Other	(5)	(7)	11
Net change in other working capital components:
Accounts receivable	(73)	(87)	72
Due to/from affiliates, net	(1)	(10)	7
Income taxes receivable/payable, net	(156)	14	(5)
Inventories	1	(2)	(66)
Other current assets	(9)	11	0
Accounts payable	(7)	71	39
Regulatory balancing accounts	114	125	53
Reserve for Aliso Canyon costs	(144)	56	31
Other current liabilities	(21)	(6)	20
Insurance receivable for Aliso Canyon costs	122	(43)	188
Changes in other noncurrent assets and liabilities, net	(322)	(144)	(93)
Net cash provided by operating activities	868	1,013	1,306
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,439)	(1,538)	(1,367)
Other	1	7	4
Net cash used in investing activities	(1,438)	(1,531)	(1,363)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(150)	(50)	0
Preferred dividends paid	(1)	(1)	(1)
Issuances of debt (maturities greater than 90 days)	349	949	0
Payments on debt (maturities greater than 90 days) and finance leases	(6)	(500)	0
Increase (decrease) in short-term debt, net	374	140	54
Debt issuance costs	(4)	(10)	0
Net cash provided by financing activities	562	528	53
Decrease in cash, cash equivalents and restricted cash, including discontinued operations	(8)	10	(4)
Cash, cash equivalents and restricted cash, January 1	18	8	12
Cash, cash equivalents and restricted cash, December 31	10	18	8
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	126	105	97
Income tax payments (refunds), net	188	0	28
Other Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	205	191	208
Increase in finance lease obligations for investment in property, plant and equipment	22	6	3
Preferred Stock [Member]
Other Noncash Investing and Financing Items [Abstract]
Dividends declared but not paid	36	36	0
Common Stock [Member]
Other Noncash Investing and Financing Items [Abstract]
Dividends declared but not paid	$ 283	$ 245	$ 207

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Preferred Stock [Member]	Common Stock [Member]	Retained earnings [Member]	Accumulated other comprehensive income (loss) [Member]	Shareholders' equity [Member]	Non-controlling interests [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]Non-controlling interests [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]	Preferred Class A [Member]	Preferred Class A [Member]Preferred Stock [Member]	Preferred Class A [Member]Retained earnings [Member]	Preferred Class A [Member]Shareholders' equity [Member]	Preferred Class B [Member]	Preferred Class B [Member]Preferred Stock [Member]	Preferred Class B [Member]Retained earnings [Member]	Preferred Class B [Member]Shareholders' equity [Member]
Beginning Balance at Dec. 31, 2016	$ 15,241	$ 0	$ 2,982	$ 10,717	$ (748)	$ 12,951	$ 2,290	$ 5,678	$ 1,338	$ 4,311	$ (8)	$ 5,641	$ 37	$ 3,510	$ 22	$ 866	$ 2,644	$ (22)
Net income	351			257		257	94	421		407		407	14	397			397
Other comprehensive loss	142				122	122	20	11					11	1				1
Share-based compensation expense	82		82			82
Preferred stock dividends declared														(1)			(1)
Common stock dividends declared	(826)			(826)		(826)		(450)		(450)		(450)
Preferred dividends of subsidiary	(1)			(1)		(1)
Issuances of stock	100		100			100
Repurchases of common stock	(15)		(15)			(15)
Equity contributed by noncontrolling interests	2						2	1					1
Distributions	(132)						(132)	(35)					(35)
Sale of noncontrolling interests, net of offering costs	196						196
Ending 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)
Cumulative-effect adjustment from change in accounting principle					(3)
Net income	1,126			1,050		1,050	76	676		669		669	7	401			401
Other comprehensive loss	(133)				(135)	(135)	2	6			(2)	(2)	8	1				1
Share-based compensation expense	83		83			83
Preferred stock dividends declared														(1)			(1)		$ (105)		$ (105)	$ (105)	$ (20)		$ (20)	$ (20)
Common stock dividends declared	(969)			(969)		(969)		(250)		(250)		(250)		(50)			(50)
Preferred dividends of subsidiary	(1)			(1)		(1)
Issuances of stock	2,326		2,326			2,326													1,693	$ 1,693		1,693	565	$ 565		565
Repurchases of common stock	(21)		(21)			(21)
Equity contributed by noncontrolling interests	66						66	65					65
Distributions	(110)						(110)	(8)					(8)
Purchases of noncontrolling interests	(8)		(1)			(1)	(7)
Sale of noncontrolling interests, net of offering costs	90		4			4	86
Increase from acquisition from noncontrolling interests	13						13
Decrease from divestiture from noncontrolling interests	(486)						(486)
Ending balance at Dec. 31, 2018	19,248	2,258	5,540	10,104	(764)	17,138	2,110	6,115	1,338	4,687	(10)	6,015	100	4,258	22	866	3,390	(20)
Cumulative-effect adjustment from change in accounting principle					(42)			0		2	(2)	0		(2)			2	(4)
Net income	2,362			2,198		2,198	164	774		767		767	7	642			642
Other comprehensive loss	(140)				(133)	(133)	(7)	(2)			(4)	(4)	2	1				1
Share-based compensation expense	75		75			75
Preferred stock dividends declared														(1)			(1)		$ (103)		$ (103)	$ (103)	$ (39)		$ (39)	$ (39)
Common stock dividends declared	(1,086)			(1,086)		(1,086)								(150)			(150)
Equity contribution from Sempra Energy								322	322			322
Preferred dividends of subsidiary	(1)			(1)		(1)
Issuances of stock	1,885		1,885			1,885
Repurchases of common stock	(26)		(26)			(26)
Equity contributed by noncontrolling interests	175						175	175					175
Distributions	(98)		5			5	(103)	(3)					(3)
Purchases of noncontrolling interests	(30)		(3)			(3)	(27)
Sale of noncontrolling interests, net of offering costs	5		4			4	1
Increase from acquisition from noncontrolling interests	3						3
Decrease from divestiture from noncontrolling interests	(440)						(440)	(281)					(281)
Ending balance at Dec. 31, 2019	$ 21,805	$ 2,258	$ 7,480	$ 11,130	$ (939)	$ 19,929	$ 1,876	$ 7,100	$ 1,660	$ 5,456	$ (16)	$ 7,100	$ 0	$ 4,748	$ 22	$ 866	$ 3,883	$ (23)

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Common stock dividends declared (USD per share)	$ 3.87	$ 3.58	$ 3.29
Preferred Class A [Member]
Preferred stock, dividends declared per share (USD per share)	6	6.10
Preferred Class B [Member]
Preferred stock, dividends declared per share (USD per share)	6.75	3.41
Southern California Gas Company [Member]
Common stock dividends declared (USD per share)	1.64	0.55
Preferred stock, dividends declared per share (USD per share)	1.50	1.50	1.50
San Diego Gas and Electric Company [Member]
Common stock dividends declared (USD per share)		$ 2.14	$ 3.86

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Significant Accounting Policies And Other Financial Data	SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA PRINCIPLES OF CONSOLIDATION Sempra Energy Sempra Energy’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based 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 17 . 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 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, which is a wholly owned subsidiary of Sempra Energy. SoCalGas SoCalGas’ common stock is wholly owned by PE, 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 Consolidated Financial Statements and Notes to Consolidated Financial Statements when discussed together or collectively: ▪ the Consolidated Financial Statements and related Notes of Sempra Energy and its subsidiaries and VIEs; ▪ the Consolidated Financial Statements and related Notes of SDG&E and its VIE (until deconsolidation of the VIE in August 2019); and ▪ the Financial Statements and related Notes of SoCalGas. Use of Estimates in the Preparation of the Financial Statements We have prepared our Consolidated Financial Statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates. Discontinued Operations In January 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. Subsequent Events We evaluated events and transactions that occurred after December 31, 2019 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments and disclosures necessary for a fair presentation. EFFECTS OF REGULATION The California Utilities’ accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, the California Utilities record regulatory liabilities when the CPUC or the FERC requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires significant judgment by management and may include, but is not limited to, consideration of: ▪ the nature of the event giving rise to the assessment ▪ existing statutes and regulatory code ▪ legal precedents ▪ regulatory principles and analogous regulatory actions ▪ testimony presented in regulatory hearings ▪ regulatory orders ▪ a commission-authorized mechanism established for the accumulation of costs ▪ status of applications for rehearings or state court appeals ▪ specific approval from a commission ▪ historical experience Sempra Mexico’s natural gas distribution utility, Ecogas, also applies U.S. GAAP for rate-regulated utilities to its operations, including the same evaluation of probability of recovery of regulatory assets described above. We provide information concerning regulatory assets and liabilities in Note 4 . Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which, at December 31, 2019, owns an 80.25% interest in Oncor, and Sharyland Holdings, which owns 100% of Sharyland Utilities. Oncor and Sharyland Utilities are regulated electric transmission and distribution utilities in Texas and their rates are regulated by the PUCT and certain cities and are subject to regulatory rate-setting processes and annual earnings oversight. Oncor and Sharyland Utilities 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, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently 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 in “Property, Plant and Equipment.” FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily nuclear decommissioning and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: ▪ quoted forward prices for commodities ▪ time value ▪ current market and contractual prices for the underlying instruments ▪ volatility factors ▪ other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and fixed-price electricity positions at SDG&E. CASH, CASH EQUIVALENTS AND RESTRICTED CASH Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase. Restricted cash primarily includes: ▪ for SDG&E, funds held by a trustee for Otay Mesa VIE to pay certain operating costs until the deconsolidation of the VIE in August 2019; and ▪ for Sempra Mexico, funds primarily denominated in Mexican pesos to pay for rights-of-way, license fees, permits, topographic surveys and other costs pursuant to trust and debt agreements related to pipeline projects. The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on the Consolidated Balance Sheets to the sum of such amounts reported on the Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) At December 31, 2019 2018 Sempra Energy Consolidated: Cash and cash equivalents $ 108 $ 102 Restricted cash, current 31 35 Restricted cash, noncurrent 3 21 Cash, cash equivalents and restricted cash in discontinued operations 75 88 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 217 $ 246 SDG&E: Cash and cash equivalents $ 10 $ 8 Restricted cash, current — 11 Restricted cash, noncurrent — 18 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 10 $ 37 COLLECTION ALLOWANCES We record allowances for the collection of trade and other accounts and notes receivable, which include allowances for doubtful customer accounts and for other receivables. We show the changes in these allowances in the table below: COLLECTION ALLOWANCES (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Allowances for collection of receivables at January 1 $ 21 $ 25 $ 29 Provisions for uncollectible accounts 22 10 12 Write-offs of uncollectible accounts (14 ) (14 ) (16 ) Allowances for collection of receivables at December 31 $ 29 $ 21 $ 25 SDG&E: Allowances for collection of receivables at January 1 $ 11 $ 9 $ 8 Provisions for uncollectible accounts 10 9 8 Write-offs of uncollectible accounts (7 ) (7 ) (7 ) Allowances for collection of receivables at December 31 $ 14 $ 11 $ 9 SoCalGas: Allowances for collection of receivables at January 1 $ 10 $ 16 $ 21 Provisions for uncollectible accounts 12 1 4 Write-offs of uncollectible accounts (7 ) (7 ) (9 ) Allowances for collection of receivables at December 31 $ 15 $ 10 $ 16 We evaluate accounts receivable collectability using a combination of factors, including past due status based on contractual terms, trends in write-offs, the age of the receivable, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. Adjustments to collection allowances are made when necessary based on the results of analysis, the aging of receivables, and historical and industry trends. We write off accounts receivable in the period in which we deem the receivable to be uncollectible. We record recoveries of accounts receivable previously written off when it is known that they will be received. CONCENTRATION OF CREDIT RISK Credit risk is the risk of loss that would be incurred as a result of nonperformance by our counterparties on their contractual obligations. We have policies governing the management of credit risk that are administered by the respective credit departments for each of the California Utilities and, on a combined basis, for all non-CPUC regulated affiliates and overseen by their separate risk management committees. This oversight includes calculating current and potential credit risk on a daily basis and monitoring actual balances in comparison to approved limits. We establish credit limits based on risk and return considerations under terms customarily available in the industry. We avoid concentration of counterparties whenever possible, and we believe our credit policies significantly reduce overall credit risk. These policies include an evaluation of: ▪ prospective counterparties’ financial condition (including credit ratings) ▪ collateral requirements ▪ the use of standardized agreements that allow for the netting of positive and negative exposures associated with a single counterparty ▪ downgrade triggers We believe that we have provided adequate reserves for counterparty nonperformance. When our development projects become operational, we rely significantly on the ability of suppliers to perform under long-term agreements and on our ability to enforce contract terms in the event of nonperformance. Also, the factors that we consider in evaluating a development project include negotiating customer and supplier agreements and, therefore, we rely on these agreements for future performance. We also may condition our decision to go forward on development projects on first obtaining these customer and supplier agreements. INVENTORIES The California Utilities value natural gas inventory using the LIFO method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. These differences are generally temporary, but may become permanent if the natural gas inventory withdrawn from storage during the year is not replaced by year end. The California Utilities generally value materials and supplies at the lower of average cost or net realizable value. Sempra Mexico and Sempra LNG value natural gas inventory and materials and supplies at the lower of average cost or net realizable value. Sempra Mexico and Sempra LNG value LNG inventory using the first-in first-out method. The components of inventories are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Natural gas LNG Materials and supplies Total 2019 2018 2019 2018 2019 2018 2019 2018 Sempra Energy Consolidated $ 110 $ 95 $ 9 $ 4 $ 158 $ 159 $ 277 $ 258 SDG&E 1 — — — 93 102 94 102 SoCalGas 90 92 — — 46 42 136 134 WILDFIRE FUND On July 12, 2019, the Wildfire Legislation was 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 financing costs without a ROE. The Wildfire Legislation established a revised legal standard for the recovery of wildfire costs (Revised Prudent Manager Standard) and established a fund (the Wildfire Fund) to provide liquidity to SDG&E, PG&E and Edison 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% 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 its 2019 rate base, the liability cap for SDG&E is approximately $900 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. 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 Note 14. 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 the estimated period of benefit, as adjusted for utilization by the IOUs. The estimated period of benefit of the Wildfire Fund asset, which is 15 years as of December 31, 2019 , 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 • 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). At December 31, 2019 , there were no such known claims from the IOUs requiring a reduction of the Wildfire Fund asset. At December 31, 2019 , the current portion of the Wildfire Fund asset was $29 million in Other Current Assets on Sempra Energy’s Consolidated Balance Sheet and in Prepaid Expenses on SDG&E’s Consolidated Balance Sheet, and the noncurrent portion of $392 million was in Wildfire Fund on Sempra Energy’s and SDG&E’s 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 and its first annual shareholder contribution of $12.9 million in December 2019. At December 31, 2019 , SDG&E expects to make annual shareholder contributions of $12.9 million in each of the next nine years . SDG&E accretes the present value of the Wildfire Fund obligation to O&M until the liability is settled. At December 31, 2019 , the Wildfire Fund obligation was $12.9 million in Other Current Liabilities and $86 million in Deferred Credits and Other on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets. INCOME TAXES Income tax expense includes current and deferred income taxes. We record deferred income taxes for temporary differences between the book and the tax basis of assets and liabilities. ITCs from prior years are amortized to income by the California Utilities over the estimated service lives of the properties as required by the CPUC. Under the regulatory accounting treatment required for flow-through temporary differences, the California Utilities and Sempra Mexico recognize: ▪ regulatory assets to offset deferred income tax liabilities if it is probable that the amounts will be recovered from customers; and ▪ regulatory liabilities to offset deferred income tax assets if it is probable that the amounts will be returned to customers. When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a more-likely-than-not chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more-likely-than-not” means a likelihood of more than 50%. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the more-likely-than-not criterion at the largest amount of tax benefit that is greater than 50% likely of being realized upon its effective resolution. Unrecognized income tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our ETR. In December 2017, the TCJA was signed into law. As a result, all cumulative undistributed earnings from non-U.S. subsidiaries were deemed repatriated and subjected to a one-time U.S. federal deemed repatriation tax. To the extent we intend to repatriate cash to the U.S. from our continuing international operations, we accrue incremental income tax. We currently do not record deferred income taxes for other basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries to the extent the related cumulative undistributed earnings are indefinitely reinvested. We recognize income tax expense for basis differences related to global intangible low-taxed income as a period cost if and when incurred. We provide additional information about income taxes in Note 8 . GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS The California Utilities, Sempra Mexico and Sempra LNG are required by AB 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas transportation. At the California Utilities, many GHG allowances are allocated to us on behalf of our customers at no cost. We record purchased and allocated GHG allowances at the lower of weighted-average cost or market. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. The California Utilities balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Mexico and Sempra LNG record the cost of GHG obligations in cost of sales. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. RENEWABLE ENERGY CERTIFICATES RECs are energy rights established by governmental agencies for the environmental and social promotion of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable energy PPAs, internal generation or separate purchases in the market to comply with the RPS established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with the RPS. The cost of RECs at SDG&E, which is recoverable in rates, is recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations. PROPERTY, PLANT AND EQUIPMENT PP&E is recorded at cost and primarily represents the buildings, equipment and other facilities used by the California Utilities to provide natural gas and electric utility services, and by the Sempra Global businesses in their operations, including construction work in progress. PP&E also includes lease improvements and other equipment at Parent and Other. Our plant costs include labor, materials and contract services and expenditures for replacement parts incurred during a major maintenance outage of a plant. In addition, the cost of utility plant at our rate-regulated businesses and PP&E under regulated projects that meet the regulatory accounting requirements of U.S. GAAP includes AFUDC. The cost of other PP&E includes capitalized interest. Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation. We discuss assets collateralized as security for certain indebtedness in Note 7 . PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) December 31, Depreciation rates for 2019 2018 2019 2018 2017 SDG&E: Natural gas operations $ 2,534 $ 2,382 2.47 % 2.44 % 2.40 % Electric distribution 7,985 7,462 3.94 3.91 3.92 Electric transmission (1) 6,577 6,222 2.79 2.76 2.71 Electric generation (2) 2,415 2,967 4.50 4.12 4.05 Other electric (3) 1,492 1,408 6.61 6.43 5.54 Construction work in progress (1) 1,501 1,221 NA NA NA Total SDG&E 22,504 21,662 SoCalGas: Natural gas operations (4) 18,370 17,268 3.60 3.60 3.63 Other non-utility 34 34 5.08 5.39 5.28 Construction work in progress 958 836 NA NA NA Total SoCalGas 19,362 18,138 Other operating units and parent (5) : Estimated useful lives Weighted-average useful life Land and land rights 278 326 16 to 50 years (6) 31 Machinery and equipment: Generating plants 1,154

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 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 modified retrospective transition method to apply the new guidance 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 $ — $ — Other long-term assets (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 and finance leases (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — As a result of the adoption of the lease standard, we derecognized the asset and liability associated with our corporate headquarters building 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 16. 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. 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. We expect no impact to SDG&E’s or SoCalGas’ balance sheets from adoption. The following table shows the expected (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. EXPECTED IMPACT FROM ADOPTION OF ASU 2016-13 (Dollars in millions) Sempra Energy Consolidated Accounts receivable – trade, net $ (1 ) Due from unconsolidated affiliates – noncurrent (6 ) Deferred income tax assets 4 Other current liabilities 4 Deferred credits and other 2 Retained earnings (7 ) Other noncontrolling interests (2 ) 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. ASU 2019-12, “Simplifying the Accounting for Income Taxes”: ASU 2019-12 simplifies certain areas of accounting for income taxes. In addition to other changes, this standard amends ASC 740, “Income Taxes,” as follows: ▪ removes the exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, including discontinued operations or other comprehensive income; ▪ simplifies the recognition of deferred taxes related to basis differences as a result of ownership changes in investments; ▪ specifies an entity is not required to allocate the consolidated amount of current and deferred tax expense to a legal entity that is not subject to tax in its separate financial statements; and ▪ requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual ETR computation in the interim period that includes the enactment date. For public entities, ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, including interim periods therein, with early adoption permitted. The transition method related to the amendments made by ASU 2019-12 vary based on the nature of the change. We are currently evaluating our planned adoption date and the effect of the standard on our ongoing financial reporting.

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2019
Revenue from Contract with Customer [Abstract]
REVENUES	REVENUES 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) Year ended December 31, 2019 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments and Parent and other Sempra Energy Consolidated By major service line: Utilities $ 4,819 $ 4,367 $ 73 $ — $ — $ (75 ) $ 9,184 Energy-related businesses — — 919 5 176 (143 ) 957 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 5 $ 176 $ (218 ) $ 10,141 By market: Gas $ 587 $ 4,367 $ 680 $ — $ 170 $ (208 ) $ 5,596 Electric 4,232 — 312 5 6 (10 ) 4,545 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 5 $ 176 $ (218 ) $ 10,141 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 5 $ 176 $ (218 ) $ 10,141 Utilities regulatory revenues 106 158 — — — — 264 Other revenues — — 383 5 234 (198 ) 424 Total revenues $ 4,925 $ 4,525 $ 1,375 $ 10 $ 410 $ (416 ) $ 10,829 Year ended December 31, 2018 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments and Parent and other Sempra Energy Consolidated By major service line: Utilities $ 4,788 $ 3,577 $ 78 $ — $ — $ (69 ) $ 8,374 Energy-related businesses — — 941 46 232 (146 ) 1,073 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 46 $ 232 $ (215 ) $ 9,447 By market: Gas $ 491 $ 3,577 $ 711 $ — $ 224 $ (203 ) $ 4,800 Electric 4,297 — 308 46 8 (12 ) 4,647 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 46 $ 232 $ (215 ) $ 9,447 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 46 $ 232 $ (215 ) $ 9,447 Utilities regulatory revenues (220 ) 385 — — — — 165 Other revenues — — 357 78 240 (185 ) 490 Total revenues $ 4,568 $ 3,962 $ 1,376 $ 124 $ 472 $ (400 ) $ 10,102 REVENUES FROM CONTRACTS WITH CUSTOMERS Our revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity through our regulated utilities. We also provide other midstream and renewable energy-related services. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity service is provided to our customers and invoice our customers for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Our performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of our performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in our customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, the California Utilities pay franchise fees to operate in various municipalities. The California Utilities bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of the California Utilities’ ability to collect from the customer, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues represent the majority of our consolidated revenues from contracts with customers and include: The transmission, distribution and storage of natural gas at: ▪ SDG&E ▪ SoCalGas ▪ Sempra Mexico’s Ecogas The generation, transmission and distribution of electricity at SDG&E. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill our customers are based on tariffs set by regulators within the respective state or country. For SDG&E and SoCalGas, which follow the provisions of U.S. GAAP governing rate-regulated operations as we discuss in Note 1, amounts that we bill to customers also include adjustments for previously recognized regulatory revenues. The California Utilities and Ecogas recognize revenues based on regulator-approved revenue requirements, which allows the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While the California Utilities’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SoCalGas recognizes annual authorized revenue for core natural gas customers using seasonal factors established in the Triennial Cost Allocation Proceeding. Accordingly, a significant portion of SoCalGas’ annual earnings are recognized in the first and fourth quarters of each year. SDG&E’s authorized revenue recognition is also impacted by seasonal factors, resulting in higher earnings in the third quarter when electric loads are typically higher than in the other three quarters of the year. SDG&E has an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. The California Utilities recognize revenues from the sale of allocated California GHG emissions allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and the California Utilities have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. The California Utilities balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Midstream Revenues Midstream revenues at Sempra Mexico and Sempra LNG typically represent revenues from long-term, U.S. dollar-based contracts with customers for the sale of natural gas and LNG, as well as storage and transportation of natural gas. Invoiced amounts are based on the volume of natural gas delivered and contracted prices. Sempra Mexico’s marketing operations sell natural gas to the CFE and other customers under supply agreements. Sempra Mexico recognizes the revenue from the sale of natural gas upon transfer of the natural gas via pipelines to customers at the agreed upon delivery points, and in the case of the CFE, at its thermoelectric power plants. Through its marketing operations, Sempra LNG has contracts to sell natural gas and LNG to Sempra Mexico that allow Sempra Mexico to satisfy its obligations under supply agreements with the CFE and other customers, and to supply Sempra Mexico’s TdM power plant. Because Sempra Mexico either immediately delivers the natural gas to its customers or consumes the benefits simultaneously (by using the gas to supply TdM), revenues from Sempra LNG’s sale of natural gas to Sempra Mexico are generally recognized over time as delivered. Revenues from LNG sales are recognized at the point when the cargo is delivered to Sempra Mexico. Revenues from the sale of LNG and natural gas by Sempra LNG to Sempra Mexico are adjusted for indemnity payments and profit sharing. We consider these adjustments to be forms of variable consideration that are associated with the sale of LNG and natural gas to Sempra Mexico, and therefore, Sempra LNG records the related costs as an offset to revenues, with no impact to Sempra Energy’s consolidated revenues. We recognize storage revenue from firm capacity reservation agreements, under which we collect a fee for reserving storage capacity for customers in our underground storage facilities. Under these firm agreements, customers pay a monthly fixed reservation fee based on the storage capacity reserved rather than the actual volumes stored. For the fixed-fee component, revenue is recognized on a straight-line basis over the term of the contract. We bill customers for any capacity used in excess of the contracted capacity and such revenues are recognized in the month of occurrence. We also recognize revenue for interruptible storage services. As we discuss in Note 5 , 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). We generate pipeline transportation revenues from firm agreements, under which customers pay a fee for reserving transportation capacity. Revenue is recognized when the volumes are delivered to the customers’ agreed upon delivery point. We recognize revenues for our stand-ready obligation to provide capacity and transportation services throughout the contractual delivery period, as the benefits are received and consumed simultaneously as customers utilize pipeline capacity for the transport and receipt of natural gas and LPG. Invoiced amounts are based on a variable usage fee and a fixed capacity charge, adjusted for the Consumer Price Index, the effects of any foreign currency translation and the actual quantity of commodity transported. Renewables Revenues Sempra Renewables and Sempra Mexico develop, invest in and operate solar and wind facilities that have long-term PPAs to sell the electricity and the related green energy attributes they generate to customers, generally load serving entities, and also for Sempra Mexico, industrial and other customers. Load serving entities will sell electric service to their end-users and wholesale customers immediately upon receipt of our power delivery, and industrial and other customers immediately consume the electricity to run their facilities, and thus, we recognize the revenue under the PPAs as the electricity is generated. We invoice customers based on the volume of energy delivered at rates pursuant to the PPAs. As we discuss in Note 5 , in December 2018, we completed the sale of Sempra Renewables’ U.S. operating solar assets, solar and battery storage development projects and its 50% ownership interest in a wind power generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Sempra LNG continues to have a contractual agreement to provide scheduling and marketing of renewable power for Sempra Mexico’s renewables’ entities. Invoiced amounts are based on a fixed fee per MWh scheduled. Other Revenues from Contracts with Customers TdM is a natural gas-fired power plant that generates revenues from selling electricity and/or resource adequacy to the California ISO and to governmental, public utility and wholesale power marketing entities, as the power is delivered at the interconnection point. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 2019 , we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra Energy’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Mexico. SoCalGas did not have any remaining performance obligations at December 31, 2019 . REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E 2020 $ 390 $ 4 2021 403 4 2022 406 4 2023 402 4 2024 349 4 Thereafter 4,699 71 Total revenues to be recognized $ 6,649 $ 91 (1) Excludes intercompany transactions. Contract Balances from Revenues from Contracts with Customers From time to time, we receive payments in advance of satisfying the performance obligations associated with customer contracts. We defer such revenues as contract liabilities and recognize them in earnings as the performance obligations are satisfied. Activities within Sempra Energy’s and SDG&E’s contract liabilities are presented below. There were no contract liability activities at SDG&E in 2018 or SoCalGas in 2019 or 2018 . CONTRACT LIABILITIES (Dollars in millions) Sempra Energy Consolidated SDG&E Opening balance, January 1, 2019 $ (70 ) $ — Revenue from performance obligations satisfied during reporting period 2 1 Payments received in advance (95 ) (92 ) Balance at December 31, 2019 (1) $ (163 ) $ (91 ) Opening balance, January 1, 2018 $ — Adoption of ASC 606 adjustment (61 ) Revenue from performance obligations satisfied during reporting period 7 Payments received in advance (16 ) Balance at December 31, 2018 $ (70 ) (1) I ncludes $4 million and $4 million in Other Current Liabilities and $159 million and $87 million in Deferred Credits and Other on the Sempra Energy and SDG&E 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 Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2019 2018 Sempra Energy Consolidated: Accounts receivable – trade, net $ 1,163 $ 1,106 Accounts receivable – other, net 16 11 Due from unconsolidated affiliates – current (1) 5 4 Assets held for sale — 6 Total $ 1,184 $ 1,127 SDG&E: Accounts receivable – trade, net $ 398 $ 368 Accounts receivable – other, net 5 6 Due from unconsolidated affiliates – current (1) 2 3 Total $ 405 $ 377 SoCalGas: Accounts receivable – trade, net $ 710 $ 634 Accounts receivable – other, net 11 5 Total $ 721 $ 639 (1) A mount is presented net of amounts due to unconsolidated affiliates on the Consolidated Balance Sheets, when right of offset exists. REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled revenues. As discussed earlier, the regulatory framework requires the California Utilities to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for the California Utilities to use a “decoupling” mechanism, which allows the California Utilities to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive mechanisms. The CPUC applies performance-based measures and incentive mechanisms to all California IOUs, under which the California Utilities have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC, and the FERC as it relates to SDG&E, authorize the California Utilities to collect revenue requirements for operating costs and capital related costs (such as depreciation, taxes and return on rate base) from customers, including: ▪ costs to purchase natural gas and electricity; ▪ costs associated with administering public purpose, demand response, and customer energy efficiency programs; ▪ other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪ costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity or service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded within a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met at the time the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund for programs authorized, including limitations on the total cost of the program, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in disallowances of recovery from ratepayer s. We discuss balancing accounts and their effects further in Note 4 . Other Revenues Sempra LNG has an agreement to supply LNG to Sempra Mexico’s ECA LNG Regasification terminal. Although the LNG sale and purchase agreement specifies a number of cargoes to be delivered annually, actual cargoes delivered by the supplier have traditionally been significantly lower than the maximum specified under the agreement. As a result, Sempra LNG is contractually required to make monthly indemnity payments to Sempra Mexico for failure to deliver the contracted LNG. Sempra Mexico generates lease revenues from operating lease agreements with PEMEX and CENAGAS for the use of natural gas and ethane pipelines and LPG storage facilities. Certain PPAs at Sempra Renewables were also accounted for as operating leases prior to sale of its solar and wind assets in December 2018 and April 2019. Sempra LNG also recognizes other revenues from: ▪ fees related to contractual counterparty obligations for non-delivery of LNG cargoes, as described above; and ▪ sales of natural gas and electricity under short-term and long-term contracts and into the spot market and other competitive markets. Revenues include the net realized gains and losses on physical and derivative settlements and net unrealized gains and losses from the change in fair values of the derivatives.

REGULATORY MATTERS

REGULATORY MATTERS	12 Months Ended
	Dec. 31, 2019
Regulated Operations [Abstract]
REGULATORY MATTERS	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2019 2018 SDG&E: Fixed-price contracts and other derivatives $ 8 $ (150 ) Deferred income taxes refundable in rates (108 ) (236 ) Pension and other postretirement benefit plan obligations 103 186 Removal obligations (2,056 ) (1,848 ) Environmental costs 45 28 Sunrise Powerlink fire mitigation 121 120 Regulatory balancing accounts (1)(2) Commodity – electric 102 (8 ) Gas transportation 22 45 Safety and reliability 77 70 Public purpose programs (124 ) (62 ) 2019 GRC retroactive impacts 111 — Other balancing accounts 106 145 Other regulatory liabilities, net (2) (153 ) (170 ) Total SDG&E (1,746 ) (1,880 ) SoCalGas: Deferred income taxes refundable in rates (203 ) (336 ) Pension and other postretirement benefit plan obligations 400 470 Employee benefit costs 44 49 Removal obligations (728 ) (833 ) Environmental costs 40 28 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (118 ) 196 Safety and reliability 295 332 Public purpose programs (273 ) (325 ) 2019 GRC retroactive impacts 400 — Other balancing accounts (7 ) (68 ) Other regulatory liabilities, net (2) (101 ) (114 ) Total SoCalGas (251 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 83 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (1,908 ) $ (2,394 ) (1) At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $108 million and $78 million , respectively. At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SoCalGas was $500 million and $185 million , respectively. (2) Includes regulatory assets earning a return. In the table above: ▪ Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. ▪ Deferred income taxes refundable/recoverable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Mexico expect to refund/recover net regulatory liabilities/assets related to deferred income taxes over the lives of the assets that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 8. ▪ Regulatory assets/liabilities related to pension and other postretirement benefit plan obligations are offset by corresponding liabilities/assets and are being recovered in rates as the plans are funded. ▪ The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪ Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪ Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪ The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 50 -year period. ▪ Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, including commodity costs. Depreciation and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. Amortization expense on regulatory assets for the years ended December 31, 2019 , 2018 and 2017 was $7 million , $5 million and $50 million , respectively, at Sempra Energy Consolidated, $3 million , $2 million and $49 million , respectively, at SDG&E, and $4 million , $3 million and $1 million , respectively, at SoCalGas. 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 %) 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 %) over its authorized 2018 revenue requirement. 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 The adopted revenue requirements associated with the period from January 1, 2019 through December 31, 2019 are being recovered in rates over a 24-month period beginning in January 2020. At December 31, 2019, SDG&E recorded an associated regulatory asset of $111 million , with $56 million as noncurrent, and SoCalGas recorded an associated regulatory asset of $400 million , with $200 million as noncurrent. In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs. The California Utilities were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). 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. 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 $89 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. Final resolution of the scope of the two-way income tax expense memorandum account for the 2016 through 2018 period is pending at the CPUC and could impact the disposition of these regulatory liabilities. We expect resolution in the first half of 2020. The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35% . As a result of the TCJA, the federal income tax rate became 21% effective January 1, 2018. Since SDG&E and SoCalGas continued to collect authorized revenues based on a 35% tax rate, SDG&E and SoCalGas recorded regulatory liabilities of $88 million and $75 million , respectively. Pursuant to the 2019 GRC FD, SDG&E and SoCalGas are refunding the regulatory balances over a 24-month period starting in January 2020. SDG&E also recorded a $66 million regulatory liability at December 31, 2019 , relating to its FERC jurisdictional rates, which it began refunding in June 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% to 56% . SDG&E also proposed to increase its authorized ROE from 10.2% to 14.3% (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% to 10.03% . In August 2019, SDG&E filed supplemental testimony to update its ROE request from 10.2% to 12.38% to reflect the impacts of the Wildfire Legislation, including a revised premium for wildfire liability risk, and its authorized return on rate base from 7.55% to 8.95% . SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52% to 56% , its authorized ROE from 10.05% to 10.7% and its authorized return on rate base from 7.34% to 7.85% . In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that are effective January 1, 2020 and will remain in effect through December 31, 2022. SDG&E did not propose a 2020 cost of preferred equity in this proceeding. In January 2020, SDG&E filed an advice letter to continue the cost of preferred equity for test year 2020 at 6.22% , which is pending CPUC approval. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on rate base Weighted rate base Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Stock 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 % The CCM was reauthorized in the 2020 cost of capital proceeding to continue through 2022. The CCM benchmark rate for the 2020 cost of capital is the average monthly utility bond index, as published by Moody’s, for the 12-month period from October 2018 through September 2019. SDG&E’s CCM benchmark rate is 4.491% , based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.024% , based on Moody’s A- utility bond index. The index applicable to each utility is based on each utility’s credit rating. The CCM benchmark rates for SDG&E and SoCalGas are the basis of comparison to determine if future measurement periods “trigger” the CCM. The 12 months ending September 2020 shall be the first “CCM Period” to determine if there has been a trigger at SDG&E or SoCalGas. The trigger occurs if the change in the applicable average Moody’s utility bond index relative to the CCM benchmark is larger than plus or minus 1.000% . Accordingly, if a change of more than plus or minus 1.000% occurs, SDG&E’s, SoCalGas’, or both utilities’ authorized ROE would be adjusted, upward or downward, by one half of the difference between the CCM benchmark and the 12-month average determined during the CCM Period. In addition, the authorized recovery rate for the respective utilities’ cost of debt and preferred stock would be adjusted to their respective actual weighted-average cost, with no change to the authorized capital structure. In the event of a CCM trigger, the CCM benchmark is also reestablished. These adjustments would become effective in authorized rates on January 1 of the year following the CCM trigger. SDG&E FERC Rate Matters and Cost of Capital SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets. SDG&E’s current estimated FERC return on rate base under the TO4 formula rate request filing is 7.51% based on its capital structure as follows: FERC–AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE – SDG&E Weighting Return on rate base Weighted return on rate base Long-Term Debt 43.44 % 4.21 % 1.83 % Common Equity 56.56 10.05 5.68 100.00 % 7.51 % FERC Formulaic Rate Filing In October 2018, SDG&E submitted its TO5 filing to the FERC proposing, among other items, an increase to SDG&E’s current authorized FERC ROE from 10.05% to 11.20% . This proceeding establishes the transmission revenue requirement, including rate of return, for SDG&E’s FERC-regulated electric transmission operations and assets. On December 31, 2018, the FERC issued its order accepting and suspending SDG&E’s TO5 filing for five months, during which the existing TO4 rates remained in effect, and established hearing and settlement procedures. 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% is the basis of SDG&E’s FERC-related revenue recognition. In October 2019, SDG&E and all settling parties reached an agreement on all issues set for hearing in the proceeding. The agreement provides for a ROE of 10.60% , consisting of a base ROE of 10.10% 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 in May 2019, which is pending before the CPUC. The CPUC granted SoCalGas’ request to delay distribution of the $100 bill credit to customers until a final decision on the rehearing. SEMPRA MEXICO In July and December of 2018, the CRE adjusted Ecogas’ natural gas distribution rates charged to end-users in 2014 through 2016. Ecogas recorded regulatory assets of $7 million and $5 million SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. SONGS STEAM GENERATOR REPLACEMENT PROJECT The replacement steam generators, which caused a water leak due to unexpected tube wear, were designed and provided by MHI. In 2013, Edison instituted arbitration proceedings against MHI seeking recovery of damages resulting from the issues with the steam generators used in SONGS Units 2 and 3. The other SONGS co-owners, SDG&E and the City of Riverside, participated as claimants and respondents. In March 2017, the International Chamber of Commerce International Court of Arbitration Tribunal (the Tribunal) overseeing the arbitration found MHI liable for breach of contract, subject to a contractual limitation of liability, and rejected claimants’ other claims. The Tribunal awarded $118 million in damages to the SONGS co-owners, but determined that MHI was the prevailing party and awarded it 95% of its arbitration costs. The damage award is offset by these costs, resulting in a net award of approximately $60 million in favor of the SONGS co-owners. SDG&E’s specific allocation of the damage award was $24 million reduced by costs awarded to MHI of approximately $12 million , resulting in a net damage award of $12 million , which was paid by MHI to SDG&E in March 2017. In accordance with the Amended Settlement Agreement discussed below, SDG&E recorded the proceeds from the MHI arbitration by reducing O&M for previously incurred legal costs of $11 million , and shared the remaining $1 million equally between ratepayers and shareholders. SETTLEMENT AGREEMENT TO RESOLVE THE CPUC’S ORDER INSTITUTING INVESTIGATION INTO THE SONGS OUTAGE In 2012, in response to the SONGS outage, the CPUC issued the SONGS OII, which was intended to determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of the outage. In 2014, the CPUC issued a final decision approving an Amended Settlement Agreement that provided for various disallowances, refunds and rate recoveries, including authorizing SDG&E to recover in rates its remaining investment in SONGS, excluding its investment in the Steam Generator Replacement Project. In 2016, the CPUC issued two procedural rulings: the first, to reopen the record of the OII to address the issue of whether the Amended Settlement Agreement is reasonable and in the public interest, and the second, directing parties to the SONGS OII to determine whether an agreement could be reached to modify the Amended Settlement Agreement previously approved by the CPUC, to resolve allegations that unreported ex parte communications between Edison and the CPUC resulted in an unfair advantage at the time the settlement agreement was negotiated. In July 2018, the CPUC approved a Revised Settlement Agreement among SDG&E, Edison, Cal PA, TURN and other intervenors that resolved all issues under consideration in the SONGS OII and made one modification to the Amended Settlement Agreement to remove the requirement to fund a GHG emissions reduction research program. In August 2018, parties to the Revised Settlement Agreement submitted a notice that they accepted the settlement agreement, as modified. In connection with the Revised Settlement Agreement, and in exchange for the release of certain SONGS-related claims, SDG&E and Edison entered into the Utility Shareholder Agreement, described below. Disallowances, Refunds and Recoveries Under the Revised Settlement Agreement, SDG&E and Edison ceased rate recovery of SONGS costs as authorized under the Amended Settlement Agreement as of December 19, 2017, when the present value of their combined remaining SONGS regulatory assets equaled $775 million , of which $152 million represents SDG&E’s share. Under the Utility Shareholder Agreement, Edison is obligated to pay SDG&E the full amount of SDG&E’s revenue requirement not recovered from ratepayers, as described below. In October 2018, SDG&E began refunding to customers SONGS-related amounts recovered in rates after December 19, 2017. Utility Shareholder Agreement In January 2018, SDG&E and Edison entered into the Utility Shareholder Agreement under which Edison has an obligation to compensate SDG&E for the revenue requirement amounts that SDG&E will no longer recover because of the Revised Settlement Agreement. In exchange for Edison’s reimbursement, the parties mutually released each other from all claims that each party had or could have asserted related to the steam generator replacement failure and its aftermath. The Utility Shareholder Agreement became effective upon CPUC approval of the Revised Settlement Agreement. Edison’s payment obligation commenced in October 2018, and amounts are due to SDG&E quarterly thereafter until April 2022. At December 31, 2019 , SDG&E has a receivable from Edison, including accrued interest, totaling $86 million , with $38 million classified as current and $48 million classified as noncurrent. This receivable reflects amounts Edison is obligated to pay to SDG&E in lieu of amounts SDG&E would have collected from ratepayers associated with the SONGS regulatory asset. 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. We expect the majority of the dismantlement work to take 10 years after receipt of the required permits. The coastal development permit was issued in October 2019. The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019. The petition seeks to invalidate the permit and to obtain injunctive relief to stop decommissioning work. We expect major decommissioning work to begin in 2020, unless the court issues an injunction. 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% 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 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 SONGS decommissioning costs. SDG&E has filed for authorization with the CPUC to withdraw up to $109 million from the NDT for forecasted 2020 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. 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 timely 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. Nuclear Decommissioning Trusts The amounts collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the trusts are invested in accordance with CPUC regulations. These trusts are shown on the Sempra Energy and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. 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 12 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 57 $ — $ — $ 57 Municipal bonds (2) 270 12 — 282 Other securities (3) 218 9 (1 ) 226 Total debt securities 545 21 (1 ) 565 Equity securities 176 339 (6 ) 509 Cash and cash equivalents 8 — — 8 Total $ 729 $ 360 $ (7 ) $ 1,082 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 2020 - 2072 . 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) Years ended December 31, 2019 2018 2017 Proceeds from sales $ 914 $ 890 $ 1,314 Gross realized gains 24 42 157 Gross realized losses (5 ) (10 ) (14 ) 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 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 The present value of SDG&E’s ARO related to decommissioning costs for the SONGS units was $611 million at December 31, 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 . We expect SDG&E’s undiscounted SONGS decommissioning payments to be $89 million in 2020, $82 million in 2021, $83 million in 2022, $63 million in 2023, $46 million in 2024, and $739 million thereafter. 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 CCC 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. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018. It is unclear when Edison will pursue litigation claims for spent fuel management costs incurred on or after August 1, 2018. 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. 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.

ACQUISTIONS, DIVESTITURES AND D

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
ACQUISTIONS, 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 TTHC In February 2020, Sempra Texas Intermediate Holding Company LLC, acquired an additional indirect 0.2% interest in Oncor through its acquisition of a 1% interest in TTHC from Hunt Strategic Utility Investment, L.L.C., including notes receivable due from TTHC with an aggregate outstanding balance of approximately $5.5 million , for a total purchase price of approximately $23 million in cash, bringing Sempra Energy’s indirect ownership in Oncor to approximately 80.45% . TTHC owns 100% of TTI, which owns 19.75% of Oncor’s outstanding membership interests. Oncor Holdings In March 2018, Sempra Energy completed the acquisition of an indirect, 100% interest in Oncor Holdings, which owned 80.03% 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 in March 2018, in a separate transaction, Sempra Energy, through its interest in Oncor Holdings, acquired an additional 0.22% 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% . TTI continues to own 19.75% of Oncor’s outstanding membership interest. Pursuant to the Merger Agreement, the reorganized EFH (renamed Sempra Texas Holdings Corp.) merged with an indirect subsidiary of Sempra Energy, with Sempra Texas Holdings Corp. continuing as the surviving company and an indirect, wholly owned subsidiary of Sempra Energy. Sempra Texas Holdings Corp. wholly owns EFIH (renamed Sempra Texas Intermediate Holding Company LLC), which holds our 100% interest in Oncor Holdings. Other assets and liabilities unrelated to Oncor that were acquired with Sempra Texas Holdings Corp. have been subsumed into our parent organization, Parent and other. Due to ring-fencing measures, existing governance mechanisms and commitments in effect, we do not have the power to direct the significant activities of Oncor Holdings and Oncor. Consequently, we account for our 100% ownership interest in Oncor Holdings as an equity method investment. See Note 6 for additional information about our equity method investment in Oncor Holdings and related ring-fencing measures. I n anticipation of the Merger, in January 2018, we completed registered public offerings of our common stock (including shares offered pursuant to forward sale agreements), series A preferred stock and long-term debt, as we discuss in Notes 7, 13 and 14. These offerings provided total initial net proceeds of approximately $7.0 billion for partial funding of the Merger Consideration, of which approximately $800 million was used to pay down commercial paper, pending the closing of the Merger. In March 2018, to fund a portion of the Merger Consideration, we settled approximately $900 million (net of underwriting discounts of $16 million ) of forward sales under the forward sale agreements entered into in connection with the public offering of common stock in January 2018 by delivery of 8,556,630 shares of newly issued Sempra Energy common stock, as we discuss in Note 14. We raised the remaining portion of the Merger Consideration through issuances of approximately $2.6 billion in commercial paper with a weighted-average maturity of 47 days and a weighted-average interest rate of 2.2% per annum. The total purchase price paid was comprised of the following: • $9,450 million of Merger Consideration; • $31 million adjustment for dividends and payments pursuant to a tax sharing agreement with Oncor and Oncor Holdings; • $26 million paid in a separate transaction to acquire an additional 0.22% of the outstanding membership interests in Oncor from OMI; and • $59 million of transaction costs included in the basis of our investment in Oncor Holdings. We accounted for the Merger as an asset acquisition, as the equity method investment in Oncor Holdings represents substantially all of the fair value of the gross assets acquired. The following table sets forth the allocation of the total purchase price paid to the identifiable assets acquired and liabilities assumed. PURCHASE PRICE ALLOCATION (Dollars in millions) At March 9, 2018 (1) Assets acquired: Accounts receivable – other, net $ 1 Due from unconsolidated affiliates 46 Investment in Oncor Holdings 9,227 Deferred income tax assets 287 Other noncurrent assets 109 Total assets acquired 9,670 Liabilities assumed: Other current liabilities 23 Pension and other postretirement benefit plan obligations 21 Deferred credits and other 58 Total liabilities assumed 102 Net assets acquired $ 9,568 Total purchase price paid $ 9,568 (1) In the fourth quarter of 2018, we received additional information regarding deferred income taxes related to the resolution of claims in EFH’s emergence from bankruptcy as of the acquisition date. As a result, we recorded an adjustment to increase our investment in Oncor Holdings by $64 million , decrease deferred income tax assets by $66 million and decrease deferred credits and other liabilities by $2 million . Also in the fourth quarter of 2018, we recorded $2 million of additional purchase price paid related to additional transaction costs. The fair value of the equity method investment in Oncor Holdings is primarily attributable to Oncor’s business. Therefore, we considered the underlying assets and liabilities of Oncor when determining the fair value of our equity method investment. As a regulated entity, Oncor’s rates are set and approved by the PUCT, and are designed to recover the cost of providing service and the opportunity to earn a reasonable return on its investments. Accordingly, Oncor applies the guidance under the provisions of U.S. GAAP governing rate-regulated operations. Under U.S. GAAP, regulation is viewed as being a characteristic (restriction) of a regulated entity’s assets and liabilities, and the impact of regulation is considered a fundamental input to measuring the fair value of Oncor’s assets and liabilities. Under this premise, we concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. In May 2019, Oncor completed the acquisition of 100% of the issued and outstanding shares of InfraREIT and 100% of the limited partnership units of its subsidiary, InfraREIT Partners, LP, 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. 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 Sharyland Utilities, LP 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 Sharyland Utilities, LP), and Sharyland Utilities, LP 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, LP. Sharyland Holdings On May 16, 2019, Sempra Energy acquired an indirect, 50% interest in Sharyland Holdings for $95 million (net of $7 million in post-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% of the membership interests in Sharyland Utilities, LP and Sharyland Utilities, LP converted into a limited liability company, named Sharyland Utilities, L.L.C. We account for our interest in Sharyland Holdings as an equity method investment. Sempra Mexico Ductos y Energéticos del Norte, S. de R.L. de C.V. On November 15, 2017, IEnova completed the asset acquisition of PEMEX’s 50% interest in DEN, a JV that holds a 50% interest in the Los Ramones Norte pipeline through TAG JV, for a purchase price of $165 million (exclusive of $18 million of cash and cash equivalents acquired), plus the assumption of $96 million of short-term debt. This acquisition increased IEnova’s ownership interest in DEN through IEnova Pipelines from 50% to 100% , and increased IEnova’s indirect ownership interest in TAG JV from 25% to 50% . IEnova Pipelines previously accounted for its 50% interest in DEN as an equity method investment. At closing, DEN became a wholly owned, consolidated subsidiary of IEnova Pipelines. DEN will continue to account for its interest in TAG JV as an equity method investment. This acquisition also included a $66 million intangible asset that represents a favorable O&M agreement, which has an amortization period of 23 years . Sempra Renewables On July 10, 2017, Sempra Renewables paid $124 million in cash for an asset acquisition of a portfolio of four solar projects located in Fresno County, California, that were under construction. Completed in 2018, the facilities were sold to a subsidiary of Con Ed in December 2018, as we discuss below. Sempra South American Utilities Compañía Transmisora del Norte Grande S.A. On December 18, 2018, Chilquinta Energía acquired a 100% 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 our former Sempra South American Utilities segment, which is presented in discontinued operations. We accounted for this business combination using the acquisition method of accounting. At the acquisition date, we allocated the $208 million in cash paid to the identifiable assets acquired ( $231 million ) and liabilities assumed ( $43 million ) based on their respective fair values, with the excess recognized as goodwill ( $38 million ), which are included below in the “Assets Held for Sale in Discontinued Operations” table. We consider the purchase price allocation at the acquisition date to be final. 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, we recorded impairment charges totaling $1.5 billion ( $900 million after tax and NCI) in June 2018, which included $1.3 billion ( $755 million after tax and NCI) at Sempra LNG, included in Impairment Losses on Sempra Energy’s Consolidated Statements of Operations, and $200 million ( $145 million after tax) at Sempra Renewables, included in Equity Earnings on Sempra Energy’s Consolidated Statements of Operations. In December 2018, we reduced the impairment of $1.3 billion recorded at Sempra LNG in June 2018 by $183 million ( $126 million after tax and NCI) as a result of the sales agreement for certain storage assets described below, resulting in a total impairment charge of $1.1 billion ( $629 million after tax and NCI) for the year ended December 31, 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. Sempra Renewables On December 13, 2018, Sempra Renewables completed the sale of the following assets to a subsidiary of Con Ed for cash proceeds of $1.6 billion : ▪ its operating solar assets, including assets that we owned through JVs or through tax equity arrangements (other than those interests held by tax equity investors); ▪ its solar and battery storage development projects; and ▪ its 50% interest in the Broken Bow 2 wind generation facility. In 2018, we recognized a pretax gain of $513 million ( $367 million after tax) in Gain on Sale of Assets on Sempra Energy’s Consolidated Statement of Operations. The following table summarizes the deconsolidation of these subsidiaries in 2018. DECONSOLIDATION OF SUBSIDIARIES (Dollars in millions) Certain subsidiaries of Sempra Renewables At December 13, 2018 Proceeds from sale, net of transaction costs $ 1,585 Cash (7 ) Restricted cash (7 ) Other current assets (14 ) Property, plant and equipment, net (1,303 ) Other investments (329 ) Other long-term assets (24 ) Current liabilities 8 Long-term debt 70 Asset retirement obligations 52 Other long-term liabilities 5 Noncontrolling interests 486 Accumulated other comprehensive income (9 ) Gain on sale $ 513 On April 22, 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 Consolidated Statements of Operations. 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% interest in Chilquinta Energía in Chile, our 83.6% 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% 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 half 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% interest in Chilquinta Energía and Tecnored and our 50% 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% 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% 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% interest in Eletrans. We expect the sale to close in the first half of 2020. Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Years ended December 31, 2019 2018 2017 Revenues $ 1,614 $ 1,585 $ 1,567 Cost of sales (1,012 ) (1,041 ) (1,060 ) Operating expenses (159 ) (206 ) (202 ) Interest and other (11 ) (6 ) (2 ) Income before income taxes and equity earnings 432 332 303 Income tax expense (72 ) (145 ) (338 ) Equity earnings 3 1 4 Income (loss) from discontinued operations, net of income tax 363 188 (31 ) Earnings attributable to noncontrolling interests (35 ) (32 ) (27 ) Earnings (losses) from discontinued operations attributable to common shares $ 328 $ 156 $ (58 ) 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) December 31, 2019 2018 Cash and cash equivalents $ 74 $ 88 Restricted cash (1) 1 — Accounts receivable, net 303 315 Due from unconsolidated affiliates 2 2 Inventories 36 38 Other current assets 29 16 Current assets $ 445 $ 459 Due from unconsolidated affiliates $ 54 $ 44 Goodwill and other intangible assets 801 819 Property, plant and equipment, net 2,618 2,357 Other noncurrent assets 40 39 Noncurrent assets $ 3,513 $ 3,259 Short-term debt $ 52 $ 55 Accounts payable 201 176 Current portion of long-term debt and finance leases 85 29 Other current liabilities 106 108 Current liabilities $ 444 $ 368 Long-term debt and finance leases $ 702 $ 708 Deferred income taxes 284 250 Other noncurrent liabilities 66 55 Noncurrent liabilities $ 1,052 $ 1,013 (1) Primarily represents funds held in accordance with Peruvian tax law. At December 31, 2019 and 2018, $551 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	12 Months Ended
	Dec. 31, 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 Consolidated Statements of Operations. 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 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. See Note 8 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR. We provide the carrying values of our investments and earnings (losses) on these investments in the following tables. EQUITY METHOD AND OTHER INVESTMENT BALANCES (Dollars in millions) Percent ownership December 31, December 31, 2019 2018 2019 2018 Sempra Texas Utilities: Oncor Holdings (1) 100 % 100 % $ 11,519 $ 9,652 Sempra Texas Utilities: Sharyland Holdings (2) 50 — $ 100 $ — Sempra Mexico: Energía Sierra Juárez (3) 50 50 39 43 IMG JV (4) 40 40 337 328 TAG JV (5) 50 50 365 376 Sempra Renewables: Auwahi Wind — 50 — 38 Cedar Creek 2 Wind — 50 — 69 Flat Ridge 2 Wind (6) — 50 — 82 Fowler Ridge 2 Wind — 50 — 45 Mehoopany Wind (7) — 50 — 57 Sempra LNG: Cameron LNG JV (8) 50.2 50.2 1,256 1,271 Total other equity method investments 2,097 2,309 Other 6 11 Total other investments $ 2,103 $ 2,320 (1) The carrying value of our equity method investment is $2,823 million and $2,814 million higher than the underlying equity in the net assets of the investee at December 31, 2019 and 2018 , respectively, due to $2,868 million of equity method goodwill and $69 million in basis differences in AOCI, offset by $114 million at December 31, 2019 and $123 million at December 31, 2018 due to a tax sharing liability to TTI under the tax sharing agreement. (2) The carrying value of our equity method investment is $42 million higher than the underlying equity in the net assets of the investee due to equity method goodwill. (3) The carrying value of our equity method investment is $12 million higher than the underlying equity in the net assets of the investee due to the remeasurement of our retained investment to fair value in 2014. (4) The carrying value of our equity method investment is $5 million higher than the underlying equity in the net assets of the investee due to guarantees. (5) The carrying value of our equity method investment is $ 130 million higher than the underlying equity in the net assets of the investee due to equity method goodwill. (6) The carrying value of our equity method investment at December 31, 2018 was $169 million lower than the underlying equity in the net assets of the investee due to an other-than-temporary impairment recorded in 2018. (7) The carrying value of our equity method investment at December 31, 2018 was $31 million lower than the underlying equity in the net assets of the investee due to an other-than-temporary impairment recorded in 2018. (8) The carrying value of our equity method investment is $263 million and $246 million higher than the underlying equity in the net assets of the investee at December 31, 2019 and 2018 , respectively, primarily due to guarantees, which we discuss below, interest capitalized on the investment prior to the JV commencing its planned principal operations in August 2019 and amortization of guarantee fees and capitalized interest thereafter. EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2019 2018 2017 EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX (1) : Sempra Texas Utilities: Sharyland Holdings $ 2 $ — $ — Sempra Renewables: Wind: Auwahi Wind — 3 5 Broken Bow 2 Wind — (2 ) (2 ) Cedar Creek 2 Wind — (1 ) (2 ) Flat Ridge 2 Wind (2) (3 ) (178 ) (13 ) Fowler Ridge 2 Wind 5 3 4 Mehoopany Wind (2) 1 (30 ) (1 ) Solar: California solar partnership — 8 7 Copper Mountain Solar 2 — 5 5 Copper Mountain Solar 3 — 8 8 Mesquite Solar 1 — 18 18 Other 2 (3 ) — Sempra LNG: Cameron LNG JV 24 — 5 Parent and other: RBS Sempra Commodities (2) — (67 ) — Other (1 ) — — 30 (236 ) 34 EARNINGS (LOSSES) RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 526 371 — Sempra Mexico: DEN — — (13 ) Energía Sierra Juárez 2 2 — IMG JV 9 29 45 TAG JV 13 9 6 550 411 38 Total $ 580 $ 175 $ 72 (1) We provide our ETR calculation in Note 8. (2) Losses from equity method investment in 2018 include an other-than-temporary impairment charge, which we discuss below. We disclose distributions received from our investments, by segment, in the table below. DISTRIBUTIONS FROM INVESTMENTS (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Texas Utilities $ 246 $ 149 $ — Sempra Mexico 2 — — Sempra Renewables 1 63 65 Parent and other 7 — — Total 256 212 65 At December 31, 2019 and 2018 , our share of the undistributed earnings of equity method investments was $634 million and $332 million , respectively, including $501 million at December 31, 2019 in undistributed earnings from investments for which we have more than 50% equity interests. SEMPRA TEXAS UTILITIES Oncor Holdings As we discuss in Note 5 , on March 9, 2018, we completed the acquisition of an indirect, 100% interest in Oncor Holdings, which, at December 31, 2019, owns an 80.25% interest in Oncor. Sempra Energy does not control Oncor Holdings or Oncor, and the ring-fencing measures, governance mechanisms and commitments in effect limit our ability to direct the management, policies and operations of Oncor Holdings and Oncor, including the deployment or disposition of their assets, declarations of dividends, strategic planning and other important corporate issues and actions. We also have limited representation on the Oncor Holdings and Oncor boards of directors. As we do not have the power to direct the significant activities of Oncor Holdings and Oncor, we account for our 100% ownership interest in Oncor Holdings as an equity method investment. 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 summarized income statement and balance sheet information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Year ended December 31, 2019 March 9 - December 31, 2018 Operating revenues $ 4,347 $ 3,347 Operating expense (3,135 ) (2,434 ) Income from operations 1,212 913 Interest expense (375 ) (285 ) Income tax expense (131 ) (119 ) Net income 643 455 Noncontrolling interest held by TTI (129 ) (94 ) Earnings attributable to Sempra Energy 514 360 At December 31, 2019 2018 Current assets $ 913 $ 772 Noncurrent assets 26,012 21,980 Current liabilities 1,626 2,217 Noncurrent liabilities 14,125 11,756 Noncontrolling interest held by TTI 2,473 1,951 In 2019, we contributed cash of $1,587 million to Oncor, including $1,067 million to fund Oncor’s May 2019 acquisition of interests in InfraREIT and certain acquisition-related expenses. In 2018, we contributed $230 million in cash to Oncor in accordance with the terms of the Merger Agreement, which enabled Oncor to achieve its required capital structure calculated for regulatory purposes. In 2019 and 2018, Oncor Holdings distributed to Sempra Energy $246 million and $149 million , respectively, in dividends and $10 million and $18 million , respectively, in tax sharing payments. Sharyland Holdings As we discuss in Note 5 , on May 16, 2019, we acquired an indirect, 50% interest in Sharyland Holdings, which owns a 100% interest in Sharyland Utilities, for $95 million , net of $7 million in post-closing adjustments, which we account for as an equity method investment. In 2019, we invested cash of $3 million in Sharyland Holdings. SEMPRA MEXICO IMG JV IEnova has a 40% interest in IMG JV, a JV with a subsidiary of TC Energy, and accounts for its interest as an equity method investment. IMG JV owns and operates the Sur de Texas-Tuxpan natural gas marine pipeline, which is fully contracted under a 35 -year natural gas transportation service contract with the CFE and commenced commercial operation in September 2019. In 2018 and 2017, Sempra Mexico invested cash of $80 million and $72 million , respectively, in IMG JV. DEN and TAG JV On November 15, 2017, IEnova acquired the remaining 50% interest in DEN, and DEN became a consolidated subsidiary. Since the acquisition date, IEnova accounts for DEN’s 50% interest in TAG JV as an equity method investment. We discuss this acquisition in Note 5 . SEMPRA RENEWABLES As a result of the plan of sale, Sempra Renewables recorded an other-than-temporary impairment on certain of our wind equity method investments totaling $200 million in 2018, which is included in Equity Earnings on Sempra Energy’s Consolidated Statement of Operations. Sempra Renewables completed the sales of all its operating solar assets, including its solar equity method investments and one wind equity method investment, in December 2018 and its remaining wind assets and investments in April 2019. We discuss these divestitures further in Note 5 . In 2018, Sempra Renewables invested cash of $5 million in its unconsolidated JVs. SEMPRA LNG Cameron LNG JV Cameron LNG JV was formed in October 2014 among Sempra Energy and three project partners, TOTAL S.A., Mitsui & Co., Ltd., and Japan LNG Investment, LLC, a company jointly owned by Mitsubishi Corporation and Nippon Yusen Kabushiki Kaisha. We account for our 50.2% investment in Cameron LNG JV under the equity method. Cameron LNG JV is constructing a three-train natural gas liquefaction export facility with a nameplate capacity of 13.9 Mtpa of LNG, with an expected export capability of 12 Mtpa of LNG, or approximately 1.7 Bcf per day. In August 2019, the first of three trains commenced commercial operation under the JV’s tolling agreements. Prior to commencing commercial operation, Sempra LNG capitalized interest of $33 million in 2019 and $47 million in each of 2018 and 2017 related to this equity method investment. In 2019, 2018 and 2017, Sempra LNG invested cash of $77 million , $228 million and $1 million , respectively, in Cameron LNG JV. Cameron LNG JV Financing General. In August 2014, Cameron LNG JV entered into finance documents (collectively, Loan Facility Agreements) for senior secured financing in an initial aggregate principal amount of up to $7.4 billion under three debt facilities provided by the Japan Bank for International Cooperation (JBIC) and 29 international commercial banks, some of which will benefit from insurance coverage provided by Nippon Export and Investment Insurance (NEXI). The Loan Facility Agreements and related finance documents provide senior secured term loans with a maturity date of July 15, 2030. The proceeds of the loans are being used for financing the cost of development and construction of the three-train Cameron LNG project. The Loan Facility Agreements and related finance documents contain customary representations and affirmative and negative covenants for project finance facilities of this kind with the lenders of the type participating in the Cameron LNG JV financing. In December 2019, Cameron LNG JV refinanced $3.0 billion of the uncovered bank facility portion of the Loan Facility Agreements in a private placement bond offering. The newly issued senior secured notes bear interest at a fixed weighted-average rate of 3.39% and have a weighted-average tenor of 15.4 years at December 31, 2019. Interest. The weighted-average all-in cost of the loans that remain outstanding under the original Loan Facility Agreements (and based on certain assumptions as to timing of drawdown) is 0.98% per annum over LIBOR prior to financial completion of the project and 1.22% per annum over LIBOR following financial completion of the project. The original Loan Facility Agreements required Cameron LNG JV to hedge 50% of outstanding borrowings to fix the interest rate, beginning in 2016. The hedges are to remain in place until the debt principal has been amortized by 50% . In November 2014, Cameron LNG JV entered into floating-to-fixed interest rate swaps for approximately $3.7 billion notional amount, resulting in an effective fixed rate of 3.19% for the LIBOR component of the interest rate on the loans. In June 2015, Cameron LNG JV entered into additional floating-to-fixed interest rate swaps effective starting in 2020, for approximately $1.5 billion notional amount, resulting in an effective fixed rate of 3.32% for the LIBOR component of the interest rate on the loans. In December 2019, approximately $790 million of the $1.5 billion notional amount was terminated as a result of the refinancing, resulting in an effective fixed rate of 3.26% for the LIBOR component of the interest rate on the remaining loans outstanding. The weighted-average all-in cost of the loans outstanding under the original Loan Facility Agreements and the newly issued senior secured notes is 3.72% . Guarantees. In August 2014 and December 2019, Sempra Energy entered into agreements for the benefit of all of Cameron LNG JV’s creditors under the original Loan Facility Agreements and the newly issued senior secured notes, respectively. Pursuant to these agreements, Sempra Energy has severally guaranteed 50.2% of Cameron LNG JV’s obligations under the original Loan Facility Agreements and the newly issued senior secured notes, or a maximum amount of $4.0 billion . Guarantees for the remaining 49.8% of Cameron LNG JV’s senior secured financing have been provided by the other project owners. Sempra Energy’s agreements and guarantees will terminate upon financial completion of the three-train Cameron LNG project, which is subject to satisfaction of certain conditions, including all three trains achieving commercial operations and meeting certain operational performance tests. We expect the project to achieve financial completion and the guarantees to be terminated approximately nine months after all three trains achieve commercial operation. Sempra Energy recorded a liability of $82 million in October 2014 for the fair value of its obligations associated with the original Loan Facility Agreements, which constitute guarantees. This liability was fully amortized at December 31, 2019. Sempra Energy recorded a liability of $3 million in December 2019 for the fair value of its obligations associated with Cameron LNG JV’s newly issued senior secured notes, which also constitute guarantees. This liability will be reduced on a straight-line basis over the duration of the guarantees by increasing our investment in Cameron LNG JV. In August 2014, Sempra Energy and the other project owners entered into a transfer restrictions agreement with Société Générale, as intercreditor agent for the lenders under the Loan Facility Agreements. Pursuant to the transfer restriction agreement, Sempra Energy agreed to certain restrictions on its ability to dispose of Sempra Energy’s indirect fully diluted economic and beneficial ownership interests in Cameron LNG JV. These restrictions vary over time. Prior to financial completion of the three-train Cameron LNG project, Sempra Energy must retain 37.65% of such interest in Cameron LNG JV. Starting six months after financial completion of the three-train Cameron LNG project, Sempra Energy must retain at least 10% of the indirect fully diluted economic and beneficial ownership interest in Cameron LNG JV. In addition, at all times, a Sempra Energy controlled (but not necessarily wholly owned) subsidiary must directly own 50.2% of the membership interests of Cameron LNG JV. Events of Default. Cameron LNG JV’s Loan Facility Agreements and related finance documents contain events of default customary for such financings, including events of default for: failure to pay principal and interest on the due date; insolvency of Cameron LNG JV; abandonment of the project; expropriation; unenforceability or termination of the finance documents; and a failure to achieve financial completion of the project by a financial completion deadline date of September 30, 2021 (with up to an additional 365 days extension beyond such date permitted in cases of force majeure). A delay in construction that results in a failure to achieve financial completion of the project by this financial completion deadline date would therefore result in an event of default under Cameron LNG JV’s financing and a potential demand on Sempra Energy’s guarantees. Security. To support Cameron LNG JV’s obligations under its debt agreements, Cameron LNG JV has granted security over all of its assets, subject to customary exceptions, and all equity interests in Cameron LNG JV have been pledged to HSBC Bank USA, National Association, as security trustee for the benefit of all of Cameron LNG JV’s creditors. As a result, an enforcement action by the lenders taken in accordance with the finance documents could result in the exercise of such security interests by the lenders and the loss of ownership interests in Cameron LNG JV by Sempra Energy and the other project partners. The security trustee under Cameron LNG JV’s financing can demand that a payment be made by Sempra Energy under its guarantees of Sempra Energy’s 50.2% share of senior debt obligations due and payable either on the date such amounts were due from Cameron LNG JV (taking into account cure periods) in the event of a failure by Cameron LNG JV to pay such senior debt obligations when they become due or within 10 business days in the event of an acceleration of senior debt obligations under the terms of the finance documents. If an event of default occurs under the Sempra Energy completion agreement, the security trustee can demand that Sempra Energy purchase its 50.2% share of all then outstanding senior debt obligations within five business days (other than in the case of a bankruptcy default, which is automatic). RBS SEMPRA COMMODITIES RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra Energy and RBS in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra Energy. We and RBS sold substantially all of the partnership’s businesses and assets in four separate transactions completed in 2010 and 2011. Since 2011, our investment balance has reflected our share of the remaining partnership assets, including amounts retained by the partnership to help offset unanticipated future general and administrative costs necessary to complete the dissolution of the partnership and the distribution of the partnership’s remaining assets, if any. We account for our investment in RBS Sempra Commodities under the equity method. 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 Consolidated Statement of Operations. We discuss matters related to RBS Sempra Commodities further in “Other Litigation” in Note 16 . SUMMARIZED FINANCIAL INFORMATION We present summarized financial information below, aggregated for all other equity method investments (excluding Oncor Holdings) for the periods in which we were invested in the entities. The amounts below represent the results of operations and aggregate financial position of 100% of each of Sempra Energy’s other equity method investments. SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2019 (1) 2018 (2) 2017 (3) Gross revenues $ 798 $ 706 $ 833 Operating expense (372 ) (609 ) (585 ) Income from operations 426 97 248 Interest expense (401 ) (322 ) (219 ) Net income (loss)/Earnings (losses) (4) 85 (36 ) 108 At December 31, 2019 (1) 2018 (2) Current assets $ 1,124 $ 564 Noncurrent assets 15,039 14,558 Current liabilities 1,232 801 Noncurrent liabilities 11,438 9,966 (1) On April 22, 2019, Sempra Renewables sold its remaining wind assets and investments to AEP. As of April 22, 2019, these wind assets and investments are no longer equity method investments. (2) On December 13, 2018, Sempra Renewables sold all its operating solar assets, including its solar equity method investments, and its 50 % interest in the Broken Bow 2 wind power generation facility to a subsidiary of Con Ed. As of December 13, 2018, the solar equity method investments and Broken Bow 2 are no longer equity method investments. (3) On November 15, 2017, IEnova completed the asset acquisition of PEMEX’s 50 % interest in DEN, increasing its ownership percentage to 100% . As of November 15, 2017, DEN is no longer an equity method investment. (4) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

DEBT AND CREDIT FACILITIES

DEBT AND CREDIT FACILITIES	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Debt and Credit Facilities	DEBT AND CREDIT FACILITIES LINES OF CREDIT Primary U.S. Committed Lines of Credit At December 31, 2019, Sempra Energy Consolidated had an aggregate of $6.7 billion in four primary U.S. committed lines of credit, which provide liquidity and support commercial paper. PRIMARY U.S. COMMITTED LINES OF CREDIT (Dollars in millions) At December 31, 2019 Total facility Commercial paper outstanding (1) Available unused credit Sempra Energy (2) $ 1,250 $ — 1,250 Sempra Global (3) 3,185 (1,624 ) 1,561 SDG&E (3)(4) 1,500 (80 ) 1,420 SoCalGas (3)(4) 750 (630 ) 120 Total $ 6,685 $ (2,334 ) $ 4,351 (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 December 31, 2019 . (3) Commercial paper outstanding is before reductions of unamortized discount of $3 million at Sempra Global and negligible amounts at SDG&E and SoCalGas. (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 December 31, 2019 . The principal terms of the primary U.S. committed lines of credit in the table above include the following: ▪ Each is a 5-year syndicated revolving credit agreement expiring in May 2024. ▪ Citibank N.A. serves as administrative agent for the Sempra Energy and Sempra Global facilities and JPMorgan Chase Bank, N.A. serves as administrative agent for the SDG&E and SoCalGas facilities. ▪ Each facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in any facility. ▪ Borrowings bear interest at benchmark rates plus a margin that varies with Sempra Energy’s credit ratings in the case of the Sempra Energy and Sempra Global lines of credit, and with the borrowing utility’s credit rating in the case of SDG&E’s and SoCalGas’ lines of credit. ▪ 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% at the end of each quarter. At December 31, 2019 , each entity was in compliance with this ratio and all other financial covenants under its respective credit facility. ▪ Sempra Energy guarantees Sempra Global’s obligations under its credit facility. Foreign Committed Lines of Credit Our foreign operations in Mexico have additional general-purpose credit facilities aggregating $1.9 billion at December 31, 2019. The principal terms of these credit facilities are described below . FOREIGN COMMITTED LINES OF CREDIT (U.S. dollar equivalent in millions) December 31, 2019 Expiration date of facility Total facility Amounts outstanding Available unused credit February 2024 (1) $ 1,500 $ (894 ) $ 606 April 2022 (2) 100 — 100 September 2021 (3) 280 (280 ) — Total $ 1,880 $ (1,174 ) $ 706 (1) Five-year revolving credit facility with a syndicate of 10 lenders. (2) Three-year revolving credit facility with Scotiabank Inverlat, S.A. Withdrawals may be made for up to one year from April 11, 2019 in either U.S. dollars or Mexican pesos. (3) Two-year revolving credit facility with The Bank of Nova Scotia. Withdrawals may be made for up to two years from September 23, 2019 in U.S. dollars. 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 December 31, 2019 , we had approximately $647 million in standby letters of credit outstanding under these agreement s. WEIGHTED-AVERAGE INTEREST RATES The weighted-average interest rates on the total short-term debt at December 31, 2019 and 2018 were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2019 2018 Sempra Energy Consolidated 2.31 % 2.99 % SDG&E 1.97 2.97 SoCalGas 1.86 2.58 LONG-TERM DEBT The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2019 2018 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ 350 $ 350 1.914% payable 2015 through February 2022 89 125 3.6% September 1, 2023 450 450 2.5% May 15, 2026 500 500 6% June 1, 2026 250 250 5.875% January and February 2034 (1) 176 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039 (1) 75 75 6% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.5% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.3% April 1, 2042 250 250 3.75% June 1, 2047 400 400 4.15% May 15, 2048 400 400 4.1% June 15, 2049 400 — 5,140 4,776 Other long-term debt: OMEC LLC variable-rate loan (4.7896% at December 31, 2018 except for $142 at 5.2925% after floating-to-fixed rate swaps through April 1, 2019), payable 2019 through 2024 (collateralized by OMEC plant assets) — 220 Finance lease obligations: Purchased-power contracts 1,255 1,270 Other 15 2 1,270 1,492 6,410 6,268 Current portion of long-term debt (56 ) (81 ) Unamortized discount on long-term debt (12 ) (12 ) Unamortized debt issuance costs (36 ) (37 ) Total SDG&E 6,306 6,138 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 500 500 3.2% June 15, 2025 350 350 2.6% June 15, 2026 500 500 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 4.125% June 1, 2048 400 400 4.3% January 15, 2049 550 550 3.95% February 15, 2050 350 — 3,800 3,450 Other long-term debt (uncollateralized): 1.875% Notes May 14, 2026 (1) 4 4 5.67% Notes January 18, 2028 5 5 Finance lease obligations 19 3 28 12 3,828 3,462 Current portion of long-term debt (6 ) (3 ) Unamortized discount on long-term debt (7 ) (6 ) Unamortized debt issuance costs (27 ) (26 ) Total SoCalGas 3,788 3,427 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2019 2018 Sempra Energy: Other long-term debt (uncollateralized): 9.8% Notes February 15, 2019 — 500 Notes at variable rates (2.69% at December 31, 2018) July 15, 2019 — 500 1.625% Notes October 7, 2019 — 500 2.4% Notes February 1, 2020 500 500 2.4% Notes March 15, 2020 500 500 2.85% Notes November 15, 2020 400 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) 700 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 850 850 2.875% Notes October 1, 2022 500 500 2.9% Notes February 1, 2023 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 350 3.25% Notes June 15, 2027 750 750 3.4% Notes February 1, 2028 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 6% Notes October 15, 2039 750 750 4% Notes February 1, 2048 800 800 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 — Build-to-suit arrangement (2) — 138 Sempra Mexico Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 207 198 Notes at variable rates (4.88% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets 237 275 3.75% Notes January 14, 2028 300 300 Bank loans including $241 at a weighted-average fixed rate of 6.87%, $147 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $35 at variable rates (5.12% at December 31, 2019), payable 2016 through March 2032, collateralized by plant assets 423 447 4.875% Notes January 14, 2048 540 540 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) 11 4 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 — Sempra LNG Other long-term debt (uncollateralized): Notes at 2.87% to 3.51% October 1, 2026 (1) 22 21 12,298 13,023 Current portion of long-term debt (1,464 ) (1,560 ) Unamortized discount on long-term debt (35 ) (38 ) Unamortized debt issuance costs (108 ) (87 ) Total other Sempra Energy 10,691 11,338 Total Sempra Energy Consolidated $ 20,785 $ 20,903 (1) Callable long-term debt not subject to make-whole provisions. (2) This arrangement is now accounted for as an operating lease liability upon adoption of the lease standard on January 1, 2019. See Note 2. MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Sempra Energy Total Sempra Energy Consolidated 2020 $ 36 $ — $ 1,465 $ 1,501 2021 386 — 1,619 2,005 2022 18 — 576 594 2023 450 — 1,285 1,735 2024 — 500 545 1,045 Thereafter 4,250 3,309 6,808 14,367 Total $ 5,140 $ 3,809 $ 12,298 $ 21,247 (1) Excludes finance lease obligations, discounts, and debt issuance costs. Various long-term obligations totaling $11.6 billion at Sempra Energy Consolidated at December 31, 2019 are unsecured. This includes unsecured long-term obligations totaling $9 million at SoCalGas. There were no unsecured long-term obligations at SDG&E. Callable Long-Term Debt At the option of Sempra Energy, SDG&E and SoCalGas, certain debt at December 31, 2019 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ 251 $ 4 $ 1,691 $ 1,946 Subject to make-whole provisions 4,889 3,800 9,097 17,786 First Mortgage Bonds The California Utilities issue first mortgage bonds secured by a lien on utility plant assets. The California Utilities may issue additional first mortgage bonds if in compliance with the provisions of their bond agreements (indentures). These indentures require, among other things, the satisfaction of pro forma earnings-coverage tests on first mortgage bond interest and the availability of sufficient mortgaged property to support the additional bonds, after giving effect to prior bond redemptions. The most restrictive of these tests (the property test) would permit the issuance, subject to CPUC authorization, of additional first mortgage bonds of $6.4 billion at SDG&E and $1.3 billion at SoCalGas at December 31, 2019 . SDG&E In May 2019, SDG&E issued $400 million of 4.1 % first mortgage bonds maturing in 2049. We received proceeds of $396 million (net of debt discount, 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. SoCalGas In June 2019, SoCalGas issued $350 million of 3.95 % first mortgage bonds maturing in 2050. We received proceeds of $345 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million ). SoCalGas used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. In January 2020, SoCalGas issued $650 million of 2.55% first mortgage bonds maturing in 2030. We received proceeds of $643 million (net of debt discount, underwriting discounts and debt issuance costs of $7 million ). SoCalGas used the proceeds from the offering to repay outstanding commercial paper and for other general corporate purposes. Other Long-Term Debt Sempra Energy In June 2019, we issued $758 million of 5.75 %, junior subordinated notes maturing in 2079, with a par value of $25 per note. We received proceeds of $733 million (net of underwriting discounts and debt issuance costs of $25 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% 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% 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% 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. Sempra Mexico In November 2019, IEnova entered into a loan agreement with International Finance Corporation and North American Development Bank and, in December 2019, received proceeds of $190 million (net of debt issuance costs of $10 million ) to fund the construction of certain solar generation projects in Mexico. The 15 -year loan bears interest based on 6-month LIBOR plus 2.25% and matures in 2034. In November 2019, IEnova entered into a floating-to-fixed interest rate swap to hedge interest payments on the $200 million variable rate loan, resulting in an all-in fixed rate of 4.03% .

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXES We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Income tax expense (benefit) from continuing operations $ 315 $ (49 ) $ 938 Income from continuing operations before income taxes and equity earnings $ 1,734 $ 714 $ 1,248 Equity earnings (losses), before income tax (1) 30 (236 ) 34 Pretax income $ 1,764 $ 478 $ 1,282 Effective income tax rate 18 % (10 )% 73 % SDG&E: Income tax expense $ 171 $ 173 $ 155 Income before income taxes $ 945 $ 849 $ 576 Effective income tax rate 18 % 20 % 27 % SoCalGas: Income tax expense $ 120 $ 92 $ 160 Income before income taxes $ 762 $ 493 $ 557 Effective income tax rate 16 % 19 % 29 % (1) We discuss how we recognize equity earnings in Note 6 . 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 ▪ state income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico has similar flow-through treatment. We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Such effects are partially mitigated by net gains (losses) from foreign currency derivatives that are hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova. We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: U.S. federal statutory income tax rate 21 % 21 % 35 % Foreign exchange and inflation effects (1) 4 6 4 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (2) 3 10 (2 ) Utility depreciation 3 12 7 State income taxes, net of federal income tax benefit 2 (8 ) 1 Effects of the TCJA — 9 48 Compensation-related items — 3 — Unrecognized income tax benefits — 4 — Noncontrolling interests in tax equity arrangements — 3 1 Resolution of prior years’ income tax items — (1 ) (3 ) Impairment losses at Sempra LNG — (32 ) — Allowance for equity funds used during construction (1 ) (4 ) (4 ) Amortization of excess deferred income taxes (1 ) (4 ) — Tax credits (2 ) (10 ) (4 ) Utility self-developed software expenditures (2 ) (7 ) (5 ) Utility repairs expenditures (3 ) (13 ) (7 ) Excess deferred income taxes outside of ratemaking (4 ) — — Other, net (2 ) 1 2 Effective income tax rate 18 % (10 )% 73 % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 35 % State income taxes, net of federal income tax benefit 6 5 3 Depreciation 3 3 7 Effects of the TCJA — — 5 Resolution of prior years’ income tax items — — (4 ) Allowance for equity funds used during construction (1 ) (2 ) (4 ) Amortization of excess deferred income taxes (1 ) (1 ) — Repairs expenditures (3 ) (3 ) (8 ) Self-developed software expenditures (3 ) (2 ) (6 ) Excess deferred income taxes outside of ratemaking (3 ) — — Other, net (1 ) (1 ) (1 ) Effective income tax rate 18 % 20 % 27 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 35 % Depreciation 4 7 9 State income taxes, net of federal income tax benefit 4 2 3 Unrecognized income tax benefits — 4 — Compensation-related items — 1 — Resolution of prior years’ income tax items — (1 ) (2 ) Allowance for equity funds used during construction (1 ) (2 ) (3 ) Amortization of excess deferred income taxes (1 ) (2 ) — Self-developed software expenditures (2 ) (3 ) (5 ) Repairs expenditures (4 ) (7 ) (8 ) Excess deferred income taxes outside of ratemaking (5 ) — — Other, net — (1 ) — Effective income tax rate 16 % 19 % 29 % (1) Due to fluctuation of the Mexican peso against the U.S. dollar. We record income tax expense (benefit) from the transactional effects of foreign currency and inflation because of appreciation (depreciation) of the Mexican peso. We also recognize gains (losses) in Other Income, Net, on the Consolidated Statements of Operations from foreign currency derivatives that are partially hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova. (2) Related to operations in Mexico. In December 2017, the TCJA was signed into law. This legislation significantly changed the IRC. The TCJA reduced the U.S. statutory corporate income tax rate from 35% to 21% , effective January 1, 2018. Deferred income tax assets and liabilities, including NOLs, were remeasured at the income tax rate expected to apply when those temporary differences reverse. The effects of the change to the income tax rate were recognized in the period when the change was enacted. This remeasurement resulted in significant reductions in deferred income tax balances at Sempra Energy Consolidated, SDG&E and SoCalGas in 2017. The remeasurement of deferred income tax balances at SDG&E and SoCalGas resulted in excess deferred income taxes that previously have been collected from ratepayers at the higher rate. As we discuss in Note 4, these excess deferred income taxes have been recorded as regulatory liabilities and will generally be refunded to ratepayers in accordance with the IRC’s normalization provisions and as determined by the CPUC and the FERC. In a January 2019 decision, the CPUC directed certain excess deferred income tax balances generated by activities outside of ratemaking be allocated to shareholders rather than ratepayers. As a result, SDG&E and SoCalGas recorded income tax benefits of $31 million and $38 million , respectively, from the release of a portion of the regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances. The TCJA imposed a one-time tax for deemed repatriation of cumulative undistributed earnings of non-U.S. subsidiaries. In addition to the deemed repatriation tax, we accrued U.S. state and non-U.S. withholding tax on our expected future repatriation of foreign undistributed earnings. We recorded the effects of the TCJA in 2017 using our best estimates and the information available to us through the date those financial statements were issued. In 2018, we adjusted our 2017 provisional estimates and completed our accounting for the income tax effects of the TCJA. The table below summarizes the effects of the TCJA in 2018 and 2017: EFFECTS OF THE TAX CUTS AND JOBS ACT OF 2017 (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2018: Consolidated Balance Sheets: Increase (decrease) in net deferred income tax liabilities due to remeasurement $ 16 $ (38 ) $ 5 Increase (decrease) in net regulatory liabilities from remeasurement of deferred income tax assets and liabilities $ 33 $ 38 $ (5 ) Consolidated Statements of Operations: Income tax expense related to remeasurement of deferred income tax assets and liabilities $ 49 $ — $ — Income tax benefit related to deemed repatriation (8 ) — — Total increase in income tax expense $ 41 $ — $ — 2017: Consolidated Balance Sheets: Decrease in net deferred income tax liabilities due to remeasurement $ (2,220 ) $ (1,400 ) $ (972 ) Increase in net regulatory liabilities from remeasurement of deferred income tax assets and liabilities $ 2,402 $ 1,428 $ 974 Consolidated Statements of Operations: Income tax expense related to remeasurement of deferred income tax assets and liabilities $ 182 $ 28 $ 2 Income tax expense related to deemed repatriation 328 — — U.S. state and non-U.S. withholding tax expense related to expected future repatriation of foreign earnings 109 — — Total increase in income tax expense $ 619 $ 28 $ 2 In January 2019, our board of directors approved a plan to sell our South American businesses, as we discuss in Note 5. Prior to this decision, our repatriation estimate excluded post-2017 earnings and other basis differences related to our South American businesses. Because of our decision to sell our South American businesses, we no longer assert indefinite reinvestment of these basis differences and have recorded the following in discontinued operations in the year ended December 31, 2019: ▪ $89 million income tax benefit primarily related to outside basis differences existing as of the January 25, 2019 approval of our plan to sell our South American businesses; and ▪ $51 million income tax expense related to the increase in outside basis differences from 2019 earnings since January 25, 2019. We expect to repatriate approximately $4 billion of foreign undistributed earnings in the foreseeable future, and have accrued $157 million of U.S. state deferred income tax liability for repatriations that we expect will begin in 2020 as cash is generated. In 2019 and 2018, we repatriated approximately $254 million and $338 million , respectively, to the U.S. We have not recorded deferred income taxes with respect to remaining basis differences of approximately $600 million between financial statement and income tax investment amounts in our non-U.S. subsidiaries because we consider them to be indefinitely reinvested as of December 31, 2019. The remaining basis differences are calculated pursuant to U.S. federal tax law, which may differ from tax law in California and foreign jurisdictions. It is currently not practicable to determine the hypothetical amount of tax that might be payable if the underlying basis differences were realized. The table below presents the geographic components of pretax income. PRETAX INCOME – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Years ended December 31, 2019 2018 2017 By geographic components: U.S. $ 1,191 $ (102 ) $ 878 Non-U.S. 573 580 404 Total (1) $ 1,764 $ 478 $ 1,282 (1) See “Income Tax Expense (Benefit) and Effective Income Tax Rates” table above for calculation of pretax income. U.S. pretax income was lower in 2018 compared to 2019 and 2017 due to the 2018 impairment of certain assets at Sempra LNG and Sempra Renewables (discussed in Notes 5 and 12), offset by the 2018 gain on the sale of assets at Sempra Renewables (discussed in Note 5) and the 2017 write-off of SDG&E’s wildfire regulatory asset (discussed in Note 16). The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Current: U.S. federal $ — $ (1 ) $ 4 U.S. state (14 ) 67 — Non-U.S. 140 127 45 Total 126 193 49 Deferred: U.S. federal 87 (121 ) 566 U.S. state 21 (183 ) 154 Non-U.S. 84 66 169 Total 192 (238 ) 889 Deferred investment tax credits (3 ) (4 ) — Total income tax expense (benefit) $ 315 $ (49 ) $ 938 SDG&E: Current: U.S. federal $ 35 $ 104 $ 100 U.S. state 31 30 65 Total 66 134 165 Deferred: U.S. federal 75 17 29 U.S. state 32 24 (41 ) Total 107 41 (12 ) Deferred investment tax credits (2 ) (2 ) 2 Total income tax expense $ 171 $ 173 $ 155 SoCalGas: Current: U.S. federal $ 8 $ 4 $ — U.S. state 24 10 23 Total 32 14 23 Deferred: U.S. federal 79 78 144 U.S. state 10 2 (5 ) Total 89 80 139 Deferred investment tax credits (1 ) (2 ) (2 ) Total income tax expense $ 120 $ 92 $ 160 The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) December 31, 2019 2018 Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 4,052 $ 3,517 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 153 382 Regulatory balancing accounts 468 359 Right-of-use assets – operating leases 131 — Property taxes 44 41 Other deferred income tax liabilities 93 133 Total deferred income tax liabilities 4,941 4,432 Deferred income tax assets: Tax credits 1,136 1,114 Net operating losses 911 723 Postretirement benefits 200 261 Compensation-related items 161 170 Operating lease liabilities 131 — Other deferred income tax assets 72 82 Accrued expenses not yet deductible 52 66 Deferred income tax assets before valuation allowances 2,663 2,416 Less: valuation allowances 144 164 Total deferred income tax assets 2,519 2,252 Net deferred income tax liability (2) $ 2,422 $ 2,180 (1) In addition to the financial over tax basis differences in fixed assets, the amount also includes financial over tax basis differences in various interests in partnerships and certain subsidiaries. (2) At December 31, 2019 and 2018, includes $155 million and $141 million , respectively, recorded as a noncurrent asset and $2,577 million and $2,321 million , respectively, recorded as a noncurrent liability on the Consolidated Balance Sheets. DEFERRED INCOME TAXES – SDG&E AND SOCALGAS (Dollars in millions) SDG&E SoCalGas December 31, December 31, 2019 2018 2019 2018 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 1,735 $ 1,578 $ 1,246 $ 1,077 Regulatory balancing accounts 141 84 327 283 Right-of-use assets – operating leases 32 — 22 — Property taxes 30 29 14 13 Other 14 10 1 2 Total deferred income tax liabilities 1,952 1,701 1,610 1,375 Deferred income tax assets: Tax credits 6 6 3 3 Postretirement benefits 37 58 120 140 Compensation-related items 6 5 25 25 Operating lease liabilities 32 — 22 — State income taxes 7 6 8 3 Accrued expenses not yet deductible 9 4 15 13 Other 7 6 14 14 Total deferred income tax assets 104 85 207 198 Net deferred income tax liability $ 1,848 $ 1,616 $ 1,403 $ 1,177 The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2019 Year expiration begins Sempra Energy Consolidated: U.S. federal: NOLs (1) $ 3,475 2031 General business tax credits (1) 433 2032 Foreign tax credits (2) 624 2024 U.S. state (2) : NOLs 3,025 2020 General business tax credits 90 2020 Non-U.S. (2) – NOLs 115 2020 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as discussed below. A valuation allowance is recorded when, based on more-likely-than-not criteria, negative evidence outweighs positive evidence with regard to our ability to realize a deferred income tax asset in the future. Of the valuation allowances recorded to date, the negative evidence outweighs the positive evidence primarily due to cumulative pretax losses in various U.S. state and non-U.S. jurisdictions resulting in deferred income tax assets that we currently do not believe will be realized on a more-likely-than-not basis. The following table provides the valuation allowances that we recorded against a portion of our total deferred income tax assets shown above in the “Deferred Income Taxes – Sempra Energy Consolidated” table. VALUATION ALLOWANCES (Dollars in millions) December 31, 2019 2018 Sempra Energy Consolidated: U.S. federal $ 90 $ 109 U.S. state 33 35 Non-U.S. 21 20 $ 144 $ 164 Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31: RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2019 2018 2017 Sempra Energy Consolidated: Balance at January 1 $ 119 $ 89 $ 90 Increase in prior period tax positions 5 7 22 Decrease in prior period tax positions — (1 ) (15 ) Increase in current period tax positions 2 24 4 Settlements with taxing authorities (32 ) — (12 ) Expiration of statutes of limitations (1 ) — — Balance at December 31 $ 93 $ 119 $ 89 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (81 ) $ (107 ) $ (77 ) increase the effective tax rate (1) 27 24 20 SDG&E: Balance at January 1 $ 11 $ 10 $ 22 Increase in prior period tax positions 1 1 9 Decrease in prior period tax positions — — (11 ) Settlements with taxing authorities — — (10 ) Balance at December 31 $ 12 $ 11 $ 10 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (9 ) $ (9 ) $ (7 ) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 61 $ 35 $ 29 Increase in prior period tax positions 1 2 3 Increase in current period tax positions 2 24 4 Settlements with taxing authorities — — (1 ) Balance at December 31 $ 64 $ 61 $ 35 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (55 ) $ (51 ) $ (26 ) increase the effective tax rate (1) 26 23 20 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above. It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) At December 31, 2019 2018 2017 Sempra Energy Consolidated: Expiration of statutes of limitations on tax assessments $ — $ (1 ) $ — Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities (8 ) (40 ) (8 ) $ (8 ) $ (41 ) $ (8 ) SDG&E: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ (6 ) $ (6 ) $ (6 ) SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ (2 ) $ (2 ) $ (2 ) Amounts accrued for interest and penalties associated with unrecognized income tax benefits are included in Income Tax Expense on the Consolidated Statements of Operations. Sempra Energy Consolidated accrued $1 million for interest expense and penalties at December 31, 2019 and 2018, respectively, on the Consolidated Balance Sheets, and recorded $1 million of interest expense and penalties in 2018 and negligible amounts in each of 2019 and 2017 on the Consolidated Statements of Operations. SDG&E and SoCalGas each accrued negligible amounts for interest expense and penalties at December 31, 2019 and 2018 on the Consolidated Balance Sheets, and recorded negligible amounts of interest expense and penalties in each of 2019, 2018 and 2017 on the Consolidated Statements of Operations. INCOME TAX AUDITS Sempra Energy is subject to U.S. federal income tax as well as income tax of multiple state and non-U.S. jurisdictions. We remain subject to examination for U.S. federal tax years after 2015. We are subject to examination by major state tax jurisdictions for tax years after 2010. Certain major non-U.S. income tax returns for tax years 2012 through the present are open to examination. We are also open to examination for non-U.S. income tax returns related to our prior interest in our commodities business, which we divested in 2010, for years 1999 through 2010. SDG&E and SoCalGas are subject to U.S. federal income tax and state income tax. They remain subject to examination for U.S. federal tax years after 2015 and state tax years after 2010. In addition, Sempra Energy has filed a protest to contest proposed state audit adjustments for tax years 2009 and 2010. The pre-2011 tax years for our major state tax jurisdictions are closed to new issues; therefore, no additional tax may be assessed by the taxing authorities for these tax years.

EMPLOYEE BENEFIT PLANS

EMPLOYEE BENEFIT PLANS	12 Months Ended
	Dec. 31, 2019
Retirement Benefits [Abstract]
Employee Benefit Plans	For our employee benefit plans, we: ▪ recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the balance sheet; ▪ measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year; and ▪ recognize changes in the funded status of pension and PBOP plans in the year in which the changes occur. Generally, those changes are reported in OCI and as a separate component of shareholders’ equity. The detailed information presented below covers the employee benefit plans of primarily Sempra Energy and its consolidated subsidiaries. Sempra Energy has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E and SoCalGas, which collectively cover all eligible employees, including members of the Sempra Energy board of directors who were participants in a predecessor plan on or before June 1, 1998. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology. IEnova has an unfunded noncontributory defined benefit plan covering all employees that provides defined benefits to retirees based on date of hire, years of service and final average earnings. Sempra Energy also has PBOP plans, including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. Other postretirement benefits include medical benefits for retirees’ spouses. Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. We review these assumptions on an annual basis and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans. RABBI TRUST In support of its Supplemental Executive Retirement, Cash Balance Restoration and Deferred Compensation Plans, Sempra Energy maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $488 million and $416 million at December 31, 2019 and 2018 , respectively. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS Benefit Plan Amendments Affecting 2019 and 2018 In 2019 and 2018, certain executive participants in a company nonqualified pension plan became eligible in this same plan for Supplemental Executive Retirement Plan benefits. This was treated as a plan amendment and increased the recorded pension liability by $5 million and $12 million at Sempra Energy and $3 million and $8 million at SDG&E in 2019 and 2018, respectively, and $2 million at SoCalGas in 2019. Settlement Accounting for Lump Sum Payments When applicable, we record settlement charges for lump sum payments from our nonqualified pension plans that are in excess of the respective plan’s service cost plus interest cost. Sempra Energy Consolidated recorded settlement charges of $24 million in 2019, Sempra Energy Consolidated and SDG&E recorded settlement charges of $12 million and $4 million , respectively, in 2018, and Sempra Energy Consolidated recorded settlement charges of $8 million in 2017. Sale of Qualified Pension Plan Annuity Contracts In March 2018, an insurance company purchased annuities for certain 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 $363 million at Sempra Energy Consolidated, including $132 million at SDG&E and $231 million at SoCalGas. This also resulted in settlement charges in net periodic benefit cost of $54 million at Sempra Energy Consolidated, including $22 million at SDG&E and $32 million at SoCalGas. The settlement charges were recorded as regulatory assets on the Consolidated Balance Sheets. Acquisition In March 2018, Sempra Energy completed the Merger, as we discuss in Note 5 , and assumed unfunded other postretirement employee benefits obligations for health care and life insurance benefits, resulting in an increase of $21 million in the other postretirement benefit plan liability at Sempra Energy Consolidated. In each of 2019 and 2018, we had $27 million in AOCI representing an actuarial loss related to Oncor’s pension plan. Special Termination Benefits Affecting 2018 and 2017 In 2018, certain nonrepresented, and in 2017, certain represented, employees age 62 or older with 5 years of service or age 55 to 61 with 10 years of service that retired under the Voluntary Retirement Enhancement Program offered in these years received an additional postretirement health benefit in the form of a $100,000 Health Reimbursement Account. We treated the benefit obligation attributable to the Health Reimbursement Account as a special termination benefit. This resulted in increases to the recorded liability for PBOP and net periodic benefit cost of $5 million for Sempra Energy Consolidated, $3 million for SDG&E and $2 million for SoCalGas in 2018 and $18 million for each of Sempra Energy Consolidated and SoCalGas in 2017. The Voluntary Retirement Enhancement Program resulted in a higher than expected number of retirements in 2017. As a result, the total lump-sum benefits paid from the Sempra Energy nonqualified and SoCalGas qualified pension plans in 2017 exceeded the settlement threshold, which triggered settlement accounting. This resulted in a reduction of the recorded pension liability and pension plan assets of $194 million at Sempra Energy Consolidated and $175 million at SoCalGas. This also resulted in settlement charges in net periodic benefit cost of $38 million at Sempra Energy Consolidated and $30 million at SoCalGas. The settlement charges at SoCalGas were recorded as regulatory assets on the Consolidated Balance Sheets. A measurement date of December 31, 2017 was used for the respective settlement accounting triggered as the year-to-date lump-sum benefit payments first exceeded the settlement threshold in December. Benefit Obligations and Assets The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2019 and 2018 , and a statement of the funded status at December 31, 2019 and 2018 : PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 3,339 $ 3,841 $ 868 $ 959 Service cost 110 124 17 21 Interest cost 139 140 36 36 Contributions from plan participants — — 21 23 Actuarial loss (gain) 445 (271 ) 45 (123 ) Plan amendments 5 12 — — Benefit payments (93 ) (113 ) (72 ) (74 ) Special termination benefits — — — 5 Acquisition — — — 21 Settlements (177 ) (394 ) (2 ) — Net obligation at December 31 3,768 3,339 913 868 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,160 2,659 1,108 1,209 Actual return on plan assets 496 (180 ) 218 (56 ) Employer contributions 276 188 8 6 Contributions from plan participants — — 21 23 Benefit payments (93 ) (113 ) (72 ) (74 ) Settlements (177 ) (394 ) (2 ) — Fair value of plan assets at December 31 2,662 2,160 1,281 1,108 Funded status at December 31 $ (1,106 ) $ (1,179 ) $ 368 $ 240 Net recorded (liability) asset at December 31 $ (1,106 ) $ (1,179 ) $ 368 $ 240 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 814 $ 971 $ 170 $ 185 Service cost 30 30 4 5 Interest cost 34 35 7 7 Contributions from plan participants — — 7 8 Actuarial loss (gain) 61 (63 ) 7 (17 ) Plan amendments 3 8 — — Benefit payments (18 ) (22 ) (18 ) (21 ) Special termination benefits — — — 3 Settlements (39 ) (145 ) — — Transfer of liability from other plans 10 — — — Net obligation at December 31 895 814 177 170 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 600 776 172 195 Actual return on plan assets 135 (56 ) 36 (12 ) Employer contributions 52 47 — 2 Contributions from plan participants — — 7 8 Benefit payments (18 ) (22 ) (18 ) (21 ) Settlements (39 ) (145 ) — — Transfer of assets from other plans 9 — — — Fair value of plan assets at December 31 739 600 197 172 Funded status at December 31 $ (156 ) $ (214 ) $ 20 $ 2 Net recorded (liability) asset at December 31 $ (156 ) $ (214 ) $ 20 $ 2 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,148 $ 2,486 $ 646 $ 737 Service cost 68 81 12 15 Interest cost 91 92 27 27 Contributions from plan participants — — 13 14 Actuarial loss (gain) 345 (215 ) 39 (100 ) Plan amendments 2 — — — Benefit payments (59 ) (65 ) (49 ) (49 ) Special termination benefits — — — 2 Settlements (65 ) (231 ) — — Transfer of liability to other plans (4 ) — — — Net obligation at December 31 2,526 2,148 688 646 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,385 1,694 916 993 Actual return on plan assets 320 (117 ) 178 (43 ) Employer contributions 152 104 1 1 Contributions from plan participants — — 13 14 Benefit payments (59 ) (65 ) (49 ) (49 ) Settlements (65 ) (231 ) — — Transfer of assets from other plans 4 — — — Fair value of plan assets at December 31 1,737 1,385 1,059 916 Funded status at December 31 $ (789 ) $ (763 ) $ 371 $ 270 Net recorded (liability) asset at December 31 $ (789 ) $ (763 ) $ 371 $ 270 Actuarial losses (gains) fluctuate based on changes in assumptions that we describe below in “Assumptions for Pension and Other Postretirement Benefit Plans” and updates to census data. In 2019, 2018 and 2017, the Society of Actuaries released updated mortality improvement projection scales, reflecting changes to projected observed longevity improvements in its mortality tables. We have incorporated these assumptions, adjusted for the Sempra Energy companies’ actual mortality experience, in our calculations for each of those years. Actuarial losses in pension plans at Sempra Energy Consolidated in 2019 were driven primarily by a decrease in discount rates and updated census data at Sempra Energy, SDG&E and SoCalGas, a decrease in the lump-sum conversion rate at SDG&E and updated salary scale assumptions at SoCalGas. These actuarial losses were partially offset by actuarial gains at SDG&E and SoCalGas due to a decrease in the interest crediting rate for the cash balance plans. Actuarial losses in PBOP plans at Sempra Energy Consolidated in 2019 were driven primarily by a decrease in discount rates at SDG&E and SoCalGas. These actuarial losses were partially offset by actuarial gains at SoCalGas, due to a reduction in the 2020 expected health care costs. Net Assets and Liabilities The assets and liabilities of the pension and PBOP plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Our funded pension and PBOP plans use the asset smoothing method, except for those at SDG&E. This method develops an asset value that recognizes realized and unrealized investment gains and losses over a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic benefit cost. SDG&E does not use the asset smoothing method, but rather recognizes realized and unrealized investment gains and losses during the current year. The 10% corridor accounting method is used at Sempra Energy Consolidated, SDG&E and SoCalGas. Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants. The asset smoothing and 10% corridor accounting methods help mitigate volatility of net periodic benefit costs from year to year. We recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets or liabilities, respectively; unrecognized changes in these assets and/or liabilities are normally recorded in AOCI on the balance sheet. The California Utilities record regulatory assets and liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on decisions by regulatory agencies. The California Utilities record annual pension and other postretirement net periodic benefit costs equal to the contributions to their qualified plans as authorized by the CPUC. The annual contributions to the pension plans are the greater of: ▪ a minimum required funding amount as required by the IRS; ▪ the amount required to maintain an 85% Adjusted Funding Target Attainment Percentage as defined by the Pension Protection Act of 2006, as amended; or ▪ beginning January 1, 2019 and for the duration of the 2019 GRC cycle, a fixed amount equal to the estimated annual service cost as defined by U.S. GAAP plus one year of a 14-year amortization of the unfunded projected benefit obligation of the pension plan as of January 1, 2019, and limited to an annual amount that keeps the fair value of the pension plan assets from exceeding 110% of the pension benefit obligation of the plan. The annual contributions to PBOP plans are equal to the lesser of the maximum tax deductible amount or the net periodic cost calculated in accordance with U.S. GAAP for pension and PBOP plans. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for the California Utilities are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. The net (liability) asset is included in the following categories on the Consolidated Balance Sheets at December 31: PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 Sempra Energy Consolidated: Noncurrent assets $ — $ — $ 391 $ 272 Current liabilities (59 ) (62 ) (3 ) (6 ) Noncurrent liabilities (1,047 ) (1,117 ) (20 ) (26 ) Net recorded (liability) asset $ (1,106 ) $ (1,179 ) $ 368 $ 240 SDG&E: Noncurrent assets $ — $ — $ 20 $ 2 Current liabilities (3 ) (2 ) — — Noncurrent liabilities (153 ) (212 ) — — Net recorded (liability) asset $ (156 ) $ (214 ) $ 20 $ 2 SoCalGas: Noncurrent assets $ — $ — $ 371 $ 270 Current liabilities (4 ) (3 ) — — Noncurrent liabilities (785 ) (760 ) — — Net recorded (liability) asset $ (789 ) $ (763 ) $ 371 $ 270 Amounts recorded in AOCI at December 31, net of income tax effects and amounts recorded as regulatory assets, are as follows: AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 Sempra Energy Consolidated (1) : Net actuarial (loss) gain $ (113 ) $ (114 ) $ 10 $ 8 Prior service cost (14 ) (12 ) — — Total $ (127 ) $ (126 ) $ 10 $ 8 SDG&E: Net actuarial loss $ (9 ) $ (4 ) Prior service cost (7 ) (6 ) Total $ (16 ) $ (10 ) SoCalGas: Net actuarial loss $ (7 ) $ (6 ) Prior service cost (3 ) (2 ) Total $ (10 ) $ (8 ) (1) Includes discontinued operations. Sempra Energy, SDG&E and SoCalGas each have a funded pension plan. The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Projected benefit obligation $ 3,578 $ 3,130 Accumulated benefit obligation 3,229 2,894 Fair value of plan assets 2,662 2,160 SDG&E: Projected benefit obligation $ 861 $ 788 Accumulated benefit obligation 818 762 Fair value of plan assets 739 600 SoCalGas: Projected benefit obligation $ 2,505 $ 2,123 Accumulated benefit obligation 2,208 1,919 Fair value of plan assets 1,737 1,385 We also have unfunded pension plans at Sempra Energy, SDG&E, SoCalGas and IEnova. The following table shows the obligations of unfunded pension plans at December 31: OBLIGATIONS OF UNFUNDED PENSION PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Projected benefit obligation $ 190 $ 209 Accumulated benefit obligation 158 186 SDG&E: Projected benefit obligation $ 34 $ 26 Accumulated benefit obligation 27 19 SoCalGas: Projected benefit obligation $ 21 $ 25 Accumulated benefit obligation 17 21 Sempra Energy, SDG&E and SoCalGas each have a funded other postretirement benefit plan. The following table shows the obligations of funded other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 32 $ 30 Fair value of plan assets 25 20 We also have unfunded other postretirement benefit plans at Sempra Energy. The following table shows the obligations of unfunded other postretirement benefit plans at December 31: OBLIGATIONS OF UNFUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 16 $ 22 Net Periodic Benefit Cost The following tables provide the components of net periodic benefit cost and pretax amounts recognized in OCI for the years ended December 31: NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 NET PERIODIC BENEFIT COST Service cost $ 110 $ 124 $ 117 $ 17 $ 21 $ 21 Interest cost 139 140 150 36 36 39 Expected return on assets (144 ) (157 ) (161 ) (71 ) (70 ) (66 ) Amortization of: Prior service cost 12 11 11 — 1 1 Actuarial loss (gain) 36 22 35 (10 ) (6 ) (4 ) Settlement charges 28 66 38 — — — Special termination benefits — — — — 5 18 Net periodic benefit cost 181 206 190 (28 ) (13 ) 9 Regulatory adjustment 77 (30 ) (42 ) 29 17 — Total expense recognized 258 176 148 1 4 9 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1) Net loss (gain) 17 56 — (3 ) (4 ) (2 ) Prior service cost 5 12 1 — — — Amortization of actuarial loss (13 ) (12 ) (10 ) — — — Amortization of prior service cost (3 ) (2 ) (1 ) — — — Settlements (28 ) (12 ) (8 ) — — — Total recognized in OCI (22 ) 42 (18 ) (3 ) (4 ) (2 ) Total recognized in net periodic benefit cost and OCI $ 236 $ 218 $ 130 $ (2 ) $ — $ 7 (1) Includes discontinued operations. NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 NET PERIODIC BENEFIT COST Service cost $ 30 $ 30 $ 29 $ 4 $ 5 $ 5 Interest cost 34 35 38 7 7 8 Expected return on assets (38 ) (47 ) (47 ) (11 ) (13 ) (11 ) Amortization of: Prior service cost 3 2 1 2 3 3 Actuarial loss (gain) 11 1 9 (2 ) (3 ) — Settlement charges — 26 — — — — Special termination benefits — — — — 3 — Net periodic benefit cost 40 47 30 — 2 5 Regulatory adjustment 14 (8 ) (8 ) — — — Total expense recognized 54 39 22 — 2 5 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 5 (1 ) 2 — — — Prior service cost 2 8 — — — — Amortization of actuarial loss — (1 ) (1 ) — — — Amortization of prior service cost (1 ) — — — — — Settlements — (4 ) — — — — Total recognized in OCI 6 2 1 — — — Total recognized in net periodic benefit cost and OCI $ 60 $ 41 $ 23 $ — $ 2 $ 5 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 NET PERIODIC BENEFIT COST Service cost $ 68 $ 81 $ 76 $ 12 $ 15 $ 14 Interest cost 91 92 98 27 27 29 Expected return on assets (94 ) (98 ) (103 ) (58 ) (56 ) (53 ) Amortization of: Prior service cost (credit) 8 8 9 (2 ) (3 ) (3 ) Actuarial loss (gain) 16 13 19 (8 ) (2 ) (3 ) Settlement charges — 32 30 — — — Special termination benefits — — — — 2 18 Net periodic benefit cost 89 128 129 (29 ) (17 ) 2 Regulatory adjustment 63 (22 ) (34 ) 29 17 — Total expense recognized 152 106 95 — — 2 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 2 1 — — — — Prior service cost 3 — — — — — Transfer of actuarial loss (4 ) — — — — — Transfer of prior service cost (1 ) — — — — — Amortization of actuarial loss (1 ) — — — — — Amortization of prior service cost — (1 ) (1 ) — — — Total recognized in OCI (1 ) — (1 ) — — — Total recognized in net periodic benefit cost and OCI $ 151 $ 106 $ 94 $ — $ — $ 2 Assumptions for Pension and Other Postretirement Benefit Plans Benefit Obligation and Net Periodic Benefit Cost Except for the IEnova plans, we develop the discount rate assumptions using a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flows to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of corporate bonds with a Bloomberg Composite of AA or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plans’ projected benefit payments discounted at this rate with the market value of the bonds selected. We develop the discount rate assumptions for the plans at IEnova by constructing a synthetic government zero coupon bond yield curve from the available market data, based on duration matching, and we add a risk spread to allow for the yields of high-quality corporate bonds. Such method is required when there is no deep market for high quality corporate bonds. Long-term return on assets is based on the weighted-average of the plans’ investment allocation as of the measurement date and the expected returns for those asset types. Interest crediting rate is based on an average 30 -year Treasury bond from the month of November of the preceding year. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under U.S. GAAP. The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31 Pension benefits Other postretirement benefits 2019 2018 2019 2018 Sempra Energy Consolidated: Discount rate 3.49 % 4.29 % 3.54 % 4.29 % Interest crediting rate (1)(2) 2.28 3.36 2.28 3.36 Rate of compensation increase 2.70-10.00 2.00-10.00 2.70-10.00 2.00-10.00 SDG&E: Discount rate 3.44 % 4.29 % 3.55 % 4.30 % Interest crediting rate (1)(2) 2.28 3.36 2.28 3.36 Rate of compensation increase 2.70-10.00 2.00-10.00 2.70-10.00 2.00-10.00 SoCalGas: Discount rate 3.50 % 4.30 % 3.55 % 4.30 % Interest crediting rate (1)(2) 2.28 3.36 2.28 3.36 Rate of compensation increase 2.70-10.00 2.00-10.00 2.70-10.00 2.00-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST YEARS ENDED DECEMBER 31 Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 Sempra Energy Consolidated: Discount rate 4.29 % 3.64 % 4.07 % 4.29 % 3.68 % 4.18 % Expected return on plan assets 7.00 7.00 7.00 6.48 6.49 6.47 Interest crediting rate (1)(2) 3.36 2.80 2.86 3.36 2.80 2.86 Rate of compensation increase 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 SDG&E: Discount rate 4.29 % 3.64 % 4.08 % 4.30 % 3.65 % 4.15 % Expected return on plan assets 7.00 7.00 7.00 6.92 6.94 6.91 Interest crediting rate (1)(2) 3.36 2.80 2.86 3.36 2.80 2.86 Rate of compensation increase 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 SoCalGas: Discount rate 4.30 % 3.65 % 4.10 % 4.30 % 3.70 % 4.20 % Expected return on plan assets 7.00 7.00 7.00 6.38 6.38 6.37 Interest crediting rate (1)(2) 3.36 2.80 2.86 3.36 2.80 2.86 Rate of compensation increase 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. Health Care Cost Trend Rates Assumed health care cost trend rates have a significant effect on the amounts that we report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans: ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans Pre-65 retirees Retirees aged 65 years and older 2019 2018 2017 2019 2018 2017 Health care cost trend rate assumed for next year 6.25 % 6.50 % 7.00 % 4.75 % 4.75 % 5.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 5.00 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2022 2022 2022 2022 Plan Assets Investment Allocation Strategy for Sempra Energy’s Pension Master Trust Sempra Energy’s pension master trust holds the investments for our pension plans and a portion of the investments for our PBOP plans. We maintain additional trusts, as we discuss below, for certain of the California Utilities’ PBOP plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra Energy. The current asset allocation objective for the pension master trust is to protect the funded status of the plans while generating sufficient returns to cover future benefit payments and accruals. We assess the portfolio performance by comparing actual returns with relevant benchmarks. Currently, the pension plans’ target asset allocations are: ▪ 35% domestic equity ▪ 24% international equity ▪ 18% long credit ▪ 8% ultra-long duration government securities ▪ 5% global real estate investment trusts ▪ 5% return-seeking credit ▪ 5% real assets The asset allocation of the plans is reviewed by our Plan Funding Committee and our Pension and Benefits Investment Committee (the Committees) on a regular basis. When evaluating strategic asset allocations, the Committees consider many variables, including: ▪ long-term cost ▪ variability and level of contributions ▪ funded status ▪ a range of expected outcomes over varying confidence levels This allocation results in a 74% target allocation to return-seeking assets and a 26% target allocation to risk-mitigating assets. We maintain asset allocations at strategic levels with reasonable bands of variance. In accordance with the Sempra Energy pension investment guidelines, derivative financial instruments may be used by the pension master trust’s equity and fixed income portfolio investment managers to equitize cash, hedge certain exposures, and as substitutes for certain types of fixed income securities. Rate of Return Assumption The expected return on assets in our pension and PBOP plans is based on the weighted-average of the plans’ investment allocations to specific asset classes as of the measurement date. We arrive at a 7% expected return on assets by considering both the historical and forecasted long-term rates of return on those asset classes. We expect a return of between 5% and 9% on return-seeking assets and between 1% and 4% for risk-mitigating assets. Certain trusts that hold assets for the SDG&E other postretirement benefit plan are subject to taxation, which impacts the expected after-tax return on assets in the plan. Concentration of Risk Plan assets are diversified across global equity and bond markets, and concentration of risk in any one economic, industry, maturity or geographic sector is limited. I nvestment Strategy for SDG&E’s and SoCalGas’ Other Postretirement Benefit Plans SDG&E’s and SoCalGas’ PBOP plans are funded by cash contributions from SDG&E and SoCalGas and their current retirees. The assets of these plans are placed into the pension master trust and other Voluntary Employee Beneficiary Association trusts. Certain assets of SDG&E’s and SoCalGas’ PBOP plans are held in the pension master trust, which invests a portion of the assets in completion portfolios that aim to reduce interest rate risk, thereby resulting in an overall target allocation of 38% to return-seeking assets and 62% to risk-mitigating assets for these well-funded plans. Certain of SoCalGas’ PBOP plans are held in a Voluntary Employee Benefit Association trust that also utilizes a completion portfolio, resulting in a target allocation of 25% to return-seeking assets and 75% to risk-mitigating assets. SDG&E’s and SoCalGas’ assets held in other Voluntary Employee Beneficiary Association trusts are invested in accordance with a de-risking glidepath that reduces the assets’ exposure to risk as the trusts become better funded. These specific allocations are periodically reviewed to ensure that plan assets are best positioned to meet plan obligations. Fair Value of Pension and Other Postretirement Benefit Plan Assets We classify the investments in Sempra Energy’s pension master trust and the trusts for the California Utilities’ PBOP plans based on the fair value hierarchy, except for certain investments measured at NAV. The following are descriptions of the valuation methods and assumptions we use to estimate the fair values of investments held by pension and other postretirement benefit plan trusts. Equity Securities – Equity securities are valued using quoted prices listed on nationally recognized securities exchanges. Fixed Income Securities – Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Certain high yield fixed-income securities are valued by applying a price adjustment to the bid side to calculate a mean and ask value. Adjustments can vary based on maturity, credit standing, and reported trade frequencies. The bid to ask spread is determined by the investment manager based on the review of the available market information. Registered Investment Companies – Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices. Where the value is a quoted price in an active market, the investment is classified within Level 1 of the fair value hierarchy. Investments in certain fixed income securities are valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks for the remaining fixed income securities. Common/Collective Trusts – Investments in common/collective trust funds are valued based on the NAV of units owned, which is based on the current fair value of the funds’ underlying assets.

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2019
Share-based Payment Arrangement, Noncash Expense [Abstract]
Share-based Compensation	SHARE-BASED COMPENSATION SEMPRA ENERGY EQUITY COMPENSATION PLANS Sempra Energy has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra Energy. The plans permit a wide variety of share-based awards, including: ▪ nonqualified stock options ▪ incentive stock options ▪ restricted stock awards ▪ restricted stock units ▪ stock appreciation rights ▪ performance awards ▪ stock payments ▪ dividend equivalents Eligible employees, including those from the California Utilities, participate in Sempra Energy’s share-based compensation plans as a component of their compensation package. In the three years ended December 31, 2019 , Sempra Energy had the following types of equity awards outstanding: ▪ Nonqualified Stock Options: Options to purchase common stock have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a three -year period (for awards granted in 2019) or over a four -year period (for awards granted in 2010 or earlier), and expire 10 years from the date of grant. Vesting and/or the ability to exercise may be accelerated upon a change in control, in accordance with severance pay agreements or in accordance with the terms of the grant. Options are subject to forfeiture or earlier expiration following termination of employment, subject to certain exceptions. ▪ Performance-Based Restricted Stock Units: These RSU awards generally vest in Sempra Energy common stock at the end of three -year (for awards granted during or after 2015) or four -year performance periods (for awards granted prior to 2015) based on Sempra Energy’s total return to shareholders relative to that of specified market indices or based on the compound annual growth rate of Sempra Energy’s EPS. The comparative market indices for the awards that vest based on total return to shareholders are the S&P 500 Utilities Index and the S&P 500 Index. We use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies to develop our targets for awards that vest based on EPS growth. ◦ For awards granted in 2013 or earlier, if Sempra Energy’s total return to shareholders exceeds target levels, up to an additional 50% of the number of granted RSUs may be issued. ◦ For awards granted during or after 2014, up to an additional 100% of the granted RSUs may be issued if total return to shareholders or EPS growth exceeds target levels. ◦ For awards granted in 2015 and 2016 and certain awards granted in 2017 and 2018 that vest based on Sempra Energy’s total return to shareholders, a modifier adds 20% to the award’s payout (as initially calculated based on total return to shareholders relative to that of specified market indices) for total shareholder return performance in the top quartile relative to historical benchmark data for Sempra Energy and reduces the award’s payout by 20% for performance in the bottom quartile. However, in no event will more than an additional 100% of the granted RSUs be issued. If performance falls within the second or third quartiles, the modifier is not triggered, and the payout is based solely on total return to shareholders relative to that of specified market indices. If Sempra Energy’s total return to shareholders or EPS growth is below the target levels but above threshold performance levels, shares are subject to partial vesting on a pro rata basis. ▪ Other Performance-Based Restricted Stock Units: RSUs were granted in 2014 and 2015 in connection with the creation of Cameron LNG JV. ◦ The 2014 awards vested in 2015 through 2017 as the Compensation Committee of Sempra Energy’s board of directors determined that the objectives of the JV were achieved. Those awards vested on the anniversary of the grant date over a period of either two or three years. ◦ The 2015 awards vested in 2019 as both of the following were achieved: (a) the Compensation Committee of Sempra Energy’s board of directors determined that Sempra Energy achieved positive cumulative net income for fiscal years 2015 through 2017 and (b) Cameron LNG JV commenced commercial operations of the first train. ▪ Service-Based Restricted Stock Units: RSUs may also be service-based; these generally vest over three -year service periods (for awards granted in 2019), or at the end of three -year (for awards granted during 2015 through 2018) or four -year service periods (for awards granted prior to 2015). For RSU awards, vesting may be subject to earlier forfeiture upon termination of employment and accelerated vesting upon a change in control under the applicable LTIP, in accordance with severance pay agreements , or at the discretion of the Compensation Committee of Sempra Energy’s board of directors . Dividend equivalents on shares subject to RSUs are reinvested to purchase additional common shares that become subject to the same vesting conditions as the RSUs to which the dividends relate. SHARE-BASED AWARDS AND COMPENSATION EXPENSE At December 31, 2019 , 7,662,352 common shares were authorized and available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three or four years. However, for awards granted to retirement-eligible participants, the expense is recognized over the initial year in which the award was granted as the award requires service through the end of the year in which it was granted. For awards granted to participants who become eligible for retirement during the requisite service period, the expense is recognized over the period between the date of grant and the later of the end of the year in which the award was granted or the date the participant first becomes eligible for retirement. Substantially all awards outstanding are classified as equity instruments; therefore, we recognize additional paid in capital as we recognize the compensation expense associated with the awards. We recognize in earnings the tax benefits (or deficiencies) resulting from tax deductions that are in excess of (or less than) tax benefits related to compensation cost recognized for share-based payments. Sempra Energy subsidiaries record an expense for the plans to the extent that subsidiary employees participate in the plans and/or the subsidiaries are allocated a portion of the Sempra Energy plans’ corporate staff costs. Total share-based compensation expense for all of Sempra Energy’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Share-based compensation expense, before income taxes (1) $ 66 $ 76 $ 78 Income tax benefit (1) (18 ) (21 ) (31 ) $ 48 $ 55 $ 47 Capitalized share-based compensation cost $ 11 $ 10 $ 9 Excess income tax deficiency $ 4 $ 15 $ — SDG&E: Share-based compensation expense, before income taxes $ 10 $ 12 $ 13 Income tax benefit (3 ) (3 ) (5 ) $ 7 $ 9 $ 8 Capitalized share-based compensation cost $ 6 $ 6 $ 5 Excess income tax deficiency $ 1 $ 3 $ — SoCalGas: Share-based compensation expense, before income taxes $ 15 $ 16 $ 17 Income tax benefit (4 ) (5 ) (7 ) $ 11 $ 11 $ 10 Capitalized share-based compensation cost $ 5 $ 4 $ 4 Excess income tax deficiency $ 1 $ 2 $ — (1) Includes activity of awards issued from the IEnova 2013 LTIP, which settle in cash upon vesting based on the price of IEnova’s common stock. SEMPRA ENERGY NONQUALIFIED STOCK OPTIONS We use a Black-Scholes option-pricing model to estimate the fair value of each nonqualified stock option grant. The use of a valuation model requires us to make certain assumptions about selected model inputs. Expected volatility is calculated based on a blend of the historical and implied volatility of Sempra Energy’s common stock price. The average expected term for options is based on the vesting schedule, contractual term of the option, expected employee exercise and post-termination behavior. The risk-free interest rate is based on U.S. Treasury zero-coupon issues with a remaining term equal to the expected term estimated at the date of the grant. All nonqualified stock options granted prior to 2019 were fully vested and compensation cost on such stock options was fully recognized by December 31, 2014. In January 2019, Sempra Energy’s board of directors granted 261,075 nonqualified stock options that are exercisable over a three -year period. The weighted-average per-share fair value for options granted was $13.20 in 2019. To calculate this fair value, we used the Black-Scholes model with the following weighted-average assumptions: KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Year ended December 31, 2019 Stock price volatility 18.63 % Expected term 5.34 years Risk-free rate of return 2.49 % Annual dividend yield 3.35 % The following table shows a summary of nonqualified stock options at December 31, 2019 and activity for the year then ended: NONQUALIFIED STOCK OPTIONS Common shares under options Weighted- average exercise price Weighted- average remaining contractual term (in years) Aggregate intrinsic value (in millions) Outstanding at January 1, 2019 56,940 $ 54.63 Granted 261,075 $ 106.76 Exercised (52,540 ) $ 54.52 Forfeited/canceled (17,898 ) $ 106.76 Outstanding at December 31, 2019 247,577 $ 105.86 8.85 $ 11 Vested or expected to vest at December 31, 2019 237,236 $ 105.82 8.84 $ 11 Exercisable at December 31, 2019 4,400 $ 55.90 0.01 $ — The aggregate intrinsic value at December 31, 2019 is the total of the difference between Sempra Energy’s closing common stock price and the exercise price for all in-the-money options. The aggregate intrinsic value for nonqualified stock options exercised in the last three years was: ▪ $4 million in 2019 ▪ $9 million in 2018 ▪ $9 million in 2017 A negligible amount of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2019 is expected to be recognized over a weighted-average period of 2.03 years . We received cash of $3 million from stock option exercises during 2019. SEMPRA ENERGY RESTRICTED STOCK UNITS We use a Monte-Carlo simulation model to estimate the fair value of our RSUs that vest based on Sempra Energy’s total return to shareholders. Our determination of fair value is affected by the historical volatility of the common stock price for Sempra Energy and its peer group companies. The valuation also is affected by the risk-free rates of return and a number of other variables. Below are key assumptions for RSUs granted in the last three years: KEY ASSUMPTIONS FOR RSUs GRANTED Years ended December 31, 2019 2018 2017 Stock price volatility 17.74 % 17.46 % 17.24 % Risk-free rate of return 2.46 % 2.00 % 1.49 % The following table shows a summary of RSUs at December 31, 2019 and activity for the year then ended: RESTRICTED STOCK UNITS Performance-based restricted stock units Service-based restricted stock units Units Weighted- average grant-date fair value Units Weighted- average grant-date fair value Nonvested at January 1, 2019 1,242,169 $ 106.11 402,361 $ 105.01 Granted 389,825 $ 113.54 260,594 $ 112.50 Vested (142,820 ) $ 100.28 (209,395 ) $ 102.68 Forfeited (402,193 ) $ 103.34 (37,773 ) $ 110.25 Nonvested at December 31, 2019 (1) 1,086,981 $ 109.85 415,787 $ 119.96 Expected to vest at December 31, 2019 1,066,375 $ 109.89 408,782 $ 109.65 (1) Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra Energy exceeds target performance conditions. In 2019 , 2018 and 2017 , the total fair value of RSU shares vested during the year was $36 million , $32 million and $45 million , respectively. The $32 million of total compensation cost related to nonvested RSUs not yet recognized as of December 31, 2019 is expected to be recognized over a weighted-average period of 2.07 years. The weighted-average per-share fair values for performance-based RSUs granted were $105.03 and $110.54 in 2018 and 2017 , respectively. The weighted-average per-share fair values for service-based RSUs granted were $107.60 and $101.88 in 2018 and 2017

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 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 Consolidated Balance Sheets. We have derivatives that are (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 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 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 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 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 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) December 31, Commodity Unit of measure 2019 2018 Sempra Energy Consolidated: Natural gas MMBtu 32 35 Electricity MWh 2 2 Congestion revenue rights MWh 48 52 SDG&E: Natural gas MMBtu 37 33 Electricity MWh 2 2 Congestion revenue rights MWh 48 52 SoCalGas: Natural gas MMBtu 2 — 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 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) December 31, 2019 December 31, 2018 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges (1) $ 1,445 2020-2034 $ 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. We also utilize foreign currency derivatives to hedge exposure to fluctuations in the Peruvian Sol related to the sale of our operations in Peru. The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) December 31, 2019 December 31, 2018 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 306 2020-2023 $ 306 2019-2023 Other foreign currency derivatives 1,796 2020-2021 1,158 2019-2020 FINANCIAL STATEMENT PRESENTATION The 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 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 CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2019 Other current assets (1) Other long-term assets Other current liabilities Deferred credits and other Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments $ — $ 3 $ (17 ) $ (140 ) Derivatives not designated as hedging instruments: Foreign exchange instruments 41 — (20 ) — Associated offsetting foreign exchange instruments (20 ) — 20 — Commodity contracts not subject to rate recovery 34 11 (41 ) (10 ) Associated offsetting commodity contracts (32 ) (2 ) 32 2 Commodity contracts subject to rate recovery 41 76 (47 ) (47 ) Associated offsetting commodity contracts (6 ) (3 ) 6 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 58 85 (53 ) (192 ) Additional cash collateral for commodity contracts not subject to rate recovery 43 — — — Additional cash collateral for commodity contracts subject to rate recovery 25 — — — Total (2) $ 126 $ 85 $ (53 ) $ (192 ) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 30 $ 76 $ (41 ) $ (47 ) Associated offsetting commodity contracts (4 ) (3 ) 4 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 26 73 (23 ) (44 ) Additional cash collateral for commodity contracts subject to rate recovery 16 — — — Total (2) $ 42 $ 73 $ (23 ) $ (44 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 11 $ — $ (6 ) $ — Associated offsetting commodity contracts (2 ) — 2 — Net amounts presented on the balance sheet 9 — (4 ) — Additional cash collateral for commodity contracts subject to rate recovery 9 — — — Total $ 18 $ — $ (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 CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2018 Other current (1) Other long-term assets Other current 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 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 Years ended December 31, Years ended December 31, 2019 2018 2017 Location 2019 2018 2017 Sempra Energy Consolidated: Interest rate and foreign exchange instruments (1) $ (5 ) $ 31 $ 19 Interest Expense (1) $ (3 ) $ — $ 4 Other Income, Net 9 2 — Interest rate instruments — — — Gain on Sale of Assets (10 ) (9 ) — Interest rate and foreign exchange instruments (174 ) 41 (34 ) Equity Earnings (5 ) (7 ) (20 ) Foreign exchange instruments (8 ) (4 ) 4 Revenues: Energy- Related Businesses (2 ) 1 2 Commodity contracts not subject to rate recovery — — 3 Revenues: Energy- Related Businesses — — (9 ) Total $ (187 ) $ 68 $ (8 ) $ (11 ) $ (13 ) $ (23 ) SDG&E: Interest rate instruments (1) $ (1 ) $ 1 $ (2 ) Interest Expense (1) $ (3 ) $ (7 ) $ (13 ) SoCalGas: Interest rate instruments $ — $ — $ — Interest Expense $ (1 ) $ (1 ) $ — (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. On August 14, 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps. For Sempra Energy Consolidated, we expect that net losses of $26 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 December 31, 2019 is approximately 15 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 20 years. The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Years ended December 31, Location 2019 2018 2017 Sempra Energy Consolidated: Foreign exchange instruments Other Income, Net $ 25 $ 3 $ 49 Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses 12 26 16 Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (140 ) 279 54 Commodity contracts subject to rate recovery Cost of Natural Gas 3 5 (2 ) Total $ (100 ) $ 313 $ 117 SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ (140 ) $ 279 $ 54 SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ 3 $ 5 $ (2 ) 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 December 31, 2019 and 2018 was $21 million and $16 million , respectively. For SoCalGas, the total fair value of this group of derivative instruments in a net liability position at December 31, 2019 and 2018 was $4 million and $5 million , respectively. At December 31, 2019 , if the credit ratings of Sempra Energy or SoCalGas were reduced below investment grade, $21 million and $4 million , respectively, of additional assets could be required to be posted as collateral for these derivative contracts. For Sempra Energy Consolidated, SDG&E and SoCalGas, some of our derivative contracts contain a provision that would permit the counterparty, in certain circumstances, to request adequate assurance of our performance under the contracts. Such additional assurance, if needed, is not material and is not included in the amounts above.

FAIR VALUE MEASUREMENTS

FAIR VALUE MEASUREMENTS	12 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS RECURRING FAIR VALUE MEASURES The three tables below, by level within the fair value hierarchy, set forth our financial assets and liabilities that were accounted for at fair value on a recurring basis at December 31, 2019 and 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. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 11 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 $5 million and $10 million investment at December 31, 2019 and 2018, respectively, measured at NAV): ▪ 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 December 31, 2019 and 2018 . RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 503 $ 6 $ — $ 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 549 525 — 1,074 Interest rate and foreign exchange instruments — 24 — 24 Commodity contracts not subject to rate recovery — 11 — 11 Effect of netting and allocation of collateral (2) 43 — — 43 Commodity contracts subject to rate recovery 5 8 95 108 Effect of netting and allocation of collateral (2) 11 8 6 25 Total $ 608 $ 576 $ 101 $ 1,285 Liabilities: Interest rate and foreign exchange instruments $ — $ 157 $ — $ 157 Commodity contracts not subject to rate recovery — 17 — 17 Commodity contracts subject to rate recovery 14 4 67 85 Effect of netting and allocation of collateral (2) (14 ) — — (14 ) Total $ — $ 178 $ 67 $ 245 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 balances and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 503 $ 6 $ — $ 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 549 525 — 1,074 Commodity contracts subject to rate recovery 1 3 95 99 Effect of netting and allocation of collateral (2) 10 — 6 16 Total $ 560 $ 528 $ 101 $ 1,189 Liabilities: Commodity contracts subject to rate recovery 14 — 67 81 Effect of netting and allocation of collateral (2) (14 ) — — (14 ) Total $ — $ — $ 67 $ 67 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 balances and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 4 $ 5 $ — $ 9 Effect of netting and allocation of collateral (1) 1 8 — 9 Total $ 5 $ 13 $ — $ 18 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) Years ended December 31, 2019 2018 2017 Balance at January 1 $ 179 $ (28 ) $ (74 ) Realized and unrealized gains (losses) (184 ) 209 34 Allocated transmission instruments 6 10 6 Settlements 27 (12 ) 6 Balance at December 31 $ 28 $ 179 $ (28 ) Change in unrealized gains (losses) relating to instruments still held at December 31 $ (139 ) $ 183 $ 30 (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 2020 $ (3.77 ) to $ 6.03 $ (1.58 ) 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 11 . 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 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2019 $ 21.00 to $ 61.15 $ 37.92 2018 22.20 to 76.85 42.69 A significant increase or decrease in market electricity forward prices would result in a significantly higher or lower fair value, respectively. We summarize long-term, fixed-price electricity position volumes in Note 11 . 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 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, 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 Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) December 31, 2019 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates $ 742 $ — $ 759 $ — $ 759 Long-term amounts due to unconsolidated affiliates 195 — 184 — 184 Total long-term debt (1) 21,247 — 22,638 26 22,664 SDG&E: Total long-term debt (2) $ 5,140 $ — $ 5,662 $ — $ 5,662 SoCalGas: Total long-term debt (3) $ 3,809 $ — $ 4,189 $ — $ 4,189 December 31, 2018 Carrying Fair value amount 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 $225 million and excluding finance lease obligations of $1,289 million . (2) Before reductions of unamortized discount and debt issuance costs of $48 million and excluding finance lease obligations of $1,270 million . (3) Before reductions of unamortized discount and debt issuance costs of $34 million and excluding finance lease obligations of $19 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 arrangement 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 15 . NON-RECURRING FAIR VALUE MEASURES Sempra Mexico TdM In 2017, while TdM was held for sale, Sempra Mexico received a purchase price offer for TdM resulting from negotiations with an active market participant. This new market information indicated that the fair value of TdM was lower than its carrying value at June 30, 2017. As a result, in the second quarter of 2017, Sempra Mexico further reduced the carrying value of TdM by recognizing a noncash impairment charge of $71 million in Impairment Losses on Sempra Energy’s Consolidated Statements of Operations. A purchase price offer is considered to be a Level 2 input in the fair value hierarchy, as it represents an observable pricing input. TdM was reclassified to held and used in June 2018 when management terminated the sales process. Sempra Renewables U.S. Wind Investments As we discuss in Notes 5 and 6 , in June 2018, our board of directors approved a plan to sell all our wind and solar equity method investments at Sempra Renewables. Because of our expectation of a shorter holding period as a result of this plan of sale, we evaluated the recoverability of the carrying amounts of each of these investments and concluded there was an other-than-temporary impairment on certain of our wind equity method investments totaling $200 million ( $145 million after tax), which we recorded in Equity Earnings on Sempra Energy’s Consolidated Statement of Operations for the year ended December 31, 2018. We measured the estimated fair value of $145 million at June 25, 2018 using a discounted cash flow model including significant unobservable inputs, adjusted for our applicable ownership percentages, which is a Level 3 measurement in the fair value hierarchy. The key inputs to the methodology were contracted and merchant pricing, and the discount rate. Sempra Renewables completed the sale of its interests in these wind equity method investments in April 2019. Sempra LNG Non-Utility Natural Gas Storage Assets As we discuss in Note 5 , in June 2018, our board of directors approved a plan to sell Mississippi Hub, our 90.9% ownership interest in Bay Gas and other non-utility assets (the non-utility natural gas storage assets). We also own a 75.4% interest in LA Storage, a salt cavern development project in Cameron Parish, Louisiana. The LA Storage project also includes an existing 23.3-mile pipeline header system that is not currently contracted. Because of the plan of sale, we considered a market participant’s view of the total value of the non-utility natural gas storage assets and determined that their fair value, less costs to sell, may be less than their carrying value. Additionally, our inability to secure customer contracts that would support further investment in LA Storage led us to assess and conclude that the full carrying value of these other U.S. midstream assets may not be recoverable. As a result, on June 25, 2018, we recorded an impairment of $1.3 billion ( $755 million after tax and NCI) in Impairment Losses on Sempra Energy’s Consolidated Statement of Operations. We measured the estimated fair value of $190 million at June 25, 2018 using a discounted cash flow approach. This approach included unobservable inputs, resulting in a Level 3 measurement in the fair value hierarchy. We considered a market participant’s view of the values of the non-utility natural gas storage assets based on an estimation of future net cash flows. To estimate future net cash flows, we considered the non-utility natural gas storage assets’ prospects for generating revenues and cash flows beyond their existing contracted capacity and tenors, including natural gas price volatility and seasonality factors, as well as discount rates commensurate with the risks inherent in the cash flows. On January 1, 2019, Sempra LNG entered into an agreement to sell Mississippi Hub and Bay Gas to an affiliate of ArcLight Capital Partners for $332 million , subject to working capital adjustments and $20 million representing Sempra LNG’s purchase of the 9.1% minority interest in Bay Gas immediately prior to and included as part of the sale. On February 7, 2019, Sempra LNG completed this sale. Additionally, in December 2018, Sempra LNG entered into an agreement to sell other non-utility assets for $5 million ; such sale was completed in January 2019. We considered the assets’ sales prices negotiated with active market participants to be a relevant and material data input. Accordingly, we updated our fair value analysis to reflect the Level 2 market participant input as the primary indicator of fair value. As a result, on December 31, 2018, we reduced the impairment of $1.3 billion recorded on June 25, 2018 by $183 million ( $126 million after tax and NCI), resulting in a total impairment of $1.1 billion ( $629 million after tax and NCI) for the year ended December 31, 2018, based on a fair value of $337 million for these non-utility natural gas storage assets. The table below summarizes significant inputs impacting our non-recurring fair value measures. Additional discussions about the related transactions are provided in Note 5 , and as applicable, in Note 6 . NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED Measurement date Estimated fair value (in millions) Valuation technique Fair value hierarchy % of fair value measurement Inputs used to Range of Non-utility natural gas storage assets December 31, 2018 $ 337 Market approach Level 2 100% Assets’ sales prices 100% Non-utility natural gas storage assets June 25, 2018 $ 190 Discounted cash flows Level 3 100% Storage rates $0.06 - $0.22 ($0.10) (1) Discount rate 10% (2) Certain of our U.S. wind equity method investments June 25, 2018 $ 145 Discounted cash flows Level 3 100% Contracted and observable merchant prices per MWh $29 - $92 (1) Discount rate 8% - 10% (8.7%) (2) TdM June 30, 2017 $ 62 Market approach Level 2 100% Purchase price offer 100% (1) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (2) An increase in the discount rate would result in a decrease in fair value.

PREFERRED STOCK

PREFERRED STOCK	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Preferred Stock	PREFERRED STOCK Sempra Energy and SDG&E are authorized to issue up to 50 million and 45 million shares of preferred stock, respectively. At December 31, 2019 and 2018 , SDG&E had no preferred stock outstanding. The rights, preferences, privileges and restrictions for any new series of preferred stock would be established by each company’s board of directors at the time of issuance. SEMPRA ENERGY MANDATORY CONVERTIBLE PREFERRED STOCK In January 2018, we issued 17,250,000 shares of our 6% mandatory convertible preferred stock, series A (series A preferred stock) in a registered public offering at $100.00 per share (or $98.20 per share after deducting underwriting discounts), including 2,250,000 shares purchased by the underwriters from us as a result of fully exercising their option to purchase such shares from us solely to cover overallotments. Each share of series A preferred stock has a liquidation value of $100.00 . We used the net proceeds of approximately $1.69 billion (net of underwriting discounts and equity issuance costs of $32 million ) to fund a portion of the Merger Consideration, as we discuss in Note 5 . In July 2018, we issued 5,750,000 shares of our 6.75% mandatory convertible preferred stock, series B (series B preferred stock) in a registered public offering at $100.00 per share (or $98.35 per share after deducting underwriting discounts), including 750,000 shares purchased by the underwriters from us as a result of fully exercising their option to purchase such shares from us solely to cover overallotments. Each share of series B preferred stock has a liquidation value of $100.00 . We used the net proceeds of approximately $565 million (net of underwriting discounts and equity issuance costs of $10 million ) to repay commercial paper, to fund working capital and for other general corporate purposes. Mandatory Conversion Unless earlier converted, each share of the series A preferred stock and series B preferred stock will automatically convert on the mandatory conversion date of January 15, 2021 and July 15, 2021, respectively. The number of shares of our common stock issuable on conversion of each series of preferred stock will be determined based on the volume-weighted average market value per share of our common stock over the 20-consecutive trading day period beginning on and including the 21st scheduled trading day immediately preceding January 15, 2021 for the series A preferred stock and July 15, 2021 for the series B preferred stock. The following table illustrates the conversion rate per share of each series of preferred stock, subject to certain anti-dilution adjustments. CONVERSION RATES Applicable market value per share of Conversion rate (number of shares of our common stock to be received upon conversion of each share of mandatory convertible preferred stock) Series A preferred stock Greater than $131.075 (which is the threshold appreciation price) 0.7629 shares (approximately equal to $100.00 divided by the threshold appreciation price) Equal to or less than $131.075 but greater than or equal to $107.00 Between 0.7629 and 0.9345 shares, determined by dividing $100.00 by the applicable market value of our common stock Less than $107.00 (which is the initial price) 0.9345 shares (approximately equal to $100.00 divided by the initial price) Series B preferred stock Greater than $136.50 (which is the threshold appreciation price) 0.7326 shares (approximately equal to $100.00 divided by the threshold appreciation price) Equal to or less than $136.50 but greater than or equal to $113.75 Between 0.7326 and 0.8791 shares, determined by dividing $100.00 by the applicable market value of our common stock Less than $113.75 (which is the initial price) 0.8791 shares (approximately equal to $100.00 divided by the initial price) Conversion at the Option of the Holder Generally, and subject to the terms of the respective series of preferred stock, at any time prior to January 15, 2021 for the series A preferred stock and July 15, 2021 for the series B preferred stock, holders may elect to convert each share of their preferred stock into shares of our common stock at the minimum conversion rate, which could result in an aggregate of approximately 13.2 million common shares with respect to conversion of series A preferred stock and 4.2 million common shares with respect to conversion of series B preferred stock, if all outstanding preferred stock under each series were converted early, subject to anti-dilution adjustments. Further, if holders elect to convert any shares of either series of preferred stock during a specified period beginning on the effective date of a fundamental change, as defined in the certificate of determination of preferences of the respective series of preferred stock, such shares of preferred stock will be converted into shares of our common stock at a fundamental change conversion rate, and the holders will also be entitled to receive a fundamental change dividend make-whole amount and accumulated dividend amount. Dividends Dividends on each series of preferred stock are payable quarterly on a cumulative basis when, as and if declared by our board of directors. The first quarterly dividend for the series A preferred stock and series B preferred stock was paid on April 15, 2018 and October 15, 2018, respectively. We may pay quarterly declared dividends in cash or, subject to certain limitations, in shares of our common stock, no par value, or in any combination of cash and shares of our common stock. Shares of common stock used to pay dividends will be valued at 97% of the volume-weighted average price per share over the five-consecutive trading day period beginning on, and including the sixth trading day prior to, the applicable dividend payment date. The holders of each series of preferred stock do not have voting rights with respect to their preferred stock. However, under certain circumstances including nonpayment of dividends for six or more dividend periods, whether or not consecutive, the authorized number of directors on our board of directors will automatically be increased by two and the holders of each series of preferred stock, voting together as a single class with holders of any and all other outstanding preferred stock of equal rank having similar voting rights, will be entitled to elect two directors to fill such newly created directorships. This right shall terminate when all accumulated dividends have been paid in full and the authorized number of directors shall automatically decrease by two, subject to the revesting of that right in the event of each subsequent nonpayment. Ranking Each series of preferred stock will rank with respect to dividend rights and distribution rights upon our liquidation, winding-up or dissolution: ▪ senior to our common stock, including our capital stock established in the future, unless the terms of such capital stock expressly provide otherwise; ▪ on parity with each series of preferred stock, including our capital stock established in the future, unless the terms of such capital stock expressly provide otherwise; ▪ junior to our capital stock established in the future, if the terms provide that such class of series of new capital stock will rank senior to the series A preferred stock and series B preferred stock; ▪ junior to our existing and future indebtedness and other liabilities; and ▪ structurally subordinated to any existing and future indebtedness and other liabilities of our subsidiaries and capital stock of our subsidiaries held by third parties. SOCALGAS PREFERRED STOCK SoCalGas is authorized to issue up to an aggregate of 11 million shares of preferred stock, series preferred stock and preference stock. The table below presents preferred stock outstanding at SoCalGas: PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2019 2018 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 SoCalGas - Total preferred stock 22 22 Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises (2 ) (2 ) Sempra Energy - Total preferred stock of subsidiary $ 20 $ 20 None of SoCalGas’ outstanding preferred stock is callable, and no shares are subject to mandatory redemption. All outstanding shares have one vote per share, cumulative preferences as to dividends and liquidation preferences of $25 per share plus any unpaid dividends. In addition to the outstanding preferred stock above, SoCalGas’ articles of incorporation authorize 5 million shares of series preferred stock and 5 million shares of preference stock, both without par value and with cumulative preferences as to dividends and liquidation value. The preference stock would rank junior to all series of preferred stock and series preferred stock. Other rights and privileges of any new series of such stock would be established by the SoCalGas board of directors at the time of issuance.

SEMPRA ENERGY - SHAREHOLDERS' E

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE	SEMPRA ENERGY – SHAREHOLDERS’ EQUITY AND EARNINGS PER COMMON SHARE SEMPRA ENERGY COMMON STOCK OFFERINGS In January 2018, we completed the offering of 26,869,158 shares of our common stock, no par value, in a registered public offering at $107.00 per share (approximately $105.07 per share after deducting underwriting discounts), with 23,364,486 shares pursuant to forward sale agreements. We received net proceeds totaling approximately $2.8 billion to fully settle these shares, as follows: ▪ $367 million (net of underwriting discounts and equity issuance costs of $8 million ) to cover overallotment shares of 3,504,672 in the first quarter of 2018 at a settlement price of $105.07 per share; ▪ $900 million (net of underwriting discounts of $16 million ) from the settlement of 8,556,630 shares in the first quarter of 2018 at a forward sale price of $105.18 per share; ▪ $800 million (net of underwriting discounts of $14 million ) from the settlement of 7,651,671 shares in the second quarter of 2018 at forward sale prices ranging from $104.53 to $104.58 per share; and ▪ $728 million (net of underwriting discounts of $13 million ) from the settlement of 7,156,185 shares in the third quarter of 2019 at a forward sale price of $101.74 per share . In July 2018, we completed the offering of 11,212,500 shares of our common stock, no par value, in a registered public offering at $113.75 per share (approximately $111.87 per share after deducting underwriting discounts), with 9,750,000 shares pursuant to forward sale agreements. We received net proceeds totaling approximately $1.2 billion to fully settle these shares, as follows: ▪ $164 million (net of underwriting discounts and equity issuance costs of $3 million ) to cover overallotment shares of 1,462,500 in the third quarter of 2018 at a settlement price of $111.87 per share; and ▪ $1,066 million (net of underwriting discounts of $18 million ) from the settlement of 9,750,000 shares in the fourth quarter of 2019 at a forward sale price of $109.33 per share. EARNINGS PER COMMON SHARE 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) Years ended December 31, 2019 2018 2017 Numerator for continuing operations: Income from continuing operations, net of income tax $ 1,999 $ 938 $ 382 Earnings attributable to noncontrolling interests (129 ) (44 ) (67 ) Mandatory convertible preferred stock dividends (142 ) (125 ) — Preferred dividends of subsidiary (1 ) (1 ) (1 ) Earnings from continuing operations attributable to common shares $ 1,727 $ 768 $ 314 Numerator for discontinued operations: Income (loss) from discontinued operations, net of income tax $ 363 $ 188 $ (31 ) Earnings attributable to noncontrolling interests (35 ) (32 ) (27 ) Earnings (losses) from discontinued operations attributable to common shares $ 328 $ 156 $ (58 ) Numerator for earnings: Earnings attributable to common shares $ 2,055 $ 924 $ 256 Denominator: Weighted-average common shares outstanding for basic EPS (1) 277,904 268,072 251,545 Dilutive effect of stock options and RSUs (2) 1,585 919 755 Dilutive effect of common shares sold forward 2,544 861 — Weighted-average common shares outstanding for diluted EPS 282,033 269,852 252,300 Basic EPS: Earnings from continuing operations $ 6.22 $ 2.86 $ 1.25 Earnings (losses) from discontinued operations $ 1.18 $ 0.59 $ (0.23 ) Earnings $ 7.40 $ 3.45 $ 1.02 Diluted EPS: Earnings from continuing operations $ 6.13 $ 2.84 $ 1.24 Earnings (losses) from discontinued operations $ 1.16 $ 0.58 $ (0.23 ) Earnings $ 7.29 $ 3.42 $ 1.01 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 617 in 2019, 641 in 2018 and 609 in 2017. 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. (2) 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, dilutive RSUs may vary widely from period-to-period. The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. The computation of diluted EPS excludes potentially dilutive shares of 80,281 for 2019, 20,814 for 2018 and 237,741 for 2017 because to include them would be antidilutive for the period. However, these shares could potentially dilute basic EPS in the future. The potentially dilutive impact from the forward sale of our common stock pursuant to the forward sale agreements that we discuss above is reflected in our diluted EPS calculation using the treasury stock method. As of December 31, 2019, we have fully settled all forward sale agreements and those shares are included in weighted-average shares common shares outstanding for basic EPS. The potentially dilutive impact from mandatory convertible preferred stock that we issued in 2018 is calculated under the if-converted method. The computation of diluted EPS for the years ended December 31, 2019 and 2018 excludes 17,471,375 and 17,197,035 potentially dilutive shares, respectively, because to include them would be antidilutive for those periods. However, these shares could potentially dilute basic EPS in the future. We discuss the 2018 issuances of our mandatory convertible preferred stock in Note 13 . We are authorized to issue 750 million shares of no par value common stock. The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY Years ended December 31, 2019 2018 2017 Common shares outstanding, January 1 273,769,513 251,358,977 250,152,514 Shares issued under forward sale agreements 16,906,185 21,175,473 — RSUs vesting (1) 463,012 509,042 362,022 Stock options exercised 52,540 138,861 164,454 Savings plan issuance 475,774 553,036 567,428 Common stock investment plan (2) 199,253 231,242 254,047 Issuance of RSUs held in our Deferred Compensation Plan 59,470 3,357 7,811 Shares repurchased (3) (212,822 ) (200,475 ) (149,299 ) Common shares outstanding, December 31 291,712,925 273,769,513 251,358,977 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) Generally, we purchase shares of our common stock or units from LTIP participants who elect to sell to us a sufficient number of vested RSUs to meet minimum statutory tax withholding requirements.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	12 Months Ended
	Dec. 31, 2019
Regulated Operations [Abstract]
SAN ONOFRE NUCLEAR GENERATING STATION	REGULATORY MATTERS REGULATORY ASSETS AND LIABILITIES We show the details of regulatory assets and liabilities in the following table and discuss them below. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2019 2018 SDG&E: Fixed-price contracts and other derivatives $ 8 $ (150 ) Deferred income taxes refundable in rates (108 ) (236 ) Pension and other postretirement benefit plan obligations 103 186 Removal obligations (2,056 ) (1,848 ) Environmental costs 45 28 Sunrise Powerlink fire mitigation 121 120 Regulatory balancing accounts (1)(2) Commodity – electric 102 (8 ) Gas transportation 22 45 Safety and reliability 77 70 Public purpose programs (124 ) (62 ) 2019 GRC retroactive impacts 111 — Other balancing accounts 106 145 Other regulatory liabilities, net (2) (153 ) (170 ) Total SDG&E (1,746 ) (1,880 ) SoCalGas: Deferred income taxes refundable in rates (203 ) (336 ) Pension and other postretirement benefit plan obligations 400 470 Employee benefit costs 44 49 Removal obligations (728 ) (833 ) Environmental costs 40 28 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (118 ) 196 Safety and reliability 295 332 Public purpose programs (273 ) (325 ) 2019 GRC retroactive impacts 400 — Other balancing accounts (7 ) (68 ) Other regulatory liabilities, net (2) (101 ) (114 ) Total SoCalGas (251 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 83 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (1,908 ) $ (2,394 ) (1) At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $108 million and $78 million , respectively. At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SoCalGas was $500 million and $185 million , respectively. (2) Includes regulatory assets earning a return. In the table above: ▪ Regulatory assets arising from fixed-price contracts and other derivatives are offset by corresponding liabilities arising from purchased power and natural gas commodity and transportation contracts. The regulatory asset is increased/decreased based on changes in the fair market value of the contracts. It is also reduced as payments are made for commodities and services under these contracts. ▪ Deferred income taxes refundable/recoverable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Mexico expect to refund/recover net regulatory liabilities/assets related to deferred income taxes over the lives of the assets that give rise to the related accumulated deferred income tax balances. Regulatory assets and liabilities include certain income tax benefits and expenses associated with flow-through items, which we discuss in Note 8. ▪ Regulatory assets/liabilities related to pension and other postretirement benefit plan obligations are offset by corresponding liabilities/assets and are being recovered in rates as the plans are funded. ▪ The regulatory asset related to employee benefit costs represents our liability associated with long-term disability insurance that will be recovered from customers in future rates as expenditures are made. ▪ Regulatory liabilities from removal obligations represent cumulative amounts collected in rates for future asset removal costs in excess of cumulative amounts incurred (or paid). ▪ Regulatory assets related to environmental costs represent the portion of our environmental liability recognized at the end of the period in excess of the amount that has been recovered through rates charged to customers. We expect this amount to be recovered in future rates as expenditures are made. ▪ The regulatory asset related to Sunrise Powerlink fire mitigation is offset by a corresponding liability for the funding of a trust to cover the mitigation costs. SDG&E expects to recover the regulatory asset in rates as the trust is funded over a remaining 50 -year period. ▪ Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, including commodity costs. Depreciation and return on rate base may also be included in certain accounts. Amounts in the balancing accounts are recoverable (receivable) or refundable (payable) in future rates, subject to CPUC approval. Amortization expense on regulatory assets for the years ended December 31, 2019 , 2018 and 2017 was $7 million , $5 million and $50 million , respectively, at Sempra Energy Consolidated, $3 million , $2 million and $49 million , respectively, at SDG&E, and $4 million , $3 million and $1 million , respectively, at SoCalGas. 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 %) 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 %) over its authorized 2018 revenue requirement. 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 The adopted revenue requirements associated with the period from January 1, 2019 through December 31, 2019 are being recovered in rates over a 24-month period beginning in January 2020. At December 31, 2019, SDG&E recorded an associated regulatory asset of $111 million , with $56 million as noncurrent, and SoCalGas recorded an associated regulatory asset of $400 million , with $200 million as noncurrent. In January 2020, the CPUC issued a final decision implementing a four-year GRC cycle for California IOUs. The California Utilities were directed to file a petition for modification to revise their 2019 GRC to add two additional attrition years, resulting in a transitional five-year GRC period (2019-2023). 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. 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 $89 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. Final resolution of the scope of the two-way income tax expense memorandum account for the 2016 through 2018 period is pending at the CPUC and could impact the disposition of these regulatory liabilities. We expect resolution in the first half of 2020. The 2016 GRC FD revenue requirement was authorized using a federal income tax rate of 35% . As a result of the TCJA, the federal income tax rate became 21% effective January 1, 2018. Since SDG&E and SoCalGas continued to collect authorized revenues based on a 35% tax rate, SDG&E and SoCalGas recorded regulatory liabilities of $88 million and $75 million , respectively. Pursuant to the 2019 GRC FD, SDG&E and SoCalGas are refunding the regulatory balances over a 24-month period starting in January 2020. SDG&E also recorded a $66 million regulatory liability at December 31, 2019 , relating to its FERC jurisdictional rates, which it began refunding in June 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% to 56% . SDG&E also proposed to increase its authorized ROE from 10.2% to 14.3% (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% to 10.03% . In August 2019, SDG&E filed supplemental testimony to update its ROE request from 10.2% to 12.38% to reflect the impacts of the Wildfire Legislation, including a revised premium for wildfire liability risk, and its authorized return on rate base from 7.55% to 8.95% . SoCalGas proposed to adjust its authorized capital structure by increasing the amount of its common equity from 52% to 56% , its authorized ROE from 10.05% to 10.7% and its authorized return on rate base from 7.34% to 7.85% . In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that are effective January 1, 2020 and will remain in effect through December 31, 2022. SDG&E did not propose a 2020 cost of preferred equity in this proceeding. In January 2020, SDG&E filed an advice letter to continue the cost of preferred equity for test year 2020 at 6.22% , which is pending CPUC approval. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on rate base Weighted rate base Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Stock 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 % The CCM was reauthorized in the 2020 cost of capital proceeding to continue through 2022. The CCM benchmark rate for the 2020 cost of capital is the average monthly utility bond index, as published by Moody’s, for the 12-month period from October 2018 through September 2019. SDG&E’s CCM benchmark rate is 4.491% , based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.024% , based on Moody’s A- utility bond index. The index applicable to each utility is based on each utility’s credit rating. The CCM benchmark rates for SDG&E and SoCalGas are the basis of comparison to determine if future measurement periods “trigger” the CCM. The 12 months ending September 2020 shall be the first “CCM Period” to determine if there has been a trigger at SDG&E or SoCalGas. The trigger occurs if the change in the applicable average Moody’s utility bond index relative to the CCM benchmark is larger than plus or minus 1.000% . Accordingly, if a change of more than plus or minus 1.000% occurs, SDG&E’s, SoCalGas’, or both utilities’ authorized ROE would be adjusted, upward or downward, by one half of the difference between the CCM benchmark and the 12-month average determined during the CCM Period. In addition, the authorized recovery rate for the respective utilities’ cost of debt and preferred stock would be adjusted to their respective actual weighted-average cost, with no change to the authorized capital structure. In the event of a CCM trigger, the CCM benchmark is also reestablished. These adjustments would become effective in authorized rates on January 1 of the year following the CCM trigger. SDG&E FERC Rate Matters and Cost of Capital SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets. SDG&E’s current estimated FERC return on rate base under the TO4 formula rate request filing is 7.51% based on its capital structure as follows: FERC–AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE – SDG&E Weighting Return on rate base Weighted return on rate base Long-Term Debt 43.44 % 4.21 % 1.83 % Common Equity 56.56 10.05 5.68 100.00 % 7.51 % FERC Formulaic Rate Filing In October 2018, SDG&E submitted its TO5 filing to the FERC proposing, among other items, an increase to SDG&E’s current authorized FERC ROE from 10.05% to 11.20% . This proceeding establishes the transmission revenue requirement, including rate of return, for SDG&E’s FERC-regulated electric transmission operations and assets. On December 31, 2018, the FERC issued its order accepting and suspending SDG&E’s TO5 filing for five months, during which the existing TO4 rates remained in effect, and established hearing and settlement procedures. 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% is the basis of SDG&E’s FERC-related revenue recognition. In October 2019, SDG&E and all settling parties reached an agreement on all issues set for hearing in the proceeding. The agreement provides for a ROE of 10.60% , consisting of a base ROE of 10.10% 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 in May 2019, which is pending before the CPUC. The CPUC granted SoCalGas’ request to delay distribution of the $100 bill credit to customers until a final decision on the rehearing. SEMPRA MEXICO In July and December of 2018, the CRE adjusted Ecogas’ natural gas distribution rates charged to end-users in 2014 through 2016. Ecogas recorded regulatory assets of $7 million and $5 million SDG&E has a 20% ownership interest in SONGS, a nuclear generating facility near San Clemente, California, which permanently ceased operations in June 2013 after an extended outage as a result of issues with the steam generators used in the facility. Edison, the majority owner and operator of SONGS, notified SDG&E that it had reached a decision to permanently retire SONGS and seek approval from the NRC to start the decommissioning activities for the entire facility. SONGS is subject to the jurisdiction of the NRC and the CPUC. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for financing its share of costs. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. SONGS STEAM GENERATOR REPLACEMENT PROJECT The replacement steam generators, which caused a water leak due to unexpected tube wear, were designed and provided by MHI. In 2013, Edison instituted arbitration proceedings against MHI seeking recovery of damages resulting from the issues with the steam generators used in SONGS Units 2 and 3. The other SONGS co-owners, SDG&E and the City of Riverside, participated as claimants and respondents. In March 2017, the International Chamber of Commerce International Court of Arbitration Tribunal (the Tribunal) overseeing the arbitration found MHI liable for breach of contract, subject to a contractual limitation of liability, and rejected claimants’ other claims. The Tribunal awarded $118 million in damages to the SONGS co-owners, but determined that MHI was the prevailing party and awarded it 95% of its arbitration costs. The damage award is offset by these costs, resulting in a net award of approximately $60 million in favor of the SONGS co-owners. SDG&E’s specific allocation of the damage award was $24 million reduced by costs awarded to MHI of approximately $12 million , resulting in a net damage award of $12 million , which was paid by MHI to SDG&E in March 2017. In accordance with the Amended Settlement Agreement discussed below, SDG&E recorded the proceeds from the MHI arbitration by reducing O&M for previously incurred legal costs of $11 million , and shared the remaining $1 million equally between ratepayers and shareholders. SETTLEMENT AGREEMENT TO RESOLVE THE CPUC’S ORDER INSTITUTING INVESTIGATION INTO THE SONGS OUTAGE In 2012, in response to the SONGS outage, the CPUC issued the SONGS OII, which was intended to determine the ultimate recovery of the investment in SONGS and the costs incurred since the commencement of the outage. In 2014, the CPUC issued a final decision approving an Amended Settlement Agreement that provided for various disallowances, refunds and rate recoveries, including authorizing SDG&E to recover in rates its remaining investment in SONGS, excluding its investment in the Steam Generator Replacement Project. In 2016, the CPUC issued two procedural rulings: the first, to reopen the record of the OII to address the issue of whether the Amended Settlement Agreement is reasonable and in the public interest, and the second, directing parties to the SONGS OII to determine whether an agreement could be reached to modify the Amended Settlement Agreement previously approved by the CPUC, to resolve allegations that unreported ex parte communications between Edison and the CPUC resulted in an unfair advantage at the time the settlement agreement was negotiated. In July 2018, the CPUC approved a Revised Settlement Agreement among SDG&E, Edison, Cal PA, TURN and other intervenors that resolved all issues under consideration in the SONGS OII and made one modification to the Amended Settlement Agreement to remove the requirement to fund a GHG emissions reduction research program. In August 2018, parties to the Revised Settlement Agreement submitted a notice that they accepted the settlement agreement, as modified. In connection with the Revised Settlement Agreement, and in exchange for the release of certain SONGS-related claims, SDG&E and Edison entered into the Utility Shareholder Agreement, described below. Disallowances, Refunds and Recoveries Under the Revised Settlement Agreement, SDG&E and Edison ceased rate recovery of SONGS costs as authorized under the Amended Settlement Agreement as of December 19, 2017, when the present value of their combined remaining SONGS regulatory assets equaled $775 million , of which $152 million represents SDG&E’s share. Under the Utility Shareholder Agreement, Edison is obligated to pay SDG&E the full amount of SDG&E’s revenue requirement not recovered from ratepayers, as described below. In October 2018, SDG&E began refunding to customers SONGS-related amounts recovered in rates after December 19, 2017. Utility Shareholder Agreement In January 2018, SDG&E and Edison entered into the Utility Shareholder Agreement under which Edison has an obligation to compensate SDG&E for the revenue requirement amounts that SDG&E will no longer recover because of the Revised Settlement Agreement. In exchange for Edison’s reimbursement, the parties mutually released each other from all claims that each party had or could have asserted related to the steam generator replacement failure and its aftermath. The Utility Shareholder Agreement became effective upon CPUC approval of the Revised Settlement Agreement. Edison’s payment obligation commenced in October 2018, and amounts are due to SDG&E quarterly thereafter until April 2022. At December 31, 2019 , SDG&E has a receivable from Edison, including accrued interest, totaling $86 million , with $38 million classified as current and $48 million classified as noncurrent. This receivable reflects amounts Edison is obligated to pay to SDG&E in lieu of amounts SDG&E would have collected from ratepayers associated with the SONGS regulatory asset. 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. We expect the majority of the dismantlement work to take 10 years after receipt of the required permits. The coastal development permit was issued in October 2019. The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019. The petition seeks to invalidate the permit and to obtain injunctive relief to stop decommissioning work. We expect major decommissioning work to begin in 2020, unless the court issues an injunction. 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% 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 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 SONGS decommissioning costs. SDG&E has filed for authorization with the CPUC to withdraw up to $109 million from the NDT for forecasted 2020 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. 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 timely 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. Nuclear Decommissioning Trusts The amounts collected in rates for SONGS’ decommissioning are invested in the NDT, which is comprised of externally managed trust funds. Amounts held by the trusts are invested in accordance with CPUC regulations. These trusts are shown on the Sempra Energy and SDG&E Consolidated Balance Sheets at fair value with the offsetting credits recorded in noncurrent Regulatory Liabilities. 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 12 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 57 $ — $ — $ 57 Municipal bonds (2) 270 12 — 282 Other securities (3) 218 9 (1 ) 226 Total debt securities 545 21 (1 ) 565 Equity securities 176 339 (6 ) 509 Cash and cash equivalents 8 — — 8 Total $ 729 $ 360 $ (7 ) $ 1,082 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 2020 - 2072 . 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) Years ended December 31, 2019 2018 2017 Proceeds from sales $ 914 $ 890 $ 1,314 Gross realized gains 24 42 157 Gross realized losses (5 ) (10 ) (14 ) 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 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 The present value of SDG&E’s ARO related to decommissioning costs for the SONGS units was $611 million at December 31, 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 . We expect SDG&E’s undiscounted SONGS decommissioning payments to be $89 million in 2020, $82 million in 2021, $83 million in 2022, $63 million in 2023, $46 million in 2024, and $739 million thereafter. 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 CCC 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. In November 2019, Edison filed a claim for spent fuel management costs in the U.S. Court of Federal Claims for the time period from January 2017 through July 2018. It is unclear when Edison will pursue litigation claims for spent fuel management costs incurred on or after August 1, 2018. 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. 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	12 Months Ended
	Dec. 31, 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 December 31, 2019 , loss contingency accruals for legal matters, including associated legal fees, that are probable and estimable were $68 million for Sempra Energy Consolidated and $21 million for SoCalGas. Amounts for Sempra Energy Consolidated and SoCalGas include $10 million for matters related to the Aliso Canyon natural gas storage facility gas leak, which we discuss below. We discuss our policy regarding accrual of legal fees in Note 1 . SDG&E 2007 Wildfire Litigation and Net Cost Recovery Status SDG&E has resolved all 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 decision, effectively ending SDG&E’s efforts to recover the wildfire regulatory asset. SoCalGas Aliso Canyon Natural Gas Storage Facility Gas Leak From October 23, 2015 through February 11, 2016, SoCalGas experienced a natural gas leak from one of the injection-and-withdrawal wells, SS25, at its Aliso Canyon natural gas storage facility in Los Angeles County. As described below in “Civil and Criminal Litigation” and “Regulatory Proceedings,” numerous lawsuits, investigations and regulatory proceedings have been initiated in response to the Leak, resulting in significant costs, which together with other Leak-related costs are discussed below in “Cost Estimates and Accounting Impact.” Civil and Criminal Litigation. As of February 21, 2020, 393 lawsuits, including approximately 36,000 plaintiffs, are pending against SoCalGas related to the Leak, 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, in the coordinated proceeding, individuals and business entities 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 of action 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, 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. Three property developers filed complaints in July and October of 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 firefighters stationed near the Aliso Canyon natural gas storage facility who 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. 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. In November 2019, the Superior Court dismissed the complaints on the grounds that the plaintiffs failed to adequately plead their claims, but gave leave for them to amend the complaints to cure the defects. In February 2020, an amended complaint was filed. In addition, a federal securities class action alleging violation of the federal securities laws was filed against Sempra Energy and certain of its officers in July 2017 in the U.S. District Court for the Southern District of California. In March 2018, the court dismissed the action with prejudice. The plaintiffs have appealed the dismissal. 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 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. In February 2019, the LA Superior Court approved a settlement between SoCalGas and the Los Angeles City Attorney’s Office, the County of Los Angeles, the California Office of the Attorney General and CARB under which SoCalGas made payments and agreed to provide funding for environmental projects totaling $120 million , including $21 million in civil penalties, as well as other safety-related commitments. In February 2016, the Los Angeles County District Attorney’s Office filed a misdemeanor criminal complaint against SoCalGas seeking penalties and other remedies for, among other things, 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). Pursuant to a settlement agreement with the Los Angeles County District Attorney’s Office, SoCalGas agreed to plead no contest to the notice charge and 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 objected 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 give the petitioners an opportunity to prove damages stemming from only the three-day delay in reporting the Leak. Regulatory Proceedings. In January 2016, CalGEM and the CPUC directed an independent analysis of the technical root cause of the Leak to be conducted by Blade. In May 2019, Blade released its report, which concluded that the Leak was caused by a failure of the production casing of the well due to corrosion and that attempts to stop the Leak were not effectively conducted, but did not identify any instances of non-compliance by SoCalGas. Blade concluded that SoCalGas’ compliance activities conducted prior to the Leak did not find indications of a casing integrity issue. Blade opined, however, that 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 CalGEM and implemented by SoCalGas, which address most of the root cause of the Leak identified during Blade’s investigation. In June 2019, the CPUC opened an OII to consider penalties against SoCalGas for the Leak, which it later bifurcated into two phases. The first phase will consider 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 (SED) 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. In November 2019, SED, based largely on the Blade report, alleged a total of 330 violations, asserting that SoCalGas violated California Public Utilities Code Section 451 and failed to cooperate in the investigation and to keep proper records. Hearings in the first phase of the OII are scheduled to begin in April 2020. 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. In a January 2016 emergency proclamation, the Governor ordered the CPUC to ensure that SoCalGas covers costs related to the Leak and its response, while protecting ratepayers. In addition, CalGEM is investigating the Leak. 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, but excluding issues with respect to air quality, public health, causation, culpability or cost responsibility regarding the Leak. The first phase established 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 relative to Phase 2 in 2020. In December 2019, the CPUC added a third phase to consider alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either 2027 or 2045. If the Aliso Canyon natural gas storage facility were to be permanently closed, or if future cash flows from its operation 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 December 31, 2019, the Aliso Canyon natural gas storage facility had a net book value of $769 million . Any significant impairment of this asset, or higher operating costs and additional capital expenditures incurred by SoCalGas which may not be recoverable in customer rates, could have a material adverse effect on SoCalGas’ and Sempra Energy’s results of operations, financial condition and cash flows. Cost Estimates and Accounting Impact. SoCalGas has incurred significant costs for temporary relocation of community residents; to control the well and stop the Leak; to mitigate the natural gas released; to purchase natural gas to replace what was lost through the Leak; 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 Blade to conduct the root cause analysis described above; to respond to various government and agency investigations regarding the Leak; and to comply with increased regulation imposed as a result of the Leak. At December 31, 2019, SoCalGas estimates its costs related to the Leak are $1,116 million (the cost estimate), which includes $1,086 million of costs recovered or probable of recovery from insurance. This estimate may rise significantly as more information becomes available. Approximately 51% of the cost estimate is for the temporary relocation program (including cleaning costs and certain labor costs). A substantial portion of the cost estimate has been paid, and $9 million is accrued as Reserve for Aliso Canyon Costs and $7 million is accrued in Deferred Credits and Other as of December 31, 2019 on SoCalGas’ and Sempra Energy’s Consolidated Balance Sheets. Except for the amounts paid or estimated to settle certain actions as described above, the cost estimate does not include litigation or regulatory costs as it is not possible at this time to predict the outcome of these actions or reasonably estimate the costs to defend or resolve the actions or the amount of damages, restitution, or civil, administrative or criminal fines, sanctions, penalties or other costs or remedies that may be imposed or incurred, which could be significant. The cost estimate also does not include certain other costs incurred by Sempra Energy associated with defending against shareholder derivative lawsuits and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. 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. We have received insurance payments for many 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. As of December 31, 2019, we recorded the expected recovery of the cost estimate related to the Leak of $339 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Consolidated Balance Sheets. This amount is net of insurance retentions and $747 million of insurance proceeds we received through December 31, 2019. 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. Sempra Mexico Energía Costa Azul. IEnova has been engaged in a long-running land dispute relating to property adjacent to its ECA LNG Regasification facility 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 the ECA LNG Regasification facility 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 LNG JV for the potential liquefaction-export project in September 2017 and December 2017, respectively, to allow natural gas liquefaction activities at the ECA LNG Regasification facility. The court issued a provisional injunction in September 2018 and maintained that provisional injunction at an April 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 by ECA LNG JV in two phases. In May 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 the ECA LNG Regasification facility. 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 Regasification facility 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 the ECA LNG Regasification facility purchased another of the 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 the ECA LNG Regasification facility and potential ECA LNG JV liquefaction-export project. 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 order prohibited construction in the remainder of the Yaqui territory. Construction of the Guaymas-El Oro segment was completed, and commercial operations began in May 2017. Following the start of commercial operations of the Guaymas-El Oro segment, IEnova reported damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory that has made that section inoperable since August 23, 2017 and, as a result, IEnova declared a force majeure event. In 2017, an appellate court ruled that the scope of the 2016 suspension order encompassed the wider Yaqui territory, which has prevented IEnova from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of IEnova and held that the Yaqui tribe was properly consulted and that consent from the Yaqui tribe was properly received. Representatives of the Bácum community appealed this decision, causing the suspension order preventing IEnova from repairing the damage to the Guaymas-El Oro segment of the Sonora pipeline in the Yaqui territory to remain in place until the appeals process is exhausted. IEnova exercised its rights under the contract, which included seeking force majeure payments for the two-year period such force majeure payments were required to be made, which ended on August 22, 2019. In July 2019, the CFE filed a request for arbitration generally to nullify certain contract terms that provide for fixed capacity payments in instances of force majeure and made a demand for substantial damages in connection with the force majeure event. In September 2019, the arbitration process ended when IEnova and the CFE reached an agreement to restart natural gas transportation service on the earlier of completion of repair of the damaged pipeline or January 15, 2020, and to modify the tariff structure and extend the term of the contract by 10 years. In January 2020, IEnova and the CFE agreed to extend the January 15, 2020 new service start date to May 15, 2020. Under the revised agreement, the CFE will resume making payments only when the damaged section of the Guaymas-El Oro segment of the Sonora pipeline is repaired. If the pipeline is not repaired by May 15, 2020 and the parties do not agree on a new service start date, IEnova retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits. If IEnova is unable to make such repairs and resume operations in the Guaymas-El Oro segment of the Sonora pipeline within this time frame or if IEnova terminates the contract and is unable to obtain recovery, there may be a material adverse impact on Sempra Energy’s results of operations and cash flows and our ability to recover the carrying value of our investment. The Sasabe-Puerto Libertad-Guaymas segment of the Sonora pipeline remains in full operation and is not impacted by these developments. Sur de Texas-Tuxpan Marine Pipeline. Sempra Mexico has a 40% interest in IMG JV, a JV with a subsidiary of TC Energy, to build, own and operate the Sur de Texas-Tuxpan natural gas marine pipeline in Mexico. The JV has an agreement to provide the CFE with natural gas transportation services under a 25 -year agreement, denominated in U.S. dollars. IMG JV previously received force majeure payments from the CFE from November 2018 through April 2019, after construction delays extended the commercial operation date. In June 2019, the CFE filed a request for arbitration generally to nullify certain contract terms that provide for fixed capacity payments in instances of force majeure and made a demand for substantial damages in connection with the force majeure event. In September 2019, the JV and the CFE amended the gas transportation services agreement to modify the tariff structure and extend the term of the contract by 10 years, which ended the arbitration process. Construction and commissioning activities on the pipeline were completed in June 2019 and, in September 2019, IMG JV received acceptance from the CFE allowing the pipeline to enter commercial operation and for service under the gas transportation contract to commence. Other Litigation Sempra Energy holds an NCI in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. NatWest Markets plc, formerly RBS, our partner in the JV, paid an assessment of £86 million (approximately $138 million in U.S. dollars) in October 2014 to HMRC for denied VAT refund claims filed in connection with the purchase of carbon credit allowances by RBS SEE, a subsidiary of RBS Sempra Commodities. RBS SEE has since been sold to JP Morgan and later to Mercuria Energy Group, Ltd. HMRC asserted that RBS was not entitled to reduce its VAT liability by VAT paid on certain carbon credit purchases during 2009 because RBS knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. After paying the assessment, RBS filed a Notice of Appeal of the assessment with the First-Tier Tribunal. Trial on the matter has been scheduled between November 2, 2020 and December 11, 2020. In 2015, liquidators filed a claim in the High Court of Justice against RBS and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and for compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in June and July of 2018, at the close of which the Liquidating Companies asserted that the Defendants were liable to the Liquidating Companies in the amount of £71.5 million (approximately $95 million in U.S. dollars at December 31, 2019 ) for dishonest assistance and, to the extent that claim is unsuccessful, to the liquidators in the same amount under the U.K. Insolvency Act of 1986. If the High Court of Justice finds the Defendants liable, it will determine the amount. JP Morgan has notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and JP Morgan has in turn sought indemnity from Sempra Energy and RBS. While the ultimate outcome remains uncertain, in the third quarter of 2018, we impaired our remaining $65 million equity method investment in RBS Sempra Commodities. Certain EFH subsidiaries that we acquired as part of the Merger are defendants in personal injury lawsuits brought in state courts throughout the U.S. As of February 21, 2020, 275 such lawsuits are pending, with 182 such lawsuits having been served. These cases allege illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They seek compensatory and punitive damages. Additionally, in connection with the EFH bankruptcy proceeding, approximately 28,000 proofs of claim were filed on behalf of persons who allege exposure to asbestos under similar circumstances and assert the right to file such lawsuits in the future. We anticipate additional lawsuits will be filed. None of these claims or lawsuits were discharged in the EFH bankruptcy proceeding. We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, employment litigation, product liability, property damage and other claims. Juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases . LEASES A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. We determine if an arrangement is or contains a lease at inception of the contract. Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate and power generating facilities if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately. Lessee Accounting We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy and peaker plant facilities. Some of our leases include options to extend the lease terms for up to 25 years , while others include options to terminate the lease within one year . Our lease liabilities and ROU assets are based on lease terms that may include such options to extend or terminate the lease when it is reasonably certain that we will exercise that option. 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-

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION We have 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, at December 31, 2019, owns an 80.25 % interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern and western and panhandle regions of Texas, and our indirect, 50% 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 our investment in Oncor Holdings in March 2018 and 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 projects for the export of LNG, holds an interest in a facility for the export of LNG, owns and operates natural gas pipelines, and buys, sells and transports natural gas through its 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 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 and the FERC. We describe the accounting policies of all of our segments in Note 1 . 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 Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 6 . 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) Years ended December 31, 2019 2018 2017 REVENUES SDG&E $ 4,925 $ 4,568 $ 4,476 SoCalGas 4,525 3,962 3,785 Sempra Mexico 1,375 1,376 1,196 Sempra Renewables 10 124 94 Sempra LNG 410 472 540 All other 3 — — Adjustments and eliminations (3 ) (3 ) (1 ) Intersegment revenues (1) (416 ) (397 ) (450 ) Total $ 10,829 $ 10,102 $ 9,640 INTEREST EXPENSE SDG&E (2) $ 411 $ 221 $ 203 SoCalGas 141 115 102 Sempra Mexico 119 120 97 Sempra Renewables 3 19 15 Sempra LNG 35 21 39 All other 450 496 284 Intercompany eliminations (82 ) (106 ) (118 ) Total $ 1,077 $ 886 $ 622 INTEREST INCOME SDG&E $ 4 $ 4 $ — SoCalGas 2 2 1 Sempra Mexico 78 65 23 Sempra Renewables 11 12 7 Sempra LNG 61 49 56 All other 4 14 — Intercompany eliminations (73 ) (61 ) (63 ) Total $ 87 $ 85 $ 24 DEPRECIATION AND AMORTIZATION SDG&E $ 760 $ 688 $ 670 SoCalGas 602 556 515 Sempra Mexico 183 175 156 Sempra Renewables — 27 38 Sempra LNG 10 26 42 All other 14 19 15 Total $ 1,569 $ 1,491 $ 1,436 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 171 $ 173 $ 155 SoCalGas 120 92 160 Sempra Mexico 227 185 227 Sempra Renewables 4 71 (226 ) Sempra LNG (5 ) (435 ) (119 ) All other (202 ) (135 ) 741 Total $ 315 $ (49 ) $ 938 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Years ended December 31 or at December 31, 2019 2018 2017 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 767 $ 669 $ 407 SoCalGas 641 400 396 Sempra Texas Utilities 528 371 — Sempra Mexico 253 237 169 Sempra Renewables 59 328 252 Sempra LNG (6 ) (617 ) 150 Discontinued operations 328 156 (58 ) All other (515 ) (620 ) (1,060 ) Total $ 2,055 $ 924 $ 256 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,522 $ 1,542 $ 1,555 SoCalGas 1,439 1,538 1,367 Sempra Mexico 624 368 248 Sempra Renewables 2 51 497 Sempra LNG 112 31 20 All other 9 14 18 Total $ 3,708 $ 3,544 $ 3,705 ASSETS SDG&E $ 20,560 $ 19,225 $ 17,844 SoCalGas 17,077 15,389 14,159 Sempra Texas Utilities 11,619 9,652 — Sempra Mexico 9,938 9,165 8,554 Sempra Renewables — 2,549 2,898 Sempra LNG 3,901 4,060 4,872 Discontinued operations 3,958 3,718 3,561 All other 749 1,070 1,351 Intersegment receivables (2,137 ) (4,190 ) (2,785 ) Total $ 65,665 $ 60,638 $ 50,454 GEOGRAPHIC INFORMATION Long-lived assets (3) : United States $ 43,719 $ 40,611 $ 31,487 Mexico 6,355 5,800 5,363 Total $ 50,074 $ 46,411 $ 36,850 Revenues (4) : United States $ 9,574 $ 8,840 $ 8,547 Mexico 1,255 1,262 1,093 Total $ 10,829 $ 10,102 $ 9,640 (1) Revenues for reportable segments include intersegment revenues of $5 million , $69 million , $120 million and $222 million for 2019 ; $4 million , $64 million , $114 million and $215 million for 2018 ; and $7 million , $74 million , $103 million and $266 million for 2017 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. (3) Includes net PP&E and investments. (4) Amounts are based on where the revenue originated, after intercompany eliminations.

QUARTERLY FINANCIAL DATA (UNAUD

QUARTERLY FINANCIAL DATA (UNAUDITED)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Data [Abstract]
Quarterly Financial Data (Unaudited)	QUARTERLY FINANCIAL DATA (UNAUDITED) We provide quarterly financial information for Sempra Energy Consolidated, SDG&E and SoCalGas below: SEMPRA ENERGY (In millions, except per share amounts) Quarters ended March 31 June 30 September 30 December 31 2019: Revenues $ 2,898 $ 2,230 $ 2,758 $ 2,943 Expenses and other income $ 2,397 $ 1,944 $ 2,310 $ 2,444 Income from continuing operations, net of income tax $ 560 $ 357 $ 653 $ 429 (Loss) income from discontinued operations, net of income tax (42 ) 78 256 71 Net income $ 518 $ 435 $ 909 $ 500 Earnings attributable to common shares $ 441 $ 354 $ 813 $ 447 Basic EPS (1) : Earnings from continuing operations $ 1.79 $ 1.03 $ 2.04 $ 1.36 (Losses) earnings from discontinued operations $ (0.19 ) $ 0.26 $ 0.89 $ 0.21 Earnings $ 1.60 $ 1.29 $ 2.93 $ 1.57 Weighted-average common shares outstanding 274.7 275.0 277.4 284.6 Diluted EPS (1) : Earnings from continuing operations (2) $ 1.78 $ 1.01 $ 2.00 $ 1.34 (Losses) earnings from discontinued operations $ (0.19 ) $ 0.25 $ 0.84 $ 0.21 Earnings (2) $ 1.59 $ 1.26 $ 2.84 $ 1.55 Weighted-average common shares outstanding 277.2 279.6 295.8 288.8 2018: Revenues $ 2,536 $ 2,175 $ 2,565 $ 2,826 Expenses and other income $ 1,943 $ 3,358 $ 2,220 $ 1,867 Income (loss) from continuing operations, net of income tax $ 330 $ (585 ) $ 280 $ 913 Income from discontinued operations, net of income tax 28 55 54 51 Net income (loss) $ 358 $ (530 ) $ 334 $ 964 Earnings (losses) attributable to common shares $ 347 $ (561 ) $ 274 $ 864 Basic EPS (1) : Earnings (losses) from continuing operations $ 1.26 $ (2.29 ) $ 0.83 $ 3.00 Earnings from discontinued operations $ 0.08 $ 0.18 $ 0.17 $ 0.15 Earnings (losses) $ 1.34 $ (2.11 ) $ 1.00 $ 3.15 Weighted-average common shares outstanding 257.9 265.8 273.9 274.3 Diluted EPS (1)(3) : Earnings (losses) from continuing operations (2) $ 1.25 $ (2.29 ) $ 0.82 $ 2.89 Earnings from discontinued operations $ 0.08 $ 0.18 $ 0.17 $ 0.14 Earnings (losses) (2) $ 1.33 $ (2.11 ) $ 0.99 $ 3.03 Weighted-average common shares outstanding 259.5 265.8 275.9 296.4 (1) EPS is computed independently for each of the quarters and therefore may not sum to the total for the year. (2) In the quarters ended September 30, 2019 and December 31, 2018, due to the dilutive effect of certain mandatory convertible preferred stock, the numerator used to calculate diluted EPS included an add-back of related mandatory convertible preferred stock dividends declared in those quarters. (3) In the quarter ended June 30, 2018, the total weighted-average potentially dilutive securities were not included in the computation of losses per common share since to do so would have decreased the loss per share. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments and recognized a pretax gain on sale of $61 million ( $45 million after tax). We discuss the sale and related gain in Note 5 . In June 2018, we recorded impairment charges totaling $1.5 billion ( $900 million after tax and NCI), which included $1.3 billion ( $755 million after tax and NCI) at Sempra LNG and $200 million ( $145 million after tax) at Sempra Renewables. In December 2018, we reduced the impairment charge at Sempra LNG by $183 million ( $126 million after tax and NCI). We discuss the impairments in Notes 5 and 12 . In December 2018, we completed the sale of our U.S. operating solar assets, solar and battery storage development projects, as well as an interest in one wind facility, and recognized a pretax gain on sale of $513 million ( $367 million after tax). We discuss the sale and related gain in Note 5 . In September 2018, we impaired our remaining equity method investment in RBS Sempra Commodities by recording a charge of $65 million in Equity Earnings. We discuss matters related to RBS Sempra Commodities further in Note 16 . SDG&E (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2019: Operating revenues $ 1,145 $ 1,094 $ 1,427 $ 1,259 Operating expenses 883 831 1,004 894 Operating income $ 262 $ 263 $ 423 $ 365 Net income $ 177 $ 146 $ 266 $ 185 Earnings attributable to noncontrolling interest (1 ) (3 ) (3 ) — Earnings attributable to common shares $ 176 $ 143 $ 263 $ 185 2018: Operating revenues $ 1,055 $ 1,051 $ 1,299 $ 1,163 Operating expenses 807 836 999 916 Operating income $ 248 $ 215 $ 300 $ 247 Net income $ 169 $ 146 $ 216 $ 145 Losses (earnings) attributable to noncontrolling interest 1 — (11 ) 3 Earnings attributable to common shares $ 170 $ 146 $ 205 $ 148 SOCALGAS (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2019: Operating revenues $ 1,361 $ 806 $ 975 $ 1,383 Operating expenses 1,060 747 762 1,000 Operating income $ 301 $ 59 $ 213 $ 383 Net income $ 264 $ 31 $ 143 $ 204 Dividends on preferred stock — (1 ) — — Earnings attributable to common shares $ 264 $ 30 $ 143 $ 204 2018: Operating revenues $ 1,126 $ 772 $ 802 $ 1,262 Operating expenses 848 703 797 1,023 Operating income $ 278 $ 69 $ 5 $ 239 Net income (loss) $ 225 $ 34 $ (14 ) $ 156 Dividends on preferred stock — (1 ) — — Earnings (losses) attributable to common shares $ 225 $ 33 $ (14 ) $ 156 SoCalGas recognizes annual authorized revenue for core natural gas customers using seasonal factors established in the Triennial Cost Allocation Proceeding. Accordingly, a significant portion of SoCalGas’ annual earnings are recognized in the first and fourth quarters each year.

SCHEDULE I - CONDENSED FINANCIA

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT	12 Months Ended
	Dec. 31, 2019
Condensed Financial Information Disclosure [Abstract]
Schedule I - Condensed Financial Information of Parent	SEMPRA ENERGY CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2019 2018 2017 Interest income $ 3 $ 14 $ — Interest expense (521 ) (495 ) (293 ) Operating expenses (124 ) (82 ) (80 ) Other income (expense), net 59 (16 ) 100 Income tax benefit 163 154 33 Loss before equity in earnings of subsidiaries (420 ) (425 ) (240 ) Equity in earnings of subsidiaries, net of income taxes 2,617 1,474 496 Net income 2,197 1,049 256 Mandatory convertible preferred stock dividends (142 ) (125 ) — Earnings $ 2,055 $ 924 $ 256 Basic EPS: Earnings $ 7.40 $ 3.45 $ 1.02 Weighted-average common shares outstanding 277,904 268,072 251,545 Diluted EPS: Earnings $ 7.29 $ 3.42 $ 1.01 Weighted-average common shares outstanding 282,033 269,852 252,300 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2019, 2018 and 2017 Pretax amount Income tax benefit (expense) Net-of-tax amount 2019: Net income $ 2,034 $ 163 $ 2,197 Other comprehensive income (loss): Foreign currency translation adjustments (43 ) — (43 ) Financial instruments (161 ) 53 (108 ) Pension and other postretirement benefits 25 (7 ) 18 Total other comprehensive loss (179 ) 46 (133 ) Comprehensive income $ 1,855 $ 209 $ 2,064 2018: Net income $ 895 $ 154 $ 1,049 Other comprehensive income (loss): Foreign currency translation adjustments (144 ) — (144 ) Financial instruments 64 (21 ) 43 Pension and other postretirement benefits (38 ) 4 (34 ) Total other comprehensive loss (118 ) (17 ) (135 ) Comprehensive income $ 777 $ 137 $ 914 2017: Net income $ 223 $ 33 $ 256 Other comprehensive income (loss): Foreign currency translation adjustments 107 — 107 Financial instruments 2 1 3 Pension and other postretirement benefits 20 (8 ) 12 Total other comprehensive income 129 (7 ) 122 Comprehensive income $ 352 $ 26 $ 378 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED BALANCE SHEETS (Dollars in millions) December 31, December 31, Assets: Cash and cash equivalents $ 6 $ 14 Due from affiliates 98 93 Income taxes receivable, net — 397 Other current assets 34 9 Total current assets 138 513 Investments in subsidiaries 32,604 28,778 Due from affiliates 3 3 Deferred income taxes 1,766 1,554 Other long-term assets 682 572 Total assets $ 35,193 $ 31,420 Liabilities and shareholders’ equity: Current portion of long-term debt $ 1,399 $ 1,498 Due to affiliates 369 287 Income taxes payable, net 274 — Other current liabilities 561 527 Total current liabilities 2,603 2,312 Long-term debt 8,856 9,647 Due to affiliates 3,138 1,812 Other long-term liabilities 667 511 Commitments and contingencies (Note 4) Shareholders’ equity 19,929 17,138 Total liabilities and shareholders’ equity $ 35,193 $ 31,420 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2019 2018 2017 Net cash provided by operating activities $ 294 $ 213 $ 89 Expenditures for property, plant and equipment (8 ) (11 ) (11 ) Expenditures for acquisition — (329 ) — Capital contributions to investees (1,528 ) (9,457 ) — Increase in loans to affiliates, net — (1 ) — Expenditures for Merger-related costs — — (12 ) Other 4 — — Net cash used in investing activities (1,532 ) (9,798 ) (23 ) Common stock dividends paid (993 ) (877 ) (755 ) Preferred dividends paid (142 ) (89 ) — Issuances of mandatory convertible preferred stock, net — 2,258 — Issuances of common stock, net 1,830 2,272 47 Repurchases of common stock (26 ) (21 ) (15 ) Issuances of long-term debt 758 4,969 1,595 Payments on long-term debt (1,500 ) (500 ) (600 ) Increase (decrease) in loans from affiliates, net 1,328 1,520 (239 ) Debt issuance costs (25 ) (37 ) (7 ) Net cash provided by financing activities 1,230 9,495 26 (Decrease) increase in cash and cash equivalents (8 ) (90 ) 92 Cash and cash equivalents, January 1 14 104 12 Cash and cash equivalents, December 31 $ 6 $ 14 $ 104 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Accrued Merger-related transaction costs $ — $ — $ 31 Preferred dividends declared but not paid 36 36 — Common dividends issued in stock 55 54 53 Common dividends declared but not paid 283 245 207 See Notes to Condensed Financial Information of Parent. The condensed financial information of Sempra Energy has been prepared in accordance with SEC Regulation S-X Rule 5-04 and Rule 12-04. We apply the same accounting policies as in the financial statements of Sempra Energy Consolidated, except that Sempra Energy accounts for the earnings of its subsidiaries under the equity method in this unconsolidated financial information. Other Income, Net, on the Condensed Statements of Operations includes: ▪ $61 million , $(6) million and $56 million of gains (losses) on dedicated assets in support of our executive retirement and deferred compensation plans in 2019, 2018 and 2017, respectively; ▪ $3 million and $50 million net gains primarily from the settlement of foreign currency derivatives to hedge Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova in 2018 and 2017, respectively; and ▪ $15 million losses in 2019 from foreign currency derivatives used to hedge exposure of fluctuations in the Peruvian Sol related to the sale of our operations in Peru. Sempra Energy received cash dividends from its consolidated subsidiaries totaling $150 million , $300 million and $450 million in 2019, 2018 and 2017, respectively. Additional information on Sempra Energy’s foreign currency derivatives is provided in Note 11 of the Notes to Consolidated Financial Statements. We describe below and in Note 2 of the Notes to Consolidated Financial Statements recent pronouncements that have had a significant effect on Sempra Energy’s financial condition, results of operations, cash flows or disclosures. ASU 2016-02, “Leases,” ASU 2018-10, “Codification Improvements to Topic 842, Leases” and ASU 2018-11, “Leases (Topic 842): Targeted Improvements” (collectively referred to as the “lease standard”): We adopted the lease standard on January 1, 2019 using the optional modified retrospective transition method to apply the new guidance as of January 1, 2019, rather than as of the earliest period presented. The adoption of the lease standard had a material impact on our balance sheet at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. The following table shows the increases (decreases) on our balance sheet at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Right-of-use assets – operating leases (1) $ 191 Deferred income tax assets (3 ) Property, plant and equipment, net (1) (147 ) Other current liabilities 3 Long-term debt (138 ) Other long-term liabilities 159 Retained earnings (2) 17 (1) Included in Other Long-Term Assets. (2) Included in Shareholders’ Equity. As a result of the adoption of the lease standard, we derecognized the asset and liability associated with our corporate headquarters building 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. ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: 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 an increase of $14 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss. ASU 2019-12, “Simplifying the Accounting for Income Taxes”: ASU 2019-12 simplifies certain areas of accounting for income taxes. In addition to other changes, this standard amends ASC 740, “ Income Taxes, ” as follows: ▪ removes the exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, including discontinued operations or other comprehensive income; ▪ simplifies the recognition of deferred taxes related to basis differences as a result of ownership changes in investments; ▪ specifies an entity is not required to allocate the consolidated amount of current and deferred tax expense to a legal entity that is not subject to tax in its separate financial statements; and ▪ requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual ETR computation in the interim period that includes the enactment date. For public entities, ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, including interim periods therein, with early adoption permitted. The transition method related to the amendments made by ASU 2019-12 vary based on the nature of the change. We are currently evaluating our planned adoption date and the effect of the standard on our ongoing financial reporting. The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2019 2018 9.8% Notes February 15, 2019 $ — $ 500 Notes at variable rates (2.69% at December 31, 2018) July 15, 2019 — 500 1.625% Notes October 7, 2019 — 500 2.4% Notes February 1, 2020 500 500 2.4% Notes March 15, 2020 500 500 2.85% Notes November 15, 2020 400 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) 700 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 850 850 2.875% Notes October 1, 2022 500 500 2.9% Notes February 1, 2023 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 350 3.25% Notes June 15, 2027 750 750 3.4% Notes February 1, 2028 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 6% Notes October 15, 2039 750 750 4% Notes February 1, 2048 800 800 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 — Build-to-suit arrangement (2) — 138 10,358 11,238 Current portion of long-term debt (1,399 ) (1,498 ) Unamortized discount on long-term debt (35 ) (38 ) Unamortized debt issuance costs (68 ) (55 ) Total long-term debt $ 8,856 $ 9,647 (1) Callable long-term debt not subject to make-whole provisions. (2) This arrangement is now accounted for as an operating lease liability upon adoption of the lease standard on January 1, 2019. See Note 2. Maturities of long-term debt at December 31, 2019 are $1.4 billion in 2020, $1.6 billion in 2021, $500 million in 2022, $1.0 billion in 2023, $500 million in 2024 and $5.4 billion thereafter. Additional information on Sempra Energy’s long-term debt is provided in Note 7 of the Notes to Consolidated Financial Statements. Sempra Energy has an operating lease commitment related to its corporate headquarters building of approximately $267 million . Sempra Energy expects payments for its operating lease to be $10 million in 2020, $11 million in 2021, $11 million in 2022, $11 million in 2023, $12 million in 2024 and $212 million thereafter. For other contingencies and guarantees related to Sempra Energy, refer to Notes 6 , 7 and 16 of the Notes to Consolidated Financial Statements.

SIGNIFICANT ACCOUNTING POLICI_2

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Policies)	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Energy Sempra Energy’s 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 17 . 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 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, which is a wholly owned subsidiary of Sempra Energy. SoCalGas SoCalGas’ common stock is wholly owned by PE, 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 Consolidated Financial Statements and Notes to Consolidated Financial Statements when discussed together or collectively: ▪ the Consolidated Financial Statements and related Notes of Sempra Energy and its subsidiaries and VIEs; ▪ the Consolidated Financial Statements and related Notes of SDG&E and its VIE (until deconsolidation of the VIE in August 2019); and ▪ the Financial Statements and related Notes of SoCalGas.
Use of Estimates in the Preparation of the Financial Statements	Use of Estimates in the Preparation of the Financial Statements We have prepared our Consolidated Financial Statements in conformity with U.S. GAAP. This requires us to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes, including the disclosure of contingent assets and liabilities at the date of the financial statements. Although we believe the estimates and assumptions are reasonable, actual amounts ultimately may differ significantly from those estimates.
Subsequent Events	Subsequent Events We evaluated events and transactions that occurred after December 31, 2019 through the date the financial statements were issued, and in the opinion of management, the accompanying statements reflect all adjustments and disclosures necessary for a fair presentation.
Discontinued Operations	Discontinued Operations In January 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.
Effects of Regulation	EFFECTS OF REGULATION The California Utilities’ accounting policies and financial statements reflect the application of U.S. GAAP provisions governing rate-regulated operations and the policies of the CPUC and the FERC. Under these provisions, a regulated utility records regulatory assets, which are generally costs that would otherwise be charged to expense, if it is probable that, through the ratemaking process, the utility will recover those assets from customers. To the extent that recovery is no longer probable, the related regulatory assets are written off. Regulatory liabilities generally represent amounts collected from customers in advance of the actual expenditure by the utility. If the actual expenditures are less than amounts previously collected from ratepayers, the excess would be refunded to customers, generally by reducing future rates. Regulatory liabilities may also arise from other transactions such as unrealized gains on fixed price contracts and other derivatives or certain deferred income tax benefits that are passed through to customers in future rates. In addition, the California Utilities record regulatory liabilities when the CPUC or the FERC requires a refund to be made to customers or has required that a gain or other transaction of net allowable costs be given to customers over future periods. Determining probability of recovery of regulatory assets requires significant judgment by management and may include, but is not limited to, consideration of: ▪ the nature of the event giving rise to the assessment ▪ existing statutes and regulatory code ▪ legal precedents ▪ regulatory principles and analogous regulatory actions ▪ testimony presented in regulatory hearings ▪ regulatory orders ▪ a commission-authorized mechanism established for the accumulation of costs ▪ status of applications for rehearings or state court appeals ▪ specific approval from a commission ▪ historical experience Sempra Mexico’s natural gas distribution utility, Ecogas, also applies U.S. GAAP for rate-regulated utilities to its operations, including the same evaluation of probability of recovery of regulatory assets described above. We provide information concerning regulatory assets and liabilities in Note 4 . Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which, at December 31, 2019, owns an 80.25% interest in Oncor, and Sharyland Holdings, which owns 100% of Sharyland Utilities. Oncor and Sharyland Utilities are regulated electric transmission and distribution utilities in Texas and their rates are regulated by the PUCT and certain cities and are subject to regulatory rate-setting processes and annual earnings oversight. Oncor and Sharyland Utilities 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, as well as certain holding companies and risk management activity. Certain business activities at IEnova are regulated by the CRE and meet the regulatory accounting requirements of U.S. GAAP. Pipeline projects currently 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 in “Property, Plant and Equipment.”
Fair Value Measurements	FAIR VALUE MEASUREMENTS We measure certain assets and liabilities at fair value on a recurring basis, primarily nuclear decommissioning and benefit plan trust assets and derivatives. We also measure certain assets at fair value on a non-recurring basis in certain circumstances. A fair value measurement reflects the assumptions market participants would use in pricing an asset or liability based on the best available information. These assumptions include the risk inherent in a particular valuation technique (such as a pricing model) and the risks inherent in the inputs to the model. Also, we consider an issuer’s credit standing when measuring its liabilities at fair value. We establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement). The three levels of the fair value hierarchy are as follows: Level 1 – Pricing inputs are unadjusted quoted prices available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Our Level 1 financial instruments primarily consist of listed equities and U.S. government treasury securities, primarily in the NDT and benefit plan trusts, and exchange-traded derivatives. Level 2 – Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including: ▪ quoted forward prices for commodities ▪ time value ▪ current market and contractual prices for the underlying instruments ▪ volatility factors ▪ other relevant economic measures Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument and can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Our financial instruments in this category include listed equities, domestic corporate bonds, municipal bonds and other foreign bonds, primarily in the NDT and benefit plan trusts, and non-exchange-traded derivatives such as interest rate instruments and over-the-counter forwards and options. Level 3 – Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value from the perspective of a market participant. Our Level 3 financial instruments consist of CRRs and fixed-price electricity positions at SDG&E. Fair Value of Financial Instruments 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 December 31, 2019 and 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. The fair value of commodity derivative assets and liabilities is presented in accordance with our netting policy, as we discuss in Note 11 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 $5 million and $10 million investment at December 31, 2019 and 2018, respectively, measured at NAV): ▪ 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 December 31, 2019 and 2018 .
Cash and Cash Equivalents and Restricted Cash	CASH, CASH EQUIVALENTS AND RESTRICTED CASH Cash equivalents are highly liquid investments with original maturities of three months or less at the date of purchase.
Collection Allowances	COLLECTION ALLOWANCES We evaluate accounts receivable collectability using a combination of factors, including past due status based on contractual terms, trends in write-offs, the age of the receivable, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. Adjustments to collection allowances are made when necessary based on the results of analysis, the aging of receivables, and historical and industry trends. We write off accounts receivable in the period in which we deem the receivable to be uncollectible. We record recoveries of accounts receivable previously written off when it is known that they will be received.
Inventories	INVENTORIES The California Utilities value natural gas inventory using the LIFO method. As inventories are sold, differences between the LIFO valuation and the estimated replacement cost are reflected in customer rates. These differences are generally temporary, but may become permanent if the natural gas inventory withdrawn from storage during the year is not replaced by year end. The California Utilities generally value materials and supplies at the lower of average cost or net realizable value. Sempra Mexico and Sempra LNG value natural gas inventory and materials and supplies at the lower of average cost or net realizable value. Sempra Mexico and Sempra LNG value LNG inventory using the first-in first-out method.
Income Taxes	INCOME TAXES Income tax expense includes current and deferred income taxes. We record deferred income taxes for temporary differences between the book and the tax basis of assets and liabilities. ITCs from prior years are amortized to income by the California Utilities over the estimated service lives of the properties as required by the CPUC. Under the regulatory accounting treatment required for flow-through temporary differences, the California Utilities and Sempra Mexico recognize: ▪ regulatory assets to offset deferred income tax liabilities if it is probable that the amounts will be recovered from customers; and ▪ regulatory liabilities to offset deferred income tax assets if it is probable that the amounts will be returned to customers. When there are uncertainties related to potential income tax benefits, in order to qualify for recognition, the position we take has to have at least a more-likely-than-not chance of being sustained (based on the position’s technical merits) upon challenge by the respective authorities. The term “more-likely-than-not” means a likelihood of more than 50%. Otherwise, we may not recognize any of the potential tax benefit associated with the position. We recognize a benefit for a tax position that meets the more-likely-than-not criterion at the largest amount of tax benefit that is greater than 50% likely of being realized upon its effective resolution. Unrecognized income tax benefits involve management’s judgment regarding the likelihood of the benefit being sustained. The final resolution of uncertain tax positions could result in adjustments to recorded amounts and may affect our ETR. In December 2017, the TCJA was signed into law. As a result, all cumulative undistributed earnings from non-U.S. subsidiaries were deemed repatriated and subjected to a one-time U.S. federal deemed repatriation tax. To the extent we intend to repatriate cash to the U.S. from our continuing international operations, we accrue incremental income tax. We currently do not record deferred income taxes for other basis differences between financial statement and income tax investment amounts in non-U.S. subsidiaries to the extent the related cumulative undistributed earnings are indefinitely reinvested. We recognize income tax expense for basis differences related to global intangible low-taxed income as a period cost if and when incurred. We provide additional information about income taxes in Note 8 . Related to operations in Mexico. In December 2017, the TCJA was signed into law. This legislation significantly changed the IRC. The TCJA reduced the U.S. statutory corporate income tax rate from 35% to 21% , effective January 1, 2018. Deferred income tax assets and liabilities, including NOLs, were remeasured at the income tax rate expected to apply when those temporary differences reverse. The effects of the change to the income tax rate were recognized in the period when the change was enacted. This remeasurement resulted in significant reductions in deferred income tax balances at Sempra Energy Consolidated, SDG&E and SoCalGas in 2017. The remeasurement of deferred income tax balances at SDG&E and SoCalGas resulted in excess deferred income taxes that previously have been collected from ratepayers at the higher rate. As we discuss in Note 4, these excess deferred income taxes have been recorded as regulatory liabilities and will generally be refunded to ratepayers in accordance with the IRC’s normalization provisions and as determined by the CPUC and the FERC. In a January 2019 decision, the CPUC directed certain excess deferred income tax balances generated by activities outside of ratemaking be allocated to shareholders rather than ratepayers. As a result, SDG&E and SoCalGas recorded income tax benefits of $31 million and $38 million , respectively, from the release of a portion of the regulatory liability established in connection with 2017 tax reform for excess deferred income tax balances. The TCJA imposed a one-time tax for deemed repatriation of cumulative undistributed earnings of non-U.S. subsidiaries.
Greenhouse Gas Allowances and Obligations and Emissions and Renewable Energy Certificates	GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS The California Utilities, Sempra Mexico and Sempra LNG are required by AB 32 to acquire GHG allowances for every metric ton of carbon dioxide equivalent emitted into the atmosphere during electric generation and natural gas transportation. At the California Utilities, many GHG allowances are allocated to us on behalf of our customers at no cost. We record purchased and allocated GHG allowances at the lower of weighted-average cost or market. We measure the compliance obligation, which is based on emissions, at the carrying value of allowances held plus the fair value of additional allowances necessary to satisfy the obligation. The California Utilities balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Mexico and Sempra LNG record the cost of GHG obligations in cost of sales. We remove the assets and liabilities from the balance sheets as the allowances are surrendered. RENEWABLE ENERGY CERTIFICATES RECs are energy rights established by governmental agencies for the environmental and social promotion of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets. Retail sellers of electricity obtain RECs through renewable energy PPAs, internal generation or separate purchases in the market to comply with the RPS established by the governmental agencies. RECs provide documentation for the generation of a unit of renewable energy that is used to verify compliance with the RPS. The cost of RECs at SDG&E, which is recoverable in rates, is recorded in Cost of Electric Fuel and Purchased Power on the Consolidated Statements of Operations.
Property, Plant and Equipment (PP&E)	The California Utilities finance their construction projects with debt and equity funds. The CPUC and the FERC allow the recovery of the cost of these funds by the capitalization of AFUDC, calculated using rates authorized by the CPUC and the FERC, as a cost component of PP&E. The California Utilities earn a return on the capitalized AFUDC after the utility property is placed in service and recover the AFUDC from their customers over the expected useful lives of the assets. Pipeline projects currently under construction by Sempra Mexico that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC. We capitalize interest costs incurred to finance capital projects and interest at equity method investments that have not commenced planned principal operations. PROPERTY, PLANT AND EQUIPMENT PP&E is recorded at cost and primarily represents the buildings, equipment and other facilities used by the California Utilities to provide natural gas and electric utility services, and by the Sempra Global businesses in their operations, including construction work in progress. PP&E also includes lease improvements and other equipment at Parent and Other. Our plant costs include labor, materials and contract services and expenditures for replacement parts incurred during a major maintenance outage of a plant. In addition, the cost of utility plant at our rate-regulated businesses and PP&E under regulated projects that meet the regulatory accounting requirements of U.S. GAAP includes AFUDC. The cost of other PP&E includes capitalized interest. Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation.
Goodwill and Other Intangible Assets	Other Intangible Assets at December 31, 2019 primarily includes: ▪ a renewable energy transmission and consumption permit previously granted by the CRE that was acquired in connection with the acquisition of the Ventika wind power generation facilities; and ▪ a favorable O&M agreement acquired in connection with the acquisition of DEN, which we discuss in Note 5 GOODWILL AND OTHER INTANGIBLE ASSETS Goodwil l Goodwill is the excess of the purchase price over the fair value of the identifiable net assets of acquired companies measured at the time of acquisition. Goodwill is not amortized, but we test it for impairment annually on October 1 or whenever events or changes in circumstances necessitate an evaluation. If the carrying value of the reporting unit, including goodwill, exceeds its fair value, and the book value of goodwill is greater than its fair value on the test date, we record a goodwill impairment loss. For our annual goodwill impairment testing, under current U.S. GAAP guidance we have the option to first make a qualitative assessment of whether it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount before applying the two-step, quantitative goodwill impairment test. If we elect to perform the qualitative assessment, we evaluate relevant events and circumstances, including but not limited to, macroeconomic conditions, industry and market considerations, cost factors, changes in key personnel and the overall financial performance of the reporting unit. If, after assessing these qualitative factors, we determine that it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, then we perform the two-step goodwill impairment test. When we perform the two-step, quantitative goodwill impairment test, we exercise judgment to develop estimates of the fair value of the reporting unit and the corresponding goodwill. Our fair value estimates are developed from the perspective of a knowledgeable market participant. We consider observable transactions in the marketplace for similar investments, if available, as well as an income-based approach such as discounted cash flow analysis. A discounted cash flow analysis may be based directly on anticipated future revenues and expenses and may be performed based on free cash flows generated within the reporting unit. Critical assumptions that affect our estimates of fair value may include: ▪ consideration of market transactions ▪ future cash flows ▪ the appropriate risk-adjusted discount rate ▪ country risk ▪ entity risk
Long-lived Assets	LONG-LIVED ASSETS We test long-lived assets for recoverability whenever events or changes in circumstances have occurred that may affect the recoverability or the estimated useful lives of long-lived assets. Long-lived assets include intangible assets subject to amortization, but do not include investments in unconsolidated entities. Events or changes in circumstances that indicate that the carrying amount of a long-lived asset may not be recoverable may include: ▪ significant decreases in the market price of an asset; ▪ a significant adverse change in the extent or manner in which we use an asset or in its physical condition; ▪ a significant adverse change in legal or regulatory factors or in the business climate that could affect the value of an asset; ▪ a current period operating or cash flow loss combined with a history of operating or cash flow losses or a projection of continuing losses associated with the use of a long-lived asset; and ▪ a current expectation that, more-likely-than-not, a long-lived asset will be sold or otherwise disposed of significantly before the end of its previously estimated useful life. A long-lived asset may be impaired when the estimated future undiscounted cash flows are less than the carrying amount of the asset. If that comparison indicates that the asset’s carrying value may not be recoverable, the impairment is measured based on the difference between the carrying amount and the fair value of the asset. This evaluation is performed at the lowest level for which separately identifiable cash flows exist.
Variable Interest Entities	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 whether an entity is a VIE and if we are the primary beneficiary.
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS For tangible long-lived assets, we record AROs for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estimated retirement cost over the life of the related asset by depreciating the asset retirement cost (measured as the present value of the obligation at the time the asset is placed into service), and accreting the obligation until the liability is settled. Our rate-regulated entities, including the California Utilities, record regulatory assets or liabilities as a result of the timing difference between the recognition of costs in accordance with U.S. GAAP and costs recovered through the rate-making process.
Contingencies	CONTINGENCIES We accrue losses for the estimated impacts of various conditions, situations or circumstances involving uncertain outcomes. For loss contingencies, we accrue the loss if an event has occurred on or before the balance sheet date and: ▪ information available through the date we file our financial statements indicates it is probable that a loss has been incurred, given the likelihood of uncertain future events; and ▪ the amount of the loss can be reasonably estimated. We do not accrue contingencies that might result in gains. We continuously assess contingencies for litigation claims, environmental remediation and other events.
Legal Fees	LEGAL FEES Legal fees that are associated with a past event for which a liability has been recorded are accrued when it is probable that fees also will be incurred and amounts are estimable. 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.
Comprehensive Income	COMPREHENSIVE INCOME Comprehensive income includes all changes in the equity of a business enterprise (except those resulting from investments by owners and distributions to owners), including: ▪ foreign currency translation adjustments ▪ certain hedging activities ▪ changes in unamortized net actuarial gain or loss and prior service cost related to pension and other postretirement benefits plans ▪ unrealized gains or losses on available-for-sale securities
Noncontrolling Interests	NONCONTROLLING INTERESTS Ownership interests in a consolidated entity that are held by unconsolidated owners are accounted for and reported as NCI.
Operation and Maintenance Expenses	OPERATION AND MAINTENANCE EXPENSES Operation and Maintenance includes O&M and general and administrative costs, consisting primarily of personnel costs, purchased materials and services, litigation expense and rent.
Foreign Currency Translation	FOREIGN CURRENCY TRANSLATION AND TRANSACTIONS The majority of our operations in South America as well as our natural gas distribution utility in Mexico, Ecogas, use their local currency as their functional currency. The assets and liabilities of their foreign operations are translated into U.S. dollars at current exchange rates at the end of the reporting period, and revenues and expenses are translated at average exchange rates for the year. The resulting noncash translation adjustments do not enter into the calculation of earnings or retained earnings, but are reflected in OCI and in AOCI. Cash flows of these consolidated foreign subsidiaries are translated into U.S. dollars using average exchange rates for the period. We report the effect of exchange rate changes on cash balances held in foreign currencies in “Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash” on the Sempra Energy Consolidated Statements of Cash Flows.
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 modified retrospective transition method to apply the new guidance 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 $ — $ — Other long-term assets (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 and finance leases (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — As a result of the adoption of the lease standard, we derecognized the asset and liability associated with our corporate headquarters building 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 16. 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. 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. We expect no impact to SDG&E’s or SoCalGas’ balance sheets from adoption. The following table shows the expected (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. EXPECTED IMPACT FROM ADOPTION OF ASU 2016-13 (Dollars in millions) Sempra Energy Consolidated Accounts receivable – trade, net $ (1 ) Due from unconsolidated affiliates – noncurrent (6 ) Deferred income tax assets 4 Other current liabilities 4 Deferred credits and other 2 Retained earnings (7 ) Other noncontrolling interests (2 ) 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. ASU 2019-12, “Simplifying the Accounting for Income Taxes”: ASU 2019-12 simplifies certain areas of accounting for income taxes. In addition to other changes, this standard amends ASC 740, “Income Taxes,” as follows: ▪ removes the exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, including discontinued operations or other comprehensive income; ▪ simplifies the recognition of deferred taxes related to basis differences as a result of ownership changes in investments; ▪ specifies an entity is not required to allocate the consolidated amount of current and deferred tax expense to a legal entity that is not subject to tax in its separate financial statements; and ▪ requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual ETR computation in the interim period that includes the enactment date. For public entities, ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, including interim periods therein, with early adoption permitted. The transition method related to the amendments made by ASU 2019-12 vary based on the nature of the change. We are currently evaluating our planned adoption date and the effect of the standard on our ongoing financial reporting. We describe below and in Note 2 of the Notes to Consolidated Financial Statements recent pronouncements that have had a significant effect on Sempra Energy’s financial condition, results of operations, cash flows or disclosures. ASU 2016-02, “Leases,” ASU 2018-10, “Codification Improvements to Topic 842, Leases” and ASU 2018-11, “Leases (Topic 842): Targeted Improvements” (collectively referred to as the “lease standard”): We adopted the lease standard on January 1, 2019 using the optional modified retrospective transition method to apply the new guidance as of January 1, 2019, rather than as of the earliest period presented. The adoption of the lease standard had a material impact on our balance sheet at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. The following table shows the increases (decreases) on our balance sheet at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Right-of-use assets – operating leases (1) $ 191 Deferred income tax assets (3 ) Property, plant and equipment, net (1) (147 ) Other current liabilities 3 Long-term debt (138 ) Other long-term liabilities 159 Retained earnings (2) 17 (1) Included in Other Long-Term Assets. (2) Included in Shareholders’ Equity. As a result of the adoption of the lease standard, we derecognized the asset and liability associated with our corporate headquarters building 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. ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: 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 an increase of $14 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss. ASU 2019-12, “Simplifying the Accounting for Income Taxes”: ASU 2019-12 simplifies certain areas of accounting for income taxes. In addition to other changes, this standard amends ASC 740, “ Income Taxes, ” as follows: ▪ removes the exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, including discontinued operations or other comprehensive income; ▪ simplifies the recognition of deferred taxes related to basis differences as a result of ownership changes in investments; ▪ specifies an entity is not required to allocate the consolidated amount of current and deferred tax expense to a legal entity that is not subject to tax in its separate financial statements; and ▪ requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual ETR computation in the interim period that includes the enactment date. For public entities, ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, including interim periods therein, with early adoption permitted. The transition method related to the amendments made by ASU 2019-12 vary based on the nature of the change. We are currently evaluating our planned adoption date and the effect of the standard on our ongoing financial reporting.
Revenue from Contract with Customer	Our revenues from contracts with customers are primarily related to the transmission, distribution and storage of natural gas and the generation, transmission and distribution of electricity through our regulated utilities. We also provide other midstream and renewable energy-related services. We assess our revenues on a contract-by-contract basis as well as a portfolio basis to determine the nature, amount, timing and uncertainty, if any, of revenues being recognized. We generally recognize revenues when performance of the promised commodity service is provided to our customers and invoice our customers for an amount that reflects the consideration we are entitled to in exchange for those services. We consider the delivery and transmission of natural gas and electricity and providing of natural gas storage services as ongoing and integrated services. Generally, natural gas or electricity services are received and consumed by the customer simultaneously. Our performance obligations related to these services are satisfied over time and represent a series of distinct services that are substantially the same and that have the same pattern of transfer to the customers. We recognize revenue based on units delivered, as the satisfaction of our performance obligations can be directly measured by the amount of natural gas or electricity delivered to the customer. In most cases, the right to consideration from the customer directly corresponds to the value transferred to the customer and we recognize revenue in the amount that we have the right to invoice. The payment terms in our customer contracts vary. Typically, we have an unconditional right to customer payments, which are due after the performance obligation to the customer is satisfied. The term between invoicing and when payment is due is typically between 10 and 90 days. We exclude sales and usage-based taxes from revenues. In addition, the California Utilities pay franchise fees to operate in various municipalities. The California Utilities bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of the California Utilities’ ability to collect from the customer, are accounted for on a gross basis and reflected in utilities revenues from contracts with customers and operating expense. Utilities Revenues Utilities revenues represent the majority of our consolidated revenues from contracts with customers and include: The transmission, distribution and storage of natural gas at: ▪ SDG&E ▪ SoCalGas ▪ Sempra Mexico’s Ecogas The generation, transmission and distribution of electricity at SDG&E. Utilities revenues are derived from and recognized upon the delivery of natural gas or electricity services to customers. Amounts that we bill our customers are based on tariffs set by regulators within the respective state or country. For SDG&E and SoCalGas, which follow the provisions of U.S. GAAP governing rate-regulated operations as we discuss in Note 1, amounts that we bill to customers also include adjustments for previously recognized regulatory revenues. The California Utilities and Ecogas recognize revenues based on regulator-approved revenue requirements, which allows the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While the California Utilities’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SoCalGas recognizes annual authorized revenue for core natural gas customers using seasonal factors established in the Triennial Cost Allocation Proceeding. Accordingly, a significant portion of SoCalGas’ annual earnings are recognized in the first and fourth quarters of each year. SDG&E’s authorized revenue recognition is also impacted by seasonal factors, resulting in higher earnings in the third quarter when electric loads are typically higher than in the other three quarters of the year. SDG&E has an arrangement to provide the California ISO with the ability to control its high-voltage transmission lines for prices approved by the FERC. Revenue is recognized over time as access is provided to the California ISO. Factors that can affect the amount, timing and uncertainty of revenues and cash flows include weather, seasonality and timing of customer billings, which may result in unbilled revenues that can vary significantly from month to month and generally approximate one-half month’s deliveries. The California Utilities recognize revenues from the sale of allocated California GHG emissions allowances at quarterly auctions administered by CARB. GHG allowances are delivered to CARB in advance of the quarterly auctions, and the California Utilities have the right to payment when the GHG allowances are sold at auction. GHG revenue is recognized on a point in time basis within the quarter the auction is held. The California Utilities balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Midstream Revenues Midstream revenues at Sempra Mexico and Sempra LNG typically represent revenues from long-term, U.S. dollar-based contracts with customers for the sale of natural gas and LNG, as well as storage and transportation of natural gas. Invoiced amounts are based on the volume of natural gas delivered and contracted prices. Sempra Mexico’s marketing operations sell natural gas to the CFE and other customers under supply agreements. Sempra Mexico recognizes the revenue from the sale of natural gas upon transfer of the natural gas via pipelines to customers at the agreed upon delivery points, and in the case of the CFE, at its thermoelectric power plants. Through its marketing operations, Sempra LNG has contracts to sell natural gas and LNG to Sempra Mexico that allow Sempra Mexico to satisfy its obligations under supply agreements with the CFE and other customers, and to supply Sempra Mexico’s TdM power plant. Because Sempra Mexico either immediately delivers the natural gas to its customers or consumes the benefits simultaneously (by using the gas to supply TdM), revenues from Sempra LNG’s sale of natural gas to Sempra Mexico are generally recognized over time as delivered. Revenues from LNG sales are recognized at the point when the cargo is delivered to Sempra Mexico. Revenues from the sale of LNG and natural gas by Sempra LNG to Sempra Mexico are adjusted for indemnity payments and profit sharing. We consider these adjustments to be forms of variable consideration that are associated with the sale of LNG and natural gas to Sempra Mexico, and therefore, Sempra LNG records the related costs as an offset to revenues, with no impact to Sempra Energy’s consolidated revenues. We recognize storage revenue from firm capacity reservation agreements, under which we collect a fee for reserving storage capacity for customers in our underground storage facilities. Under these firm agreements, customers pay a monthly fixed reservation fee based on the storage capacity reserved rather than the actual volumes stored. For the fixed-fee component, revenue is recognized on a straight-line basis over the term of the contract. We bill customers for any capacity used in excess of the contracted capacity and such revenues are recognized in the month of occurrence. We also recognize revenue for interruptible storage services. As we discuss in Note 5 , 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). We generate pipeline transportation revenues from firm agreements, under which customers pay a fee for reserving transportation capacity. Revenue is recognized when the volumes are delivered to the customers’ agreed upon delivery point. We recognize revenues for our stand-ready obligation to provide capacity and transportation services throughout the contractual delivery period, as the benefits are received and consumed simultaneously as customers utilize pipeline capacity for the transport and receipt of natural gas and LPG. Invoiced amounts are based on a variable usage fee and a fixed capacity charge, adjusted for the Consumer Price Index, the effects of any foreign currency translation and the actual quantity of commodity transported. Renewables Revenues Sempra Renewables and Sempra Mexico develop, invest in and operate solar and wind facilities that have long-term PPAs to sell the electricity and the related green energy attributes they generate to customers, generally load serving entities, and also for Sempra Mexico, industrial and other customers. Load serving entities will sell electric service to their end-users and wholesale customers immediately upon receipt of our power delivery, and industrial and other customers immediately consume the electricity to run their facilities, and thus, we recognize the revenue under the PPAs as the electricity is generated. We invoice customers based on the volume of energy delivered at rates pursuant to the PPAs. As we discuss in Note 5 , in December 2018, we completed the sale of Sempra Renewables’ U.S. operating solar assets, solar and battery storage development projects and its 50% ownership interest in a wind power generation facility. In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. Sempra LNG continues to have a contractual agreement to provide scheduling and marketing of renewable power for Sempra Mexico’s renewables’ entities. Invoiced amounts are based on a fixed fee per MWh scheduled. Other Revenues from Contracts with Customers TdM is a natural gas-fired power plant that generates revenues from selling electricity and/or resource adequacy to the California ISO and to governmental, public utility and wholesale power marketing entities, as the power is delivered at the interconnection point. Remaining Performance Obligations We do not disclose information about remaining performance obligations for (a) contracts with an original expected length of one year or less, (b) variable consideration recognized at the amount at which we have the right to invoice for services performed, or (c) variable consideration allocated to wholly unsatisfied performance obligations. For contracts greater than one year, at December 31, 2019 , we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra Energy’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Mexico. SoCalGas did not have any remaining performance obligations at December 31, 2019 . REVENUES FROM SOURCES OTHER THAN CONTRACTS WITH CUSTOMERS Certain of our revenues are derived from sources other than contracts with customers and are accounted for under other accounting standards outside the scope of ASC 606. Utilities Regulatory Revenues Alternative Revenue Programs We recognize revenues from alternative revenue programs when the regulator-specified conditions for recognition have been met and adjust these revenues as they are recovered or refunded through future utility service. Decoupled revenues. As discussed earlier, the regulatory framework requires the California Utilities to recover authorized revenue based on estimated annual demand forecasts approved in regular proceedings before the CPUC. However, actual demand for natural gas and electricity will generally vary from CPUC-approved forecasted demand due to the impacts from weather volatility, energy efficiency programs, rooftop solar and other factors affecting consumption. The CPUC regulatory framework provides for the California Utilities to use a “decoupling” mechanism, which allows the California Utilities to record revenue shortfalls or excess revenues resulting from any difference between actual and forecasted demand to be recovered or refunded in authorized revenue in a subsequent period based on the nature of the account. Incentive mechanisms. The CPUC applies performance-based measures and incentive mechanisms to all California IOUs, under which the California Utilities have earnings potential above authorized base margins if they achieve or exceed specific performance and operating goals. Generally, for performance-based awards, if performance is above or below specific benchmarks, the utility is eligible for financial awards or subject to financial penalties. Incentive awards are included in revenues when we receive required CPUC approval of the award, the timing of which may not be consistent from year to year. We would record penalties for results below the specified benchmarks against revenues when we believe it is probable that the CPUC would assess a penalty. Other Cost-Based Regulatory Recovery The CPUC, and the FERC as it relates to SDG&E, authorize the California Utilities to collect revenue requirements for operating costs and capital related costs (such as depreciation, taxes and return on rate base) from customers, including: ▪ costs to purchase natural gas and electricity; ▪ costs associated with administering public purpose, demand response, and customer energy efficiency programs; ▪ other programmatic activities, such as gas distribution, gas transmission, gas storage integrity management and wildfire mitigation; and ▪ costs associated with third party liability insurance premiums. Authorized costs are recovered as the commodity or service is delivered. To the extent authorized amounts collected vary from actual costs, the differences are generally recovered or refunded within a subsequent period based on the nature of the balancing account mechanism. In general, the revenue recognition criteria for balanced costs billed to customers are met at the time the costs are incurred. Because these costs are substantially recovered in rates through a balancing account mechanism, changes in these costs are reflected as changes in revenues. The CPUC and the FERC may impose various review procedures before authorizing recovery or refund for programs authorized, including limitations on the total cost of the program, revenue requirement limits or reviews of costs for reasonableness. These procedures could result in disallowances of recovery from ratepayer s. We discuss balancing accounts and their effects further in Note 4 . Other Revenues Sempra LNG has an agreement to supply LNG to Sempra Mexico’s ECA LNG Regasification terminal. Although the LNG sale and purchase agreement specifies a number of cargoes to be delivered annually, actual cargoes delivered by the supplier have traditionally been significantly lower than the maximum specified under the agreement. As a result, Sempra LNG is contractually required to make monthly indemnity payments to Sempra Mexico for failure to deliver the contracted LNG. Sempra Mexico generates lease revenues from operating lease agreements with PEMEX and CENAGAS for the use of natural gas and ethane pipelines and LPG storage facilities. Certain PPAs at Sempra Renewables were also accounted for as operating leases prior to sale of its solar and wind assets in December 2018 and April 2019. Sempra LNG also recognizes other revenues from: ▪ fees related to contractual counterparty obligations for non-delivery of LNG cargoes, as described above; and ▪ sales of natural gas and electricity under short-term and long-term contracts and into the spot market and other competitive markets. Revenues include the net realized gains and losses on physical and derivative settlements and net unrealized gains and losses from the change in fair values of the derivatives.
Business Combinations	The fair value of the equity method investment in Oncor Holdings is primarily attributable to Oncor’s business. Therefore, we considered the underlying assets and liabilities of Oncor when determining the fair value of our equity method investment. As a regulated entity, Oncor’s rates are set and approved by the PUCT, and are designed to recover the cost of providing service and the opportunity to earn a reasonable return on its investments. Accordingly, Oncor applies the guidance under the provisions of U.S. GAAP governing rate-regulated operations. Under U.S. GAAP, regulation is viewed as being a characteristic (restriction) of a regulated entity’s assets and liabilities, and the impact of regulation is considered a fundamental input to measuring the fair value of Oncor’s assets and liabilities. Under this premise, we concluded that the carrying values of all assets and liabilities recoverable through rates are representative of their fair values. We consolidate assets acquired and liabilities assumed as of the purchase date and include earnings from acquisitions in consolidated earnings after the purchase date.
Investments in Noncontrolling Interests	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 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 Consolidated Statements of Operations. 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 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. See Note 8 for information on how equity earnings and losses before income taxes are factored into the calculations of our pretax income or loss and ETR.
Employee Benefit Plans	For our employee benefit plans, we: ▪ recognize an asset for a plan’s overfunded status or a liability for a plan’s underfunded status in the balance sheet; ▪ measure a plan’s assets and its obligations that determine its funded status as of the end of the fiscal year; and ▪ recognize changes in the funded status of pension and PBOP plans in the year in which the changes occur. Generally, those changes are reported in OCI and as a separate component of shareholders’ equity. The detailed information presented below covers the employee benefit plans of primarily Sempra Energy and its consolidated subsidiaries. Sempra Energy has funded and unfunded noncontributory traditional defined benefit and cash balance plans, including separate plans for SDG&E and SoCalGas, which collectively cover all eligible employees, including members of the Sempra Energy board of directors who were participants in a predecessor plan on or before June 1, 1998. Pension benefits under the traditional defined benefit plans are based on service and final average earnings, while the cash balance plans provide benefits using a career average earnings methodology. IEnova has an unfunded noncontributory defined benefit plan covering all employees that provides defined benefits to retirees based on date of hire, years of service and final average earnings. Sempra Energy also has PBOP plans, including separate plans for SDG&E and SoCalGas, which collectively cover all domestic and certain foreign employees. The life insurance plans are both contributory and noncontributory, and the health care plans are contributory. Participants’ contributions are adjusted annually. Other postretirement benefits include medical benefits for retirees’ spouses. Pension and other postretirement benefits costs and obligations are dependent on assumptions used in calculating such amounts. We review these assumptions on an annual basis and update them as appropriate. We consider current market conditions, including interest rates, in making these assumptions. We use a December 31 measurement date for all of our plans. Net Assets and Liabilities The assets and liabilities of the pension and PBOP plans are affected by changing market conditions as well as when actual plan experience is different than assumed. Such events result in investment gains and losses, which we defer and recognize in pension and other postretirement benefit costs over a period of years. Our funded pension and PBOP plans use the asset smoothing method, except for those at SDG&E. This method develops an asset value that recognizes realized and unrealized investment gains and losses over a three-year period. This adjusted asset value, known as the market-related value of assets, is used in conjunction with an expected long-term rate of return to determine the expected return-on-assets component of net periodic benefit cost. SDG&E does not use the asset smoothing method, but rather recognizes realized and unrealized investment gains and losses during the current year. The 10% corridor accounting method is used at Sempra Energy Consolidated, SDG&E and SoCalGas. Under the corridor accounting method, if as of the beginning of a year unrecognized net gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets, the excess is amortized over the average remaining service period of active participants. The asset smoothing and 10% corridor accounting methods help mitigate volatility of net periodic benefit costs from year to year. We recognize the overfunded or underfunded status of defined benefit pension and other postretirement plans as assets or liabilities, respectively; unrecognized changes in these assets and/or liabilities are normally recorded in AOCI on the balance sheet. The California Utilities record regulatory assets and liabilities that offset the funded pension and other postretirement plans’ assets or liabilities, as these costs are expected to be recovered in future utility rates based on decisions by regulatory agencies. The California Utilities record annual pension and other postretirement net periodic benefit costs equal to the contributions to their qualified plans as authorized by the CPUC. The annual contributions to the pension plans are the greater of: ▪ a minimum required funding amount as required by the IRS; ▪ the amount required to maintain an 85% Adjusted Funding Target Attainment Percentage as defined by the Pension Protection Act of 2006, as amended; or ▪ beginning January 1, 2019 and for the duration of the 2019 GRC cycle, a fixed amount equal to the estimated annual service cost as defined by U.S. GAAP plus one year of a 14-year amortization of the unfunded projected benefit obligation of the pension plan as of January 1, 2019, and limited to an annual amount that keeps the fair value of the pension plan assets from exceeding 110% of the pension benefit obligation of the plan. The annual contributions to PBOP plans are equal to the lesser of the maximum tax deductible amount or the net periodic cost calculated in accordance with U.S. GAAP for pension and PBOP plans. Any differences between booked net periodic benefit cost and amounts contributed to the pension and other postretirement plans for the California Utilities are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities. Assumptions for Pension and Other Postretirement Benefit Plans Benefit Obligation and Net Periodic Benefit Cost Except for the IEnova plans, we develop the discount rate assumptions using a bond selection-settlement portfolio approach. This approach develops a discount rate by selecting a portfolio of high quality corporate bonds that generate sufficient cash flows to provide for projected benefit payments of the plan. The selected bond portfolio is derived from a universe of corporate bonds with a Bloomberg Composite of AA or higher. After the bond portfolio is selected, a single interest rate is determined that equates the present value of the plans’ projected benefit payments discounted at this rate with the market value of the bonds selected. We develop the discount rate assumptions for the plans at IEnova by constructing a synthetic government zero coupon bond yield curve from the available market data, based on duration matching, and we add a risk spread to allow for the yields of high-quality corporate bonds. Such method is required when there is no deep market for high quality corporate bonds. Long-term return on assets is based on the weighted-average of the plans’ investment allocation as of the measurement date and the expected returns for those asset types. Interest crediting rate is based on an average 30 -year Treasury bond from the month of November of the preceding year. We amortize prior service cost using straight line amortization over average future service (or average expected lifetime for plans where participants are substantially inactive employees), which is an alternative method allowed under U.S. GAAP. Fair Value of Pension and Other Postretirement Benefit Plan Assets We classify the investments in Sempra Energy’s pension master trust and the trusts for the California Utilities’ PBOP plans based on the fair value hierarchy, except for certain investments measured at NAV. The following are descriptions of the valuation methods and assumptions we use to estimate the fair values of investments held by pension and other postretirement benefit plan trusts. Equity Securities – Equity securities are valued using quoted prices listed on nationally recognized securities exchanges. Fixed Income Securities – Certain fixed income securities are valued at the closing price reported in the active market in which the security is traded. Other fixed income securities are valued based on yields currently available on comparable securities of issuers with similar credit ratings. When quoted prices are not available for identical or similar securities, the security is valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks. Certain high yield fixed-income securities are valued by applying a price adjustment to the bid side to calculate a mean and ask value. Adjustments can vary based on maturity, credit standing, and reported trade frequencies. The bid to ask spread is determined by the investment manager based on the review of the available market information. Registered Investment Companies – Investments in mutual funds sponsored by a registered investment company are valued based on exchange listed prices. Where the value is a quoted price in an active market, the investment is classified within Level 1 of the fair value hierarchy. Investments in certain fixed income securities are valued under a discounted cash flow approach that maximizes observable inputs, such as current yields of similar instruments, but includes adjustments for certain risks that may not be observable, such as credit and liquidity risks for the remaining fixed income securities. Common/Collective Trusts – Investments in common/collective trust funds are valued based on the NAV of units owned, which is based on the current fair value of the funds’ underlying assets. Private Equity Funds – These funds consist of investments in private equities that are held by limited partnerships following various strategies, including private equity and corporate finance. These partnerships generally have limited lives of 10 years, after which liquidating distributions will be received. The value is determined based on the NAV of the proportionate share of an ownership interest in partners’ capital. Holdings in these types of private equity funds are negligible, as the funds are well past their expected investment term and have distributed the bulk of proceeds from investment sales. Derivative Financial Instruments – Futures contracts that are publicly traded in active markets are valued at closing prices as of the last business day of the year. Forward currency contracts are valued at the prevailing forward exchange rate of the underlying currencies, and unrealized gain (loss) is recorded daily. Fixed income futures and options are marked to market daily. Equity index futures contracts are valued at the last sales price quoted on the exchange on which they primarily trade. While management believes the valuation methods described above are appropriate and consistent with other market participants, the use of different methodologies or assumptions to determine the fair value of certain financial instruments could result in a different fair value measurement at the reporting date. We provide more discussion of fair value measurements in Notes 1 and 12 . The following tables set forth by level within the fair value hierarchy a summary of the investments in our pension and other postretirement benefit plan trusts measured at fair value on a recurring basis.
Share-based Compensation	Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases. We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over the requisite service period of the award, which is generally three or four SEMPRA ENERGY NONQUALIFIED STOCK OPTIONS SEMPRA ENERGY RESTRICTED STOCK UNITS
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 Consolidated Balance Sheets. We have derivatives that are (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 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 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 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 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 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. 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. We also utilize foreign currency derivatives to hedge exposure to fluctuations in the Peruvian Sol related to the sale of our operations in Peru. INTEREST RATE DERIVATIVES
Earnings Per Share	The potentially dilutive impact from stock options and RSUs is calculated under the treasury stock method. Under this method, proceeds based on the exercise price and unearned compensation are assumed to be used to repurchase shares on the open market at the average market price for the period, reducing the number of potential new shares to be issued and sometimes causing an antidilutive effect. 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.
Leases	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	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.
Environmental Costs	We generally capitalize the significant costs we incur to mitigate or prevent future environmental contamination or extend the life, increase the capacity, or improve the safety or efficiency of property used in current operations. The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations: At the California Utilities, costs that relate to current operations or an existing condition caused by past operations are generally recorded as a regulatory asset due to the probability that these costs will be recovered in rates. The environmental issues currently facing us, except for those related to the Aliso Canyon natural gas storage facility leak as we discuss above or resolved during the last three years, include (1) investigation and remediation of the California Utilities’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by the California Utilities at which we have been identified as a PRP and (3) mitigation of damage to the marine environment caused by the cooling-water discharge from SONGS.
Segment Reporting	We have 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, at December 31, 2019, owns an 80.25 % interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern and western and panhandle regions of Texas, and our indirect, 50% 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 our investment in Oncor Holdings in March 2018 and 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 projects for the export of LNG, holds an interest in a facility for the export of LNG, owns and operates natural gas pipelines, and buys, sells and transports natural gas through its 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 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 and the FERC. We describe the accounting policies of all of our segments in Note 1 . 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.

SCHEDULE I - CONDENSED FINANC_2

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT (Policies)	12 Months Ended
	Dec. 31, 2019
Condensed Financial Information Disclosure [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 modified retrospective transition method to apply the new guidance 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 $ — $ — Other long-term assets (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 and finance leases (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — As a result of the adoption of the lease standard, we derecognized the asset and liability associated with our corporate headquarters building 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 16. 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. 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. We expect no impact to SDG&E’s or SoCalGas’ balance sheets from adoption. The following table shows the expected (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. EXPECTED IMPACT FROM ADOPTION OF ASU 2016-13 (Dollars in millions) Sempra Energy Consolidated Accounts receivable – trade, net $ (1 ) Due from unconsolidated affiliates – noncurrent (6 ) Deferred income tax assets 4 Other current liabilities 4 Deferred credits and other 2 Retained earnings (7 ) Other noncontrolling interests (2 ) 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. ASU 2019-12, “Simplifying the Accounting for Income Taxes”: ASU 2019-12 simplifies certain areas of accounting for income taxes. In addition to other changes, this standard amends ASC 740, “Income Taxes,” as follows: ▪ removes the exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, including discontinued operations or other comprehensive income; ▪ simplifies the recognition of deferred taxes related to basis differences as a result of ownership changes in investments; ▪ specifies an entity is not required to allocate the consolidated amount of current and deferred tax expense to a legal entity that is not subject to tax in its separate financial statements; and ▪ requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual ETR computation in the interim period that includes the enactment date. For public entities, ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, including interim periods therein, with early adoption permitted. The transition method related to the amendments made by ASU 2019-12 vary based on the nature of the change. We are currently evaluating our planned adoption date and the effect of the standard on our ongoing financial reporting. We describe below and in Note 2 of the Notes to Consolidated Financial Statements recent pronouncements that have had a significant effect on Sempra Energy’s financial condition, results of operations, cash flows or disclosures. ASU 2016-02, “Leases,” ASU 2018-10, “Codification Improvements to Topic 842, Leases” and ASU 2018-11, “Leases (Topic 842): Targeted Improvements” (collectively referred to as the “lease standard”): We adopted the lease standard on January 1, 2019 using the optional modified retrospective transition method to apply the new guidance as of January 1, 2019, rather than as of the earliest period presented. The adoption of the lease standard had a material impact on our balance sheet at January 1, 2019 due to the initial recognition of ROU assets and lease liabilities for operating leases. The following table shows the increases (decreases) on our balance sheet at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Right-of-use assets – operating leases (1) $ 191 Deferred income tax assets (3 ) Property, plant and equipment, net (1) (147 ) Other current liabilities 3 Long-term debt (138 ) Other long-term liabilities 159 Retained earnings (2) 17 (1) Included in Other Long-Term Assets. (2) Included in Shareholders’ Equity. As a result of the adoption of the lease standard, we derecognized the asset and liability associated with our corporate headquarters building 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. ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income”: 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 an increase of $14 million to beginning Retained Earnings and Accumulated Other Comprehensive Loss. ASU 2019-12, “Simplifying the Accounting for Income Taxes”: ASU 2019-12 simplifies certain areas of accounting for income taxes. In addition to other changes, this standard amends ASC 740, “ Income Taxes, ” as follows: ▪ removes the exception to the incremental approach for intraperiod tax allocation when there is a loss from continuing operations and income or a gain from other items, including discontinued operations or other comprehensive income; ▪ simplifies the recognition of deferred taxes related to basis differences as a result of ownership changes in investments; ▪ specifies an entity is not required to allocate the consolidated amount of current and deferred tax expense to a legal entity that is not subject to tax in its separate financial statements; and ▪ requires an entity to reflect the effect of an enacted change in tax laws or rates in the annual ETR computation in the interim period that includes the enactment date. For public entities, ASU 2019-12 is effective for fiscal years beginning after December 15, 2020, including interim periods therein, with early adoption permitted. The transition method related to the amendments made by ASU 2019-12 vary based on the nature of the change. We are currently evaluating our planned adoption date and the effect of the standard on our ongoing financial reporting.

SIGNIFICANT ACCOUNTING POLICI_3

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Schedule of Cash, Cash Equivalents and Restricted Cash	The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on the Consolidated Balance Sheets to the sum of such amounts reported on the Consolidated Statements of Cash Flows. RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Dollars in millions) At December 31, 2019 2018 Sempra Energy Consolidated: Cash and cash equivalents $ 108 $ 102 Restricted cash, current 31 35 Restricted cash, noncurrent 3 21 Cash, cash equivalents and restricted cash in discontinued operations 75 88 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 217 $ 246 SDG&E: Cash and cash equivalents $ 10 $ 8 Restricted cash, current — 11 Restricted cash, noncurrent — 18 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 10 $ 37
Schedule Of Receivables Collection Allowances	We record allowances for the collection of trade and other accounts and notes receivable, which include allowances for doubtful customer accounts and for other receivables. We show the changes in these allowances in the table below: COLLECTION ALLOWANCES (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Allowances for collection of receivables at January 1 $ 21 $ 25 $ 29 Provisions for uncollectible accounts 22 10 12 Write-offs of uncollectible accounts (14 ) (14 ) (16 ) Allowances for collection of receivables at December 31 $ 29 $ 21 $ 25 SDG&E: Allowances for collection of receivables at January 1 $ 11 $ 9 $ 8 Provisions for uncollectible accounts 10 9 8 Write-offs of uncollectible accounts (7 ) (7 ) (7 ) Allowances for collection of receivables at December 31 $ 14 $ 11 $ 9 SoCalGas: Allowances for collection of receivables at January 1 $ 10 $ 16 $ 21 Provisions for uncollectible accounts 12 1 4 Write-offs of uncollectible accounts (7 ) (7 ) (9 ) Allowances for collection of receivables at December 31 $ 15 $ 10 $ 16
Schedule of Inventory	The components of inventories are as follows: INVENTORY BALANCES AT DECEMBER 31 (Dollars in millions) Natural gas LNG Materials and supplies Total 2019 2018 2019 2018 2019 2018 2019 2018 Sempra Energy Consolidated $ 110 $ 95 $ 9 $ 4 $ 158 $ 159 $ 277 $ 258 SDG&E 1 — — — 93 102 94 102 SoCalGas 90 92 — — 46 42 136 134
Schedule of Property, Plant and Equipment	DEPRECIATION EXPENSE (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated $ 1,551 $ 1,470 $ 1,368 SDG&E 757 686 621 SoCalGas 598 553 514 PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) December 31, Depreciation rates for 2019 2018 2019 2018 2017 SDG&E: Natural gas operations $ 2,534 $ 2,382 2.47 % 2.44 % 2.40 % Electric distribution 7,985 7,462 3.94 3.91 3.92 Electric transmission (1) 6,577 6,222 2.79 2.76 2.71 Electric generation (2) 2,415 2,967 4.50 4.12 4.05 Other electric (3) 1,492 1,408 6.61 6.43 5.54 Construction work in progress (1) 1,501 1,221 NA NA NA Total SDG&E 22,504 21,662 SoCalGas: Natural gas operations (4) 18,370 17,268 3.60 3.60 3.63 Other non-utility 34 34 5.08 5.39 5.28 Construction work in progress 958 836 NA NA NA Total SoCalGas 19,362 18,138 Other operating units and parent (5) : Estimated useful lives Weighted-average useful life Land and land rights 278 326 16 to 50 years (6) 31 Machinery and equipment: Generating plants 1,154 869 15 to 20 years 18 LNG terminals 1,134 1,134 43 years 43 Pipelines and storage 3,596 3,413 5 to 50 years 41 Other 180 183 1 to 50 years 6 Construction work in progress 895 451 NA NA Other (7) 226 439 3 to 50 years 15 7,463 6,815 Total Sempra Energy Consolidated $ 49,329 $ 46,615 (1) At December 31, 2019 , includes $484 million in electric transmission assets and $13 million in construction work in progress related to SDG&E’s 90 % interest in the Southwest Powerlink transmission line, jointly owned by SDG&E with other utilities. SDG&E, and each of the other owners, holds its undivided interest as a tenant in common in the property. Each owner is responsible for its share of the project and participates in decisions concerning operations and capital expenditures. SDG&E’s share of operating expenses is included in Sempra Energy’s and SDG&E’s Consolidated Statements of Operations. (2) Includes capital lease assets of $1.3 billion at December 31, 2018 . (3) Includes capital lease assets of $13 million at December 31, 2018 . (4) Includes capital lease assets of $40 million at December 31, 2018 . (5) Includes $178 million and $154 million at December 31, 2019 and 2018 , respectively, of utility plant, primarily pipelines and other distribution assets at Ecogas. (6) Estimated useful lives are for land rights. (7) Includes capital lease assets of $136 million and associated leasehold improvements of $24 million at December 31, 2018 related to our corporate headquarters build-to-suit arrangement, which is accounted for as a ROU asset as of January 1, 2019 upon adoption of the lease standard. ACCUMULATED DEPRECIATION (Dollars in millions) December 31, 2019 2018 SDG&E: Accumulated depreciation: Electric (1) $ 4,705 $ 4,558 Natural gas 832 794 Total SDG&E 5,537 5,352 SoCalGas: Accumulated depreciation of natural gas utility plant in service (2) 6,023 5,685 Accumulated depreciation – other non-utility 15 14 Total SoCalGas 6,038 5,699 Other operating units and parent and other: Accumulated depreciation – other (3) 1,302 1,125 Total Sempra Energy Consolidated $ 12,877 $ 12,176 (1) Includes accumulated depreciation for capital lease assets of $48 million at December 31, 2018 . Includes $263 million at December 31, 2019 related to SDG&E’s 90 % interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities. (2) Includes accumulated depreciation for capital lease assets of $37 million at December 31, 2018 . (3) Includes accumulated depreciation for capital lease assets of $10 million and associated leasehold improvements of $3 million at December 31, 2018 related to our corporate headquarters’ build-to-suit arrangement, which is accounted for as a ROU asset as of January 1, 2019. Includes $49 million and $43 million at December 31, 2019 and 2018 , respectively, of accumulated depreciation for utility plant at Ecogas.
Schedule Of Capitalized Financing Costs	The table below summarizes capitalized interest and AFUDC. CAPITALIZED FINANCING COSTS (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated $ 183 $ 193 $ 247 SDG&E 75 82 85 SoCalGas 47 48 60
Schedule Of Other Intangible Assets	Other Intangible Assets included on the Sempra Energy Consolidated Balance Sheets are as follows: OTHER INTANGIBLE ASSETS (Dollars in millions) Amortization period (years) December 31, 2019 2018 Renewable energy transmission and consumption permit 19 $ 154 $ 154 O&M agreement 23 66 66 Other 10 years to indefinite 30 30 250 250 Less accumulated amortization: Renewable energy transmission and consumption permit (24 ) (16 ) O&M agreement (6 ) (3 ) Other (7 ) (7 ) (37 ) (26 ) $ 213 $ 224
Schedule Of Variable Interest Entities	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 current liabilities 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
Schedule Of Asset Retirement Obligations	The changes in ARO are as follows: CHANGES IN ASSET RETIREMENT OBLIGATIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2019 2018 2019 2018 2019 2018 Balance as of January 1 (1) $ 2,972 $ 2,876 $ 874 $ 839 $ 2,063 $ 1,953 Accretion expense 123 121 39 39 81 78 Liabilities incurred 2 7 — — — — Deconsolidation and reclassification (2) (2 ) (61 ) (2 ) — — — Payments (46 ) (42 ) (44 ) (39 ) (2 ) (3 ) Revisions 34 71 (1 ) 35 35 35 Balance at December 31 (1) $ 3,083 $ 2,972 $ 866 $ 874 $ 2,177 $ 2,063 (1) Current portion of the ARO for Sempra Energy Consolidated is included in Other Current Liabilities on the Consolidated Balance Sheets. (2) In 2018, we reclassified $6 million at Sempra Renewables and $8 million at Sempra LNG to liabilities held for sale, and $5 million related to TdM from liabilities held for sale, and deconsolidated $52 million at Sempra Renewables, as we discuss in Note 5. Liabilities held for sale are included in Other Current Liabilities on the Sempra Energy Consolidated Balance Sheets.
Schedule Of Changes In Accumulated Other Comprehensive Income By Component	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) Sempra Energy Consolidated (2) : Balance as of December 31, 2016 $ (527 ) $ (125 ) $ (96 ) $ (748 ) OCI before reclassifications 107 (4 ) — 103 Amounts reclassified from AOCI — 7 12 19 Net OCI 107 3 12 122 Balance as of December 31, 2017 (420 ) (122 ) (84 ) (626 ) Cumulative-effect adjustment from change in accounting principle — (3 ) — (3 ) OCI before reclassifications (144 ) 40 (52 ) (156 ) Amounts reclassified from AOCI — 3 18 21 Net OCI (144 ) 43 (34 ) (135 ) 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) (43 ) (116 ) (18 ) (177 ) Amounts reclassified from AOCI (3) — 8 36 44 Net OCI (43 ) (108 ) 18 (133 ) Balance as of December 31, 2019 $ (607 ) $ (215 ) $ (117 ) $ (939 ) SDG&E: Balance as of December 31, 2016 $ (8 ) $ (8 ) OCI before reclassifications (1 ) (1 ) Amounts reclassified from AOCI 1 1 Net OCI — — Balance as of December 31, 2017 (8 ) (8 ) OCI before reclassifications (6 ) (6 ) Amounts reclassified from AOCI 4 4 Net OCI (2 ) (2 ) Balance as of December 31, 2018 (10 ) (10 ) Cumulative-effect adjustment from change in accounting principle (2 ) (2 ) OCI before reclassifications (5 ) (5 ) Amounts reclassified from AOCI 1 1 Net OCI (4 ) (4 ) Balance as of December 31, 2019 $ (16 ) $ (16 ) SoCalGas: Balance as of December 31, 2016 $ (13 ) $ (9 ) $ (22 ) Amounts reclassified from AOCI — 1 1 Net OCI — 1 1 Balance as of December 31, 2017 (13 ) (8 ) (21 ) OCI before reclassifications — (1 ) (1 ) Amounts reclassified from AOCI 1 1 2 Net OCI 1 — 1 Balance as of December 31, 2018 (12 ) (8 ) (20 ) Cumulative-effect adjustment from change in accounting principle (2 ) (2 ) (4 ) OCI before reclassifications (3) — (4 ) (4 ) Amounts reclassified from AOCI (3) 1 4 5 Net OCI 1 — 1 Balance as of December 31, 2019 $ (13 ) $ (10 ) $ (23 ) (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.
Schedule Of Reclassifications Out Of Accumulated Other Comprehensive Income	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated other comprehensive income (loss) components Amounts reclassified from accumulated other comprehensive income (loss) Affected line item on Consolidated Statements of Operations Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Financial instruments: Interest rate and foreign exchange instruments (1) $ 3 $ — $ (4 ) Interest Expense (9 ) (2 ) — Other Income, Net Interest rate instruments 10 9 — Gain on Sale of Assets Interest rate and foreign exchange instruments 5 7 20 Equity Earnings Foreign exchange instruments 2 (1 ) (2 ) Revenues: Energy-Related Businesses Commodity contracts not subject to rate recovery — — 9 Revenues: Energy-Related Businesses Total before income tax 11 13 23 (2 ) (4 ) (6 ) Income Tax (Expense) Benefit Net of income tax 9 9 17 (1 ) (6 ) (10 ) Earnings Attributable to Noncontrolling Interests $ 8 $ 3 $ 7 Pension and other postretirement benefits (2) : Amortization of actuarial loss $ 12 $ 11 $ 10 Other Income, Net Amortization of actuarial loss 1 1 — Income (Loss) from Discontinued Operations, Net of Income Tax Amortization of prior service cost 3 2 1 Other Income, Net Settlement charges 28 12 8 Other Income, Net Total before income tax 44 26 19 (12 ) (8 ) (7 ) Income Tax (Expense) Benefit Net of income tax $ 32 $ 18 $ 12 Total reclassifications for the period, net of tax $ 40 $ 21 $ 19 SDG&E: Financial instruments: Interest rate instruments (1) $ 3 $ 7 $ 13 Interest Expense (3 ) (7 ) (13 ) Earnings Attributable to Noncontrolling Interest $ — $ — $ — Pension and other postretirement benefits (2) : Amortization of actuarial loss $ — $ 1 $ 1 Other Income, Net Amortization of prior service cost 1 — — Other Income, Net Settlement charges — 4 — Other Income, Net Total before income tax 1 5 1 — (1 ) — Income Tax Expense Net of income tax $ 1 $ 4 $ 1 Total reclassifications for the period, net of tax $ 1 $ 4 $ 1 SoCalGas: Financial instruments: Interest rate instruments $ 1 $ 1 $ — Interest Expense Pension and other postretirement benefits (2) : Amortization of actuarial loss $ 1 $ — $ — Other Income, Net Amortization of prior service cost — 1 1 Other Income, Net Total before income tax 1 1 1 (1 ) — — Income Tax Expense Net of income tax $ — $ 1 $ 1 Total reclassifications for the period, net of tax $ 1 $ 2 $ 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 “Net Periodic Benefit Cost” in Note 9 ).
Schedule Of Noncontrolling Interests	The following table provides information about noncontrolling ownership interests held by others (not including preferred shareholders) recorded in Other Noncontrolling Interests in Total Equity on Sempra Energy’s Consolidated Balance Sheets: OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by noncontrolling interests Equity (deficit) held by noncontrolling interests December 31, December 31, 2019 2018 2019 2018 SDG&E: Otay Mesa VIE — % 100 % $ — $ 100 Sempra Mexico: IEnova 33.4 33.5 1,608 1,592 IEnova subsidiaries (1) 10.0 - 46.3 10.0 - 49.0 15 13 Sempra Renewables: Tax equity arrangements – wind (2) NA NA — 158 PXiSE Energy Solutions, LLC (3) NA 11.1 — 1 Sempra LNG: Bay Gas — 9.1 — 18 Liberty Gas Storage, LLC 24.6 24.6 (13 ) (12 ) ECA LNG JV 16.7 — 12 — Parent and other: PXiSE Energy Solutions, LLC (3) 20.0 NA 1 — Discontinued Operations: Chilquinta Energía subsidiaries (1) 19.7 - 43.4 19.7 - 43.4 23 23 Luz del Sur 16.4 16.4 205 193 Tecsur 9.8 9.8 5 4 Total Sempra Energy $ 1,856 $ 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.
Schedule of Related Party Transactions	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) December 31, 2019 2018 Sempra Energy Consolidated: Total due from various unconsolidated affiliates – current $ 32 $ 37 Sempra Mexico (1) : IMG JV – Note due March 15, 2022 (2) $ 742 $ 641 Energía Sierra Juárez – Note (3) — 3 Total due from unconsolidated affiliates – noncurrent $ 742 $ 644 Total due to various unconsolidated affiliates – current $ (5 ) $ (10 ) Sempra Mexico (1) : TAG Pipelines Norte, S. de R.L. de C.V. – Note due December 20, 2021 (4) $ (39 ) $ (37 ) TAG JV – 5.74% Note due December 17, 2029 (5) (156 ) — Total due to unconsolidated affiliates – noncurrent $ (195 ) $ (37 ) SDG&E: Sempra Energy $ (37 ) $ (43 ) SoCalGas (10 ) (6 ) Various affiliates (6 ) (12 ) Total due to unconsolidated affiliates – current $ (53 ) $ (61 ) Income taxes due from Sempra Energy (6) $ 130 $ 5 SoCalGas: SDG&E $ 10 $ 6 Various affiliates 1 1 Total due from unconsolidated affiliates – current $ 11 $ 7 Sempra Energy $ (45 ) $ (34 ) Various affiliates (2 ) — Total due to unconsolidated affiliates – current $ (47 ) $ (34 ) Income taxes due from (to) Sempra Energy (6) $ 152 $ (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 $751 million U.S. dollar-equivalent, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps ( 9.65% at December 31, 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% at December 31, 2018). (4) U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps ( 4.81% at December 31, 2019 ). (5) U.S. dollar-denominated loan at a fixed interest rate. (6) S DG&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) Years ended December 31, 2019 2018 2017 Revenues: Sempra Energy Consolidated $ 52 $ 64 $ 43 SDG&E 6 5 8 SoCalGas 69 64 74 Cost of Sales: Sempra Energy Consolidated $ 50 $ 46 $ 47 SDG&E 74 73 71 SoCalGas 8 — —
Schedule Of Other Income (Expense)	Other Income, Net on the Consolidated Statements of Operations consists of the following: OTHER INCOME, NET (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 94 $ 98 $ 168 Investment gains (losses) (1) 61 (6 ) 56 Gains on interest rate and foreign exchange instruments, net 34 7 47 Foreign currency transaction gains (losses), net (2) 21 (6 ) (33 ) Non-service component of net periodic benefit cost (132 ) (35 ) (20 ) Penalties related to billing practices OII (8 ) — — Interest on regulatory balancing accounts, net 14 2 3 Sundry, net (7 ) (2 ) (1 ) Total $ 77 $ 58 $ 220 SDG&E: Allowance for equity funds used during construction $ 56 $ 61 $ 63 Non-service component of net periodic benefit (cost) credit (20 ) (6 ) 4 Interest on regulatory balancing accounts, net 13 4 3 Sundry, net (10 ) (3 ) — Total $ 39 $ 56 $ 70 SoCalGas: Allowance for equity funds used during construction $ 34 $ 36 $ 44 Non-service component of net periodic benefit cost (72 ) (10 ) (5 ) Penalties related to billing practices OII (8 ) — — Interest on regulatory balancing accounts, net 1 (2 ) — Sundry, net (10 ) (9 ) (8 ) Total $ (55 ) $ 15 $ 31 (1) Represents investment gains (losses) on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are partially offset by corresponding changes in compensation expense related to the plans, recorded in O&M on the Consolidated Statements of Operations. (2) Includes gains of $30 million in 2019 and losses of $3 million and $35 million in 2018 and 2017, respectively, from translation to U.S. dollars of a Mexican peso-denominated loan to IMG JV, which are offset by corresponding amounts included in Equity Earnings on the Consolidated Statements of Operations.

NEW ACCOUNTING STANDARDS NEW AC

NEW ACCOUNTING STANDARDS NEW ACCOUNTING STANDARDS (Tables)	12 Months Ended
	Dec. 31, 2019
Accounting Changes and Error Corrections [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	We expect no impact to SDG&E’s or SoCalGas’ balance sheets from adoption. The following table shows the expected (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. EXPECTED IMPACT FROM ADOPTION OF ASU 2016-13 (Dollars in millions) Sempra Energy Consolidated Accounts receivable – trade, net $ (1 ) Due from unconsolidated affiliates – noncurrent (6 ) Deferred income tax assets 4 Other current liabilities 4 Deferred credits and other 2 Retained earnings (7 ) Other noncontrolling interests (2 ) 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 $ — $ — Other long-term assets (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 and finance leases (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — The following table shows the increases (decreases) on our balance sheet at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Right-of-use assets – operating leases (1) $ 191 Deferred income tax assets (3 ) Property, plant and equipment, net (1) (147 ) Other current liabilities 3 Long-term debt (138 ) Other long-term liabilities 159 Retained earnings (2) 17 (1) Included in Other Long-Term Assets. (2) Included in Shareholders’ Equity.

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 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) Year ended December 31, 2019 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments and Parent and other Sempra Energy Consolidated By major service line: Utilities $ 4,819 $ 4,367 $ 73 $ — $ — $ (75 ) $ 9,184 Energy-related businesses — — 919 5 176 (143 ) 957 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 5 $ 176 $ (218 ) $ 10,141 By market: Gas $ 587 $ 4,367 $ 680 $ — $ 170 $ (208 ) $ 5,596 Electric 4,232 — 312 5 6 (10 ) 4,545 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 5 $ 176 $ (218 ) $ 10,141 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 5 $ 176 $ (218 ) $ 10,141 Utilities regulatory revenues 106 158 — — — — 264 Other revenues — — 383 5 234 (198 ) 424 Total revenues $ 4,925 $ 4,525 $ 1,375 $ 10 $ 410 $ (416 ) $ 10,829 Year ended December 31, 2018 SDG&E SoCalGas Sempra Mexico Sempra Renewables Sempra LNG Consolidating adjustments and Parent and other Sempra Energy Consolidated By major service line: Utilities $ 4,788 $ 3,577 $ 78 $ — $ — $ (69 ) $ 8,374 Energy-related businesses — — 941 46 232 (146 ) 1,073 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 46 $ 232 $ (215 ) $ 9,447 By market: Gas $ 491 $ 3,577 $ 711 $ — $ 224 $ (203 ) $ 4,800 Electric 4,297 — 308 46 8 (12 ) 4,647 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 46 $ 232 $ (215 ) $ 9,447 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 46 $ 232 $ (215 ) $ 9,447 Utilities regulatory revenues (220 ) 385 — — — — 165 Other revenues — — 357 78 240 (185 ) 490 Total revenues $ 4,568 $ 3,962 $ 1,376 $ 124 $ 472 $ (400 ) $ 10,102
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at December 31, 2019 , we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra Energy’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Mexico. SoCalGas did not have any remaining performance obligations at December 31, 2019 . REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E 2020 $ 390 $ 4 2021 403 4 2022 406 4 2023 402 4 2024 349 4 Thereafter 4,699 71 Total revenues to be recognized $ 6,649 $ 91 (1) Excludes intercompany transactions.
Schedule of Contract Liabilities	Activities within Sempra Energy’s and SDG&E’s contract liabilities are presented below. There were no contract liability activities at SDG&E in 2018 or SoCalGas in 2019 or 2018 . CONTRACT LIABILITIES (Dollars in millions) Sempra Energy Consolidated SDG&E Opening balance, January 1, 2019 $ (70 ) $ — Revenue from performance obligations satisfied during reporting period 2 1 Payments received in advance (95 ) (92 ) Balance at December 31, 2019 (1) $ (163 ) $ (91 ) Opening balance, January 1, 2018 $ — Adoption of ASC 606 adjustment (61 ) Revenue from performance obligations satisfied during reporting period 7 Payments received in advance (16 ) Balance at December 31, 2018 $ (70 ) (1) I ncludes $4 million and $4 million in Other Current Liabilities and $159 million and $87 million in Deferred Credits and Other on the Sempra Energy and SDG&E Consolidated Balance Sheets, respectively.
Schedule of Contract Accounts Receivable	The table below shows receivable balances associated with revenues from contracts with customers on our Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2019 2018 Sempra Energy Consolidated: Accounts receivable – trade, net $ 1,163 $ 1,106 Accounts receivable – other, net 16 11 Due from unconsolidated affiliates – current (1) 5 4 Assets held for sale — 6 Total $ 1,184 $ 1,127 SDG&E: Accounts receivable – trade, net $ 398 $ 368 Accounts receivable – other, net 5 6 Due from unconsolidated affiliates – current (1) 2 3 Total $ 405 $ 377 SoCalGas: Accounts receivable – trade, net $ 710 $ 634 Accounts receivable – other, net 11 5 Total $ 721 $ 639 (1) A mount is presented net of amounts due to unconsolidated affiliates on the Consolidated Balance Sheets, when right of offset exists.

REGULATORY MATTERS (Tables)

REGULATORY MATTERS (Tables)	12 Months Ended
	Dec. 31, 2019
Regulated Operations [Abstract]
Schedule of Regulatory Assets	We show the details of regulatory assets and liabilities in the following table and discuss them below. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2019 2018 SDG&E: Fixed-price contracts and other derivatives $ 8 $ (150 ) Deferred income taxes refundable in rates (108 ) (236 ) Pension and other postretirement benefit plan obligations 103 186 Removal obligations (2,056 ) (1,848 ) Environmental costs 45 28 Sunrise Powerlink fire mitigation 121 120 Regulatory balancing accounts (1)(2) Commodity – electric 102 (8 ) Gas transportation 22 45 Safety and reliability 77 70 Public purpose programs (124 ) (62 ) 2019 GRC retroactive impacts 111 — Other balancing accounts 106 145 Other regulatory liabilities, net (2) (153 ) (170 ) Total SDG&E (1,746 ) (1,880 ) SoCalGas: Deferred income taxes refundable in rates (203 ) (336 ) Pension and other postretirement benefit plan obligations 400 470 Employee benefit costs 44 49 Removal obligations (728 ) (833 ) Environmental costs 40 28 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (118 ) 196 Safety and reliability 295 332 Public purpose programs (273 ) (325 ) 2019 GRC retroactive impacts 400 — Other balancing accounts (7 ) (68 ) Other regulatory liabilities, net (2) (101 ) (114 ) Total SoCalGas (251 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 83 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (1,908 ) $ (2,394 ) (1) At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $108 million and $78 million , respectively. At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SoCalGas was $500 million and $185 million , respectively. (2) Includes regulatory assets earning a return.
Schedule of Regulatory Liabilities	We show the details of regulatory assets and liabilities in the following table and discuss them below. REGULATORY ASSETS (LIABILITIES) (Dollars in millions) December 31, 2019 2018 SDG&E: Fixed-price contracts and other derivatives $ 8 $ (150 ) Deferred income taxes refundable in rates (108 ) (236 ) Pension and other postretirement benefit plan obligations 103 186 Removal obligations (2,056 ) (1,848 ) Environmental costs 45 28 Sunrise Powerlink fire mitigation 121 120 Regulatory balancing accounts (1)(2) Commodity – electric 102 (8 ) Gas transportation 22 45 Safety and reliability 77 70 Public purpose programs (124 ) (62 ) 2019 GRC retroactive impacts 111 — Other balancing accounts 106 145 Other regulatory liabilities, net (2) (153 ) (170 ) Total SDG&E (1,746 ) (1,880 ) SoCalGas: Deferred income taxes refundable in rates (203 ) (336 ) Pension and other postretirement benefit plan obligations 400 470 Employee benefit costs 44 49 Removal obligations (728 ) (833 ) Environmental costs 40 28 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (118 ) 196 Safety and reliability 295 332 Public purpose programs (273 ) (325 ) 2019 GRC retroactive impacts 400 — Other balancing accounts (7 ) (68 ) Other regulatory liabilities, net (2) (101 ) (114 ) Total SoCalGas (251 ) (601 ) Sempra Mexico: Deferred income taxes recoverable in rates 83 81 Other regulatory assets 6 6 Total Sempra Energy Consolidated $ (1,908 ) $ (2,394 ) (1) At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $108 million and $78 million , respectively. At December 31, 2019 and 2018 , the noncurrent portion of regulatory balancing accounts – net undercollected for SoCalGas was $500 million and $185 million , respectively. (2) Includes regulatory assets earning a return.
Proposed Revenue Requirements	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 In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that are effective January 1, 2020 and will remain in effect through December 31, 2022. SDG&E did not propose a 2020 cost of preferred equity in this proceeding. In January 2020, SDG&E filed an advice letter to continue the cost of preferred equity for test year 2020 at 6.22% , which is pending CPUC approval. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on rate base Weighted rate base Authorized weighting Return on Weighted 45.25 % 4.59 % 2.08 % Long-Term Debt 45.60 % 4.23 % 1.93 % 2.75 6.22 0.17 Preferred Stock 2.40 6.00 0.14 52.00 10.20 5.30 Common Equity 52.00 10.05 5.23 100.00 % 7.55 % 100.00 % 7.30 %
Schedule Of FERC Cost Of Capital Table	SDG&E’s current estimated FERC return on rate base under the TO4 formula rate request filing is 7.51% based on its capital structure as follows: FERC–AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE – SDG&E Weighting Return on rate base Weighted return on rate base Long-Term Debt 43.44 % 4.21 % 1.83 % Common Equity 56.56 10.05 5.68 100.00 % 7.51 %

ACQUISTIONS, DIVESTITURES AND_2

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table sets forth the allocation of the total purchase price paid to the identifiable assets acquired and liabilities assumed. PURCHASE PRICE ALLOCATION (Dollars in millions) At March 9, 2018 (1) Assets acquired: Accounts receivable – other, net $ 1 Due from unconsolidated affiliates 46 Investment in Oncor Holdings 9,227 Deferred income tax assets 287 Other noncurrent assets 109 Total assets acquired 9,670 Liabilities assumed: Other current liabilities 23 Pension and other postretirement benefit plan obligations 21 Deferred credits and other 58 Total liabilities assumed 102 Net assets acquired $ 9,568 Total purchase price paid $ 9,568 (1) In the fourth quarter of 2018, we received additional information regarding deferred income taxes related to the resolution of claims in EFH’s emergence from bankruptcy as of the acquisition date. As a result, we recorded an adjustment to increase our investment in Oncor Holdings by $64 million , decrease deferred income tax assets by $66 million and decrease deferred credits and other liabilities by $2 million . Also in the fourth quarter of 2018, we recorded $2 million
Schedule Of Assets Held for Sale and Deconsolidation of Subsidiaries Table	The following table summarizes the deconsolidation of these subsidiaries in 2018. DECONSOLIDATION OF SUBSIDIARIES (Dollars in millions) Certain subsidiaries of Sempra Renewables At December 13, 2018 Proceeds from sale, net of transaction costs $ 1,585 Cash (7 ) Restricted cash (7 ) Other current assets (14 ) Property, plant and equipment, net (1,303 ) Other investments (329 ) Other long-term assets (24 ) Current liabilities 8 Long-term debt 70 Asset retirement obligations 52 Other long-term liabilities 5 Noncontrolling interests 486 Accumulated other comprehensive income (9 ) Gain on sale $ 513

INVESTMENTS IN UNCONSOLIDATED_2

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	12 Months Ended
	Dec. 31, 2019
Investments [Abstract]
Schedule Of Equity Method And Other Investments	We provide the carrying values of our investments and earnings (losses) on these investments in the following tables. EQUITY METHOD AND OTHER INVESTMENT BALANCES (Dollars in millions) Percent ownership December 31, December 31, 2019 2018 2019 2018 Sempra Texas Utilities: Oncor Holdings (1) 100 % 100 % $ 11,519 $ 9,652 Sempra Texas Utilities: Sharyland Holdings (2) 50 — $ 100 $ — Sempra Mexico: Energía Sierra Juárez (3) 50 50 39 43 IMG JV (4) 40 40 337 328 TAG JV (5) 50 50 365 376 Sempra Renewables: Auwahi Wind — 50 — 38 Cedar Creek 2 Wind — 50 — 69 Flat Ridge 2 Wind (6) — 50 — 82 Fowler Ridge 2 Wind — 50 — 45 Mehoopany Wind (7) — 50 — 57 Sempra LNG: Cameron LNG JV (8) 50.2 50.2 1,256 1,271 Total other equity method investments 2,097 2,309 Other 6 11 Total other investments $ 2,103 $ 2,320 (1) The carrying value of our equity method investment is $2,823 million and $2,814 million higher than the underlying equity in the net assets of the investee at December 31, 2019 and 2018 , respectively, due to $2,868 million of equity method goodwill and $69 million in basis differences in AOCI, offset by $114 million at December 31, 2019 and $123 million at December 31, 2018 due to a tax sharing liability to TTI under the tax sharing agreement. (2) The carrying value of our equity method investment is $42 million higher than the underlying equity in the net assets of the investee due to equity method goodwill. (3) The carrying value of our equity method investment is $12 million higher than the underlying equity in the net assets of the investee due to the remeasurement of our retained investment to fair value in 2014. (4) The carrying value of our equity method investment is $5 million higher than the underlying equity in the net assets of the investee due to guarantees. (5) The carrying value of our equity method investment is $ 130 million higher than the underlying equity in the net assets of the investee due to equity method goodwill. (6) The carrying value of our equity method investment at December 31, 2018 was $169 million lower than the underlying equity in the net assets of the investee due to an other-than-temporary impairment recorded in 2018. (7) The carrying value of our equity method investment at December 31, 2018 was $31 million lower than the underlying equity in the net assets of the investee due to an other-than-temporary impairment recorded in 2018. (8) The carrying value of our equity method investment is $263 million and $246 million higher than the underlying equity in the net assets of the investee at December 31, 2019 and 2018 , respectively, primarily due to guarantees, which we discuss below, interest capitalized on the investment prior to the JV commencing its planned principal operations in August 2019 and amortization of guarantee fees and capitalized interest thereafter. EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2019 2018 2017 EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX (1) : Sempra Texas Utilities: Sharyland Holdings $ 2 $ — $ — Sempra Renewables: Wind: Auwahi Wind — 3 5 Broken Bow 2 Wind — (2 ) (2 ) Cedar Creek 2 Wind — (1 ) (2 ) Flat Ridge 2 Wind (2) (3 ) (178 ) (13 ) Fowler Ridge 2 Wind 5 3 4 Mehoopany Wind (2) 1 (30 ) (1 ) Solar: California solar partnership — 8 7 Copper Mountain Solar 2 — 5 5 Copper Mountain Solar 3 — 8 8 Mesquite Solar 1 — 18 18 Other 2 (3 ) — Sempra LNG: Cameron LNG JV 24 — 5 Parent and other: RBS Sempra Commodities (2) — (67 ) — Other (1 ) — — 30 (236 ) 34 EARNINGS (LOSSES) RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 526 371 — Sempra Mexico: DEN — — (13 ) Energía Sierra Juárez 2 2 — IMG JV 9 29 45 TAG JV 13 9 6 550 411 38 Total $ 580 $ 175 $ 72 (1) We provide our ETR calculation in Note 8. (2) Losses from equity method investment in 2018 include an other-than-temporary impairment charge, which we discuss below. We disclose distributions received from our investments, by segment, in the table below. DISTRIBUTIONS FROM INVESTMENTS (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Texas Utilities $ 246 $ 149 $ — Sempra Mexico 2 — — Sempra Renewables 1 63 65 Parent and other 7 — — Total 256 212 65
Schedule of Summarized Financial Information	We provide summarized income statement and balance sheet information for Oncor Holdings in the following table. SUMMARIZED FINANCIAL INFORMATION – ONCOR HOLDINGS (Dollars in millions) Year ended December 31, 2019 March 9 - December 31, 2018 Operating revenues $ 4,347 $ 3,347 Operating expense (3,135 ) (2,434 ) Income from operations 1,212 913 Interest expense (375 ) (285 ) Income tax expense (131 ) (119 ) Net income 643 455 Noncontrolling interest held by TTI (129 ) (94 ) Earnings attributable to Sempra Energy 514 360 At December 31, 2019 2018 Current assets $ 913 $ 772 Noncurrent assets 26,012 21,980 Current liabilities 1,626 2,217 Noncurrent liabilities 14,125 11,756 Noncontrolling interest held by TTI 2,473 1,951 We present summarized financial information below, aggregated for all other equity method investments (excluding Oncor Holdings) for the periods in which we were invested in the entities. The amounts below represent the results of operations and aggregate financial position of 100% of each of Sempra Energy’s other equity method investments. SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2019 (1) 2018 (2) 2017 (3) Gross revenues $ 798 $ 706 $ 833 Operating expense (372 ) (609 ) (585 ) Income from operations 426 97 248 Interest expense (401 ) (322 ) (219 ) Net income (loss)/Earnings (losses) (4) 85 (36 ) 108 At December 31, 2019 (1) 2018 (2) Current assets $ 1,124 $ 564 Noncurrent assets 15,039 14,558 Current liabilities 1,232 801 Noncurrent liabilities 11,438 9,966 (1) On April 22, 2019, Sempra Renewables sold its remaining wind assets and investments to AEP. As of April 22, 2019, these wind assets and investments are no longer equity method investments. (2) On December 13, 2018, Sempra Renewables sold all its operating solar assets, including its solar equity method investments, and its 50 % interest in the Broken Bow 2 wind power generation facility to a subsidiary of Con Ed. As of December 13, 2018, the solar equity method investments and Broken Bow 2 are no longer equity method investments. (3) On November 15, 2017, IEnova completed the asset acquisition of PEMEX’s 50 % interest in DEN, increasing its ownership percentage to 100% . As of November 15, 2017, DEN is no longer an equity method investment. (4) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

DEBT AND CREDIT FACILITIES (Tab

DEBT AND CREDIT FACILITIES (Tables)	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The weighted-average interest rates on the total short-term debt at December 31, 2019 and 2018 were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2019 2018 Sempra Energy Consolidated 2.31 % 2.99 % SDG&E 1.97 2.97 SoCalGas 1.86 2.58 PRIMARY U.S. COMMITTED LINES OF CREDIT (Dollars in millions) At December 31, 2019 Total facility Commercial paper outstanding (1) Available unused credit Sempra Energy (2) $ 1,250 $ — 1,250 Sempra Global (3) 3,185 (1,624 ) 1,561 SDG&E (3)(4) 1,500 (80 ) 1,420 SoCalGas (3)(4) 750 (630 ) 120 Total $ 6,685 $ (2,334 ) $ 4,351 (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 December 31, 2019 . (3) Commercial paper outstanding is before reductions of unamortized discount of $3 million at Sempra Global and negligible amounts at SDG&E and SoCalGas. (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 December 31, 2019 . . FOREIGN COMMITTED LINES OF CREDIT (U.S. dollar equivalent in millions) December 31, 2019 Expiration date of facility Total facility Amounts outstanding Available unused credit February 2024 (1) $ 1,500 $ (894 ) $ 606 April 2022 (2) 100 — 100 September 2021 (3) 280 (280 ) — Total $ 1,880 $ (1,174 ) $ 706 (1) Five-year revolving credit facility with a syndicate of 10 lenders. (2) Three-year revolving credit facility with Scotiabank Inverlat, S.A. Withdrawals may be made for up to one year from April 11, 2019 in either U.S. dollars or Mexican pesos. (3) Two-year revolving credit facility with The Bank of Nova Scotia. Withdrawals may be made for up to two years from September 23, 2019 in U.S. dollars.
Schedule Of Long-term Debt	Sempra Energy LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2019 2018 Sempra Energy: Other long-term debt (uncollateralized): 9.8% Notes February 15, 2019 — 500 Notes at variable rates (2.69% at December 31, 2018) July 15, 2019 — 500 1.625% Notes October 7, 2019 — 500 2.4% Notes February 1, 2020 500 500 2.4% Notes March 15, 2020 500 500 2.85% Notes November 15, 2020 400 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) 700 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 850 850 2.875% Notes October 1, 2022 500 500 2.9% Notes February 1, 2023 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 350 3.25% Notes June 15, 2027 750 750 3.4% Notes February 1, 2028 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 6% Notes October 15, 2039 750 750 4% Notes February 1, 2048 800 800 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 — Build-to-suit arrangement (2) — 138 Sempra Mexico Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 207 198 Notes at variable rates (4.88% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets 237 275 3.75% Notes January 14, 2028 300 300 Bank loans including $241 at a weighted-average fixed rate of 6.87%, $147 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $35 at variable rates (5.12% at December 31, 2019), payable 2016 through March 2032, collateralized by plant assets 423 447 4.875% Notes January 14, 2048 540 540 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) 11 4 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 — Sempra LNG Other long-term debt (uncollateralized): Notes at 2.87% to 3.51% October 1, 2026 (1) 22 21 12,298 13,023 Current portion of long-term debt (1,464 ) (1,560 ) Unamortized discount on long-term debt (35 ) (38 ) Unamortized debt issuance costs (108 ) (87 ) Total other Sempra Energy 10,691 11,338 Total Sempra Energy Consolidated $ 20,785 $ 20,903 (1) Callable long-term debt not subject to make-whole provisions. (2) This arrangement is now accounted for as an operating lease liability upon adoption of the lease standard on January 1, 2019. See Note 2. The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2019 2018 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ 350 $ 350 1.914% payable 2015 through February 2022 89 125 3.6% September 1, 2023 450 450 2.5% May 15, 2026 500 500 6% June 1, 2026 250 250 5.875% January and February 2034 (1) 176 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039 (1) 75 75 6% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.5% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.3% April 1, 2042 250 250 3.75% June 1, 2047 400 400 4.15% May 15, 2048 400 400 4.1% June 15, 2049 400 — 5,140 4,776 Other long-term debt: OMEC LLC variable-rate loan (4.7896% at December 31, 2018 except for $142 at 5.2925% after floating-to-fixed rate swaps through April 1, 2019), payable 2019 through 2024 (collateralized by OMEC plant assets) — 220 Finance lease obligations: Purchased-power contracts 1,255 1,270 Other 15 2 1,270 1,492 6,410 6,268 Current portion of long-term debt (56 ) (81 ) Unamortized discount on long-term debt (12 ) (12 ) Unamortized debt issuance costs (36 ) (37 ) Total SDG&E 6,306 6,138 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 500 500 3.2% June 15, 2025 350 350 2.6% June 15, 2026 500 500 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 4.125% June 1, 2048 400 400 4.3% January 15, 2049 550 550 3.95% February 15, 2050 350 — 3,800 3,450 Other long-term debt (uncollateralized): 1.875% Notes May 14, 2026 (1) 4 4 5.67% Notes January 18, 2028 5 5 Finance lease obligations 19 3 28 12 3,828 3,462 Current portion of long-term debt (6 ) (3 ) Unamortized discount on long-term debt (7 ) (6 ) Unamortized debt issuance costs (27 ) (26 ) Total SoCalGas 3,788 3,427 The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2019 2018 9.8% Notes February 15, 2019 $ — $ 500 Notes at variable rates (2.69% at December 31, 2018) July 15, 2019 — 500 1.625% Notes October 7, 2019 — 500 2.4% Notes February 1, 2020 500 500 2.4% Notes March 15, 2020 500 500 2.85% Notes November 15, 2020 400 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) 700 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 850 850 2.875% Notes October 1, 2022 500 500 2.9% Notes February 1, 2023 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 350 3.25% Notes June 15, 2027 750 750 3.4% Notes February 1, 2028 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 6% Notes October 15, 2039 750 750 4% Notes February 1, 2048 800 800 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 — Build-to-suit arrangement (2) — 138 10,358 11,238 Current portion of long-term debt (1,399 ) (1,498 ) Unamortized discount on long-term debt (35 ) (38 ) Unamortized debt issuance costs (68 ) (55 ) Total long-term debt $ 8,856 $ 9,647
Schedule of Maturities of Long-term Debt	MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Sempra Energy Total Sempra Energy Consolidated 2020 $ 36 $ — $ 1,465 $ 1,501 2021 386 — 1,619 2,005 2022 18 — 576 594 2023 450 — 1,285 1,735 2024 — 500 545 1,045 Thereafter 4,250 3,309 6,808 14,367 Total $ 5,140 $ 3,809 $ 12,298 $ 21,247 (1)
Schedule Of Callable Long Term Debt	At the option of Sempra Energy, SDG&E and SoCalGas, certain debt at December 31, 2019 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ 251 $ 4 $ 1,691 $ 1,946 Subject to make-whole provisions 4,889 3,800 9,097 17,786

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Schedule of Effective Income Tax Rate Reconciliation	We provide our calculations of ETRs in the following table. INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Income tax expense (benefit) from continuing operations $ 315 $ (49 ) $ 938 Income from continuing operations before income taxes and equity earnings $ 1,734 $ 714 $ 1,248 Equity earnings (losses), before income tax (1) 30 (236 ) 34 Pretax income $ 1,764 $ 478 $ 1,282 Effective income tax rate 18 % (10 )% 73 % SDG&E: Income tax expense $ 171 $ 173 $ 155 Income before income taxes $ 945 $ 849 $ 576 Effective income tax rate 18 % 20 % 27 % SoCalGas: Income tax expense $ 120 $ 92 $ 160 Income before income taxes $ 762 $ 493 $ 557 Effective income tax rate 16 % 19 % 29 % (1) We discuss how we recognize equity earnings in Note 6 . 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 ▪ state income taxes The AFUDC related to equity recorded for regulated construction projects at Sempra Mexico has similar flow-through treatment. We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Such effects are partially mitigated by net gains (losses) from foreign currency derivatives that are hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova. We present in the table below reconciliations of net U.S. statutory federal income tax rates to our ETRs. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: U.S. federal statutory income tax rate 21 % 21 % 35 % Foreign exchange and inflation effects (1) 4 6 4 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (2) 3 10 (2 ) Utility depreciation 3 12 7 State income taxes, net of federal income tax benefit 2 (8 ) 1 Effects of the TCJA — 9 48 Compensation-related items — 3 — Unrecognized income tax benefits — 4 — Noncontrolling interests in tax equity arrangements — 3 1 Resolution of prior years’ income tax items — (1 ) (3 ) Impairment losses at Sempra LNG — (32 ) — Allowance for equity funds used during construction (1 ) (4 ) (4 ) Amortization of excess deferred income taxes (1 ) (4 ) — Tax credits (2 ) (10 ) (4 ) Utility self-developed software expenditures (2 ) (7 ) (5 ) Utility repairs expenditures (3 ) (13 ) (7 ) Excess deferred income taxes outside of ratemaking (4 ) — — Other, net (2 ) 1 2 Effective income tax rate 18 % (10 )% 73 % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 35 % State income taxes, net of federal income tax benefit 6 5 3 Depreciation 3 3 7 Effects of the TCJA — — 5 Resolution of prior years’ income tax items — — (4 ) Allowance for equity funds used during construction (1 ) (2 ) (4 ) Amortization of excess deferred income taxes (1 ) (1 ) — Repairs expenditures (3 ) (3 ) (8 ) Self-developed software expenditures (3 ) (2 ) (6 ) Excess deferred income taxes outside of ratemaking (3 ) — — Other, net (1 ) (1 ) (1 ) Effective income tax rate 18 % 20 % 27 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 35 % Depreciation 4 7 9 State income taxes, net of federal income tax benefit 4 2 3 Unrecognized income tax benefits — 4 — Compensation-related items — 1 — Resolution of prior years’ income tax items — (1 ) (2 ) Allowance for equity funds used during construction (1 ) (2 ) (3 ) Amortization of excess deferred income taxes (1 ) (2 ) — Self-developed software expenditures (2 ) (3 ) (5 ) Repairs expenditures (4 ) (7 ) (8 ) Excess deferred income taxes outside of ratemaking (5 ) — — Other, net — (1 ) — Effective income tax rate 16 % 19 % 29 % (1) Due to fluctuation of the Mexican peso against the U.S. dollar. We record income tax expense (benefit) from the transactional effects of foreign currency and inflation because of appreciation (depreciation) of the Mexican peso. We also recognize gains (losses) in Other Income, Net, on the Consolidated Statements of Operations from foreign currency derivatives that are partially hedging Sempra Mexico parent’s exposure to movements in the Mexican peso from its controlling interest in IEnova. (2) Related to operations in Mexico.
Schedule of Impact of Changes in Legislation	The table below summarizes the effects of the TCJA in 2018 and 2017: EFFECTS OF THE TAX CUTS AND JOBS ACT OF 2017 (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas 2018: Consolidated Balance Sheets: Increase (decrease) in net deferred income tax liabilities due to remeasurement $ 16 $ (38 ) $ 5 Increase (decrease) in net regulatory liabilities from remeasurement of deferred income tax assets and liabilities $ 33 $ 38 $ (5 ) Consolidated Statements of Operations: Income tax expense related to remeasurement of deferred income tax assets and liabilities $ 49 $ — $ — Income tax benefit related to deemed repatriation (8 ) — — Total increase in income tax expense $ 41 $ — $ — 2017: Consolidated Balance Sheets: Decrease in net deferred income tax liabilities due to remeasurement $ (2,220 ) $ (1,400 ) $ (972 ) Increase in net regulatory liabilities from remeasurement of deferred income tax assets and liabilities $ 2,402 $ 1,428 $ 974 Consolidated Statements of Operations: Income tax expense related to remeasurement of deferred income tax assets and liabilities $ 182 $ 28 $ 2 Income tax expense related to deemed repatriation 328 — — U.S. state and non-U.S. withholding tax expense related to expected future repatriation of foreign earnings 109 — — Total increase in income tax expense $ 619 $ 28 $ 2
Schedule Of Geographic Components Of Income Before Income Taxes And Equity Earnings Of Certain Unconsolidated Subsidiaries	The table below presents the geographic components of pretax income. PRETAX INCOME – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Years ended December 31, 2019 2018 2017 By geographic components: U.S. $ 1,191 $ (102 ) $ 878 Non-U.S. 573 580 404 Total (1) $ 1,764 $ 478 $ 1,282 (1) See “Income Tax Expense (Benefit) and Effective Income Tax Rates” table above for calculation of pretax income.
Schedule Of Components Of Income Tax Expense	The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Current: U.S. federal $ — $ (1 ) $ 4 U.S. state (14 ) 67 — Non-U.S. 140 127 45 Total 126 193 49 Deferred: U.S. federal 87 (121 ) 566 U.S. state 21 (183 ) 154 Non-U.S. 84 66 169 Total 192 (238 ) 889 Deferred investment tax credits (3 ) (4 ) — Total income tax expense (benefit) $ 315 $ (49 ) $ 938 SDG&E: Current: U.S. federal $ 35 $ 104 $ 100 U.S. state 31 30 65 Total 66 134 165 Deferred: U.S. federal 75 17 29 U.S. state 32 24 (41 ) Total 107 41 (12 ) Deferred investment tax credits (2 ) (2 ) 2 Total income tax expense $ 171 $ 173 $ 155 SoCalGas: Current: U.S. federal $ 8 $ 4 $ — U.S. state 24 10 23 Total 32 14 23 Deferred: U.S. federal 79 78 144 U.S. state 10 2 (5 ) Total 89 80 139 Deferred investment tax credits (1 ) (2 ) (2 ) Total income tax expense $ 120 $ 92 $ 160
Schedule Of Components Of Deferred Tax Assets And Liabilities	The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) December 31, 2019 2018 Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 4,052 $ 3,517 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 153 382 Regulatory balancing accounts 468 359 Right-of-use assets – operating leases 131 — Property taxes 44 41 Other deferred income tax liabilities 93 133 Total deferred income tax liabilities 4,941 4,432 Deferred income tax assets: Tax credits 1,136 1,114 Net operating losses 911 723 Postretirement benefits 200 261 Compensation-related items 161 170 Operating lease liabilities 131 — Other deferred income tax assets 72 82 Accrued expenses not yet deductible 52 66 Deferred income tax assets before valuation allowances 2,663 2,416 Less: valuation allowances 144 164 Total deferred income tax assets 2,519 2,252 Net deferred income tax liability (2) $ 2,422 $ 2,180 (1) In addition to the financial over tax basis differences in fixed assets, the amount also includes financial over tax basis differences in various interests in partnerships and certain subsidiaries. (2) At December 31, 2019 and 2018, includes $155 million and $141 million , respectively, recorded as a noncurrent asset and $2,577 million and $2,321 million , respectively, recorded as a noncurrent liability on the Consolidated Balance Sheets. DEFERRED INCOME TAXES – SDG&E AND SOCALGAS (Dollars in millions) SDG&E SoCalGas December 31, December 31, 2019 2018 2019 2018 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 1,735 $ 1,578 $ 1,246 $ 1,077 Regulatory balancing accounts 141 84 327 283 Right-of-use assets – operating leases 32 — 22 — Property taxes 30 29 14 13 Other 14 10 1 2 Total deferred income tax liabilities 1,952 1,701 1,610 1,375 Deferred income tax assets: Tax credits 6 6 3 3 Postretirement benefits 37 58 120 140 Compensation-related items 6 5 25 25 Operating lease liabilities 32 — 22 — State income taxes 7 6 8 3 Accrued expenses not yet deductible 9 4 15 13 Other 7 6 14 14 Total deferred income tax assets 104 85 207 198 Net deferred income tax liability $ 1,848 $ 1,616 $ 1,403 $ 1,177
Summary of Tax Credit Carryforwards	The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2019 Year expiration begins Sempra Energy Consolidated: U.S. federal: NOLs (1) $ 3,475 2031 General business tax credits (1) 433 2032 Foreign tax credits (2) 624 2024 U.S. state (2) : NOLs 3,025 2020 General business tax credits 90 2020 Non-U.S. (2) – NOLs 115 2020 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as discussed below.
Summary of Operating Loss Carryforwards	The following table summarizes our unused NOLs and tax credit carryforwards. NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Dollars in millions) Unused amount at December 31, 2019 Year expiration begins Sempra Energy Consolidated: U.S. federal: NOLs (1) $ 3,475 2031 General business tax credits (1) 433 2032 Foreign tax credits (2) 624 2024 U.S. state (2) : NOLs 3,025 2020 General business tax credits 90 2020 Non-U.S. (2) – NOLs 115 2020 (1) We have recorded deferred income tax benefits on these NOLs and tax credits, in total, because we currently believe they will be realized on a more-likely-than-not-basis. (2) We have not recorded deferred income tax benefits on a portion of these NOLs and tax credits because we currently believe they will not be realized on a more-likely-than-not-basis, as discussed below.
Summary of Income Tax Contingencies	Following is a reconciliation of the changes in unrecognized income tax benefits and the potential effect on our ETR for the years ended December 31: RECONCILIATION OF UNRECOGNIZED INCOME TAX BENEFITS (Dollars in millions) 2019 2018 2017 Sempra Energy Consolidated: Balance at January 1 $ 119 $ 89 $ 90 Increase in prior period tax positions 5 7 22 Decrease in prior period tax positions — (1 ) (15 ) Increase in current period tax positions 2 24 4 Settlements with taxing authorities (32 ) — (12 ) Expiration of statutes of limitations (1 ) — — Balance at December 31 $ 93 $ 119 $ 89 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (81 ) $ (107 ) $ (77 ) increase the effective tax rate (1) 27 24 20 SDG&E: Balance at January 1 $ 11 $ 10 $ 22 Increase in prior period tax positions 1 1 9 Decrease in prior period tax positions — — (11 ) Settlements with taxing authorities — — (10 ) Balance at December 31 $ 12 $ 11 $ 10 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (9 ) $ (9 ) $ (7 ) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 61 $ 35 $ 29 Increase in prior period tax positions 1 2 3 Increase in current period tax positions 2 24 4 Settlements with taxing authorities — — (1 ) Balance at December 31 $ 64 $ 61 $ 35 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (55 ) $ (51 ) $ (26 ) increase the effective tax rate (1) 26 23 20 (1) Includes temporary book and tax differences that are treated as flow-through for ratemaking purposes, as discussed above.
Summary of Positions for which Significant Change in Unrecognized Tax Benefits is Reasonably Possible	It is reasonably possible that within the next 12 months, unrecognized income tax benefits could decrease due to the following: POSSIBLE DECREASES IN UNRECOGNIZED INCOME TAX BENEFITS WITHIN 12 MONTHS (Dollars in millions) At December 31, 2019 2018 2017 Sempra Energy Consolidated: Expiration of statutes of limitations on tax assessments $ — $ (1 ) $ — Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities (8 ) (40 ) (8 ) $ (8 ) $ (41 ) $ (8 ) SDG&E: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ (6 ) $ (6 ) $ (6 ) SoCalGas: Potential resolution of audit issues with various U.S. federal, state and local taxing authorities $ (2 ) $ (2 ) $ (2 )

EMPLOYEE BENEFIT PLANS (Tables)

EMPLOYEE BENEFIT PLANS (Tables)	12 Months Ended
	Dec. 31, 2019
Retirement Benefits [Abstract]
Schedule Of Defined Benefit Plans, Change In Benefit Obligation And Fair Value Of Plan Assets	The following three tables provide a reconciliation of the changes in the plans’ projected benefit obligations and the fair value of assets during 2019 and 2018 , and a statement of the funded status at December 31, 2019 and 2018 : PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 3,339 $ 3,841 $ 868 $ 959 Service cost 110 124 17 21 Interest cost 139 140 36 36 Contributions from plan participants — — 21 23 Actuarial loss (gain) 445 (271 ) 45 (123 ) Plan amendments 5 12 — — Benefit payments (93 ) (113 ) (72 ) (74 ) Special termination benefits — — — 5 Acquisition — — — 21 Settlements (177 ) (394 ) (2 ) — Net obligation at December 31 3,768 3,339 913 868 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,160 2,659 1,108 1,209 Actual return on plan assets 496 (180 ) 218 (56 ) Employer contributions 276 188 8 6 Contributions from plan participants — — 21 23 Benefit payments (93 ) (113 ) (72 ) (74 ) Settlements (177 ) (394 ) (2 ) — Fair value of plan assets at December 31 2,662 2,160 1,281 1,108 Funded status at December 31 $ (1,106 ) $ (1,179 ) $ 368 $ 240 Net recorded (liability) asset at December 31 $ (1,106 ) $ (1,179 ) $ 368 $ 240 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 814 $ 971 $ 170 $ 185 Service cost 30 30 4 5 Interest cost 34 35 7 7 Contributions from plan participants — — 7 8 Actuarial loss (gain) 61 (63 ) 7 (17 ) Plan amendments 3 8 — — Benefit payments (18 ) (22 ) (18 ) (21 ) Special termination benefits — — — 3 Settlements (39 ) (145 ) — — Transfer of liability from other plans 10 — — — Net obligation at December 31 895 814 177 170 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 600 776 172 195 Actual return on plan assets 135 (56 ) 36 (12 ) Employer contributions 52 47 — 2 Contributions from plan participants — — 7 8 Benefit payments (18 ) (22 ) (18 ) (21 ) Settlements (39 ) (145 ) — — Transfer of assets from other plans 9 — — — Fair value of plan assets at December 31 739 600 197 172 Funded status at December 31 $ (156 ) $ (214 ) $ 20 $ 2 Net recorded (liability) asset at December 31 $ (156 ) $ (214 ) $ 20 $ 2 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,148 $ 2,486 $ 646 $ 737 Service cost 68 81 12 15 Interest cost 91 92 27 27 Contributions from plan participants — — 13 14 Actuarial loss (gain) 345 (215 ) 39 (100 ) Plan amendments 2 — — — Benefit payments (59 ) (65 ) (49 ) (49 ) Special termination benefits — — — 2 Settlements (65 ) (231 ) — — Transfer of liability to other plans (4 ) — — — Net obligation at December 31 2,526 2,148 688 646 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,385 1,694 916 993 Actual return on plan assets 320 (117 ) 178 (43 ) Employer contributions 152 104 1 1 Contributions from plan participants — — 13 14 Benefit payments (59 ) (65 ) (49 ) (49 ) Settlements (65 ) (231 ) — — Transfer of assets from other plans 4 — — — Fair value of plan assets at December 31 1,737 1,385 1,059 916 Funded status at December 31 $ (789 ) $ (763 ) $ 371 $ 270 Net recorded (liability) asset at December 31 $ (789 ) $ (763 ) $ 371 $ 270
Schedule Of Defined Benefit Plans, Amounts Recognized In Balance Sheet	The net (liability) asset is included in the following categories on the Consolidated Balance Sheets at December 31: PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 Sempra Energy Consolidated: Noncurrent assets $ — $ — $ 391 $ 272 Current liabilities (59 ) (62 ) (3 ) (6 ) Noncurrent liabilities (1,047 ) (1,117 ) (20 ) (26 ) Net recorded (liability) asset $ (1,106 ) $ (1,179 ) $ 368 $ 240 SDG&E: Noncurrent assets $ — $ — $ 20 $ 2 Current liabilities (3 ) (2 ) — — Noncurrent liabilities (153 ) (212 ) — — Net recorded (liability) asset $ (156 ) $ (214 ) $ 20 $ 2 SoCalGas: Noncurrent assets $ — $ — $ 371 $ 270 Current liabilities (4 ) (3 ) — — Noncurrent liabilities (785 ) (760 ) — — Net recorded (liability) asset $ (789 ) $ (763 ) $ 371 $ 270
Schedule Of Defined Benefit Plans, Amounts In Accumulated Other Comprehensive Income	Amounts recorded in AOCI at December 31, net of income tax effects and amounts recorded as regulatory assets, are as follows: AMOUNTS IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2019 2018 Sempra Energy Consolidated (1) : Net actuarial (loss) gain $ (113 ) $ (114 ) $ 10 $ 8 Prior service cost (14 ) (12 ) — — Total $ (127 ) $ (126 ) $ 10 $ 8 SDG&E: Net actuarial loss $ (9 ) $ (4 ) Prior service cost (7 ) (6 ) Total $ (16 ) $ (10 ) SoCalGas: Net actuarial loss $ (7 ) $ (6 ) Prior service cost (3 ) (2 ) Total $ (10 ) $ (8 )
Schedule Of Defined Benefit Plans, Pension Plans With Benefit Obligations In Excess Of Plan Assets	The following table shows the obligations of funded pension plans with benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED PENSION PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Projected benefit obligation $ 3,578 $ 3,130 Accumulated benefit obligation 3,229 2,894 Fair value of plan assets 2,662 2,160 SDG&E: Projected benefit obligation $ 861 $ 788 Accumulated benefit obligation 818 762 Fair value of plan assets 739 600 SoCalGas: Projected benefit obligation $ 2,505 $ 2,123 Accumulated benefit obligation 2,208 1,919 Fair value of plan assets 1,737 1,385 We also have unfunded pension plans at Sempra Energy, SDG&E, SoCalGas and IEnova. The following table shows the obligations of unfunded pension plans at December 31: OBLIGATIONS OF UNFUNDED PENSION PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Projected benefit obligation $ 190 $ 209 Accumulated benefit obligation 158 186 SDG&E: Projected benefit obligation $ 34 $ 26 Accumulated benefit obligation 27 19 SoCalGas: Projected benefit obligation $ 21 $ 25 Accumulated benefit obligation 17 21 Sempra Energy, SDG&E and SoCalGas each have a funded other postretirement benefit plan. The following table shows the obligations of funded other postretirement benefit plans with accumulated postretirement benefit obligations in excess of plan assets at December 31: OBLIGATIONS OF FUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 32 $ 30 Fair value of plan assets 25 20 We also have unfunded other postretirement benefit plans at Sempra Energy. The following table shows the obligations of unfunded other postretirement benefit plans at December 31: OBLIGATIONS OF UNFUNDED OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) 2019 2018 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 16 $ 22
Schedule of Net Periodic Costs and Amounts Recognized in OCI	The following tables provide the components of net periodic benefit cost and pretax amounts recognized in OCI for the years ended December 31: NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 NET PERIODIC BENEFIT COST Service cost $ 110 $ 124 $ 117 $ 17 $ 21 $ 21 Interest cost 139 140 150 36 36 39 Expected return on assets (144 ) (157 ) (161 ) (71 ) (70 ) (66 ) Amortization of: Prior service cost 12 11 11 — 1 1 Actuarial loss (gain) 36 22 35 (10 ) (6 ) (4 ) Settlement charges 28 66 38 — — — Special termination benefits — — — — 5 18 Net periodic benefit cost 181 206 190 (28 ) (13 ) 9 Regulatory adjustment 77 (30 ) (42 ) 29 17 — Total expense recognized 258 176 148 1 4 9 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1) Net loss (gain) 17 56 — (3 ) (4 ) (2 ) Prior service cost 5 12 1 — — — Amortization of actuarial loss (13 ) (12 ) (10 ) — — — Amortization of prior service cost (3 ) (2 ) (1 ) — — — Settlements (28 ) (12 ) (8 ) — — — Total recognized in OCI (22 ) 42 (18 ) (3 ) (4 ) (2 ) Total recognized in net periodic benefit cost and OCI $ 236 $ 218 $ 130 $ (2 ) $ — $ 7 (1) Includes discontinued operations. NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 NET PERIODIC BENEFIT COST Service cost $ 30 $ 30 $ 29 $ 4 $ 5 $ 5 Interest cost 34 35 38 7 7 8 Expected return on assets (38 ) (47 ) (47 ) (11 ) (13 ) (11 ) Amortization of: Prior service cost 3 2 1 2 3 3 Actuarial loss (gain) 11 1 9 (2 ) (3 ) — Settlement charges — 26 — — — — Special termination benefits — — — — 3 — Net periodic benefit cost 40 47 30 — 2 5 Regulatory adjustment 14 (8 ) (8 ) — — — Total expense recognized 54 39 22 — 2 5 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 5 (1 ) 2 — — — Prior service cost 2 8 — — — — Amortization of actuarial loss — (1 ) (1 ) — — — Amortization of prior service cost (1 ) — — — — — Settlements — (4 ) — — — — Total recognized in OCI 6 2 1 — — — Total recognized in net periodic benefit cost and OCI $ 60 $ 41 $ 23 $ — $ 2 $ 5 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 NET PERIODIC BENEFIT COST Service cost $ 68 $ 81 $ 76 $ 12 $ 15 $ 14 Interest cost 91 92 98 27 27 29 Expected return on assets (94 ) (98 ) (103 ) (58 ) (56 ) (53 ) Amortization of: Prior service cost (credit) 8 8 9 (2 ) (3 ) (3 ) Actuarial loss (gain) 16 13 19 (8 ) (2 ) (3 ) Settlement charges — 32 30 — — — Special termination benefits — — — — 2 18 Net periodic benefit cost 89 128 129 (29 ) (17 ) 2 Regulatory adjustment 63 (22 ) (34 ) 29 17 — Total expense recognized 152 106 95 — — 2 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 2 1 — — — — Prior service cost 3 — — — — — Transfer of actuarial loss (4 ) — — — — — Transfer of prior service cost (1 ) — — — — — Amortization of actuarial loss (1 ) — — — — — Amortization of prior service cost — (1 ) (1 ) — — — Total recognized in OCI (1 ) — (1 ) — — — Total recognized in net periodic benefit cost and OCI $ 151 $ 106 $ 94 $ — $ — $ 2
Schedule of Assumptions Used	The significant assumptions affecting benefit obligation and net periodic benefit cost are as follows: WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION AT DECEMBER 31 Pension benefits Other postretirement benefits 2019 2018 2019 2018 Sempra Energy Consolidated: Discount rate 3.49 % 4.29 % 3.54 % 4.29 % Interest crediting rate (1)(2) 2.28 3.36 2.28 3.36 Rate of compensation increase 2.70-10.00 2.00-10.00 2.70-10.00 2.00-10.00 SDG&E: Discount rate 3.44 % 4.29 % 3.55 % 4.30 % Interest crediting rate (1)(2) 2.28 3.36 2.28 3.36 Rate of compensation increase 2.70-10.00 2.00-10.00 2.70-10.00 2.00-10.00 SoCalGas: Discount rate 3.50 % 4.30 % 3.55 % 4.30 % Interest crediting rate (1)(2) 2.28 3.36 2.28 3.36 Rate of compensation increase 2.70-10.00 2.00-10.00 2.70-10.00 2.00-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST YEARS ENDED DECEMBER 31 Pension benefits Other postretirement benefits 2019 2018 2017 2019 2018 2017 Sempra Energy Consolidated: Discount rate 4.29 % 3.64 % 4.07 % 4.29 % 3.68 % 4.18 % Expected return on plan assets 7.00 7.00 7.00 6.48 6.49 6.47 Interest crediting rate (1)(2) 3.36 2.80 2.86 3.36 2.80 2.86 Rate of compensation increase 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 SDG&E: Discount rate 4.29 % 3.64 % 4.08 % 4.30 % 3.65 % 4.15 % Expected return on plan assets 7.00 7.00 7.00 6.92 6.94 6.91 Interest crediting rate (1)(2) 3.36 2.80 2.86 3.36 2.80 2.86 Rate of compensation increase 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 SoCalGas: Discount rate 4.30 % 3.65 % 4.10 % 4.30 % 3.70 % 4.20 % Expected return on plan assets 7.00 7.00 7.00 6.38 6.38 6.37 Interest crediting rate (1)(2) 3.36 2.80 2.86 3.36 2.80 2.86 Rate of compensation increase 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 2.00-10.00 (1) Interest crediting rate for pension benefits applies only to funded cash balance plans. (2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas. ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans Pre-65 retirees Retirees aged 65 years and older 2019 2018 2017 2019 2018 2017 Health care cost trend rate assumed for next year 6.25 % 6.50 % 7.00 % 4.75 % 4.75 % 5.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 5.00 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2022 2022 2022 2022
Schedule of Health Care Cost Trend Rates	Assumed health care cost trend rates have a significant effect on the amounts that we report for the health care plan costs. Following are the health care cost trend rates applicable to our postretirement benefit plans: ASSUMED HEALTH CARE COST TREND RATES AT DECEMBER 31 Other postretirement benefit plans Pre-65 retirees Retirees aged 65 years and older 2019 2018 2017 2019 2018 2017 Health care cost trend rate assumed for next year 6.25 % 6.50 % 7.00 % 4.75 % 4.75 % 5.00 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 5.00 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2022 2022 2022 2022
Schedule Of Defined Benefit Plans, Fair Value Of Plan Assets By Level In Fair Value Hierarchy	The fair values of our pension plan assets by asset category are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Total Sempra Energy Consolidated: Cash and cash equivalents $ 17 $ — $ 17 Equity securities: Domestic 923 — 923 International 555 1 556 Registered investment companies 96 — 96 Fixed income securities: Domestic government bonds 228 39 267 International government bonds — 9 9 Domestic corporate bonds — 346 346 International corporate bonds — 62 62 Registered investment companies — 2 2 Total investment assets in the fair value hierarchy $ 1,819 $ 459 2,278 Accounts receivable/payable, net (38 ) Investments measured at NAV: Common/collective trusts 417 Private equity funds 5 Total investment assets $ 2,662 SDG&E’s proportionate share of investment assets $ 739 SoCalGas’ proportionate share of investment assets $ 1,737 Fair value at December 31, 2018 Level 1 Level 2 Total Sempra Energy Consolidated: Cash and cash equivalents $ 14 $ — $ 14 Equity securities: Domestic 727 — 727 International 437 — 437 Registered investment companies 74 — 74 Fixed income securities: Domestic government bonds 197 29 226 International government bonds — 8 8 Domestic corporate bonds — 311 311 International corporate bonds — 53 53 Registered investment companies — 1 1 Total investment assets in the fair value hierarchy $ 1,449 $ 402 1,851 Accounts receivable/payable, net (21 ) Investments measured at NAV: Common/collective trusts 326 Private equity funds 4 Total investment assets $ 2,160 SDG&E’s proportionate share of investment assets $ 600 SoCalGas’ proportionate share of investment assets $ 1,385 The fair values by asset category of the PBOP plan assets held in the pension master trust and in the additional trusts for SoCalGas’ PBOP plans and SDG&E’s PBOP plan trusts are as follows: FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Total SDG&E: Equity securities: Domestic $ 21 $ — $ 21 International 13 — 13 Registered investment companies 68 — 68 Fixed income securities: Domestic government bonds 32 1 33 Domestic corporate bonds — 8 8 International corporate bonds — 1 1 Registered investment companies — 8 8 Total investment assets in the fair value hierarchy 134 18 152 Accounts receivable/payable, net (2 ) Investments measured at NAV – Common/collective trusts 47 Total investment assets 197 SoCalGas: Cash and cash equivalents 3 — 3 Equity securities: Domestic 78 — 78 International 48 — 48 Registered investment companies 52 — 52 Fixed income securities: Domestic government bonds 267 21 288 International government bonds 1 10 11 Domestic corporate bonds — 309 309 International corporate bonds — 40 40 Registered investment companies — 75 75 Derivative financial instruments 3 — 3 Total investment assets in the fair value hierarchy 452 455 907 Accounts receivable/payable, net (5 ) Investments measured at NAV – Common/collective trusts 157 Total investment assets 1,059 Other Sempra Energy: Equity securities: Domestic 9 — 9 International 4 — 4 Fixed income securities: Domestic government bonds 3 1 4 Domestic corporate bonds — 3 3 International corporate bonds — 1 1 Total investment assets in the fair value hierarchy 16 5 21 Investments measured at NAV – Common/collective trusts 4 Total other Sempra Energy investment assets 25 Total Sempra Energy Consolidated investment assets in the fair value hierarchy $ 602 $ 478 Total Sempra Energy Consolidated investment assets $ 1,281 FAIR VALUE MEASUREMENTS – INVESTMENT ASSETS OF OTHER POSTRETIREMENT BENEFIT PLANS (Dollars in millions) Fair value at December 31, 2018 Level 1 Level 2 Total SDG&E: Cash and cash equivalents $ 1 $ — $ 1 Equity securities: Domestic 37 — 37 International 22 — 22 Registered investment companies 59 — 59 Fixed income securities: Domestic government bonds 10 1 11 Domestic corporate bonds — 16 16 International corporate bonds — 3 3 Registered investment companies — 7 7 Total investment assets in the fair value hierarchy 129 27 156 Accounts receivable/payable, net (1 ) Investments measured at NAV – Common/collective trusts 17 Total investment assets 172 SoCalGas: Cash and cash equivalents 6 — 6 Equity securities: Domestic 66 — 66 International 39 — 39 Registered investment companies 62 — 62 Fixed income securities: Domestic government bonds 236 13 249 International government bonds 1 4 5 Domestic corporate bonds — 175 175 International corporate bonds — 21 21 Registered investment companies — 64 64 Derivative financial instruments (4 ) — (4 ) Total investment assets in the fair value hierarchy 406 277 683 Accounts receivable/payable, net (4 ) Investments measured at NAV – Common/collective trusts 237 Total investment assets 916 Other Sempra Energy: Equity securities: Domestic 6 — 6 International 4 — 4 Fixed income securities: Domestic government bonds 2 — 2 Domestic corporate bonds — 2 2 Registered investment companies — 1 1 Total investment assets in the fair value hierarchy 12 3 15 Investments measured at NAV – Common/collective trusts 4 Private equity funds 1 Total other Sempra Energy investment assets 20 Total Sempra Energy Consolidated investment assets in the fair value hierarchy $ 547 $ 307 Total Sempra Energy Consolidated investment assets $ 1,108
Schedule Of Defined Benefit Plans, Estimated Future Employer Contributions In Next Fiscal Year	We expect to contribute the following amounts to our pension and PBOP plans in 2020 : EXPECTED CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Pension plans $ 268 $ 53 $ 154 Other postretirement benefit plans 7 1 1
Schedule of Expected Benefit Payments	The following table shows the total benefits we expect to pay for the next 10 years to current employees and retirees from the plans or from company assets. EXPECTED BENEFIT PAYMENTS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Pension benefits Other postretirement benefits Pension benefits Other postretirement benefits Pension benefits Other postretirement benefits 2020 $ 410 $ 50 $ 115 $ 10 $ 229 $ 35 2021 263 48 69 10 166 35 2022 258 48 64 10 162 35 2023 243 48 64 10 156 35 2024 239 48 62 10 153 35 2025-2029 1,128 240 283 48 725 176
Schedule Of Defined Benefit Plans Contributions	Employer contributions to the savings plans were as follows: EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS (Dollars in millions) 2019 2018 2017 Sempra Energy Consolidated $ 44 $ 43 $ 41 SDG&E 15 15 14 SoCalGas 24 23 22

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2019
Share-based Payment Arrangement, Noncash Expense [Abstract]
Schedule Of Share-based Compensation Expense	Total share-based compensation expense for all of Sempra Energy’s share-based awards was comprised as follows: SHARE-BASED COMPENSATION EXPENSE (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated: Share-based compensation expense, before income taxes (1) $ 66 $ 76 $ 78 Income tax benefit (1) (18 ) (21 ) (31 ) $ 48 $ 55 $ 47 Capitalized share-based compensation cost $ 11 $ 10 $ 9 Excess income tax deficiency $ 4 $ 15 $ — SDG&E: Share-based compensation expense, before income taxes $ 10 $ 12 $ 13 Income tax benefit (3 ) (3 ) (5 ) $ 7 $ 9 $ 8 Capitalized share-based compensation cost $ 6 $ 6 $ 5 Excess income tax deficiency $ 1 $ 3 $ — SoCalGas: Share-based compensation expense, before income taxes $ 15 $ 16 $ 17 Income tax benefit (4 ) (5 ) (7 ) $ 11 $ 11 $ 10 Capitalized share-based compensation cost $ 5 $ 4 $ 4 Excess income tax deficiency $ 1 $ 2 $ — (1) Includes activity of awards issued from the IEnova 2013 LTIP, which settle in cash upon vesting based on the price of IEnova’s common stock.
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	To calculate this fair value, we used the Black-Scholes model with the following weighted-average assumptions: KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Year ended December 31, 2019 Stock price volatility 18.63 % Expected term 5.34 years Risk-free rate of return 2.49 % Annual dividend yield 3.35 %
Schedule Of Non-qualified Stock Options	The following table shows a summary of nonqualified stock options at December 31, 2019 and activity for the year then ended: NONQUALIFIED STOCK OPTIONS Common shares under options Weighted- average exercise price Weighted- average remaining contractual term (in years) Aggregate intrinsic value (in millions) Outstanding at January 1, 2019 56,940 $ 54.63 Granted 261,075 $ 106.76 Exercised (52,540 ) $ 54.52 Forfeited/canceled (17,898 ) $ 106.76 Outstanding at December 31, 2019 247,577 $ 105.86 8.85 $ 11 Vested or expected to vest at December 31, 2019 237,236 $ 105.82 8.84 $ 11 Exercisable at December 31, 2019 4,400 $ 55.90 0.01 $ —
Schedule Of Restricted Stock Awards And Units Valuation Assumptions	Below are key assumptions for RSUs granted in the last three years: KEY ASSUMPTIONS FOR RSUs GRANTED Years ended December 31, 2019 2018 2017 Stock price volatility 17.74 % 17.46 % 17.24 % Risk-free rate of return 2.46 % 2.00 % 1.49 %
Schedule Of Restricted Stock Units	The following table shows a summary of RSUs at December 31, 2019 and activity for the year then ended: RESTRICTED STOCK UNITS Performance-based restricted stock units Service-based restricted stock units Units Weighted- average grant-date fair value Units Weighted- average grant-date fair value Nonvested at January 1, 2019 1,242,169 $ 106.11 402,361 $ 105.01 Granted 389,825 $ 113.54 260,594 $ 112.50 Vested (142,820 ) $ 100.28 (209,395 ) $ 102.68 Forfeited (402,193 ) $ 103.34 (37,773 ) $ 110.25 Nonvested at December 31, 2019 (1) 1,086,981 $ 109.85 415,787 $ 119.96 Expected to vest at December 31, 2019 1,066,375 $ 109.89 408,782 $ 109.65 (1) Each RSU represents the right to receive one share of our common stock if applicable performance conditions are satisfied. For all performance-based RSUs, up to an additional 100% of the shares represented by the RSUs may be issued if Sempra Energy exceeds target performance conditions.

DERIVATIVE FINANCIAL INSTRUME_2

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)	12 Months Ended
	Dec. 31, 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) December 31, Commodity Unit of measure 2019 2018 Sempra Energy Consolidated: Natural gas MMBtu 32 35 Electricity MWh 2 2 Congestion revenue rights MWh 48 52 SDG&E: Natural gas MMBtu 37 33 Electricity MWh 2 2 Congestion revenue rights MWh 48 52 SoCalGas: Natural gas MMBtu 2 —
Notional Amounts Of Interest Rate Derivatives Table	The following table presents the net notional amounts of our interest rate derivatives, excluding JVs. INTEREST RATE DERIVATIVES (Dollars in millions) December 31, 2019 December 31, 2018 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges (1) $ 1,445 2020-2034 $ 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. The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) December 31, 2019 December 31, 2018 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 306 2020-2023 $ 306 2019-2023 Other foreign currency derivatives 1,796 2020-2021 1,158 2019-2020
Derivative Instruments on the Consolidated Balance Sheet Table	DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2019 Other current assets (1) Other long-term assets Other current liabilities Deferred credits and other Sempra Energy Consolidated: Derivatives designated as hedging instruments: Interest rate and foreign exchange instruments $ — $ 3 $ (17 ) $ (140 ) Derivatives not designated as hedging instruments: Foreign exchange instruments 41 — (20 ) — Associated offsetting foreign exchange instruments (20 ) — 20 — Commodity contracts not subject to rate recovery 34 11 (41 ) (10 ) Associated offsetting commodity contracts (32 ) (2 ) 32 2 Commodity contracts subject to rate recovery 41 76 (47 ) (47 ) Associated offsetting commodity contracts (6 ) (3 ) 6 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 58 85 (53 ) (192 ) Additional cash collateral for commodity contracts not subject to rate recovery 43 — — — Additional cash collateral for commodity contracts subject to rate recovery 25 — — — Total (2) $ 126 $ 85 $ (53 ) $ (192 ) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 30 $ 76 $ (41 ) $ (47 ) Associated offsetting commodity contracts (4 ) (3 ) 4 3 Associated offsetting cash collateral — — 14 — Net amounts presented on the balance sheet 26 73 (23 ) (44 ) Additional cash collateral for commodity contracts subject to rate recovery 16 — — — Total (2) $ 42 $ 73 $ (23 ) $ (44 ) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 11 $ — $ (6 ) $ — Associated offsetting commodity contracts (2 ) — 2 — Net amounts presented on the balance sheet 9 — (4 ) — Additional cash collateral for commodity contracts subject to rate recovery 9 — — — Total $ 18 $ — $ (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 CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2018 Other current (1) Other long-term assets Other current 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 Consolidated Statements Of Operations Table	The table below includes the effects of derivative instruments designated as cash flow hedges on the 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 Years ended December 31, Years ended December 31, 2019 2018 2017 Location 2019 2018 2017 Sempra Energy Consolidated: Interest rate and foreign exchange instruments (1) $ (5 ) $ 31 $ 19 Interest Expense (1) $ (3 ) $ — $ 4 Other Income, Net 9 2 — Interest rate instruments — — — Gain on Sale of Assets (10 ) (9 ) — Interest rate and foreign exchange instruments (174 ) 41 (34 ) Equity Earnings (5 ) (7 ) (20 ) Foreign exchange instruments (8 ) (4 ) 4 Revenues: Energy- Related Businesses (2 ) 1 2 Commodity contracts not subject to rate recovery — — 3 Revenues: Energy- Related Businesses — — (9 ) Total $ (187 ) $ 68 $ (8 ) $ (11 ) $ (13 ) $ (23 ) SDG&E: Interest rate instruments (1) $ (1 ) $ 1 $ (2 ) Interest Expense (1) $ (3 ) $ (7 ) $ (13 ) SoCalGas: Interest rate instruments $ — $ — $ — Interest Expense $ (1 ) $ (1 ) $ — (1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. On August 14, 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps.
Undesignated Derivative Impact on the Consolidated Statements of Operations	The following table summarizes the effects of derivative instruments not designated as hedging instruments on the Consolidated Statements of Operations. UNDESIGNATED DERIVATIVE IMPACTS (Dollars in millions) Pretax gain (loss) on derivatives recognized in earnings Years ended December 31, Location 2019 2018 2017 Sempra Energy Consolidated: Foreign exchange instruments Other Income, Net $ 25 $ 3 $ 49 Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses 12 26 16 Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power (140 ) 279 54 Commodity contracts subject to rate recovery Cost of Natural Gas 3 5 (2 ) Total $ (100 ) $ 313 $ 117 SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ (140 ) $ 279 $ 54 SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ 3 $ 5 $ (2 )

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 503 $ 6 $ — $ 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 549 525 — 1,074 Interest rate and foreign exchange instruments — 24 — 24 Commodity contracts not subject to rate recovery — 11 — 11 Effect of netting and allocation of collateral (2) 43 — — 43 Commodity contracts subject to rate recovery 5 8 95 108 Effect of netting and allocation of collateral (2) 11 8 6 25 Total $ 608 $ 576 $ 101 $ 1,285 Liabilities: Interest rate and foreign exchange instruments $ — $ 157 $ — $ 157 Commodity contracts not subject to rate recovery — 17 — 17 Commodity contracts subject to rate recovery 14 4 67 85 Effect of netting and allocation of collateral (2) (14 ) — — (14 ) Total $ — $ 178 $ 67 $ 245 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 balances and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SDG&E (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 503 $ 6 $ — $ 509 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 46 11 — 57 Municipal bonds — 282 — 282 Other securities — 226 — 226 Total debt securities 46 519 — 565 Total nuclear decommissioning trusts (1) 549 525 — 1,074 Commodity contracts subject to rate recovery 1 3 95 99 Effect of netting and allocation of collateral (2) 10 — 6 16 Total $ 560 $ 528 $ 101 $ 1,189 Liabilities: Commodity contracts subject to rate recovery 14 — 67 81 Effect of netting and allocation of collateral (2) (14 ) — — (14 ) Total $ — $ — $ 67 $ 67 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 balances and cash equivalents. (2) Includes the effect of the contractual ability to settle contracts under master netting agreements and with cash collateral, as well as cash collateral not offset. RECURRING FAIR VALUE MEASURES – SOCALGAS (Dollars in millions) Fair value at December 31, 2019 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 4 $ 5 $ — $ 9 Effect of netting and allocation of collateral (1) 1 8 — 9 Total $ 5 $ 13 $ — $ 18 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) Years ended December 31, 2019 2018 2017 Balance at January 1 $ 179 $ (28 ) $ (74 ) Realized and unrealized gains (losses) (184 ) 209 34 Allocated transmission instruments 6 10 6 Settlements 27 (12 ) 6 Balance at December 31 $ 28 $ 179 $ (28 ) Change in unrealized gains (losses) relating to instruments still held at December 31 $ (139 ) $ 183 $ 30 (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements.
Schedule of Auction Price 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 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2019 $ 21.00 to $ 61.15 $ 37.92 2018 22.20 to 76.85 42.69 CONGESTION REVENUE RIGHTS AUCTION PRICE INPUTS Settlement year Price per MWh Median price per MWh 2020 $ (3.77 ) to $ 6.03 $ (1.58 ) 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 Consolidated Balance Sheets. FAIR VALUE OF FINANCIAL INSTRUMENTS (Dollars in millions) December 31, 2019 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates $ 742 $ — $ 759 $ — $ 759 Long-term amounts due to unconsolidated affiliates 195 — 184 — 184 Total long-term debt (1) 21,247 — 22,638 26 22,664 SDG&E: Total long-term debt (2) $ 5,140 $ — $ 5,662 $ — $ 5,662 SoCalGas: Total long-term debt (3) $ 3,809 $ — $ 4,189 $ — $ 4,189 December 31, 2018 Carrying Fair value amount 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 $225 million and excluding finance lease obligations of $1,289 million . (2) Before reductions of unamortized discount and debt issuance costs of $48 million and excluding finance lease obligations of $1,270 million . (3) Before reductions of unamortized discount and debt issuance costs of $34 million and excluding finance lease obligations of $19 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 arrangement 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 .
Fair Value Measurements, Nonrecurring Table	The table below summarizes significant inputs impacting our non-recurring fair value measures. Additional discussions about the related transactions are provided in Note 5 , and as applicable, in Note 6 . NON-RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED Measurement date Estimated fair value (in millions) Valuation technique Fair value hierarchy % of fair value measurement Inputs used to Range of Non-utility natural gas storage assets December 31, 2018 $ 337 Market approach Level 2 100% Assets’ sales prices 100% Non-utility natural gas storage assets June 25, 2018 $ 190 Discounted cash flows Level 3 100% Storage rates $0.06 - $0.22 ($0.10) (1) Discount rate 10% (2) Certain of our U.S. wind equity method investments June 25, 2018 $ 145 Discounted cash flows Level 3 100% Contracted and observable merchant prices per MWh $29 - $92 (1) Discount rate 8% - 10% (8.7%) (2) TdM June 30, 2017 $ 62 Market approach Level 2 100% Purchase price offer 100% (1) Generally, significant increases (decreases) in this input in isolation would result in a significantly higher (lower) fair value measurement. (2) An increase in the discount rate would result in a decrease in fair value.

PREFERRED STOCK (Tables)

PREFERRED STOCK (Tables)	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Schedule Of Preferred Stock	The following table illustrates the conversion rate per share of each series of preferred stock, subject to certain anti-dilution adjustments. CONVERSION RATES Applicable market value per share of Conversion rate (number of shares of our common stock to be received upon conversion of each share of mandatory convertible preferred stock) Series A preferred stock Greater than $131.075 (which is the threshold appreciation price) 0.7629 shares (approximately equal to $100.00 divided by the threshold appreciation price) Equal to or less than $131.075 but greater than or equal to $107.00 Between 0.7629 and 0.9345 shares, determined by dividing $100.00 by the applicable market value of our common stock Less than $107.00 (which is the initial price) 0.9345 shares (approximately equal to $100.00 divided by the initial price) Series B preferred stock Greater than $136.50 (which is the threshold appreciation price) 0.7326 shares (approximately equal to $100.00 divided by the threshold appreciation price) Equal to or less than $136.50 but greater than or equal to $113.75 Between 0.7326 and 0.8791 shares, determined by dividing $100.00 by the applicable market value of our common stock Less than $113.75 (which is the initial price) 0.8791 shares (approximately equal to $100.00 divided by the initial price) PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2019 2018 $25 par value, authorized 1,000,000 shares: 6% Series, 79,011 shares outstanding $ 3 $ 3 6% Series A, 783,032 shares outstanding 19 19 SoCalGas - Total preferred stock 22 22 Less: 50,970 shares of the 6% Series outstanding owned by Pacific Enterprises (2 ) (2 ) Sempra Energy - Total preferred stock of subsidiary $ 20 $ 20

SEMPRA ENERGY - SHAREHOLDERS'_2

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE (Tables)	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
Schedule Of Earnings Per Share Computations	EARNINGS (LOSSES) PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2019 2018 2017 Numerator for continuing operations: Income from continuing operations, net of income tax $ 1,999 $ 938 $ 382 Earnings attributable to noncontrolling interests (129 ) (44 ) (67 ) Mandatory convertible preferred stock dividends (142 ) (125 ) — Preferred dividends of subsidiary (1 ) (1 ) (1 ) Earnings from continuing operations attributable to common shares $ 1,727 $ 768 $ 314 Numerator for discontinued operations: Income (loss) from discontinued operations, net of income tax $ 363 $ 188 $ (31 ) Earnings attributable to noncontrolling interests (35 ) (32 ) (27 ) Earnings (losses) from discontinued operations attributable to common shares $ 328 $ 156 $ (58 ) Numerator for earnings: Earnings attributable to common shares $ 2,055 $ 924 $ 256 Denominator: Weighted-average common shares outstanding for basic EPS (1) 277,904 268,072 251,545 Dilutive effect of stock options and RSUs (2) 1,585 919 755 Dilutive effect of common shares sold forward 2,544 861 — Weighted-average common shares outstanding for diluted EPS 282,033 269,852 252,300 Basic EPS: Earnings from continuing operations $ 6.22 $ 2.86 $ 1.25 Earnings (losses) from discontinued operations $ 1.18 $ 0.59 $ (0.23 ) Earnings $ 7.40 $ 3.45 $ 1.02 Diluted EPS: Earnings from continuing operations $ 6.13 $ 2.84 $ 1.24 Earnings (losses) from discontinued operations $ 1.16 $ 0.58 $ (0.23 ) Earnings $ 7.29 $ 3.42 $ 1.01 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 617 in 2019, 641 in 2018 and 609 in 2017. 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. (2) 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, dilutive RSUs may vary widely from period-to-period.
Schedule Of Common Stock Activity	The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY Years ended December 31, 2019 2018 2017 Common shares outstanding, January 1 273,769,513 251,358,977 250,152,514 Shares issued under forward sale agreements 16,906,185 21,175,473 — RSUs vesting (1) 463,012 509,042 362,022 Stock options exercised 52,540 138,861 164,454 Savings plan issuance 475,774 553,036 567,428 Common stock investment plan (2) 199,253 231,242 254,047 Issuance of RSUs held in our Deferred Compensation Plan 59,470 3,357 7,811 Shares repurchased (3) (212,822 ) (200,475 ) (149,299 ) Common shares outstanding, December 31 291,712,925 273,769,513 251,358,977 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares. (3) Generally, we purchase shares of our common stock or units from LTIP participants who elect to sell to us a sufficient number of vested RSUs to meet minimum statutory tax withholding requirements.

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	12 Months Ended
	Dec. 31, 2019
Regulated Operations [Abstract]
Schedule of Nuclear Decommissioning Trusts	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 12 . NUCLEAR DECOMMISSIONING TRUSTS (Dollars in millions) Cost Gross unrealized gains Gross unrealized losses Estimated fair value At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 57 $ — $ — $ 57 Municipal bonds (2) 270 12 — 282 Other securities (3) 218 9 (1 ) 226 Total debt securities 545 21 (1 ) 565 Equity securities 176 339 (6 ) 509 Cash and cash equivalents 8 — — 8 Total $ 729 $ 360 $ (7 ) $ 1,082 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 2020 - 2072 .
Schedule of Securities Sold	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) Years ended December 31, 2019 2018 2017 Proceeds from sales $ 914 $ 890 $ 1,314 Gross realized gains 24 42 157 Gross realized losses (5 ) (10 ) (14 )

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 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 CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2019 Sempra Energy Consolidated SDG&E SoCalGas Right-of-use assets: Operating leases: Right-of-use assets $ 591 $ 130 $ 94 Finance leases: Property, plant and equipment 1,353 1,326 27 Accumulated depreciation (64 ) (57 ) (7 ) Property, plant and equipment, net 1,289 1,269 20 Total right-of-use assets $ 1,880 $ 1,399 $ 114 Lease liabilities: Operating leases: Other current liabilities $ 52 $ 27 $ 18 Deferred credits and other 445 102 75 497 129 93 Finance leases: Current portion of long-term debt and finance leases 26 20 6 Long-term debt and finance leases 1,263 1,250 13 1,289 1,270 19 Total lease liabilities $ 1,786 $ 1,399 $ 112 Weighted-average remaining lease term (in years): Operating leases 13 6 6 Finance leases 19 20 6 Weighted-average discount rate: Operating leases 6.01 % 3.55 % 3.73 % Finance leases 14.76 % 14.83 % 3.23 %
Lease, Cost	The components of lease costs were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (1) (Dollars in millions) Year ended December 31, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating lease costs $ 96 $ 33 $ 27 Finance lease costs: Amortization of ROU assets 24 18 6 Interest on lease liabilities 173 173 — Total finance lease costs 197 191 6 Short-term lease costs (2) 6 2 — Variable lease costs (2) 482 471 10 Total lease costs $ 781 $ 697 $ 43 (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 Cash Flow, Supplemental Disclosures	Cash paid for amounts included in the measurement of lease liabilities was as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF CASH FLOWS (Dollars in millions) Year ended December 31, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating activities: Cash paid for operating leases $ 101 $ 33 $ 27 Cash paid for finance leases 173 173 — Financing activities: Cash paid for finance leases 24 18 6 Increase in operating lease obligations for right-of-use assets 585 158 118 Increase in finance lease obligations for investment in PP&E 38 16 22
Lessee, Operating Lease, Liability, Maturity	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) December 31, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating leases Finance leases Operating leases Finance leases Operating leases Finance leases 2020 $ 75 $ 198 $ 30 $ 192 $ 22 $ 6 2021 75 193 32 190 20 3 2022 63 192 22 190 18 2 2023 54 192 17 190 13 2 2024 50 187 15 185 12 2 Thereafter 452 2,629 28 2,624 19 5 Total undiscounted lease payments 769 3,591 144 3,571 104 20 Less: imputed interest (272 ) (2,302 ) (15 ) (2,301 ) (11 ) (1 ) Total lease liabilities 497 1,289 129 1,270 93 19 Less: current lease liabilities (52 ) (26 ) (27 ) (20 ) (18 ) (6 ) Long-term lease liabilities $ 445 $ 1,263 $ 102 $ 1,250 $ 75 $ 13
Finance Lease, Liability, Maturity	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) December 31, 2019 Sempra Energy Consolidated SDG&E SoCalGas Operating leases Finance leases Operating leases Finance leases Operating leases Finance leases 2020 $ 75 $ 198 $ 30 $ 192 $ 22 $ 6 2021 75 193 32 190 20 3 2022 63 192 22 190 18 2 2023 54 192 17 190 13 2 2024 50 187 15 185 12 2 Thereafter 452 2,629 28 2,624 19 5 Total undiscounted lease payments 769 3,591 144 3,571 104 20 Less: imputed interest (272 ) (2,302 ) (15 ) (2,301 ) (11 ) (1 ) Total lease liabilities 497 1,289 129 1,270 93 19 Less: current lease liabilities (52 ) (26 ) (27 ) (20 ) (18 ) (6 ) Long-term lease liabilities $ 445 $ 1,263 $ 102 $ 1,250 $ 75 $ 13
Schedule of Rent Expense	Rent expense for operating leases was as follows: RENT EXPENSE – OPERATING LEASES (Dollars in millions) Years ended December 31, 2018 2017 Sempra Energy Consolidated $ 122 $ 107 SDG&E 27 28 SoCalGas 41 43
Schedule Of Operating Leases Future Minimum Payments Due	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 arrangement 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
Lessor, Operating Lease, Payments to be Received, Maturity	We provide information below for leases for which we are the lessor. LESSOR INFORMATION – SEMPRA ENERGY (Dollars in millions) December 31, 2019 2018 Assets subject to operating leases: Assets held for sale $ — $ 172 Property, plant and equipment (1) 1,038 1,022 Accumulated depreciation (179 ) (142 ) Property, plant and equipment, net $ 859 $ 880 December 31, 2019 Maturity analysis of operating lease payments: 2020 $ 201 2021 193 2022 193 2023 193 2024 193 Thereafter 2,402 Total undiscounted cash flows $ 3,375 (1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.
Operating Lease, Lease Income	LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA ENERGY (Dollars in millions) Years ended December 31, 2019 2018 2017 Fixed lease payments $ 200 $ 194 $ 193 Variable lease payments 6 72 44 Total revenues from operating leases (1) $ 206 $ 266 $ 237 Depreciation expense $ 38 $ 72 $ 57 (1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.
Schedule Of Estimated Future Payments Under Natural Gas Contracts	At December 31, 2019 , the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts are as follows: FUTURE MINIMUM PAYMENTS – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Storage and transportation Natural gas (1) Total (1) 2020 $ 169 $ 23 $ 192 2021 161 15 176 2022 76 11 87 2023 54 11 65 2024 43 12 55 Thereafter 297 7 304 Total minimum payments $ 800 $ 79 $ 879 (1) Excludes amounts related to the LNG purchase agreement discussed below. FUTURE MINIMUM PAYMENTS – SOCALGAS (Dollars in millions) Transportation Natural gas Total 2020 $ 122 $ 2 $ 124 2021 117 1 118 2022 36 — 36 2023 23 — 23 2024 13 — 13 Thereafter 35 — 35 Total minimum payments $ 346 $ 3 $ 349
Schedule Of Payments Under Natural Gas Contracts	Total payments under natural gas contracts and natural gas storage and transportation contracts as well as payments to meet additional portfolio needs at Sempra Energy Consolidated and SoCalGas were as follows: PAYMENTS UNDER NATURAL GAS CONTRACTS (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated $ 1,326 $ 1,345 $ 1,429 SoCalGas 1,181 1,169 1,213
Schedule Of L N G Commitment Amounts	At December 31, 2019 , the following LNG commitment amounts are based on the assumption that all cargoes, less those already confirmed to be diverted, under the agreement are delivered: LNG COMMITMENT AMOUNTS (Dollars in millions) 2020 $ 265 2021 368 2022 370 2023 374 2024 387 Thereafter 1,842 Total $ 3,606
Schedule Of Estimated Future Payments Under Purchased Power Contracts	At December 31, 2019 , the future minimum payments under long-term purchased-power contracts for Sempra Energy Consolidated and SDG&E are as follows: FUTURE MINIMUM PAYMENTS – PURCHASED-POWER CONTRACTS (Dollars in millions) 2020 $ 233 2021 229 2022 233 2023 194 2024 166 Thereafter 904 Total minimum payments (1) $ 1,959 (1) Excludes purchase agreements accounted for as finance leases.
Schedule Of Environmental Remediation Costs Capitalized In Period	The following table shows our capital expenditures (including construction work in progress) in order to comply with environmental laws and regulations: CAPITAL EXPENDITURES FOR ENVIRONMENTAL ISSUES (Dollars in millions) Years ended December 31, 2019 2018 2017 Sempra Energy Consolidated $ 80 $ 100 $ 91 SDG&E 39 38 46 SoCalGas 41 62 45
Schedule Of Environmental Remediation Costs, Status Of Remediation Sites	The table below shows the status at December 31, 2019 of the California Utilities’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP: STATUS OF ENVIRONMENTAL SITES # Sites complete (1) # Sites in process SDG&E: Manufactured-gas sites 3 — Third-party waste-disposal sites 2 1 SoCalGas: Manufactured-gas sites 39 3 Third-party waste-disposal sites 5 2 (1) There may be ongoing compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring .
Schedule of Environmental Loss Contingencies by Site	The following table shows our accrued liabilities for environmental matters at December 31, 2019 . Of the total liability, $15 million is recorded on a discounted basis, with discount rates ranging from 1.5% to 3% . ACCRUED LIABILITIES FOR ENVIRONMENTAL MATTERS (Dollars in millions) Manufactured- gas sites Waste disposal sites (PRP) (1) Other Total (2) SDG&E (3) $ — $ 2 $ 3 $ 5 SoCalGas (4) 43 2 — 45 Other — 1 — 1 Total Sempra Energy $ 43 $ 5 $ 3 $ 51 (1) Sites for which we have been identified as a PRP. (2) Includes $7 million , $1 million and $6 million classified as current liabilities, and $44 million , $4 million and $39 million classified as noncurrent liabilities on Sempra Energy’s, SDG&E’s and SoCalGas’ Consolidated Balance Sheets, respectively. (3) Does not include SDG&E’s liability for SONGS marine environment mitigation. (4) Does not include SoCalGas’ liability for environmental matters for the Leak at the Aliso Canyon natural gas storage facility. We discuss matters related to the Leak above in “Legal Proceedings – SoCalGas – Aliso Canyon Natural Gas Storage Facility Gas Leak.”

SEGMENT INFORMATION (Tables)

SEGMENT INFORMATION (Tables)	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables show selected information by segment from our Consolidated Statements of Operations and Consolidated Balance Sheets. We provide information about our equity method investments by segment in Note 6 . 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) Years ended December 31, 2019 2018 2017 REVENUES SDG&E $ 4,925 $ 4,568 $ 4,476 SoCalGas 4,525 3,962 3,785 Sempra Mexico 1,375 1,376 1,196 Sempra Renewables 10 124 94 Sempra LNG 410 472 540 All other 3 — — Adjustments and eliminations (3 ) (3 ) (1 ) Intersegment revenues (1) (416 ) (397 ) (450 ) Total $ 10,829 $ 10,102 $ 9,640 INTEREST EXPENSE SDG&E (2) $ 411 $ 221 $ 203 SoCalGas 141 115 102 Sempra Mexico 119 120 97 Sempra Renewables 3 19 15 Sempra LNG 35 21 39 All other 450 496 284 Intercompany eliminations (82 ) (106 ) (118 ) Total $ 1,077 $ 886 $ 622 INTEREST INCOME SDG&E $ 4 $ 4 $ — SoCalGas 2 2 1 Sempra Mexico 78 65 23 Sempra Renewables 11 12 7 Sempra LNG 61 49 56 All other 4 14 — Intercompany eliminations (73 ) (61 ) (63 ) Total $ 87 $ 85 $ 24 DEPRECIATION AND AMORTIZATION SDG&E $ 760 $ 688 $ 670 SoCalGas 602 556 515 Sempra Mexico 183 175 156 Sempra Renewables — 27 38 Sempra LNG 10 26 42 All other 14 19 15 Total $ 1,569 $ 1,491 $ 1,436 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 171 $ 173 $ 155 SoCalGas 120 92 160 Sempra Mexico 227 185 227 Sempra Renewables 4 71 (226 ) Sempra LNG (5 ) (435 ) (119 ) All other (202 ) (135 ) 741 Total $ 315 $ (49 ) $ 938 SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Years ended December 31 or at December 31, 2019 2018 2017 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 767 $ 669 $ 407 SoCalGas 641 400 396 Sempra Texas Utilities 528 371 — Sempra Mexico 253 237 169 Sempra Renewables 59 328 252 Sempra LNG (6 ) (617 ) 150 Discontinued operations 328 156 (58 ) All other (515 ) (620 ) (1,060 ) Total $ 2,055 $ 924 $ 256 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,522 $ 1,542 $ 1,555 SoCalGas 1,439 1,538 1,367 Sempra Mexico 624 368 248 Sempra Renewables 2 51 497 Sempra LNG 112 31 20 All other 9 14 18 Total $ 3,708 $ 3,544 $ 3,705 ASSETS SDG&E $ 20,560 $ 19,225 $ 17,844 SoCalGas 17,077 15,389 14,159 Sempra Texas Utilities 11,619 9,652 — Sempra Mexico 9,938 9,165 8,554 Sempra Renewables — 2,549 2,898 Sempra LNG 3,901 4,060 4,872 Discontinued operations 3,958 3,718 3,561 All other 749 1,070 1,351 Intersegment receivables (2,137 ) (4,190 ) (2,785 ) Total $ 65,665 $ 60,638 $ 50,454 GEOGRAPHIC INFORMATION Long-lived assets (3) : United States $ 43,719 $ 40,611 $ 31,487 Mexico 6,355 5,800 5,363 Total $ 50,074 $ 46,411 $ 36,850 Revenues (4) : United States $ 9,574 $ 8,840 $ 8,547 Mexico 1,255 1,262 1,093 Total $ 10,829 $ 10,102 $ 9,640 (1) Revenues for reportable segments include intersegment revenues of $5 million , $69 million , $120 million and $222 million for 2019 ; $4 million , $64 million , $114 million and $215 million for 2018 ; and $7 million , $74 million , $103 million and $266 million for 2017 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. (3) Includes net PP&E and investments. (4) Amounts are based on where the revenue originated, after intercompany eliminations.

QUARTERLY FINANCIAL DATA (UNA_2

QUARTERLY FINANCIAL DATA (UNAUDITED) (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Data [Abstract]
Schedule Of Quarterly Financial Data Table	SDG&E (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2019: Operating revenues $ 1,145 $ 1,094 $ 1,427 $ 1,259 Operating expenses 883 831 1,004 894 Operating income $ 262 $ 263 $ 423 $ 365 Net income $ 177 $ 146 $ 266 $ 185 Earnings attributable to noncontrolling interest (1 ) (3 ) (3 ) — Earnings attributable to common shares $ 176 $ 143 $ 263 $ 185 2018: Operating revenues $ 1,055 $ 1,051 $ 1,299 $ 1,163 Operating expenses 807 836 999 916 Operating income $ 248 $ 215 $ 300 $ 247 Net income $ 169 $ 146 $ 216 $ 145 Losses (earnings) attributable to noncontrolling interest 1 — (11 ) 3 Earnings attributable to common shares $ 170 $ 146 $ 205 $ 148 SOCALGAS (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2019: Operating revenues $ 1,361 $ 806 $ 975 $ 1,383 Operating expenses 1,060 747 762 1,000 Operating income $ 301 $ 59 $ 213 $ 383 Net income $ 264 $ 31 $ 143 $ 204 Dividends on preferred stock — (1 ) — — Earnings attributable to common shares $ 264 $ 30 $ 143 $ 204 2018: Operating revenues $ 1,126 $ 772 $ 802 $ 1,262 Operating expenses 848 703 797 1,023 Operating income $ 278 $ 69 $ 5 $ 239 Net income (loss) $ 225 $ 34 $ (14 ) $ 156 Dividends on preferred stock — (1 ) — — Earnings (losses) attributable to common shares $ 225 $ 33 $ (14 ) $ 156 We provide quarterly financial information for Sempra Energy Consolidated, SDG&E and SoCalGas below: SEMPRA ENERGY (In millions, except per share amounts) Quarters ended March 31 June 30 September 30 December 31 2019: Revenues $ 2,898 $ 2,230 $ 2,758 $ 2,943 Expenses and other income $ 2,397 $ 1,944 $ 2,310 $ 2,444 Income from continuing operations, net of income tax $ 560 $ 357 $ 653 $ 429 (Loss) income from discontinued operations, net of income tax (42 ) 78 256 71 Net income $ 518 $ 435 $ 909 $ 500 Earnings attributable to common shares $ 441 $ 354 $ 813 $ 447 Basic EPS (1) : Earnings from continuing operations $ 1.79 $ 1.03 $ 2.04 $ 1.36 (Losses) earnings from discontinued operations $ (0.19 ) $ 0.26 $ 0.89 $ 0.21 Earnings $ 1.60 $ 1.29 $ 2.93 $ 1.57 Weighted-average common shares outstanding 274.7 275.0 277.4 284.6 Diluted EPS (1) : Earnings from continuing operations (2) $ 1.78 $ 1.01 $ 2.00 $ 1.34 (Losses) earnings from discontinued operations $ (0.19 ) $ 0.25 $ 0.84 $ 0.21 Earnings (2) $ 1.59 $ 1.26 $ 2.84 $ 1.55 Weighted-average common shares outstanding 277.2 279.6 295.8 288.8 2018: Revenues $ 2,536 $ 2,175 $ 2,565 $ 2,826 Expenses and other income $ 1,943 $ 3,358 $ 2,220 $ 1,867 Income (loss) from continuing operations, net of income tax $ 330 $ (585 ) $ 280 $ 913 Income from discontinued operations, net of income tax 28 55 54 51 Net income (loss) $ 358 $ (530 ) $ 334 $ 964 Earnings (losses) attributable to common shares $ 347 $ (561 ) $ 274 $ 864 Basic EPS (1) : Earnings (losses) from continuing operations $ 1.26 $ (2.29 ) $ 0.83 $ 3.00 Earnings from discontinued operations $ 0.08 $ 0.18 $ 0.17 $ 0.15 Earnings (losses) $ 1.34 $ (2.11 ) $ 1.00 $ 3.15 Weighted-average common shares outstanding 257.9 265.8 273.9 274.3 Diluted EPS (1)(3) : Earnings (losses) from continuing operations (2) $ 1.25 $ (2.29 ) $ 0.82 $ 2.89 Earnings from discontinued operations $ 0.08 $ 0.18 $ 0.17 $ 0.14 Earnings (losses) (2) $ 1.33 $ (2.11 ) $ 0.99 $ 3.03 Weighted-average common shares outstanding 259.5 265.8 275.9 296.4 (1) EPS is computed independently for each of the quarters and therefore may not sum to the total for the year. (2) In the quarters ended September 30, 2019 and December 31, 2018, due to the dilutive effect of certain mandatory convertible preferred stock, the numerator used to calculate diluted EPS included an add-back of related mandatory convertible preferred stock dividends declared in those quarters. (3) In the quarter ended June 30, 2018, the total weighted-average potentially dilutive securities were not included in the computation of losses per common share since to do so would have decreased the loss per share.

SCHEDULE I - CONDENSED FINANC_3

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)	12 Months Ended
	Dec. 31, 2019
Condensed Financial Information Disclosure [Abstract]
Schedule of Condensed Statements of Operations	SEMPRA ENERGY CONDENSED STATEMENTS OF OPERATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2019 2018 2017 Interest income $ 3 $ 14 $ — Interest expense (521 ) (495 ) (293 ) Operating expenses (124 ) (82 ) (80 ) Other income (expense), net 59 (16 ) 100 Income tax benefit 163 154 33 Loss before equity in earnings of subsidiaries (420 ) (425 ) (240 ) Equity in earnings of subsidiaries, net of income taxes 2,617 1,474 496 Net income 2,197 1,049 256 Mandatory convertible preferred stock dividends (142 ) (125 ) — Earnings $ 2,055 $ 924 $ 256 Basic EPS: Earnings $ 7.40 $ 3.45 $ 1.02 Weighted-average common shares outstanding 277,904 268,072 251,545 Diluted EPS: Earnings $ 7.29 $ 3.42 $ 1.01 Weighted-average common shares outstanding 282,033 269,852 252,300 See Notes to Condensed Financial Information of Parent.
Schedule Of Condensed Statements Of Comprehensive Income	SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2019, 2018 and 2017 Pretax amount Income tax benefit (expense) Net-of-tax amount 2019: Net income $ 2,034 $ 163 $ 2,197 Other comprehensive income (loss): Foreign currency translation adjustments (43 ) — (43 ) Financial instruments (161 ) 53 (108 ) Pension and other postretirement benefits 25 (7 ) 18 Total other comprehensive loss (179 ) 46 (133 ) Comprehensive income $ 1,855 $ 209 $ 2,064 2018: Net income $ 895 $ 154 $ 1,049 Other comprehensive income (loss): Foreign currency translation adjustments (144 ) — (144 ) Financial instruments 64 (21 ) 43 Pension and other postretirement benefits (38 ) 4 (34 ) Total other comprehensive loss (118 ) (17 ) (135 ) Comprehensive income $ 777 $ 137 $ 914 2017: Net income $ 223 $ 33 $ 256 Other comprehensive income (loss): Foreign currency translation adjustments 107 — 107 Financial instruments 2 1 3 Pension and other postretirement benefits 20 (8 ) 12 Total other comprehensive income 129 (7 ) 122 Comprehensive income $ 352 $ 26 $ 378 See Notes to Condensed Financial Information of Parent.
Schedule Of Condensed Balance Sheets	SEMPRA ENERGY CONDENSED BALANCE SHEETS (Dollars in millions) December 31, December 31, Assets: Cash and cash equivalents $ 6 $ 14 Due from affiliates 98 93 Income taxes receivable, net — 397 Other current assets 34 9 Total current assets 138 513 Investments in subsidiaries 32,604 28,778 Due from affiliates 3 3 Deferred income taxes 1,766 1,554 Other long-term assets 682 572 Total assets $ 35,193 $ 31,420 Liabilities and shareholders’ equity: Current portion of long-term debt $ 1,399 $ 1,498 Due to affiliates 369 287 Income taxes payable, net 274 — Other current liabilities 561 527 Total current liabilities 2,603 2,312 Long-term debt 8,856 9,647 Due to affiliates 3,138 1,812 Other long-term liabilities 667 511 Commitments and contingencies (Note 4) Shareholders’ equity 19,929 17,138 Total liabilities and shareholders’ equity $ 35,193 $ 31,420 See Notes to Condensed Financial Information of Parent.
Schedule of Condensed Statements of Cash Flows	SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2019 2018 2017 Net cash provided by operating activities $ 294 $ 213 $ 89 Expenditures for property, plant and equipment (8 ) (11 ) (11 ) Expenditures for acquisition — (329 ) — Capital contributions to investees (1,528 ) (9,457 ) — Increase in loans to affiliates, net — (1 ) — Expenditures for Merger-related costs — — (12 ) Other 4 — — Net cash used in investing activities (1,532 ) (9,798 ) (23 ) Common stock dividends paid (993 ) (877 ) (755 ) Preferred dividends paid (142 ) (89 ) — Issuances of mandatory convertible preferred stock, net — 2,258 — Issuances of common stock, net 1,830 2,272 47 Repurchases of common stock (26 ) (21 ) (15 ) Issuances of long-term debt 758 4,969 1,595 Payments on long-term debt (1,500 ) (500 ) (600 ) Increase (decrease) in loans from affiliates, net 1,328 1,520 (239 ) Debt issuance costs (25 ) (37 ) (7 ) Net cash provided by financing activities 1,230 9,495 26 (Decrease) increase in cash and cash equivalents (8 ) (90 ) 92 Cash and cash equivalents, January 1 14 104 12 Cash and cash equivalents, December 31 $ 6 $ 14 $ 104 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Accrued Merger-related transaction costs $ — $ — $ 31 Preferred dividends declared but not paid 36 36 — Common dividends issued in stock 55 54 53 Common dividends declared but not paid 283 245 207
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	We expect no impact to SDG&E’s or SoCalGas’ balance sheets from adoption. The following table shows the expected (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. EXPECTED IMPACT FROM ADOPTION OF ASU 2016-13 (Dollars in millions) Sempra Energy Consolidated Accounts receivable – trade, net $ (1 ) Due from unconsolidated affiliates – noncurrent (6 ) Deferred income tax assets 4 Other current liabilities 4 Deferred credits and other 2 Retained earnings (7 ) Other noncontrolling interests (2 ) 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 $ — $ — Other long-term assets (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 and finance leases (138 ) — — Deferred credits and other 436 110 93 Retained earnings 17 — — The following table shows the increases (decreases) on our balance sheet at January 1, 2019 from adoption of the lease standard. IMPACT FROM ADOPTION OF THE LEASE STANDARD (Dollars in millions) Right-of-use assets – operating leases (1) $ 191 Deferred income tax assets (3 ) Property, plant and equipment, net (1) (147 ) Other current liabilities 3 Long-term debt (138 ) Other long-term liabilities 159 Retained earnings (2) 17 (1) Included in Other Long-Term Assets. (2) Included in Shareholders’ Equity.
Schedule Of Long-term Debt	Sempra Energy LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2019 2018 Sempra Energy: Other long-term debt (uncollateralized): 9.8% Notes February 15, 2019 — 500 Notes at variable rates (2.69% at December 31, 2018) July 15, 2019 — 500 1.625% Notes October 7, 2019 — 500 2.4% Notes February 1, 2020 500 500 2.4% Notes March 15, 2020 500 500 2.85% Notes November 15, 2020 400 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) 700 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 850 850 2.875% Notes October 1, 2022 500 500 2.9% Notes February 1, 2023 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 350 3.25% Notes June 15, 2027 750 750 3.4% Notes February 1, 2028 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 6% Notes October 15, 2039 750 750 4% Notes February 1, 2048 800 800 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 — Build-to-suit arrangement (2) — 138 Sempra Mexico Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 207 198 Notes at variable rates (4.88% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets 237 275 3.75% Notes January 14, 2028 300 300 Bank loans including $241 at a weighted-average fixed rate of 6.87%, $147 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $35 at variable rates (5.12% at December 31, 2019), payable 2016 through March 2032, collateralized by plant assets 423 447 4.875% Notes January 14, 2048 540 540 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) 11 4 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 — Sempra LNG Other long-term debt (uncollateralized): Notes at 2.87% to 3.51% October 1, 2026 (1) 22 21 12,298 13,023 Current portion of long-term debt (1,464 ) (1,560 ) Unamortized discount on long-term debt (35 ) (38 ) Unamortized debt issuance costs (108 ) (87 ) Total other Sempra Energy 10,691 11,338 Total Sempra Energy Consolidated $ 20,785 $ 20,903 (1) Callable long-term debt not subject to make-whole provisions. (2) This arrangement is now accounted for as an operating lease liability upon adoption of the lease standard on January 1, 2019. See Note 2. The following tables show the detail and maturities of long-term debt outstanding: LONG-TERM DEBT AND FINANCE LEASES (Dollars in millions) December 31, 2019 2018 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ 350 $ 350 1.914% payable 2015 through February 2022 89 125 3.6% September 1, 2023 450 450 2.5% May 15, 2026 500 500 6% June 1, 2026 250 250 5.875% January and February 2034 (1) 176 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039 (1) 75 75 6% June 1, 2039 300 300 5.35% May 15, 2040 250 250 4.5% August 15, 2040 500 500 3.95% November 15, 2041 250 250 4.3% April 1, 2042 250 250 3.75% June 1, 2047 400 400 4.15% May 15, 2048 400 400 4.1% June 15, 2049 400 — 5,140 4,776 Other long-term debt: OMEC LLC variable-rate loan (4.7896% at December 31, 2018 except for $142 at 5.2925% after floating-to-fixed rate swaps through April 1, 2019), payable 2019 through 2024 (collateralized by OMEC plant assets) — 220 Finance lease obligations: Purchased-power contracts 1,255 1,270 Other 15 2 1,270 1,492 6,410 6,268 Current portion of long-term debt (56 ) (81 ) Unamortized discount on long-term debt (12 ) (12 ) Unamortized debt issuance costs (36 ) (37 ) Total SDG&E 6,306 6,138 SoCalGas: First mortgage bonds (collateralized by plant assets): 3.15% September 15, 2024 500 500 3.2% June 15, 2025 350 350 2.6% June 15, 2026 500 500 5.75% November 15, 2035 250 250 5.125% November 15, 2040 300 300 3.75% September 15, 2042 350 350 4.45% March 15, 2044 250 250 4.125% June 1, 2048 400 400 4.3% January 15, 2049 550 550 3.95% February 15, 2050 350 — 3,800 3,450 Other long-term debt (uncollateralized): 1.875% Notes May 14, 2026 (1) 4 4 5.67% Notes January 18, 2028 5 5 Finance lease obligations 19 3 28 12 3,828 3,462 Current portion of long-term debt (6 ) (3 ) Unamortized discount on long-term debt (7 ) (6 ) Unamortized debt issuance costs (27 ) (26 ) Total SoCalGas 3,788 3,427 The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2019 2018 9.8% Notes February 15, 2019 $ — $ 500 Notes at variable rates (2.69% at December 31, 2018) July 15, 2019 — 500 1.625% Notes October 7, 2019 — 500 2.4% Notes February 1, 2020 500 500 2.4% Notes March 15, 2020 500 500 2.85% Notes November 15, 2020 400 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) 700 700 Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021 850 850 2.875% Notes October 1, 2022 500 500 2.9% Notes February 1, 2023 500 500 4.05% Notes December 1, 2023 500 500 3.55% Notes June 15, 2024 500 500 3.75% Notes November 15, 2025 350 350 3.25% Notes June 15, 2027 750 750 3.4% Notes February 1, 2028 1,000 1,000 3.8% Notes February 1, 2038 1,000 1,000 6% Notes October 15, 2039 750 750 4% Notes February 1, 2048 800 800 5.75% Junior Subordinated Notes July 1, 2079 (1) 758 — Build-to-suit arrangement (2) — 138 10,358 11,238 Current portion of long-term debt (1,399 ) (1,498 ) Unamortized discount on long-term debt (35 ) (38 ) Unamortized debt issuance costs (68 ) (55 ) Total long-term debt $ 8,856 $ 9,647

SIGNIFICANT ACCOUNTING POLICI_4

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details) - segment	3 Months Ended	9 Months Ended
	Mar. 31, 2019	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	6	5

SIGNIFICANT ACCOUNTING POLICI_5

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - EFFECTS OF REGULATION (Details)	Dec. 31, 2019
Oncor Electric Delivery Company LLC [Member] | Sempra Texas Utilities [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	80.25%
Sharyland Utilities [Member] | Sharyland Holdings, LP [Member] | Sharyland Holdings, LP [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100.00%

SIGNIFICANT ACCOUNTING POLICI_6

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CASH AND CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Presentation Of Restricted Cash [Line Items]
Cash and cash equivalents	$ 108	$ 102
Restricted cash, current	31	35
Restricted cash, noncurrent	3	21
Cash, cash equivalents and restricted cash in discontinued operations	75	88
Cash, cash equivalents and restricted cash, including discontinued operations, December 31	217	246	$ 364	$ 425
San Diego Gas and Electric Company [Member]
Presentation Of Restricted Cash [Line Items]
Cash and cash equivalents	10	8
Restricted cash, current	0	11
Restricted cash, noncurrent	0	18
Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows	$ 10	$ 37	$ 29	$ 20

SIGNIFICANT ACCOUNTING POLICI_7

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - COLLECTION ALLOWANCES (Details) - Allowance, Credit Loss [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance balance at January 1	$ 21	$ 25	$ 29
Provisions for uncollectible accounts	22	10	12
Write-offs of uncollectible accounts	(14)	(14)	(16)
Allowance balance at December 31	29	21	25
San Diego Gas and Electric Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance balance at January 1	11	9	8
Provisions for uncollectible accounts	10	9	8
Write-offs of uncollectible accounts	(7)	(7)	(7)
Allowance balance at December 31	14	11	9
Southern California Gas Company [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Allowance balance at January 1	10	16	21
Provisions for uncollectible accounts	12	1	4
Write-offs of uncollectible accounts	(7)	(7)	(9)
Allowance balance at December 31	$ 15	$ 10	$ 16

SIGNIFICANT ACCOUNTING POLICI_8

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Inventory [Line Items]
Natural gas	$ 110	$ 95
LNG	9	4
Materials and supplies	158	159
Inventories	277	258
SDG&E [Member]
Inventory [Line Items]
Natural gas	1	0
LNG	0	0
Materials and supplies	93	102
Inventories	94	102
SoCalGas [Member]
Inventory [Line Items]
Natural gas	90	92
LNG	0	0
Materials and supplies	46	42
Inventories	$ 136	$ 134

SIGNIFICANT ACCOUNTING POLICI_9

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details) - USD ($)	Jul. 12, 2019	Dec. 31, 2019	Jul. 25, 2019	Dec. 31, 2018
Loss Contingencies [Line Items]
Liquidity fund, maximum borrowing capacity	$ 10,500,000,000
Initial shareholder contributions	7,500,000,000
Additional annual contributions, aggregate value	$ 3,000,000,000
Period of annual contributions	10 years
Noncurrent portion of the Wildfire Fund asset		$ 392,000,000		$ 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	20.00%
Initial liability cap	$ 900,000,000
Initial shareholder contributions	322,500,000
Additional annual contributions, aggregate value	129,000,000
Period of annual contributions		9 years
Wildfire fund asset			$ 451,500,000
Amortization of wildfire fund asset		15 years
Current portion of Wildfire fund		$ 29,000,000
Noncurrent portion of the Wildfire Fund asset		392,000,000		$ 0
Wildfire fund, liability			$ 451,500,000
Additional annual contributions		12,900,000
Wildfire fund obligations in current liabilities		12,900,000
Wildlife fund obligations in deferred credits and other		$ 86,000,000
San Diego Gas and Electric Company [Member] | Minimum [Member]
Loss Contingencies [Line Items]
Fire risk mitigation capital improvements	215,000,000
Wildfire Fund [Member]
Loss Contingencies [Line Items]
Liquidity fund, maximum borrowing capacity	10,500,000,000
PG&E [Member]
Loss Contingencies [Line Items]
Initial shareholder contributions	4,800,000,000
Additional annual contributions, aggregate value	1,900,000,000
Edison [Member]
Loss Contingencies [Line Items]
Initial shareholder contributions	2,400,000,000
Additional annual contributions, aggregate value	945,000,000
SDG&E and Edison [Member]
Loss Contingencies [Line Items]
Total shareholder contribution	$ 3,800,000,000

SIGNIFICANT ACCOUNTING POLIC_10

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 49,329	$ 46,615
Depreciation expense	1,551	1,470	$ 1,368
Accumulated depreciation	12,877	12,176
San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	22,504	21,662
Depreciation expense	757	686	621
Accumulated depreciation	5,537	5,352
Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	19,362	18,138
Depreciation expense	598	553	$ 514
Accumulated depreciation	6,038	5,699
Natural gas operations [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,534	$ 2,382
Depreciation rates (percentage)	2.47%	2.44%	2.40%
Accumulated depreciation	$ 832	$ 794
Natural gas operations [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 18,370	$ 17,268
Depreciation rates (percentage)	3.60%	3.60%	3.63%
Capital leased assets		$ 40
Accumulated depreciation	$ 6,023	5,685
Accumulated depreciation of capital leased assets		37
Electric distribution [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 7,985	$ 7,462
Depreciation rates (percentage)	3.94%	3.91%	3.92%
Electric transmission [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 6,577	$ 6,222
Depreciation rates (percentage)	2.79%	2.76%	2.71%
Electric generation [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,415	$ 2,967
Depreciation rates (percentage)	4.50%	4.12%	4.05%
Capital leased assets		$ 1,300
Other electric [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,492	$ 1,408
Depreciation rates (percentage)	6.61%	6.43%	5.54%
Capital leased assets		$ 13
Construction work in progress [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,501	1,221
Construction work in progress [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	958	836
Other non-utility [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 34	$ 34
Depreciation rates (percentage)	5.08%	5.39%	5.28%
Accumulated depreciation	$ 15	$ 14
Other non-utility [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	1,302	1,125
Land and land rights [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 278	326
Land and land rights [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	16 years
Land and land rights [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Land and land rights [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	31 years
Generating plants [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,154	869
Generating plants [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	15 years
Generating plants [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	20 years
Generating plants [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	18 years
LNG terminals [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,134	1,134
LNG terminals [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	43 years
LNG terminals [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	43 years
LNG terminals [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	43 years
Pipelines and storage [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 3,596	3,413
Pipelines and storage [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	5 years
Pipelines and storage [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Pipelines and storage [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	41 years
Other [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 180	183
Other [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	1 year
Other [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Other [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	6 years
Construction work in progress [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 895	451
Other [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 226	439
Capital leased assets		136
Leasehold Improvements, Gross		24
Accumulated depreciation of capital leased assets		10
Other [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	3 years
Other [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	50 years
Other [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	15 years
Total Other Operating Units And Parent [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 7,463	6,815
Plant, pipeline and other distribution assets of ecogas [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	49	43
Plant, pipeline and other distribution assets of ecogas [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	178	154
Electricity [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	4,705	4,558
Accumulated depreciation of capital leased assets		48
Leasehold Improvements [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation		$ 3
Southwest Powerlink (SWPL) transmission line [Member] | Electric transmission [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	484
Accumulated depreciation	263
Southwest Powerlink (SWPL) transmission line [Member] | Construction work in progress [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 13
Southwest Powerlink [Member] | Southwest Powerlink (SWPL) transmission line [Member] | Electric transmission [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Ownership interest	90.00%

SIGNIFICANT ACCOUNTING POLIC_11

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 183	$ 193	$ 247
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	75	82	85
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 47	$ 48	$ 60

SIGNIFICANT ACCOUNTING POLIC_12

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 1,602	$ 1,602
Total intangible assets, gross	250	250
Accumulated amortization	(37)	(26)
Other intangible assets	213	224
Intangible assets amortization expense	11	16	$ 18
Future intangible asset amortization expense per year	$ 12
Renewable energy and consumption permit [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period	19 years
Intangible assets, gross	$ 154	154
Accumulated amortization	$ (24)	(16)
O&M agreement [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period	23 years
Intangible assets, gross	$ 66	66
Accumulated amortization	(6)	(3)
Other [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	30	30
Accumulated amortization	$ (7)	$ (7)
Other [Member] | Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period	10 years

SIGNIFICANT ACCOUNTING POLIC_13

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details) $ in Millions	Mar. 09, 2018	Oct. 03, 2019USD ($)MW	Dec. 31, 2019USD ($)	Aug. 23, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
ASSETS
Cash and cash equivalents			$ 108		$ 102
Inventories			277		258
Total current assets			3,339		3,645
Property, plant and equipment, net			36,452		34,439
Other long-term assets			732		962
Total assets			65,665		60,638	$ 50,454
Liabilities [Abstract]
Other current liabilities			866		935
Total current liabilities			9,150		7,523
Asset retirement obligations			3,083		2,972	2,876
Deferred credits and other			2,048		1,493
Equity [Abstract]
Other noncontrolling interests			1,856		2,090
Total liabilities and equity			65,665		60,638
Equity method investment			11,519		9,652
San Diego Gas and Electric Company [Member]
ASSETS
Cash and cash equivalents			10		8
Inventories			94		102
Total current assets			1,158		894
Property, plant and equipment, net			16,967		16,310
Other long-term assets			202		420
Total assets			20,560		19,225
Liabilities [Abstract]
Other current liabilities			176		141
Total current liabilities			1,310		1,428
Asset retirement obligations			866		874	$ 839
Deferred credits and other			677		488
Equity [Abstract]
Other noncontrolling interests			0		100
Total liabilities and equity			20,560		19,225
San Diego Gas and Electric Company [Member] | Otay Mesa VIE [Member]
Investments [Abstract]
Generating capacity (in mw) | MW		605
Put option		$ 280
Equity of Variable interest entity					100
Sempra Mexico [Member]
Equity [Abstract]
VIE, carrying amount of assets			126		286
Sempra Renewables [Member] | Noncontrolling Tax Equity Investors [Member]
Equity [Abstract]
Assets held for sale					301
VIE, liabilities held-for-sale					9
VIE, equity amount					158
Sempra LNG [Member] | Cameron LNG Holdings [Member]
Equity [Abstract]
Equity method investment			1,256		1,271
Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Utilities [Member]
Equity [Abstract]
Equity method investment			$ 11,519		$ 9,652
Oncor Electric Delivery Company LLC [Member]
Equity [Abstract]
Acquired percentage interest	80.25%
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Equity [Abstract]
Ownership percentage in consolidated entity	100.00%
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC [Member]
Equity [Abstract]
Acquired percentage interest	80.03%
Otay Mesa VIE [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
ASSETS
Cash and cash equivalents				$ 8
Accounts receivable, net				11
Inventories				4
Total current assets				23
Property, plant and equipment, net				272
Other long-term assets				27
Total assets				322
Liabilities [Abstract]
Accounts payable				10
Other current liabilities				2
Total current liabilities				12
Asset retirement obligations				2
Deferred credits and other				27
Total deferred credits and other liabilities				29
Equity [Abstract]
Other noncontrolling interests				281
Total liabilities and equity				$ 322

SIGNIFICANT ACCOUNTING POLIC_14

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 2,972	$ 2,876
Accretion expense	123	121
Liabilities incurred	2	7
Deconsolidation and reclassification	(2)	(61)
Payments	(46)	(42)
Revisions	34	71
Ending Balance	3,083	2,972
San Diego Gas and Electric Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	874	839
Accretion expense	39	39
Liabilities incurred	0	0
Deconsolidation and reclassification	(2)	0
Payments	(44)	(39)
Revisions	(1)	35
Ending Balance	866	874
Southern California Gas Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	2,063	1,953
Accretion expense	81	78
Liabilities incurred	0	0
Deconsolidation and reclassification	0	0
Payments	(2)	(3)
Revisions	35	35
Ending Balance	$ 2,177	2,063
Termoelectrica de Mexicali [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Reclassified from held for sale		5
Sempra Renewables [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Reclassified to held for sale		6
Sempra LNG [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Reclassified to held for sale		8
Sempra Renewables [Member] | Disposal Group Disposed of by Sale [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Deconsolidation and reclassification		$ 52

SIGNIFICANT ACCOUNTING POLIC_15

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2019	Jan. 01, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	$ 17,138
AOCI, ending balance	19,929	$ 17,138
Cumulative-effect adjustment from change in accounting principle				$ 15	$ (1)
San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	6,015
AOCI, ending balance	7,100	6,015
Cumulative-effect adjustment from change in accounting principle		0
Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	4,258
AOCI, ending balance	4,748	4,258
Cumulative-effect adjustment from change in accounting principle		(2)
Foreign currency translation adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(564)	(420)	$ (527)
OCI before reclassifications	(43)	(144)	107
Amounts reclassified from AOCI	0	0	0
Total other comprehensive income (loss)	(43)	(144)	107
AOCI, ending balance	(607)	(564)	(420)
Cumulative-effect adjustment from change in accounting principle		0	0
Financial instruments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(82)	(122)	(125)
OCI before reclassifications	(116)	40	(4)
Amounts reclassified from AOCI	8	3	7
Total other comprehensive income (loss)	(108)	43	3
AOCI, ending balance	(215)	(82)	(122)
Cumulative-effect adjustment from change in accounting principle		(25)	(3)
Financial instruments [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(12)	(13)	(13)
OCI before reclassifications	0	0
Amounts reclassified from AOCI	1	1	0
Total other comprehensive income (loss)	1	1	0
AOCI, ending balance	(13)	(12)	(13)
Cumulative-effect adjustment from change in accounting principle		(2)
Pension and other postretirement benefits [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(118)	(84)	(96)
OCI before reclassifications	(18)	(52)	0
Amounts reclassified from AOCI	36	18	12
Total other comprehensive income (loss)	18	(34)	12
AOCI, ending balance	(117)	(118)	(84)
Cumulative-effect adjustment from change in accounting principle		(17)	0
Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(10)	(8)	(8)
OCI before reclassifications	(5)	(6)	(1)
Amounts reclassified from AOCI	1	4	1
Total other comprehensive income (loss)	(4)	(2)	0
AOCI, ending balance	(16)	(10)	(8)
Cumulative-effect adjustment from change in accounting principle		(2)
Pension and other postretirement benefits [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(8)	(8)	(9)
OCI before reclassifications	(4)	(1)
Amounts reclassified from AOCI	4	1	1
Total other comprehensive income (loss)	0	0	1
AOCI, ending balance	(10)	(8)	(8)
Cumulative-effect adjustment from change in accounting principle		(2)
Accumulated other comprehensive income (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(764)	(626)	(748)
OCI before reclassifications	(177)	(156)	103
Amounts reclassified from AOCI	44	21	19
Total other comprehensive income (loss)	(133)	(135)	122
AOCI, ending balance	(939)	(764)	(626)
Cumulative-effect adjustment from change in accounting principle		(42)	(3)	$ (42)	$ (3)
Accumulated other comprehensive income (loss) [Member] | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(10)	(8)	(8)
OCI before reclassifications	(5)	(6)	(1)
Amounts reclassified from AOCI	1	4	1
Total other comprehensive income (loss)	(4)	(2)	0
AOCI, ending balance	(16)	(10)	(8)
Cumulative-effect adjustment from change in accounting principle		(2)
Accumulated other comprehensive income (loss) [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(20)	(21)	(22)
OCI before reclassifications	(4)	(1)
Amounts reclassified from AOCI	5	2	1
Total other comprehensive income (loss)	1	1	1
AOCI, ending balance	$ (23)	(20)	$ (21)
Cumulative-effect adjustment from change in accounting principle		$ (4)

SIGNIFICANT ACCOUNTING POLIC_16

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended								12 Months Ended
	Dec. 31, 2018	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense										$ (1,077)	$ (886)	$ (622)
Other income, net										(77)	(58)	(220)
Gain on sale of assets	$ 513									63	513	2
Equity earnings										580	175	72
Energy-related businesses										1,381	1,563	1,350
(Loss) income from discontinued operations, net of income tax		$ (71)	$ (256)	$ (78)	$ 42	$ (51)	$ (54)	$ (55)	$ (28)	(328)	(156)	58
Income before income taxes										1,734	714	1,248
Income tax (expense) benefit										(315)	49	(938)
Net of income tax										1,999	938	382
Earnings attributable to noncontrolling interest										(164)	(76)	(94)
Earnings attributable to common shares		447	813	354	441	864	274	(561)	347
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense										(411)	(221)	(203)
Other income, net										(39)	(56)	(70)
Income before income taxes										945	849	576
Income tax (expense) benefit										(171)	(173)	(155)
Earnings attributable to noncontrolling interest		$ 0	$ (3)	$ (3)	$ (1)	$ 3	$ (11)	$ 0	$ 1	(7)	(7)	(14)
Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense										(141)	(115)	(102)
Other income, net										55	(15)	(31)
Income before income taxes										762	493	557
Income tax (expense) benefit										(120)	(92)	(160)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares										40	21	19
Reclassification out of Accumulated Other Comprehensive Income [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares										1	4	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares										1	2	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes										11	13	23
Income tax (expense) benefit										(2)	(4)	(6)
Net of income tax										9	9	17
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments [Member] | Interest rate and foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense										3	0	(4)
Other income, net										(9)	(2)	0
Equity earnings										5	7	20
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments [Member] | Interest rate instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain on sale of assets										10	9	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments [Member] | Interest rate instruments [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense										3	7	13
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments [Member] | Foreign exchange instruments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Energy-related businesses										2	(1)	(2)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Energy-related businesses										0	0	9
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments attributable to Noncontrolling interests [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest										(1)	(6)	(10)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments attributable to Noncontrolling interests [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest										(3)	(7)	(13)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments attributable to parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares										8	3	7
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments attributable to parent [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to common shares										0	0	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments attributable to parent [Member] | Interest rate instruments [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense										1	1	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of actuarial loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										12	11	10
(Loss) income from discontinued operations, net of income tax										1	1	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of actuarial loss [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										0	1	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of actuarial loss [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										1	0	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of prior service cost [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										3	2	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of prior service cost [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										1	0	0
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of prior service cost [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										0	1	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 income, net										28	12	8
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Settlements Attributable to Parent [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other income, net										0	4	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 before income taxes										44	26	19
Income tax (expense) benefit										(12)	(8)	(7)
Net of income tax										32	18	12
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes										1	5	1
Income tax (expense) benefit										0	(1)	0
Net of income tax										1	4	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and other postretirement benefits [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income before income taxes										1	1	1
Income tax (expense) benefit										(1)	0	0
Net of income tax										$ 0	$ 1	$ 1

SIGNIFICANT ACCOUNTING POLIC_17

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Feb. 07, 2019	Feb. 28, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Noncontrolling Interest [Line Items]
Stock repurchased in the period			$ 26	$ 21	$ 15
Sempra Mexico [Member] | IEnova [Member]
Noncontrolling Interest [Line Items]
Stock repurchased during the period (in shares)			2,620,000	2,000,000
Stock repurchased in the period			$ 10	$ 7
IEnova [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership interest			66.60%	66.50%	66.40%
IEnova [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership interest			50.00%
Bay Gas [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership interest				9.10%
Cash consideration (fair value of total consideration)		$ 20
Bay Gas [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Changes, Sale of Interest by Parent, Percent	100.00%

SIGNIFICANT ACCOUNTING POLIC_18

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 1,856	$ 2,090
Otay Mesa VIE [Member] | SDG&E [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.00%	100.00%
Other noncontrolling interests	$ 0	$ 100
IEnova [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	33.40%	33.50%
Other noncontrolling interests	$ 1,608	$ 1,592
IEnova subsidiaries | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 15	$ 13
IEnova subsidiaries | Sempra Mexico [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	10.00%	10.00%
IEnova subsidiaries | Sempra Mexico [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	46.30%	49.00%
Tax equity arrangement – wind [Member] | Sempra Renewables [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 0	$ 158
PXISE Energy Solutions LLC [Member] | Sempra Renewables [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		11.10%
Other noncontrolling interests	$ 0	$ 1
PXISE Energy Solutions LLC [Member] | Corporate and Other [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	20.00%
Other noncontrolling interests	$ 1	$ 0
Bay Gas Storage Company [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.00%	9.10%
Other noncontrolling interests	$ 0	$ 18
Liberty Gas Storage [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	24.60%	24.60%
Other noncontrolling interests	$ (13)	$ (12)
ECA LNG JV [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	16.70%	0.00%
Other noncontrolling interests	$ 12	$ 0
Chilquinta Energia subsidiaries [Member] | Discontinued Operations, Held-for-sale [Member]
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 23	$ 23
Chilquinta Energia subsidiaries [Member] | Discontinued Operations, Held-for-sale [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	19.70%	19.70%
Chilquinta Energia subsidiaries [Member] | Discontinued Operations, Held-for-sale [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	43.40%	43.40%
Luz Del Sur [Member] | Discontinued Operations, Held-for-sale [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	16.40%	16.40%
Other noncontrolling interests	$ 205	$ 193
Tecsur [Member] | Discontinued Operations, Held-for-sale [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	9.80%	9.80%
Other noncontrolling interests	$ 5	$ 4

SIGNIFICANT ACCOUNTING POLIC_19

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Foreign currency transaction gains (losses)	$ 21	$ (6)	$ (33)

SIGNIFICANT ACCOUNTING POLIC_20

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details)	12 Months Ended
	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2019MXN ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 32,000,000	$ 37,000,000
Due from unconsolidated affiliates - noncurrent	742,000,000	644,000,000
Due to unconsolidated affiliates - current	(5,000,000)	(10,000,000)
Due to unconsolidated affiliates, noncurrent	$ (195,000,000)	$ (37,000,000)
ESJ joint venture [Member]
Related Party Transaction [Line Items]
Related party transaction rate		8.89%
TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Related party transaction rate	4.81%
TAG JV Notes [Member]
Related Party Transaction [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.74%		5.74%
LIBOR [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Variable percentage rate	6.375%
LIBOR [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Variable percentage rate	2.90%
Sempra Mexico [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (195,000,000)	$ (37,000,000)
Sempra Mexico [Member] | IMG [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	742,000,000	641,000,000
Total facility	751,000,000		$ 14,200,000,000
Sempra Mexico [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	0	3,000,000
Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	(39,000,000)	(37,000,000)
Sempra Mexico [Member] | TAG JV Notes [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (156,000,000)	0
Sempra Mexico [Member] | Interbank Equilibrium Rate [Member] | IMG [Member]
Related Party Transaction [Line Items]
Variable percentage rate	2.20%
Related party transaction rate	9.65%
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ (53,000,000)	(61,000,000)
Total facility	1,500,000,000
San Diego Gas and Electric Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(37,000,000)	(43,000,000)
Income taxes due from Sempra Energy	130,000,000	5,000,000
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(10,000,000)	(6,000,000)
San Diego Gas and Electric Company [Member] | Due to/from Various Affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(6,000,000)	(12,000,000)
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	11,000,000	7,000,000
Due to unconsolidated affiliates - current	(47,000,000)	(34,000,000)
Total facility	750,000,000
Southern California Gas Company [Member] | Due to/from Sempra Energy [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(45,000,000)	(34,000,000)
Income taxes due to Sempra Energy		(4,000,000)
Income taxes due from Sempra Energy	152,000,000
Southern California Gas Company [Member] | Due to/from Various Affiliates [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	1,000,000	1,000,000
Southern California Gas Company [Member] | Due to/from SDGE [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	10,000,000	6,000,000
Southern California Gas Company [Member] | Other related parties [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ (2,000,000)	$ 0

SIGNIFICANT ACCOUNTING POLIC_21

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - AFFILIATES REVENUE AND COST OF SALES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)MW	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Related Party Transaction [Line Items]
Related party revenue	$ 52	$ 64	$ 43
Related party cost of sales	50	46	47
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Related party revenue	6	5	8
Related party cost of sales	74	73	71
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Related party revenue	69	64	74
Related party cost of sales	$ 8	$ 0	$ 0
Minimum [Member] | Federal Funds Rate [Member] | California Utilities [Member]
Related Party Transaction [Line Items]
Variable percentage rate	0.13%
Maximum [Member] | Federal Funds Rate [Member] | California Utilities [Member]
Related Party Transaction [Line Items]
Variable percentage rate	0.20%
Energia Sierra Juarez Wind Project [Member] | San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Power purchase agreement term	20 years
Generating capacity (in mw) | MW	155

SIGNIFICANT ACCOUNTING POLIC_22

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RESTRICTED NET ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Oct. 31, 2019	Jan. 01, 2019
Significant Restrictions of Subsidiaries [Line Items]
Undistributed earnings of equity investments	$ 634
Sempra Texas Utilities [Member] | Oncor Electric Delivery Holdings Company LLC [Member]
Significant Restrictions of Subsidiaries [Line Items]
Maximum ratio of indebtedness to total capitalization	0.65
Ownership percentage in equity method investee	100.00%
Plan percentage of capital structure allocated to debt	57.50%
Plan percentage of capital structure allocated to equity	42.50%
Sempra Texas Utilities [Member] | Oncor Electric Delivery Company LLC [Member]
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	80.25%
Sempra Mexico [Member] | Mexican Subsidiaries [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 178
Sempra Mexico [Member] | IEnova Pipelines [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	17
Sempra Mexico [Member] | Ventika [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	14
Sempra Mexico [Member] | Energia Sierra Juarez Wind Project [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 15
Ownership percentage in equity method investee	50.00%
Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 171
Ownership percentage in equity method investee	50.00%
Sempra LNG [Member] | Cameron LNG Holdings [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 10,300
Consolidated Entities [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	10,400
Unconsolidated Entities [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	21,500
San Diego Gas and Electric Company [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	6,200
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 885
Authorized percentage of equity	52.00%
Minimum common equity ratio		10.60%	11.20%
Southern California Gas Company [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 4,000
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 742
Authorized percentage of equity	52.00%
California Utilities [Member]
Significant Restrictions of Subsidiaries [Line Items]
Maximum ratio of indebtedness to total capitalization	0.65
Sempra Texas Utilities [Member] | Sharyland Holdings, LP [Member]
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50.00%
Sempra Texas Utilities [Member] | Sharyland Utilities [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 115
Maximum ratio of indebtedness to total capitalization	0.70
Ownership percentage in equity method investee	100.00%
Plan percentage of capital structure allocated to debt	55.00%
Plan percentage of capital structure allocated to equity	45.00%
Oncor Electric Delivery Company LLC [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 10,900

SIGNIFICANT ACCOUNTING POLIC_23

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER INCOME, NET (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Other Income [Line Items]
Allowance for equity funds used during construction		$ 94	$ 98	$ 168
Investment (losses) gains		61	(6)	56
Gains on interest rate and foreign exchange instruments, net		34	7	47
Foreign currency transaction gains (losses)		21	(6)	(33)
Non-service component of net periodic benefit cost		(132)	(35)	(20)
Penalties related to billing practices OII		(8)	0	0
Interest on regulatory balancing accounts, net		14	2	3
Sundry, net		(7)	(2)	(1)
Total		77	58	220
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		56	61	63
Non-service component of net periodic benefit cost		(20)	(6)	4
Interest on regulatory balancing accounts, net		13	4	3
Sundry, net		(10)	(3)	0
Total		39	56	70
Southern California Gas Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		34	36	44
Non-service component of net periodic benefit cost		(72)	(10)	(5)
Penalties related to billing practices OII	$ (8)	(8)	0	0
Interest on regulatory balancing accounts, net		1	(2)	0
Sundry, net		(10)	(9)	(8)
Total		(55)	15	31
Sempra Mexico [Member] | IMG [Member]
Other Income [Line Items]
Foreign currency transaction gains (losses)		$ 30	$ (3)	$ (35)

NEW ACCOUNTING STANDARDS - BALA

NEW ACCOUNTING STANDARDS - BALANCE SHEET IMPACT (Details) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other long-term assets	$ 324		$ 249
Property, plant and equipment, net	36,452		34,439
Right-of-use assets – operating leases	591
Deferred income taxes	2,577		2,321
Other current liabilities	866		935
Deferred credits and other	2,048		1,493
Retained earnings	11,130		10,104
Other noncontrolling interests	1,856		2,090
Accounting Standards Update 2016-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Assets held for sale		$ 13
Other long-term assets		(71)
Property, plant and equipment, net		(147)
Right-of-use assets – operating leases		603
Deferred income taxes		(3)
Other current liabilities		80
Long-term debt and finance leases		(138)
Deferred credits and other		436
Retained earnings		17
Accounting Standards Update 2016-13 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred income taxes	4
Other current liabilities	4
Deferred credits and other	2
Retained earnings	(7)
Other noncontrolling interests	(2)
Accounts receivable – trade, net	(1)
Due from unconsolidated affiliates – noncurrent	(6)
San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other long-term assets	24		5
Property, plant and equipment, net	16,967		16,310
Right-of-use assets – operating leases	130
Deferred income taxes	1,848		1,616
Other current liabilities	176		141
Deferred credits and other	677		488
Retained earnings	5,456		4,687
Other noncontrolling interests	0		100
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
Other long-term assets		0
Property, plant and equipment, net		0
Right-of-use assets – operating leases		130
Deferred income taxes		0
Other current liabilities		20
Long-term debt and finance leases		0
Deferred credits and other		110
Retained earnings		0
Southern California Gas Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other long-term assets	44		29
Property, plant and equipment, net	13,324		12,439
Right-of-use assets – operating leases	94
Deferred income taxes	1,403		1,177
Other current liabilities	222		217
Deferred credits and other	422		330
Retained earnings	$ 3,883		$ 3,390
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
Other long-term assets		0
Property, plant and equipment, net		0
Right-of-use assets – operating leases		116
Deferred income taxes		0
Other current liabilities		23
Long-term debt and finance leases		0
Deferred credits and other		93
Retained earnings		$ 0

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ 10,141	$ 9,447
Utilities regulatory revenues									264	165
Other revenues									424	490
Total revenues	$ 2,943	$ 2,758	$ 2,230	$ 2,898	$ 2,826	$ 2,565	$ 2,175	$ 2,536	10,829	10,102	$ 9,640
Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									9,184	8,374
Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									957	1,073
Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									5,596	4,800
Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,545	4,647
Operating Segments [Member] | San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,819	4,788
Utilities regulatory revenues									106	(220)
Other revenues									0	0
Total revenues									4,925	4,568
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,819	4,788
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									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									587	491
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,232	4,297
Operating Segments [Member] | Southern California Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,367	3,577
Utilities regulatory revenues									158	385
Other revenues									0	0
Total revenues									4,525	3,962
Operating Segments [Member] | Southern California Gas Company [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,367	3,577
Operating Segments [Member] | Southern California Gas Company [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments [Member] | Southern California Gas Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,367	3,577
Operating Segments [Member] | Southern California Gas Company [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments [Member] | Sempra Mexico [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									992	1,019
Utilities regulatory revenues									0	0
Other revenues									383	357
Total revenues									1,375	1,376
Operating Segments [Member] | Sempra Mexico [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									73	78
Operating Segments [Member] | Sempra Mexico [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									919	941
Operating Segments [Member] | Sempra Mexico [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									680	711
Operating Segments [Member] | Sempra Mexico [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									312	308
Operating Segments [Member] | Sempra Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									5	46
Utilities regulatory revenues									0	0
Other revenues									5	78
Total revenues									10	124
Operating Segments [Member] | Sempra Renewables [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments [Member] | Sempra Renewables [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									5	46
Operating Segments [Member] | Sempra Renewables [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments [Member] | Sempra Renewables [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									5	46
Operating Segments [Member] | Sempra LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									176	232
Utilities regulatory revenues									0	0
Other revenues									234	240
Total revenues									410	472
Operating Segments [Member] | Sempra LNG [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0
Operating Segments [Member] | Sempra LNG [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									176	232
Operating Segments [Member] | Sempra LNG [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									170	224
Operating Segments [Member] | Sempra LNG [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									6	8
Consolidating Adjustments [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(218)	(215)
Utilities regulatory revenues									0	0
Other revenues									(198)	(185)
Total revenues									(416)	(400)
Consolidating Adjustments [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(75)	(69)
Consolidating Adjustments [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(143)	(146)
Consolidating Adjustments [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(208)	(203)
Consolidating Adjustments [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ (10)	$ (12)

NEW ACCOUNTING STANDARDS - NARR

NEW ACCOUNTING STANDARDS - NARRATIVE (Details) - USD ($) $ in Millions	Dec. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings	$ 11,130		$ 10,104
Regulatory Liability, Noncurrent	3,741		4,016
Accumulated other comprehensive income (loss)	(939)		(764)
Accounting Standards Update 2018-02 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings		$ 40
Regulatory Liability, Noncurrent		2
Accumulated other comprehensive income (loss)		42
San Diego Gas and Electric Company [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Retained earnings	5,456		4,687
Regulatory Liability, Noncurrent	2,319		2,404
Accumulated other comprehensive income (loss)	(16)		(10)
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]
Retained earnings	3,883		3,390
Regulatory Liability, Noncurrent	1,422		1,612
Accumulated other comprehensive income (loss)	$ (23)		$ (20)
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 Liability, Noncurrent		2
Accumulated other comprehensive income (loss)		$ 4

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Dec. 31, 2019USD ($)
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	$ 390
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	$ 403
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	$ 406
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	$ 402
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	$ 349
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4,699
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	$ 6,649
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	$ 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]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 71
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	$ 91

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Contract with Customer, Liability [Roll Forward]
Beginning balance	$ (70)	$ 0
Adoption of ASC 606 adjustment		(61)
Revenue from performance obligations satisfied during reporting period	2	7
Payments received in advance	(95)	(16)
Ending balance	(163)	(70)
Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Ending balance	(4)
Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Ending balance	(159)
San Diego Gas and Electric Company [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	0
Revenue from performance obligations satisfied during reporting period	1
Payments received in advance	(92)
Ending balance	(91)	$ 0
San Diego Gas and Electric Company [Member] | Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Ending balance	(4)
San Diego Gas and Electric Company [Member] | Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Ending balance	$ (87)

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,184	$ 1,127
Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,163	1,106
Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	16	11
Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	5	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	405	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	398	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	5	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	2	3
Southern California Gas Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	721	639
Southern California Gas Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	710	634
Southern California Gas Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 11	$ 5

REGULATORY MATTERS - REGULATORY

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Amortization expense on regulatory assets	$ 7	$ 5	$ 50
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,908)	(2,394)
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	108	78
Amortization expense on regulatory assets	3	2	49
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)	8	(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)	(108)	(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)	103	186
San Diego Gas and Electric Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,056)	(1,848)
San Diego Gas and Electric Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	45	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)	$ 121	120
Remaining amortization period	50
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)	$ 102	(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)	22	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)	77	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)	(124)	(62)
San Diego Gas and Electric Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	111	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)	106	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)	(153)	(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)	(1,746)	(1,880)
Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	500	185
Amortization expense on regulatory assets	4	3	$ 1
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)	(203)	(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)	400	470
Southern California Gas Company [Member] | Employee benefit costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	44	49
Southern California Gas Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(728)	(833)
Southern California Gas Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	40	28
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	295	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)	(273)	(325)
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Commodity - gas including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(118)	196
Southern California Gas Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	400	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)	(7)	(68)
Southern California Gas Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(101)	(114)
Southern California Gas Company [Member] | Net Regulatory Assets (Liabilities) SoCalGas [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(251)	(601)
Sempra Mexico [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	83	81
Sempra Mexico [Member] | Other Regulatory 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	Dec. 31, 2019	Dec. 31, 2018
General Rate Case [Line Items]
Regulatory assets, noncurrent			$ 1,930	$ 1,589
San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement		$ 2,203
Regulatory assets, noncurrent			440	454
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			66
Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC requested revenue requirement		$ 2,937
Regulatory assets, noncurrent			1,407	1,051
Southern California Gas Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability				$ 89
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]
GRC revenue requirement	$ 1,990
General Rate Case, Revenue Requirement, Difference From Requested Amount	213
Revenue increase	$ 107
Percent increase	5.70%
Regulatory assets			111
Regulatory assets, noncurrent			56
2019 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC revenue requirement	$ 2,770
General Rate Case, Revenue Requirement, Difference From Requested Amount	167
Revenue increase	$ 314
Percent increase	12.80%
Regulatory assets			400
Regulatory assets, noncurrent			$ 200
Electricity [Member] | 2019 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC revenue requirement	$ 1,590
Natural Gas, Gathering, Transportation, Marketing and Processing [Member] | 2019 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC revenue requirement	$ 400

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] | San Diego Gas and Electric Company [Member] | O&M [Member]
General Rate Case [Line Items]
Revenue increase	$ 20
Percent increase	2.64%
2020 GRC FD [Member] | San Diego Gas and Electric Company [Member] | Capital-related Costs [Member]
General Rate Case [Line Items]
Revenue increase	$ 114
Percent increase	9.74%
2020 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 220
Percent increase	7.92%
2020 GRC FD [Member] | Southern California Gas Company [Member] | O&M [Member]
General Rate Case [Line Items]
Revenue increase	$ 36
Percent increase	2.64%
2020 GRC FD [Member] | Southern California Gas Company [Member] | Capital-related Costs [Member]
General Rate Case [Line Items]
Revenue increase	$ 184
Percent increase	14.36%
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] | San Diego Gas and Electric Company [Member] | O&M [Member]
General Rate Case [Line Items]
Revenue increase	$ 19
Percent increase	2.47%
2021 GRC FD [Member] | San Diego Gas and Electric Company [Member] | Capital-related Costs [Member]
General Rate Case [Line Items]
Revenue increase	$ 83
Percent increase	6.47%
2021 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
Revenue increase	$ 150
Percent increase	5.00%
2021 GRC FD [Member] | Southern California Gas Company [Member] | O&M [Member]
General Rate Case [Line Items]
Revenue increase	$ 34
Percent increase	2.40%
2021 GRC FD [Member] | Southern California Gas Company [Member] | Capital-related Costs [Member]
General Rate Case [Line Items]
Revenue increase	$ 116
Percent increase	7.93%

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL & FERC RATES (Details) - USD ($) $ in Millions	Jan. 01, 2020	Oct. 31, 2019	Jan. 31, 2020	Oct. 31, 2019	Apr. 30, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2022	Jan. 01, 2019
California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
CCM Benchmark Rate, Increase (Decrease) Percent For Trigger						1.00%
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Minimum common equity ratio		10.60%		10.60%					11.20%
FERC Requirement To Maintain Common Equity Ratio At Or Above, Base		10.10%		10.10%
FERC, Revenue Requirement				$ 17
FERC requirement, additional basis spread		0.50%
San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighted return on rate base					7.55%
CCM Benchmark Rate						4.491%
San Diego Gas and Electric Company [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighting						100.00%
Weighted return on rate base						7.51%
San Diego Gas and Electric Company [Member] | Capital Structure, Long Term Debt [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighting						43.44%
Return on rate base						4.21%
Weighted return on rate base						1.83%
San Diego Gas and Electric Company [Member] | Capital Structure, Common Equity [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting					52.00%
Return on rate base					10.20%
San Diego Gas and Electric Company [Member] | Capital Structure, Common Equity [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighting						56.56%
Return on rate base						10.05%	10.05%
Weighted return on rate base						5.68%
Southern California Gas Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighted return on rate base					7.34%
CCM Benchmark Rate						4.024%
Southern California Gas Company [Member] | Capital Structure, Common Equity [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting					52.00%
Return on rate base					10.05%
Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighted return on rate base	10.03%
Cost Of Capital Authorized Return On Rate Base, Revised	8.95%
Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Capital Structure, Preferred Stock [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting			6.22%
Subsequent Event [Member] | San Diego Gas and Electric Company [Member] | Capital Structure, Common Equity [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting	56.00%
Return on rate base	14.30%
Cost Of Capital Authorized Rate Of Recovery, Revised	12.38%
Subsequent Event [Member] | Southern California Gas Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Weighted return on rate base	7.85%
Subsequent Event [Member] | Southern California Gas Company [Member] | Capital Structure, Common Equity [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting	56.00%
Return on rate base	10.70%
Forecast [Member] | San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								100.00%
Weighted return on rate base								7.55%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Capital Structure, Long Term Debt [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								45.25%
Return on rate base								4.59%
Weighted return on rate base								2.08%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Capital Structure, Preferred Stock [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								2.75%
Return on rate base								6.22%
Weighted return on rate base								0.17%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Capital Structure, Common Equity [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								52.00%
Return on rate base								10.20%
Weighted return on rate base								5.30%
Forecast [Member] | Southern California Gas Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								100.00%
Weighted return on rate base								7.30%
Forecast [Member] | Southern California Gas Company [Member] | Capital Structure, Long Term Debt [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								45.60%
Return on rate base								4.23%
Weighted return on rate base								1.93%
Forecast [Member] | Southern California Gas Company [Member] | Capital Structure, Preferred Stock [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								2.40%
Return on rate base								6.00%
Weighted return on rate base								0.14%
Forecast [Member] | Southern California Gas Company [Member] | Capital Structure, Common Equity [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Authorized weighting								52.00%
Return on rate base								10.05%
Weighted return on rate base								5.23%

REGULATORY MATTERS - BILLING PR

REGULATORY MATTERS - BILLING PRACTICES (Details) - USD ($)	1 Months Ended		12 Months Ended
	May 31, 2019	Jan. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jul. 31, 2018
Public Utilities, General Disclosures [Line Items]
Penalties Expense			$ 8,000,000	$ 0	$ 0
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Penalties Expense		$ 8,000,000	$ 8,000,000	0	$ 0
Penalties Payable		3,000,000
Penalties Credited to Customers		$ 5,000,000
Days Customers Bills Were Delayed		45 days
Penalty Credit Per Customer	$ 100	$ 100
Sempra Mexico [Member]
Public Utilities, General Disclosures [Line Items]
Regulatory assets				$ 5,000,000		$ 7,000,000

ACQUISTIONS, DIVESTITURES AND_3

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Sempra Texas Utility (Details) - USD ($) $ / shares in Units, $ in Millions

May 17, 2019

May 16, 2019

Mar. 09, 2018

Mar. 08, 2018

Feb. 29, 2020

Jan. 31, 2018

Dec. 31, 2019

Sep. 30, 2019

Jun. 30, 2018

Mar. 31, 2018

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Business Acquisition [Line Items]

Repayments of debt

$ 800

Issuances of common stock, net

$ 1,830

$ 2,272

$ 47

Oncor Electric Delivery Company LLC [Member]

Business Acquisition [Line Items]

Acquired percentage interest

80.25%

Sempra Texas Holdings Corp [Member]

Business Acquisition [Line Items]

Proceeds from issuance of debt and equity

$ 7,000

Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC [Member]

Business Acquisition [Line Items]

Acquired percentage interest

80.03%

Oncor Electric Delivery Holdings Company LLC [Member]

Business Acquisition [Line Items]

Total purchase price paid

$ 9,568

Sharyland Holdings, LP [Member]

Business Acquisition [Line Items]

Acquired percentage interest

50.00%

Total purchase price paid

$ 95

Post closing adjustments

$ 7

Sempra Texas Intermediate Holding Company LLC [Member] | Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Holdings Company LLC [Member]

Business Acquisition [Line Items]

Ownership percentage in consolidated entity

100.00%

Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Oncor Electric Delivery Company LLC [Member]

Business Acquisition [Line Items]

Ownership percentage in consolidated entity

0.22%

Acquired percentage interest

0.22%

Cash consideration (fair value of total consideration)

$ 26

Total purchase price paid

26

Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Holdings Corp [Member]

Business Acquisition [Line Items]

Cash consideration (fair value of total consideration)

9,450

Additional consideration transferred

31

Transaction costs incurred

$ 59

Oncor Electric Delivery Holdings Company LLC [Member] | InfraREIT Acquisition [Member]

Business Acquisition [Line Items]

Acquired percentage interest

100.00%

Total purchase price paid

$ 1,275

Share price (USD per share)

$ 21

Management agreement termination fee

$ 40

Debt assumed

$ 953

Repayments of assumed debt

602

Repayments of secured debt

$ 351

Oncor Electric Delivery Holdings Company LLC [Member] | InfraREIT Partners [Member]

Business Acquisition [Line Items]

Acquired percentage interest

100.00%

Sharyland Holdings, LP [Member] | Sharyland Holdings, LP [Member] | Sharyland Utilities [Member]

Business Acquisition [Line Items]

Acquired percentage interest

100.00%

Settlement of Forward Sale Contracts [Member] | Common Stock [Member]

Business Acquisition [Line Items]

Issuances of common stock, net

$ 900

$ 1,066

$ 728

$ 800

$ 900

Payments of stock issuance costs

$ 16

$ 18

$ 13

$ 14

$ 16

Shares issued (in shares)

8,556,630

9,750,000

7,156,185

7,651,671

8,556,630

Commercial paper [Member] | Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Holdings Corp [Member]

Business Acquisition [Line Items]

Proceeds from issuance of debt

$ 2,600

Weighted average term, of line of credit

47 days

Weighted average rate

2.20%

Oncor Electric Delivery Holdings Company LLC [Member]

Business Acquisition [Line Items]

Capital contributions to investees

$ 1,330

Subsequent Event [Member] | TTI [Member]

Business Acquisition [Line Items]

Ownership percentage in consolidated entity

100.00%

Subsequent Event [Member] | Oncor Electric Delivery Company LLC [Member]

Business Acquisition [Line Items]

Ownership percentage in consolidated entity

19.75%

Ownership percentage held by noncontrolling owners

80.45%

Subsequent Event [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | TTHC [Member]

Business Acquisition [Line Items]

Additional interest acquired (as a percent)

1.00%

Subsequent Event [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Electric Delivery Company LLC Additional Acquisition [Member] | Oncor Electric Delivery Company LLC [Member]

Business Acquisition [Line Items]

Acquired percentage interest

0.20%

Cash consideration (fair value of total consideration)

$ 23

Notes receivable acquired

$ 5.5

ACQUISTIONS, DIVESTITURES AND_4

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Schedule of Purchase Price Allocation (Details) - Oncor Electric Delivery Holdings Company LLC [Member] - USD ($) $ in Millions	Mar. 09, 2018	Dec. 31, 2018
Assets acquired:
Accounts receivable	$ 1
Due from unconsolidated affiliates	46
Investment in Oncor Holdings	9,227
Deferred income taxes	287
Other noncurrent assets	109
Total assets acquired	9,670
Liabilities assumed:
Other current liabilities	23
Pension and other postretirement benefit plan obligations	21
Deferred credits and other	58
Total liabilities assumed	102
Net assets acquired	9,568
Total purchase price paid	$ 9,568
Scenario, Adjustment [Member]
Assets acquired:
Investment in Oncor Holdings		$ 64
Deferred income taxes		66
Liabilities assumed:
Deferred credits and other		2
Total purchase price paid		$ 2

ACQUISTIONS, DIVESTITURES AND_5

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Sempra Mexico (Details) - USD ($) $ in Millions	Nov. 15, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Nov. 14, 2017
Business Acquisition [Line Items]
Cash paid, net of cash and cash equivalents acquired		$ 0	$ 9,568	$ 147
IEnova [Member] | Sempra Mexico [Member] | Ductos Energéticos del Norte [Member]
Business Acquisition [Line Items]
Acquired percentage interest	50.00%
Ownership percentage before acquisition					50.00%
Cash paid, net of cash and cash equivalents acquired	$ 165
Cash acquired from acquisition	18
Debt assumed	$ 96
Ownership percentage in consolidated entity	100.00%
Ownership percentage in equity method investee					50.00%
Other intangible assets	$ 66
Weighted average life of finite-lived intangible acquired	23 years
Ramones Norte Pipeline [Member] | IEnova [Member] | Sempra Mexico [Member] | Ductos Energéticos del Norte [Member]
Business Acquisition [Line Items]
Ownership percentage before acquisition	25.00%				50.00%
Ownership percentage in consolidated entity	50.00%

ACQUISTIONS, DIVESTITURES AND_6

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Sempra Renewables (Details) - Sempra Renewables [Member] - Great Valley Solar [Member] $ in Millions	Jul. 10, 2017USD ($)project
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration) | $	$ 124
Number of projects acquired | project	4

ACQUISTIONS, DIVESTITURES AND_7

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Sempra South American Utilities (Details) - USD ($) $ in Millions	Dec. 18, 2018	Dec. 31, 2019	Dec. 31, 2018
Business Acquisition [Line Items]
Goodwill		$ 1,602	$ 1,602
Compania Transmisora del Norte Grande S.A. [Member]
Business Acquisition [Line Items]
Total purchase price paid	$ 226
Cash consideration (fair value of total consideration)	208
Cash and cash equivalents	18
Identifiable assets acquired	231
Liabilities assumed	43
Goodwill	$ 38
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%

ACQUISTIONS, DIVESTITURES AND_8

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Divestitures (Details) - USD ($) $ in Millions	Apr. 22, 2019	Dec. 13, 2018	Apr. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Feb. 07, 2019	Jan. 31, 2019	Jan. 01, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (loss) on deconsolidation		$ 367
Current liabilities				$ 368		$ 444	$ 368
Gain on sale of assets				513		$ 63	513	$ 2
Disposal Group Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset impairment charges					$ 1,500
Asset Impairment Charges, Net of Taxes and Noncontrolling Interests					900
Disposal Group Disposed of by Sale [Member] | Certain Subsidiaries Of Sempra Renewables [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale		1,600
Gain on sale of equity interests		513
Proceeds from sale, net of transaction costs		1,585
Cash		(7)
Restricted cash		(7)
Other current assets		(14)
Property, plant and equipment, net		(1,303)
Other investments		(329)
Other noncurrent assets		(24)
Current liabilities		8
Long-term debt		70
Asset retirement obligations		52
Other noncurrent liabilities		5
Noncontrolling interests		486
Accumulated other comprehensive income		$ (9)
Sempra LNG [Member] | Disposal Group Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset impairment charges				(183)	1,300		1,100
Asset Impairment Charges, Net of Taxes and Noncontrolling Interests				(126)	755		629
Proceeds from sale				$ 5			$ 5
Sempra Renewables [Member] | Disposal Group Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Asset impairment charges					200
Asset Impairment Charges, Net of Taxes and Noncontrolling Interests					$ 145
Sempra Renewables [Member] | Disposal Group Held-for-sale [Member] | Wind Generation Projects [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 569
Gain on sale of assets	61		$ 61
Gain on sale of assets, after tax	$ 45		$ 45
Sempra LNG [Member] | Disposal Group Disposed of by Sale [Member] | Mississippi Hub And Bay Gas [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale									$ 322		$ 332
Sempra LNG [Member] | Disposal Group Disposed of by Sale [Member] | Other Non-Utility assets [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale										$ 5

ACQUISTIONS, DIVESTITURES AND_9

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Discontinued Operations (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Oct. 12, 2019	Sep. 27, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations, net of income tax									$ 363	$ 188	$ (31)
Earnings attributable to noncontrolling interests									(35)	(32)	(27)
(Loss) income from discontinued operations, net of income tax	$ 71	$ 256	$ 78	$ (42)	$ 51	$ 54	$ 55	$ 28	328	156	(58)
Cash, cash equivalents and restricted cash in discontinued operations	75				88				75	88
Noncurrent assets	3,513				3,259				3,513	3,259
Liabilities held for sale in discontinued operations	444				368				444	368
Noncurrent liabilities	1,052				1,013				1,052	1,013
Discontinued Operations, Held-for-sale [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Assets held for sale	445				459				445	459
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]
Proceeds from sale													$ 3,590
Revenues									1,614	1,585	1,567
Cost of sales									(1,012)	(1,041)	(1,060)
Operating expenses									(159)	(206)	(202)
Interest and other									(11)	(6)	(2)
Income before income taxes and equity earnings									432	332	303
Income tax expense									(72)	(145)	(338)
Equity earnings									3	1	4
Income (loss) from discontinued operations, net of income tax									363	188	(31)
(Loss) income from discontinued operations, net of income tax									328	156	$ (58)
Cash and cash equivalents	74				88				74	88
Cash, cash equivalents and restricted cash in discontinued operations	1				0				1	0
Accounts receivable, net	303				315				303	315
Due from unconsolidated affiliates	2				2				2	2
Inventories	36				38				36	38
Other current assets	29				16				29	16
Assets held for sale	445				459				445	459
Due from unconsolidated affiliates	54				44				54	44
Goodwill and other intangible assets	801				819				801	819
Property, plant and equipment, net	2,618				2,357				2,618	2,357
Other noncurrent assets	40				39				40	39
Noncurrent assets	3,513				3,259				3,513	3,259
Short-term debt	52				55				52	55
Accounts payable	201				176				201	176
Current portion of long-term debt and finance leases	85				29				85	29
Other current liabilities	106				108				106	108
Liabilities held for sale in discontinued operations	444				368				444	368
Long-term debt and finance leases	702				708				702	708
Deferred income taxes	284				250				284	250
Other noncurrent liabilities	66				55				66	55
Noncurrent liabilities	1,052				1,013				1,052	1,013
Cumulative foreign currency translation adjustments	$ 551				$ 506				$ 551	$ 506
Chilquinta Energia [Member] | 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]
Ownership interest	100.00%								100.00%			100.00%
Proceeds from sale												$ 2,230
Luz Del Sur [Member] | 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]
Ownership interest	83.60%								83.60%				83.60%
Eletrans [Member] | 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]
Ownership interest												50.00%
Eletrans [Member] | Chilquinta Energia [Member] | 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]
Ownership interest												50.00%
Eletrans [Member] | State Grid International Development Limited [Member] | 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]
Ownership interest												100.00%

INVESTMENTS IN UNCONSOLIDATED_3

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 11,519	$ 9,652
Other investments	2,103	2,320
Goodwill	1,602	1,602
Equity earnings, before income tax	30	(236)	$ 34
Equity earnings (losses), net of tax	550	411	38
Total equity earnings	580	175	72
Distributions from investments	256	212	65
Cameron LNG Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount of equity method investment and underlying equity	263	246
Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Other investments	2,097	2,309
Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Other investments	6	11
Sempra Texas Intermediate Holding Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	$ 246	$ 149	0
Sempra Texas Intermediate Holding Company LLC [Member] | Sharyland Holdings, LP [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	0.00%
Equity method investment	$ 100	$ 0
Difference between carrying amount of equity method investment and underlying equity	42
Equity earnings, before income tax	$ 2	$ 0	0
Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Electric Delivery Holdings Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100.00%	100.00%
Equity method investment	$ 11,519	$ 9,652
Difference between carrying amount of equity method investment and underlying equity	2,823	2,814
Goodwill	2,868	2,868
Equity method investment, difference between carrying amount and underlying equity, aoci	69	69
Equity method investment, difference between carrying amount and underlying equity, tax sharing liability	114	123
Equity earnings (losses), net of tax	526	371	0
Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	2	0	0
Sempra Mexico [Member] | Ductos Energéticos del Norte [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings (losses), net of tax	$ 0	$ 0	(13)
Sempra Mexico [Member] | Energia Sierra Juarez Wind Project [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%
Other investments	$ 39	$ 43
Difference between carrying amount of equity method investment and underlying equity	12	12
Equity earnings (losses), net of tax	$ 2	$ 2	0
Sempra Mexico [Member] | IMG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	40.00%	40.00%
Other investments	$ 337	$ 328
Difference between carrying amount of equity method investment and underlying equity	5	5
Equity earnings (losses), net of tax	$ 9	$ 29	45
Sempra Mexico [Member] | TAG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%
Other investments	$ 365	$ 376
Difference between carrying amount of equity method investment and underlying equity	130	130
Equity earnings (losses), net of tax	13	9	6
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	1	63	65
Sempra Renewables [Member] | California Solar Partnership [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	8	7
Sempra Renewables [Member] | Copper Mountain Solar 3 [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	8	8
Sempra Renewables [Member] | Broken Bow 2 Wind [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	$ 0	$ (2)	(2)
Sempra Renewables [Member] | Cedar Creek 2 Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%
Other investments	$ 0	$ 69
Equity earnings, before income tax	$ 0	$ (1)	(2)
Sempra Renewables [Member] | Flat Ridge 2 Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%
Other investments	$ 0	$ 82
Other than temporary impairment in investment		169
Equity earnings, before income tax	$ (3)	$ (178)	(13)
Sempra Renewables [Member] | Fowler Ridge 2 Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%
Other investments	$ 0	$ 45
Equity earnings, before income tax	$ 5	$ 3	4
Sempra Renewables [Member] | Mehoopany Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%
Other investments	$ 0	$ 57
Other than temporary impairment in investment		31
Equity earnings, before income tax	1	(30)	(1)
Sempra Renewables [Member] | Copper Mountain Solar 2 [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	5	5
Sempra Renewables [Member] | Mesquite Solar 1 [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	$ 0	$ 18	18
Sempra Renewables [Member] | Auwahi Wind [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%
Other investments	$ 0	$ 38
Equity earnings, before income tax	0	3	5
Sempra Renewables [Member] | Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	$ 2	$ (3)	0
Sempra LNG [Member] | Cameron LNG Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.20%	50.20%
Other investments	$ 1,256	$ 1,271
Equity earnings, before income tax	24	0	5
Sempra Energy and Other [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	7	0	0
Sempra Energy and Other [Member] | R B S Sempra Commodities [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	(67)	0
Sempra Energy and Other [Member] | Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	$ (1)	$ 0	$ 0

INVESTMENTS IN UNCONSOLIDATED_4

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details) $ in Millions	May 16, 2019USD ($)	Mar. 09, 2018	Nov. 15, 2017	Dec. 31, 2019USD ($)MTBcf	Sep. 30, 2018USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2019USD ($)MTBcf	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Nov. 14, 2017	Jun. 30, 2015USD ($)	Nov. 30, 2014USD ($)	Oct. 01, 2014USD ($)
Schedule of Equity Method Investments [Line Items]
Undistributed earnings of equity method investments				$ 634			$ 634	$ 332
Undistributed earnings, equity method investments, over 50 percent owned				501			501
Interest costs capitalized							183	$ 193	$ 247
Fair value at origin guarantee obligation associated with cash flow requirements				3			3						$ 82
Oncor Electric Delivery Holdings Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Cash contributed to fund the acquisition				$ 1,067			$ 1,067
R B S Sempra Commodities [Member]
Schedule of Equity Method Investments [Line Items]
Other than temporary impairment					$ 65
Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee				50.20%			50.20%
Threshold for canceling of hedge, Percent of unamortized principal							50.00%
Indirect economic and beneficial and ownership interest prior to financial completion				37.65%			37.65%
Indirect economic and beneficial and ownership interest after financial completion				10.00%			10.00%
Cameron LNG [Member] | Other Long Term Debt, Due July 2030 [Member]
Schedule of Equity Method Investments [Line Items]
Maximum exposure percentage				50.20%			50.20%
Debt instrument, maximum borrowing amount				$ 4,000			$ 4,000
Maximum exposure, remaining percentage				49.80%			49.80%
Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Electric Delivery Holdings Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee				100.00%			100.00%	100.00%
Sempra Mexico [Member] | IMG [Member]
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments								$ 80	72
Ownership percentage in equity method investee				40.00%			40.00%
Transportation service contract term							35 years
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments								5
Sempra Renewables [Member] | Wind Investments [Member]
Schedule of Equity Method Investments [Line Items]
Other than temporary impairment								200
Sempra LNG [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments							$ 77	228	1
Ownership percentage in equity method investee				50.20%			50.20%
Project capacity | MT				13.9			13.9
Proved undeveloped reserve | MT				12			12
Proved undeveloped reserve per day | Bcf				1.7			1.7
Interest costs capitalized							$ 33	47	$ 47
Debt amount				$ 7,400			$ 7,400
Debt instrument converted				$ 3,000
Fixed percentage interest rate				3.39%			3.39%
Term of contract							15 years 4 months 24 days
Percentage of debt hedged by interest rate derivatives				50.00%			50.00%
Notional amount of derivatives											$ 1,500	$ 3,700
Derivative amount terminated				$ 790
Effective fixed rate (as a percent)				3.26%
Weighted-average all-in cost of loans outstanding (as a percent)				3.72%
Sempra LNG [Member] | LIBOR [Member] | Cameron LNG [Member]
Schedule of Equity Method Investments [Line Items]
Fixed percentage interest rate											3.32%	3.19%
Weighted average rate prior to project completion				0.98%			0.98%
Weighted average rate after project completion				1.22%			1.22%
Sharyland Holdings, LP [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest	50.00%
Payments to acquire equity method investments	$ 95						$ 3
Post-closing adjustments	$ 7
Sharyland Holdings, LP [Member] | Sharyland Utilities [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest	100.00%
Ductos Energéticos del Norte [Member] | Sempra Mexico [Member] | IEnova [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity			100.00%
Acquired percentage interest			50.00%
Ownership percentage in equity method investee										50.00%
Oncor Electric Delivery Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest		80.25%
Oncor Electric Delivery Company LLC [Member] | Sempra Texas Holdings Corp [Member]
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest		80.03%
Oncor Electric Delivery Holdings Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments							1,587	230
Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Holdings Corp [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity		100.00%
Sempra Energy [Member] | Oncor Electric Delivery Holdings Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Dividends						$ 246		149
Payments from tax sharing arrangements							$ 10	$ 18
Ramones Norte Pipeline [Member] | Ductos Energéticos del Norte [Member] | Sempra Mexico [Member] | IEnova [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity			50.00%

INVESTMENTS IN UNCONSOLIDATED_5

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	Nov. 15, 2017	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 13, 2018	Nov. 14, 2017
Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Gross revenue			$ 798	$ 706	$ 833
Operating expense			(372)	(609)	(585)
Income from operations			426	97	248
Interest expense			(401)	(322)	(219)
Net income/earnings			85	(36)	$ 108
Current assets		$ 564	1,124	564
Noncurrent assets		14,558	15,039	14,558
Current liabilities		801	1,232	801
Noncurrent liabilities		9,966	11,438	9,966
Oncor Electric Delivery Holdings Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Gross revenue		3,347	4,347
Operating expense		(2,434)	(3,135)
Income from operations		913	1,212
Interest expense		(285)	(375)
Income tax expense		(119)	(131)
Net income/earnings		455	643
Noncontrolling interest held by TTI		(94)	(129)
Earnings attributable to Sempra Energy		360	514
Current assets		772	913	772
Noncurrent assets		21,980	26,012	21,980
Current liabilities		2,217	1,626	2,217
Noncurrent liabilities		11,756	14,125	11,756
Noncontrolling Interest held by TTI		$ 1,951	$ 2,473	$ 1,951
Sempra Renewables [Member] | Broken Bow 2 Wind [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee						50.00%
IEnova [Member] | Ductos Energéticos del Norte [Member] | Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee							50.00%
Ownership percentage before acquisition							50.00%
Acquired percentage interest	50.00%
Ownership percentage in consolidated entity	100.00%

DEBT AND CREDIT FACILITIES - NA

DEBT AND CREDIT FACILITIES - NARRATIVE (Details)	Aug. 14, 2019USD ($)	Jan. 12, 2018	Jan. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Jun. 30, 2019USD ($)	May 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2019USD ($)lender	Nov. 30, 2019USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding				$ 647,000,000				$ 647,000,000
Unsecured debt				11,600,000,000				11,600,000,000
Callable long-term debt, not subject to make-whole provisions				1,946,000,000				1,946,000,000
Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount, Per Note					$ 25
Junior Subordinated Debt [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Stated percentage rate					5.75%
Debt amount					$ 758,000,000
Proceeds from Debt, Net of Issuance Costs					733,000,000
Debt Issuance Costs, Gross					$ 25,000,000
Otay Mesa VIE [Member] | Variable-Rate Loan. Due August 2024 [Member]
Debt Instrument [Line Items]
Proceeds from (Repayments of) Debt	$ (211,000,000)
Sempra Mexico [Member] | IEnova Loan Agreement [Member]
Debt Instrument [Line Items]
Proceeds from Debt, Net of Issuance Costs				190,000,000
Debt Issuance Costs, Gross				$ 10,000,000				10,000,000
Term of contract				15 years
Sempra Mexico [Member] | IEnova Loan Agreement [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Basis spread on variable percentage rate				2.25%
Sempra Energy [Member]
Debt Instrument [Line Items]
Total facility				$ 1,250,000,000				1,250,000,000
Available unused credit				$ 1,250,000,000				$ 1,250,000,000
Sempra Energy [Member] | Floating Rate Notes Due Twenty Nineteen [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Basis spread on variable percentage rate		0.25%
Sempra Energy [Member] | Floating Rate Notes Due Twenty Twenty One [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Basis spread on variable percentage rate		0.50%
Sempra U.S. Businesses [Member]
Debt Instrument [Line Items]
Lines of Credit Facility, Number of Lenders | lender								23
Line of Credit Facility, Lenders, Percent of Facility								6.00%
Line Of Credit Facility, Maximum Ratio Of Indebtedness To Total Capitalization				65.00%				65.00%
Total facility				$ 6,685,000,000				$ 6,685,000,000
Available unused credit				$ 4,351,000,000				$ 4,351,000,000
Sempra Energy Consolidated [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding				2.31%			2.99%	2.31%
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Line Of Credit Facility, Maximum Ratio Of Indebtedness To Total Capitalization				65.00%				65.00%
Total facility				$ 750,000,000				$ 750,000,000
Available unused credit				$ 120,000,000				$ 120,000,000
Weighted average interest rate on total short-term debt outstanding				1.86%			2.58%	1.86%
Unsecured debt				$ 9,000,000				$ 9,000,000
Callable long-term debt, not subject to make-whole provisions				4,000,000				4,000,000
First mortgage bonds available for future issuance				1,300,000,000				1,300,000,000
Gross long-term debt				$ 3,800,000,000			$ 3,450,000,000	$ 3,800,000,000
Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Stated percentage rate					3.95%
Southern California Gas Company [Member] | Bonds [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Debt amount					$ 350,000,000
Proceeds from Debt, Net of Issuance Costs					345,000,000
Debt Issuance Costs, Gross					$ 5,000,000
OMEC LLC [Member] | Secured Debt [Member] | December 2018 OMEC Loan Agreement [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Basis spread on variable percentage rate							2.00%
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Line Of Credit Facility, Maximum Ratio Of Indebtedness To Total Capitalization				65.00%				65.00%
Total facility				$ 1,500,000,000				$ 1,500,000,000
Available unused credit				$ 1,420,000,000				$ 1,420,000,000
Weighted average interest rate on total short-term debt outstanding				1.97%			2.97%	1.97%
Callable long-term debt, not subject to make-whole provisions				$ 251,000,000				$ 251,000,000
First mortgage bonds available for future issuance				6,400,000,000				6,400,000,000
Gross long-term debt				5,140,000,000			$ 4,776,000,000	5,140,000,000
San Diego Gas and Electric Company [Member] | Bonds [Member] | FirstMortgageBondsDueJune2049 [Member]
Debt Instrument [Line Items]
Stated percentage rate						4.10%
Debt amount						$ 400,000,000
Proceeds from Debt, Net of Issuance Costs						$ 396,000,000
Debt Issuance Costs, Gross				$ 4,000,000				$ 4,000,000
Derivative Instrument, Interest Rate Hedge Maturity in 2034 [Member]
Debt Instrument [Line Items]
Notional amount of derivative liability									$ 200,000,000
Fixed interest rate after floating to fixed interest rate swaps									4.03%
Subsequent Event [Member] | Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Stated percentage rate			2.55%
Subsequent Event [Member] | Southern California Gas Company [Member] | Bonds [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Debt amount			$ 650,000,000
Proceeds from Debt, Net of Issuance Costs			643,000,000
Debt Issuance Costs, Gross			$ 7,000,000
On Or After October 1, 2024 [Member] | Junior Subordinated Debt [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Price, Percentage					100.00%
Before October 1, 2024, Amended Tax Regulations [Member] | Junior Subordinated Debt [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Price, Percentage					100.00%
Before October 1, 2024, Equity Credit Methodology Update [Member] | Junior Subordinated Debt [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Debt Instrument, Redemption Price, Percentage					102.00%

DEBT AND CREDIT FACILITIES - SU

DEBT AND CREDIT FACILITIES - SUMMARY OF LINES OF CREDIT (Details) - USD ($)	Dec. 31, 2019	Dec. 31, 2018
Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding	$ (2,334,000,000)
Sempra Energy [Member]
Line of Credit Facility [Line Items]
Total facility	1,250,000,000
Available unused credit	1,250,000,000
Committed lines of credit, capacity for issuance of letters of credit	200,000,000
Line of credit, increase limit	500,000,000
Sempra Energy [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Sempra Global [Member]
Line of Credit Facility [Line Items]
Total facility	3,185,000,000
Available unused credit	1,561,000,000
Sempra Global [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding	(1,624,000,000)
Unamortized discount on long-term debt	3,000,000
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Total facility	1,500,000,000
Available unused credit	1,420,000,000
Unamortized discount on long-term debt	12,000,000	$ 12,000,000
San Diego Gas and Electric Company [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding	(80,000,000)
Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Total facility	750,000,000
Available unused credit	120,000,000
Committed lines of credit, capacity for issuance of letters of credit	100,000,000
Line of credit, increase limit	250,000,000
Unamortized discount on long-term debt	7,000,000	$ 6,000,000
Southern California Gas Company [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding	(630,000,000)
Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	1,880,000,000
Line of credit outstanding	(1,174,000,000)
Available unused credit	706,000,000
Foreign Committed Lines of Credit, Due February 2024 [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	1,500,000,000
Line of credit outstanding	(894,000,000)
Available unused credit	606,000,000
Foreign Committed Lines of Credit, Due April 2022 [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	100,000,000
Line of credit outstanding	0
Available unused credit	100,000,000
Foreign Committed Lines of Credit, Due September 2021 [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	280,000,000
Line of credit outstanding	(280,000,000)
Available unused credit	$ 0

DEBT AND CREDIT FACILITIES - SC

DEBT AND CREDIT FACILITIES - SCHEDULE OF LONG-TERM DEBT INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Long-term lease liabilities	$ 1,263
Finance lease obligations	1,289
Current portion of long-term debt	(1,526)	$ (1,644)
Long-term debt and finance leases	20,785	20,903
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Gross long-term debt	5,140	4,776
Long-term lease liabilities	1,250
Long term debt and lease obligations, including current maturities	6,410	6,268
Finance lease obligations	1,270
Current portion of long-term debt	(56)	(81)
Unamortized discount on long-term debt	(12)	(12)
Unamortized debt issuance costs	(36)	(37)
Debt and Lease Obligation	6,306	6,138
Long-term debt and finance leases	6,306	6,138
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due August 2021 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 350	350
Stated percentage rate	3.00%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due February 2022 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 89	125
Stated percentage rate	1.914%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due September 2023 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 450	450
Stated percentage rate	3.60%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due May 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	2.50%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	6.00%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due January And February 2034 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 176	176
Stated percentage rate	5.875%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2035 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	5.35%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due September 2037 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	6.125%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2039 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 75	75
Stated percentage rate	4.00%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2039 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 300	300
Stated percentage rate	6.00%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2040 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	5.35%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due August 2040 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	4.50%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due November 2041 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	3.95%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due April 2042 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	4.30%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2047 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 400	400
Stated percentage rate	3.75%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2048 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 400	400
Stated percentage rate	4.15%
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 15 2049 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 400	0
Stated percentage rate	4.10%
San Diego Gas and Electric Company [Member] | Finance Lease Obligations, Purchased Power Contracts [Member]
Debt Instrument [Line Items]
Long-term lease liabilities	$ 1,255	1,270
San Diego Gas and Electric Company [Member] | Finance Lease Obligations, Other [Member]
Debt Instrument [Line Items]
Long-term lease liabilities	15	2
San Diego Gas and Electric Company [Member] | Other Long-term Debt [Member]
Debt Instrument [Line Items]
Long term debt and lease obligations, including current maturities	1,270	1,492
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Gross long-term debt	3,800	3,450
Long-term lease liabilities	13
Long term debt and lease obligations, including current maturities	3,828	3,462
Finance lease obligations	19	3
Finance lease obligations and other long term debt	28	12
Current portion of long-term debt	(6)	(3)
Unamortized discount on long-term debt	(7)	(6)
Unamortized debt issuance costs	(27)	(26)
Debt and Lease Obligation	3,788	3,427
Long-term debt and finance leases	3,788	3,427
Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	2.60%
Southern California Gas Company [Member] | First Mortgage Bonds, Due September 2024 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	3.15%
Southern California Gas Company [Member] | First Mortgage Bonds Due June 2025 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 350	350
Stated percentage rate	3.20%
Southern California Gas Company [Member] | First Mortgage Bonds, Due November 2035 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	5.75%
Southern California Gas Company [Member] | First Mortgage Bonds, Due November 2040 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 300	300
Stated percentage rate	5.125%
Southern California Gas Company [Member] | First Mortgage Bonds, Due September 2042 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 350	350
Stated percentage rate	3.75%
Southern California Gas Company [Member] | First Mortgage Bonds, Due March 2044 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 250	250
Stated percentage rate	4.45%
Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2048 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 400	400
Stated percentage rate	4.125%
Southern California Gas Company [Member] | First Mortgage Bonds, Due January 2049 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 550	550
Stated percentage rate	4.30%
Southern California Gas Company [Member] | First Mortgage Bonds, Due February 2050 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 350	0
Stated percentage rate	3.95%
Southern California Gas Company [Member] | Other Long-term Debt, Due May 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 4	4
Stated percentage rate	1.875%
Southern California Gas Company [Member] | Other Long-term Debt, Due January 2028 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 5	5
Stated percentage rate	5.67%
Sempra Energy [Member]
Debt Instrument [Line Items]
Build to suit arrangement	$ 0	138
Sempra Energy [Member] | Other Long-term Debt, Due February 2019 [Member]
Debt Instrument [Line Items]
Gross long-term debt	0	$ 500
Stated percentage rate		9.80%
Sempra Energy [Member] | Other Long-term Debt, Due July 2019 [Member]
Debt Instrument [Line Items]
Gross long-term debt	0	$ 500
Sempra Energy [Member] | Other Long-term Debt, October 2019 [Member]
Debt Instrument [Line Items]
Gross long-term debt	0	$ 500
Stated percentage rate		1.625%
Sempra Energy [Member] | Other Long Term Debt Due February 2020 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	$ 500
Stated percentage rate	2.40%
Sempra Energy [Member] | Other Long Term Debt Due March 2020 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	2.40%
Sempra Energy [Member] | Other Long Term Debt, Due November 2020 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 400	400
Stated percentage rate	2.85%
Sempra Energy [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 700	700
Sempra Energy [Member] | Other Long Term Debt, Variable Rate Notes Due March 2021 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 850	850
Fixed interest rate after floating to fixed interest rate swaps	3.069%
Sempra Energy [Member] | Other Long Term Debt, Due October 2022 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	2.875%
Sempra Energy [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	2.90%
Sempra Energy [Member] | Other Long-term Debt, Due December 2023 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	4.05%
Sempra Energy [Member] | Other Long-term Debt, Due June 2024 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 500	500
Stated percentage rate	3.55%
Sempra Energy [Member] | Other Long Term Debt Due November 2025 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 350	350
Stated percentage rate	3.75%
Sempra Energy [Member] | Other Long Term Debt Due June 2027 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 750	750
Stated percentage rate	3.25%
Sempra Energy [Member] | Other Long Term Debt Due February 2028 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 1,000	1,000
Stated percentage rate	3.40%
Sempra Energy [Member] | Other Long Term Debt Due February 2038 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 1,000	1,000
Stated percentage rate	3.80%
Sempra Energy [Member] | Other Long-term Debt, Due October 2039 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 750	750
Stated percentage rate	6.00%
Sempra Energy [Member] | Other Long Term Debt Due February 2048 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 800	800
Stated percentage rate	4.00%
Sempra Energy [Member] | Other Long-term Debt, Junior Subordinated Notes, Due July 2079 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 758	0
Stated percentage rate	5.75%
Sempra Mexico [Member] | Other Long-term Debt, Due January 2028 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Sempra Mexico [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 207	198
Stated percentage rate	6.30%
Fixed interest rate after floating to fixed interest rate swaps	4.12%
Sempra Mexico [Member] | Other Long-Term Debt, Due 2016 Through December 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 237	275
Fixed interest rate after floating to fixed interest rate swaps	4.88%
Sempra Mexico [Member] | Other Long-term Debt, Currently Through January 2028 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 300	300
Sempra Mexico [Member] | Other Long-Term Debt, Payable 2016 Through March 2032 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 423	447
Stated percentage rate	6.87%
Notional amount of derivative liability	$ 147
Long-term debt subject to fixed rate	241
Long-term debt subject to variable rate	$ 35
Sempra Mexico [Member] | Other Long-Term Debt, Payable 2016 Through March 2032 [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Fixed interest rate after floating to fixed interest rate swaps	6.54%
Sempra Mexico [Member] | Other Long-term Debt, Currently Through January 2048 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 540	540
Stated percentage rate	4.875%
Sempra Mexico [Member] | Other Long-term Debt, Currently Through July 2028 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 11	4
Sempra Mexico [Member] | Other Long-Term Debt, Payable 2022 Through November 2034 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 200	0
Fixed interest rate after floating to fixed interest rate swaps	4.0275%
Sempra LNG [Member] | Other Long-term Debt, Currently Through October 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 22	21
Sempra LNG [Member] | Other Long-term Debt, Currently Through October 2026 [Member] | Minimum [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.87%
Sempra LNG [Member] | Other Long-term Debt, Currently Through October 2026 [Member] | Maximum [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.51%
Other Sempra Energy [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 12,298	13,023
Current portion of long-term debt	(1,464)	(1,560)
Unamortized discount on long-term debt	(35)	(38)
Unamortized debt issuance costs	(108)	(87)
Long-term debt and finance leases	$ 10,691	$ 11,338
LIBOR [Member] | Sempra Energy [Member] | Other Long-term Debt, Due July 2019 [Member]
Debt Instrument [Line Items]
Stated percentage rate		2.69%
LIBOR [Member] | Sempra Energy [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.50%
LIBOR [Member] | Sempra Mexico [Member] | Other Long-Term Debt, Payable 2016 Through March 2032 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.12%
LIBOR [Member] | Sempra Mexico [Member] | Other Long-term Debt, Currently Through July 2028 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Otay Mesa VIE [Member]
Debt Instrument [Line Items]
Current portion of long-term debt		$ (28)
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Current portion of long-term debt		(28)
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member] | Otay Mesa Energy Center Loan Payable Currently Through April 2019 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 0	220
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member] | Otay Mesa Energy Center Loan Payable 2019 through 2024 [Member]
Debt Instrument [Line Items]
Notional amount of derivative liability		$ 142
Fixed interest rate after floating to fixed interest rate swaps		5.2925%
Otay Mesa VIE [Member] | LIBOR [Member] | San Diego Gas and Electric Company [Member] | Otay Mesa Energy Center Loan Payable Currently Through April 2019 [Member]
Debt Instrument [Line Items]
Stated percentage rate		4.7896%

DEBT AND CREDIT FACILITIES - MA

DEBT AND CREDIT FACILITIES - MATURITIES OF LONG-TERM DEBT (5 YEAR SCHEDULE) (Details) $ in Millions	Dec. 31, 2019USD ($)
Schedule Of Long Term Debt Maturities [Line Items]
2020	$ 1,501
2021	2,005
2022	594
2023	1,735
2024	1,045
Thereafter	14,367
Total	21,247
San Diego Gas and Electric Company [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2020	36
2021	386
2022	18
2023	450
2024	0
Thereafter	4,250
Total	5,140
Southern California Gas Company [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2020	0
2021	0
2022	0
2023	0
2024	500
Thereafter	3,309
Total	3,809
Other Sempra Energy [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2020	1,465
2021	1,619
2022	576
2023	1,285
2024	545
Thereafter	6,808
Total	$ 12,298

DEBT AND CREDIT FACILITIES - CA

DEBT AND CREDIT FACILITIES - CALLABLE LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2019USD ($)
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	$ 1,946
Callable long-term debt, subject to make-whole provisions	17,786
San Diego Gas and Electric Company [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	251
Callable long-term debt, subject to make-whole provisions	4,889
Southern California Gas Company [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	4
Callable long-term debt, subject to make-whole provisions	3,800
Other Sempra Energy [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	1,691
Callable long-term debt, subject to make-whole provisions	$ 9,097

INCOME TAXES - RECONCILIATION T

INCOME TAXES - RECONCILIATION TO EFFECTIVE TAX RATE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit) from continuing operations	$ 315	$ (49)	$ 938
Income from continuing operations before income taxes and equity earnings	1,734	714	1,248
Equity earnings, before income tax	30	(236)	34
Pretax income	$ 1,764	$ 478	$ 1,282
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	35.00%
Foreign exchange and inflation effects	4.00%	6.00%	4.00%
Non-U.S. earnings taxed at lower statutory income tax rates	3.00%	10.00%	(2.00%)
Depreciation	3.00%	12.00%	7.00%
State income taxes, net of federal income tax benefit	2.00%	(8.00%)	1.00%
Effects of the TCJA	0	0.09	0.48
Compensation-related items	0.00%	3.00%	0.00%
Unrecognized income tax benefits	0.00%	4.00%	0.00%
Noncontrolling interests in tax equity arrangements	0.00%	3.00%	1.00%
Resolution of prior years’ income tax items	0.00%	(1.00%)	(3.00%)
Impairment losses at Sempra LNG	0.00%	(32.00%)	0.00%
Allowance for equity funds used during construction	(1.00%)	(4.00%)	(4.00%)
Amortization of excess deferred income taxes	(1.00%)	(4.00%)	0.00%
Tax credits	(2.00%)	(10.00%)	(4.00%)
Utility self-developed software expenditures	(2.00%)	(7.00%)	(5.00%)
Utility repairs expenditures	(3.00%)	(13.00%)	(7.00%)
Excess deferred income taxes outside of ratemaking	(4.00%)	0.00%	0.00%
Other, net	(2.00%)	1.00%	2.00%
Effective income tax rate	18.00%	(10.00%)	73.00%
San Diego Gas and Electric Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit) from continuing operations	$ 171	$ 173	$ 155
Income from continuing operations before income taxes and equity earnings	945	849	576
Pretax income	$ 945	$ 849	$ 576
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	35.00%
Depreciation	3.00%	3.00%	7.00%
State income taxes, net of federal income tax benefit	6.00%	5.00%	3.00%
Effects of the TCJA	0	0	0.05
Resolution of prior years’ income tax items	0.00%	0.00%	(4.00%)
Allowance for equity funds used during construction	(1.00%)	(2.00%)	(4.00%)
Amortization of excess deferred income taxes	(1.00%)	(1.00%)	0.00%
Utility self-developed software expenditures	(3.00%)	(2.00%)	(6.00%)
Utility repairs expenditures	(3.00%)	(3.00%)	(8.00%)
Excess deferred income taxes outside of ratemaking	(3.00%)	0.00%	0.00%
Other, net	(1.00%)	(1.00%)	(1.00%)
Effective income tax rate	18.00%	20.00%	27.00%
Southern California Gas Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit) from continuing operations	$ 120	$ 92	$ 160
Income from continuing operations before income taxes and equity earnings	762	493	557
Pretax income	$ 762	$ 493	$ 557
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	35.00%
Depreciation	4.00%	7.00%	9.00%
State income taxes, net of federal income tax benefit	4.00%	2.00%	3.00%
Compensation-related items	0.00%	1.00%	0.00%
Unrecognized income tax benefits	0.00%	4.00%	0.00%
Resolution of prior years’ income tax items	0.00%	(1.00%)	(2.00%)
Allowance for equity funds used during construction	(1.00%)	(2.00%)	(3.00%)
Amortization of excess deferred income taxes	(1.00%)	(2.00%)	0.00%
Utility self-developed software expenditures	(2.00%)	(3.00%)	(5.00%)
Utility repairs expenditures	(4.00%)	(7.00%)	(8.00%)
Excess deferred income taxes outside of ratemaking	(5.00%)	0.00%	0.00%
Other, net	0.00%	(1.00%)	0.00%
Effective income tax rate	16.00%	19.00%	29.00%

INCOME TAXES - EFFECTS OF THE T

INCOME TAXES - EFFECTS OF THE TAX CUTS AND JOBS ACT OF 2017 (Details) - USD ($) $ in Millions	11 Months Ended	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		21.00%	21.00%	35.00%
Decrease in net deferred income tax liabilities due to remeasurement			$ 16	$ (2,220)
Increase in net regulatory liabilities from remeasurement of deferred tax income tax assets and liabilities			33	2,402
Income tax expense, related to remeasurement of deferred income tax assets and liabilities			49	182
Income tax expense related to deemed repatriation			(8)	328
U.S. state and non-U.S. withholding tax expense, related to expected future repatriation of foreign earnings				109
Total increase in income tax expense			41	$ 619
Income tax benefit related to outside differences on plans to sell businesses		$ 89
Income tax expense related to increase in outside basis differences	$ 51
Foreign undistributed earnings	4,000	4,000
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested	157	157
Foreign earnings repatriated		$ 254	$ 338
San Diego Gas and Electric Company [Member]
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		21.00%	21.00%	35.00%
Income tax expense recognized in current period, related to remeasurement of deferred income tax assets and liabilities		$ 31
Decrease in net deferred income tax liabilities due to remeasurement			$ (38)	$ (1,400)
Increase in net regulatory liabilities from remeasurement of deferred tax income tax assets and liabilities			38	1,428
Income tax expense, related to remeasurement of deferred income tax assets and liabilities			0	28
Income tax expense related to deemed repatriation			0	0
U.S. state and non-U.S. withholding tax expense, related to expected future repatriation of foreign earnings				0
Total increase in income tax expense			$ 0	$ 28
Southern California Gas Company [Member]
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent		21.00%	21.00%	35.00%
Income tax expense recognized in current period, related to remeasurement of deferred income tax assets and liabilities		$ 38
Decrease in net deferred income tax liabilities due to remeasurement			$ 5	$ (972)
Increase in net regulatory liabilities from remeasurement of deferred tax income tax assets and liabilities			(5)	974
Income tax expense, related to remeasurement of deferred income tax assets and liabilities			0	2
Income tax expense related to deemed repatriation			0	0
U.S. state and non-U.S. withholding tax expense, related to expected future repatriation of foreign earnings				0
Total increase in income tax expense			$ 0	$ 2
Non-U.S. [Member]
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested	$ 600	$ 600

INCOME TAXES - COMPONENTS OF IN

INCOME TAXES - COMPONENTS OF INCOME TAX EXPENSE (BENEFIT) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S.	$ 1,191	$ (102)	$ 878
Non-U.S.	573	580	404
Pretax income	1,764	478	1,282
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	0	(1)	4
U.S. state	(14)	67	0
Non-U.S.	140	127	45
Total	126	193	49
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	87	(121)	566
U.S. state	21	(183)	154
Non-U.S.	84	66	169
Total	192	(238)	889
Deferred investment tax credits	(3)	(4)	0
Total income tax expense (benefit)	315	(49)	938
San Diego Gas and Electric Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	945	849	576
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	35	104	100
U.S. state	31	30	65
Total	66	134	165
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	75	17	29
U.S. state	32	24	(41)
Total	107	41	(12)
Deferred investment tax credits	(2)	(2)	2
Total income tax expense (benefit)	171	173	155
Southern California Gas Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	762	493	557
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	8	4	0
U.S. state	24	10	23
Total	32	14	23
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	79	78	144
U.S. state	10	2	(5)
Total	89	80	139
Deferred investment tax credits	(1)	(2)	(2)
Total income tax expense (benefit)	$ 120	$ 92	$ 160

INCOME TAXES - DEFERRED INCOME

INCOME TAXES - DEFERRED INCOME TAXES (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Deferred income tax assets:
Less: valuation allowances	$ 144	$ 164
Deferred income taxes, noncurrent	155	141
Deferred income taxes	2,577	2,321
Sempra Energy Consolidated [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	4,052	3,517
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	153	382
Regulatory balancing accounts	468	359
Right-of-use assets – operating leases	131	0
Property taxes	44	41
Other deferred income tax liabilities	93	133
Total deferred income tax liabilities	4,941	4,432
Deferred income tax assets:
Tax credits	1,136	1,114
Net operating losses	911	723
Postretirement benefits	200	261
Compensation-related items	161	170
Operating lease liabilities	131	0
Other deferred income tax assets	72	82
Accrued expenses not yet deductible	52	66
Deferred income tax assets before valuation allowances	2,663	2,416
Less: valuation allowances	144	164
Total deferred income tax assets	2,519	2,252
Net deferred income tax liability	2,422	2,180
Deferred income taxes, noncurrent	155	141
Deferred income taxes	2,577	2,321
San Diego Gas and Electric Company [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	1,735	1,578
Regulatory balancing accounts	141	84
Right-of-use assets – operating leases	32	0
Property taxes	30	29
Other deferred income tax liabilities	14	10
Total deferred income tax liabilities	1,952	1,701
Deferred income tax assets:
Tax credits	6	6
Postretirement benefits	37	58
Compensation-related items	6	5
Operating lease liabilities	32	0
Other deferred income tax assets	7	6
Accrued expenses not yet deductible	9	4
State income taxes	7	6
Total deferred income tax assets	104	85
Net deferred income tax liability	1,848	1,616
Deferred income taxes	1,848	1,616
Southern California Gas Company [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	1,246	1,077
Regulatory balancing accounts	327	283
Right-of-use assets – operating leases	22	0
Property taxes	14	13
Other deferred income tax liabilities	1	2
Total deferred income tax liabilities	1,610	1,375
Deferred income tax assets:
Tax credits	3	3
Postretirement benefits	120	140
Compensation-related items	25	25
Operating lease liabilities	22	0
Other deferred income tax assets	14	14
Accrued expenses not yet deductible	15	13
State income taxes	8	3
Total deferred income tax assets	207	198
Net deferred income tax liability	1,403	1,177
Deferred income taxes	$ 1,403	$ 1,177

INCOME TAXES - NET OPERATING LO

INCOME TAXES - NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Operating Loss Carryforwards [Line Items]
Valuation allowances	$ 144	$ 164
U.S. Federal [Member]
Operating Loss Carryforwards [Line Items]
NOLs	3,475
Valuation allowances	90	109
U.S. Federal [Member] | General business tax credits [Member]
Operating Loss Carryforwards [Line Items]
Tax credits	433
U.S. Federal [Member] | Foreign tax credits [Member]
Operating Loss Carryforwards [Line Items]
Tax credits	624
U.S. state [Member]
Operating Loss Carryforwards [Line Items]
NOLs	3,025
Valuation allowances	33	35
U.S. state [Member] | General business tax credits [Member]
Operating Loss Carryforwards [Line Items]
Tax credits	90
Non-U.S. [Member]
Operating Loss Carryforwards [Line Items]
NOLs	115
Valuation allowances	$ 21	$ 20

INCOME TAXES - UNRECOGNIZED TAX

INCOME TAXES - UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	$ 1	$ 1
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0	1	$ 0
Reconciliation of Unrecognized Tax Benefits
Beginning balance	119	89	90
Increase in prior period tax positions	5	7	22
Decrease in prior period tax positions	0	(1)	(15)
Increase in current period tax positions	2	24	4
Settlements with taxing authorities	(32)	0	(12)
Expiration of statutes of limitations	(1)	0	0
Ending balance	93	119	89
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(81)	(107)	(77)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	27	24	20
San Diego Gas and Electric Company [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	0	0
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0	0	0
Reconciliation of Unrecognized Tax Benefits
Beginning balance	11	10	22
Increase in prior period tax positions	1	1	9
Decrease in prior period tax positions	0	0	(11)
Settlements with taxing authorities	0	0	(10)
Ending balance	12	11	10
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(9)	(9)	(7)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	1	1	1
Southern California Gas Company [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits, Income Tax Penalties and Interest Accrued	0	0
Unrecognized Tax Benefits, Income Tax Penalties and Interest Expense	0	0	0
Reconciliation of Unrecognized Tax Benefits
Beginning balance	61	35	29
Increase in prior period tax positions	1	2	3
Increase in current period tax positions	2	24	4
Increase Resulting from Settlements with Taxing Authorities	0
Settlements with taxing authorities		0	(1)
Ending balance	64	61	35
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(55)	(51)	(26)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	$ 26	$ 23	$ 20

INCOME TAXES - CHANGES IN UNREC

INCOME TAXES - CHANGES IN UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ (8)	$ (41)	$ (8)
Expiration of statutes of limitations on tax assessments [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	0	(1)	0
Potential resolution of audit issues with various U.S. federal, state, and local non-U.S. taxing authorities [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	(8)	(40)	(8)
Potential resolution of audit issues with various U.S. federal, state, and local non-U.S. taxing authorities [Member] | San Diego Gas and Electric Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	(6)	(6)	(6)
Potential resolution of audit issues with various U.S. federal, state, and local non-U.S. taxing authorities [Member] | Southern California Gas Company [Member]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ (2)	$ (2)	$ (2)

EMPLOYEE BENEFIT PLANS - NARRAT

EMPLOYEE BENEFIT PLANS - NARRATIVE (Details) - USD ($) $ in Thousands	Mar. 09, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Dedicated assets in support of certain benefit plans		$ 488,000	$ 416,000
Benefit obligation payment for settlement			54,000
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments		5,000	12,000
Benefit obligation payment for settlement				$ 38,000
Plan assets, payment for settlement		177,000	394,000
Increase due to business combination		0	0
Settlement charges		28,000	12,000	8,000
Increase in liability due to special termination benefits		0	0
Decrease in defined benefit plan obligation due to settlement		177,000	394,000	194,000
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments		0	0
Plan assets, payment for settlement		2,000	0
Increase due to business combination		0	21,000
Settlement charges		0	0	0
Increase in liability due to special termination benefits		0	5,000	18,000
Decrease in defined benefit plan obligation due to settlement		2,000	0
San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments		3,000	8,000
Plan assets, payment for settlement		39,000	145,000
Settlement charges		0	4,000	0
Increase in liability due to special termination benefits		0	0
Decrease in defined benefit plan obligation due to settlement		39,000	145,000
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments		0	0
Plan assets, payment for settlement		0	0
Settlement charges		0	0	0
Increase in liability due to special termination benefits		0	3,000
Decrease in defined benefit plan obligation due to settlement		0	0
Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments		2,000	0
Benefit obligation payment for settlement				30,000
Plan assets, payment for settlement		65,000	231,000
Increase in liability due to special termination benefits		0	0
Decrease in defined benefit plan obligation due to settlement		65,000	231,000	175,000
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments		0	0
Plan assets, payment for settlement		0	0
Increase in liability due to special termination benefits		0	2,000	18,000
Decrease in defined benefit plan obligation due to settlement		0	0
Qualified Plan [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Decrease in defined benefit plan obligation due to settlement			363,000
Qualified Plan [Member] | San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement			22,000
Decrease in defined benefit plan obligation due to settlement			132,000
Qualified Plan [Member] | Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement			32,000
Decrease in defined benefit plan obligation due to settlement			231,000
Nonqualified Plan [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement		24,000	12,000	$ 8,000
Nonqualified Plan [Member] | San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement			4,000
Sempra Texas Holdings Corp [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Increase due to business combination	$ 21,000
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC [Member] | Sempra Texas Intermediate Holding Company LLC [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Gain (loss) arising during the period		$ (27,000)	(27,000)
Voluntary Retirement Enhancement Program [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Settlement charges			$ 100,000

EMPLOYEE BENEFIT PLANS - EMPLOY

EMPLOYEE BENEFIT PLANS - EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (1,067)	$ (1,143)
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Expected return on plan assets	7.00%
Pension Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 3,339	3,841
Service cost	110	124	$ 117
Interest cost	139	140	150
Contributions from plan participants	0	0
Actuarial loss (gain)	445	(271)
Plan amendments	5	12
Benefit payments	(93)	(113)
Special termination benefits	0	0
Acquisition	0	0
Settlements	(177)	(394)	(194)
Net obligation at December 31	3,768	3,339	3,841
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	2,160	2,659
Actual return on plan assets	496	(180)
Employer contributions	276	188
Contributions from plan participants	0	0
Benefit payments	(93)	(113)
Settlements	(177)	(394)
Net recorded (liability) asset at December 31	2,662	2,160	2,659
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(1,106)	(1,179)
Net recorded (liability) asset at December 31	(1,106)	(1,179)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0
Current liabilities	(59)	(62)
Noncurrent liabilities	(1,047)	(1,117)
Net recorded (liability) asset	(1,106)	(1,179)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(113)	(114)
Prior service cost	(14)	(12)
Total	(127)	(126)
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	3,578	3,130
Accumulated benefit obligation	3,229	2,894
Fair value of plan assets	2,662	2,160
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	110	124	117
Interest cost	139	140	150
Expected return on assets	(144)	(157)	(161)
Amortization of Prior service cost (credit)	12	11	11
Amortization of actuarial loss (gain)	36	22	35
Settlement charges	28	66	38
Special termination benefits	0	0	0
Net periodic benefit cost	181	206	190
Regulatory adjustment	77	(30)	(42)
Total expense recognized	258	176	148
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	17	56	0
Prior service cost	5	12	1
Amortization of actuarial loss	(13)	(12)	(10)
Amortization of prior service cost	(3)	(2)	(1)
Settlements	(28)	(12)	(8)
Total recognized in OCI	(22)	42	(18)
Total recognized in net periodic benefit cost and OCI	$ 236	$ 218	$ 130
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.49%	4.29%
Interest crediting rate	2.28%	3.36%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	4.29%	3.64%	4.07%
Expected return on plan assets	7.00%	7.00%	7.00%
Interest crediting rate	3.36%	2.80%	2.86%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 268
EXPECTED BENEFIT PAYMENTS
2020	410
2021	263
2022	258
2023	243
2024	239
2025-2029	$ 1,128
Pension Plan [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
Pension Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.00%	2.00%	2.00%
Other Postretirement Benefits Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 868	$ 959
Service cost	17	21	$ 21
Interest cost	36	36	39
Contributions from plan participants	21	23
Actuarial loss (gain)	45	(123)
Plan amendments	0	0
Benefit payments	(72)	(74)
Special termination benefits	0	5	18
Acquisition	0	21
Settlements	(2)	0
Net obligation at December 31	913	868	959
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,108	1,209
Actual return on plan assets	218	(56)
Employer contributions	8	6
Contributions from plan participants	21	23
Benefit payments	(72)	(74)
Settlements	(2)	0
Net recorded (liability) asset at December 31	1,281	1,108	1,209
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	368	240
Net recorded (liability) asset at December 31	368	240
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	391	272
Current liabilities	(3)	(6)
Noncurrent liabilities	(20)	(26)
Net recorded (liability) asset	368	240
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	10	8
Prior service cost	0	0
Total	10	8
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	17	21	21
Interest cost	36	36	39
Expected return on assets	(71)	(70)	(66)
Amortization of Prior service cost (credit)	0	1	1
Amortization of actuarial loss (gain)	(10)	(6)	(4)
Settlement charges	0	0	0
Special termination benefits	0	5	18
Net periodic benefit cost	(28)	(13)	9
Regulatory adjustment	29	17	0
Total expense recognized	1	4	9
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	(3)	(4)	(2)
Prior service cost	0	0	0
Amortization of actuarial loss	0	0	0
Amortization of prior service cost	0	0	0
Settlements	0	0	0
Total recognized in OCI	(3)	(4)	(2)
Total recognized in net periodic benefit cost and OCI	$ (2)	$ 0	$ 7
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.54%	4.29%
Interest crediting rate	2.28%	3.36%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	4.29%	3.68%	4.18%
Expected return on plan assets	6.48%	6.49%	6.47%
Interest crediting rate	3.36%	2.80%	2.86%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 7
EXPECTED BENEFIT PAYMENTS
2020	50
2021	48
2022	48
2023	48
2024	48
2025-2029	$ 240
Other Postretirement Benefits Plan [Member] | Pre-65Retiree [Member]
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	6.25%	6.50%	7.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	5.00%
Other Postretirement Benefits Plan [Member] | Retiree Aged 65 or Older [Member]
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	4.75%	4.75%	5.00%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.50%	4.50%	4.50%
Other Postretirement Benefits Plan [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
Other Postretirement Benefits Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.00%	2.00%	2.00%
San Diego Gas and Electric Company [Member]
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (153)	$ (212)
San Diego Gas and Electric Company [Member] | Pension Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	814	971
Service cost	30	30	$ 29
Interest cost	34	35	38
Contributions from plan participants	0	0
Actuarial loss (gain)	61	(63)
Plan amendments	3	8
Benefit payments	(18)	(22)
Special termination benefits	0	0
Settlements	(39)	(145)
Transfer of liability from other plans	10	0
Net obligation at December 31	895	814	971
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	600	776
Actual return on plan assets	135	(56)
Employer contributions	52	47
Contributions from plan participants	0	0
Benefit payments	(18)	(22)
Settlements	(39)	(145)
Transfer of assets from other plans	9	0
Net recorded (liability) asset at December 31	739	600	776
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(156)	(214)
Net recorded (liability) asset at December 31	(156)	(214)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0
Current liabilities	(3)	(2)
Noncurrent liabilities	(153)	(212)
Net recorded (liability) asset	(156)	(214)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(9)	(4)
Prior service cost	(7)	(6)
Total	(16)	(10)
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	861	788
Accumulated benefit obligation	818	762
Fair value of plan assets	739	600
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	30	30	29
Interest cost	34	35	38
Expected return on assets	(38)	(47)	(47)
Amortization of Prior service cost (credit)	3	2	1
Amortization of actuarial loss (gain)	11	1	9
Settlement charges	0	26	0
Special termination benefits	0	0	0
Net periodic benefit cost	40	47	30
Regulatory adjustment	14	(8)	(8)
Total expense recognized	54	39	22
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	5	(1)	2
Prior service cost	2	8	0
Amortization of actuarial loss	0	(1)	(1)
Amortization of prior service cost	(1)	0	0
Settlements	0	(4)	0
Total recognized in OCI	6	2	1
Total recognized in net periodic benefit cost and OCI	$ 60	$ 41	$ 23
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.44%	4.29%
Interest crediting rate	2.28%	3.36%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	4.29%	3.64%	4.08%
Expected return on plan assets	7.00%	7.00%	7.00%
Interest crediting rate	3.36%	2.80%	2.86%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 53
EXPECTED BENEFIT PAYMENTS
2020	115
2021	69
2022	64
2023	64
2024	62
2025-2029	$ 283
San Diego Gas and Electric Company [Member] | Pension Plan [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
San Diego Gas and Electric Company [Member] | Pension Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.00%	2.00%	2.00%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 170	$ 185
Service cost	4	5	$ 5
Interest cost	7	7	8
Contributions from plan participants	7	8
Actuarial loss (gain)	7	(17)
Plan amendments	0	0
Benefit payments	(18)	(21)
Special termination benefits	0	3
Settlements	0	0
Transfer of liability from other plans	0	0
Net obligation at December 31	177	170	185
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	172	195
Actual return on plan assets	36	(12)
Employer contributions	0	2
Contributions from plan participants	7	8
Benefit payments	(18)	(21)
Settlements	0	0
Transfer of assets from other plans	0	0
Net recorded (liability) asset at December 31	197	172	195
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	20	2
Net recorded (liability) asset at December 31	20	2
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	20	2
Current liabilities	0	0
Noncurrent liabilities	0	0
Net recorded (liability) asset	20	2
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	4	5	5
Interest cost	7	7	8
Expected return on assets	(11)	(13)	(11)
Amortization of Prior service cost (credit)	2	3	3
Amortization of actuarial loss (gain)	(2)	(3)	0
Settlement charges	0	0	0
Special termination benefits	0	3	0
Net periodic benefit cost	0	2	5
Regulatory adjustment	0	0	0
Total expense recognized	0	2	5
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	0	0	0
Prior service cost	0	0	0
Amortization of actuarial loss	0	0	0
Amortization of prior service cost	0	0	0
Settlements	0	0	0
Total recognized in OCI	0	0	0
Total recognized in net periodic benefit cost and OCI	$ 0	$ 2	$ 5
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.55%	4.30%
Interest crediting rate	2.28%	3.36%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	4.30%	3.65%	4.15%
Expected return on plan assets	6.92%	6.94%	6.91%
Interest crediting rate	3.36%	2.80%	2.86%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2020	10
2021	10
2022	10
2023	10
2024	10
2025-2029	$ 48
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.00%	2.00%	2.00%
Southern California Gas Company [Member] | Pension Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 2,148	$ 2,486
Service cost	68	81	$ 76
Interest cost	91	92	98
Contributions from plan participants	0	0
Actuarial loss (gain)	345	(215)
Plan amendments	2	0
Benefit payments	(59)	(65)
Special termination benefits	0	0
Settlements	(65)	(231)	(175)
Transfer of liability from other plans	(4)	0
Net obligation at December 31	2,526	2,148	2,486
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,385	1,694
Actual return on plan assets	320	(117)
Employer contributions	152	104
Contributions from plan participants	0	0
Benefit payments	(59)	(65)
Settlements	(65)	(231)
Transfer of assets from other plans	4	0
Net recorded (liability) asset at December 31	1,737	1,385	1,694
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(789)	(763)
Net recorded (liability) asset at December 31	(789)	(763)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0
Current liabilities	(4)	(3)
Noncurrent liabilities	(785)	(760)
Net recorded (liability) asset	(789)	(763)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(7)	(6)
Prior service cost	(3)	(2)
Total	(10)	(8)
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	2,505	2,123
Accumulated benefit obligation	2,208	1,919
Fair value of plan assets	1,737	1,385
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	68	81	76
Interest cost	91	92	98
Expected return on assets	(94)	(98)	(103)
Amortization of Prior service cost (credit)	8	8	9
Amortization of actuarial loss (gain)	16	13	19
Settlement charges	0	32	30
Special termination benefits	0	0	0
Net periodic benefit cost	89	128	129
Regulatory adjustment	63	(22)	(34)
Total expense recognized	152	106	95
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	2	1	0
Prior service cost	3	0	0
Transfer of actuarial loss	(4)	0	0
Transfer of prior service cost	(1)	0	0
Amortization of actuarial loss	(1)	0	0
Amortization of prior service cost	0	(1)	(1)
Total recognized in OCI	(1)	0	(1)
Total recognized in net periodic benefit cost and OCI	$ 151	$ 106	$ 94
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.50%	4.30%
Interest crediting rate	2.28%	3.36%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	4.30%	3.65%	4.10%
Expected return on plan assets	7.00%	7.00%	7.00%
Interest crediting rate	3.36%	2.80%	2.86%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 154
EXPECTED BENEFIT PAYMENTS
2020	229
2021	166
2022	162
2023	156
2024	153
2025-2029	$ 725
Southern California Gas Company [Member] | Pension Plan [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
Southern California Gas Company [Member] | Pension Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.00%	2.00%	2.00%
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 646	$ 737
Service cost	12	15	$ 14
Interest cost	27	27	29
Contributions from plan participants	13	14
Actuarial loss (gain)	39	(100)
Plan amendments	0	0
Benefit payments	(49)	(49)
Special termination benefits	0	2	18
Settlements	0	0
Transfer of liability from other plans	0	0
Net obligation at December 31	688	646	737
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	916	993
Actual return on plan assets	178	(43)
Employer contributions	1	1
Contributions from plan participants	13	14
Benefit payments	(49)	(49)
Settlements	0	0
Transfer of assets from other plans	0	0
Net recorded (liability) asset at December 31	1,059	916	993
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	371	270
Net recorded (liability) asset at December 31	371	270
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	371	270
Current liabilities	0	0
Noncurrent liabilities	0	0
Net recorded (liability) asset	371	270
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	12	15	14
Interest cost	27	27	29
Expected return on assets	(58)	(56)	(53)
Amortization of Prior service cost (credit)	(2)	(3)	(3)
Amortization of actuarial loss (gain)	(8)	(2)	(3)
Settlement charges	0	0	0
Special termination benefits	0	2	18
Net periodic benefit cost	(29)	(17)	2
Regulatory adjustment	29	17	0
Total expense recognized	0	0	2
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	0	0	0
Prior service cost	0	0	0
Transfer of actuarial loss	0	0	0
Transfer of prior service cost	0	0	0
Amortization of actuarial loss	0	0	0
Amortization of prior service cost	0	0	0
Total recognized in OCI	0	0	0
Total recognized in net periodic benefit cost and OCI	$ 0	$ 0	$ 2
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.55%	4.30%
Interest crediting rate	2.28%	3.36%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	4.30%	3.70%	4.20%
Expected return on plan assets	6.38%	6.38%	6.37%
Interest crediting rate	3.36%	2.80%	2.86%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2020	35
2021	35
2022	35
2023	35
2024	35
2025-2029	$ 176
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	10.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	10.00%	10.00%	10.00%
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.00%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.00%	2.00%	2.00%
Unfunded Plan [Member] | Pension Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	$ 190	$ 209
Accumulated benefit obligation	158	186
Unfunded Plan [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	16	22
Unfunded Plan [Member] | San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	34	26
Accumulated benefit obligation	27	19
Unfunded Plan [Member] | Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	21	25
Accumulated benefit obligation	17	21
Funded Plan [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	32	30
Fair value of plan assets	$ 25	$ 20
Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	26.00%
Risk Mitigating Assets [Member] | Maximum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Expected return on plan assets	4.00%
Risk Mitigating Assets [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Expected return on plan assets	1.00%
Risk Mitigating Assets [Member] | San Diego Gas and Electric Company [Member]
EXPECTED BENEFIT PAYMENTS
Asset allocations	62.00%
Risk Mitigating Assets [Member] | Southern California Gas Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	75.00%
EXPECTED BENEFIT PAYMENTS
Asset allocations	62.00%
Long Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	18.00%

EMPLOYEE BENEFIT PLANS - PLAN A

EMPLOYEE BENEFIT PLANS - PLAN ASSETS (Details)	12 Months Ended
	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	7.00%
Domestic Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	35.00%
International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	24.00%
Long Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	18.00%
Ultra-long duration government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	8.00%
Defined Benefit Plan, Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	5.00%
Return Seeking Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	5.00%
Real Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	5.00%
Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	74.00%
Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	26.00%
Minimum [Member] | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	5.00%
Minimum [Member] | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	1.00%
Maximum [Member] | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	9.00%
Maximum [Member] | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
San Diego Gas and Electric Company [Member] | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	38.00%
San Diego Gas and Electric Company [Member] | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Asset allocations	62.00%
Southern California Gas Company [Member] | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	25.00%
Asset allocations	38.00%
Southern California Gas Company [Member] | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	75.00%
Asset allocations	62.00%

EMPLOYEE BENEFIT PLANS - FAIR V

EMPLOYEE BENEFIT PLANS - FAIR VALUE OF PLAN ASSETS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 2,662	$ 2,160	$ 2,659
Accounts receivable payable, net	(38)	(21)
Pension Plan [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	17	14
Pension Plan [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	923	727
Pension Plan [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	556	437
Pension Plan [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	96	74
Pension Plan [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	267	226
Pension Plan [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	8
Pension Plan [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	346	311
Pension Plan [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	62	53
Pension Plan [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	1
Pension Plan [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2,278	1,851
Pension Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Investments measured at NAV	417	326
Pension Plan [Member] | Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Investments measured at NAV	5	4
Pension Plan [Member] | Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	17	14
Pension Plan [Member] | Level 1 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	923	727
Pension Plan [Member] | Level 1 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	555	437
Pension Plan [Member] | Level 1 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	96	74
Pension Plan [Member] | Level 1 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	228	197
Pension Plan [Member] | Level 1 [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 1 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 1 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 1 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 1 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,819	1,449
Pension Plan [Member] | Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 2 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 2 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	0
Pension Plan [Member] | Level 2 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Pension Plan [Member] | Level 2 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	39	29
Pension Plan [Member] | Level 2 [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	8
Pension Plan [Member] | Level 2 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	346	311
Pension Plan [Member] | Level 2 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	62	53
Pension Plan [Member] | Level 2 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2	1
Pension Plan [Member] | Level 2 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	459	402
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,281	1,108	1,209
Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	602	547
Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	478	307
San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	739	600	776
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	197	172	195
Accounts receivable payable, net	(2)	(1)
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21	37
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	13	22
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	68	59
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	33	11
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	16
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	3
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	7
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	152	156
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Investments measured at NAV	47	17
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21	37
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	13	22
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	68	59
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	32	10
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	134	129
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	16
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	3
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	8	7
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	18	27
Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,737	1,385	1,694
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,059	916	$ 993
Accounts receivable payable, net	(5)	(4)
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	6
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	78	66
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	48	39
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	52	62
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	288	249
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	11	5
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	309	175
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	40	21
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	75	64
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan, Derivative [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	(4)
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	907	683
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Investments measured at NAV	157	237
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	6
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	78	66
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	48	39
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	52	62
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	267	236
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	1
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Defined Benefit Plan, Derivative [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	(4)
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	452	406
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21	13
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	4
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	309	175
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	40	21
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	75	64
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Defined Benefit Plan, Derivative [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	455	277
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	25	20
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	6
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	4
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	2
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	21	15
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Investments measured at NAV	4	4
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Investments measured at NAV		1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	9	6
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	4
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		0
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	16	12
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0	0
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1	0
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	3	2
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member] | Total investment assets in the fair value hierarchy [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 5	$ 3

EMPLOYEE BENEFIT PLANS - SAVING

EMPLOYEE BENEFIT PLANS - SAVINGS PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 44	$ 43	$ 41
Market value of employer stock held by plan	1,300	1,000
San Diego Gas and Electric Company [Member]
Savings Plan [Line Items]
Employer contributions to defined benefit plan	15	15	14
Southern California Gas Company [Member]
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 24	$ 23	$ 22

SHARE-BASED COMPENSATION - SHAR

SHARE-BASED COMPENSATION - SHARE-BASED COMPENSATION EXPENSE/ OPTIONS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Number of shares available for future grants (in shares)	7,662,352
Number of shares authorized for issuance (in shares)	7,662,352
Share-based compensation expense, before income taxes	$ 66	$ 76	$ 78
Income tax benefit	(18)	(21)	(31)
Capitalized share-based compensation cost	11	10	9
Excess income tax deficiency	4	15	0
Share-based compensation expense, net of taxes	$ 48	$ 55	$ 47
Stock option exercise period (in years)	3 years
Weighted-average fair value for options granted (in dollars per share)	$ 13.20
Stock price volatility (as a percent)	18.63%
Expected term (in years)	5 years 4 months 2 days
Risk-free rate of return (as a percent)	2.49%
Annual dividend yield (as a percent)	3.35%
Common shares under options
Beginning balance (in shares)	56,940
Options grants in period (in shares)	261,075
Exercised (in shares)	(52,540)	(138,861)	(164,454)
Forfeited/canceled (in shares)	(17,898)
Ending balance (in shares)	247,577	56,940
Vested at period end (in shares)	237,236
Exercisable at period end (in shares)	4,400
Weighted- average exercise price
Beginning balance (in dollars per share)	$ 54.63
Granted (in dollars per share)	106.76
Exercised (in dollars per share)	54.52
Forfeited/canceled (in dollars per share)	106.76
Ending balance (in dollars per share)	105.86	$ 54.63
Vested at period end, Weighted- average exercise price (in dollars per share)	105.82
Exercisable at period end, Weighted- average exercise price (in dollars per share)	$ 55.90
Outstanding at period end, Weighted- average remaining contractual term	8 years 10 months 6 days
Vested at period end, Weighted- average remaining contractual term	8 years 10 months 2 days
Exercisable at period end, Weighted- average remaining contractual term	3 days
Outstanding at period end, Aggregate intrinsic value	$ 11
Vested at period end, Aggregate intrinsic value	11
Exercisable at period end, Aggregate intrinsic value	0
Aggregate intrinsic value of options exercised	$ 4	$ 9	$ 9
Weighted average period over which unrecognized compensation cost will be recognized	2 years 10 days
Cash received from exercise of options	$ 3
San Diego Gas and Electric Company [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	10	12	13
Income tax benefit	(3)	(3)	(5)
Capitalized share-based compensation cost	6	6	5
Excess income tax deficiency	1	3	0
Share-based compensation expense, net of taxes	7	9	8
Southern California Gas Company [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	15	16	17
Income tax benefit	(4)	(5)	(7)
Capitalized share-based compensation cost	5	4	4
Excess income tax deficiency	1	2	0
Share-based compensation expense, net of taxes	$ 11	$ 11	$ 10
Share-based Payment Arrangement, Option [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Expiration period	10 years
Awardsgrantedin2019 [Member] | Share-based Payment Arrangement, Option [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awardsgrantedin2019 [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Awardsgrantedin2010andprior [Member] | Share-based Payment Arrangement, Option [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	4 years
Awarded during or after two thousand fifteen [Member] | Performance Shares [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Award vesting rights maximum additional award	100.00%
Award vesting rights, Increase modifier for top quartile	20.00%
Award vesting rights, decrease modifier for bottom quartile	20.00%
Awards Before 2015 [Member] | Performance Shares [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	4 years
Awards Before 2015 [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	4 years
Awards Granted in 2013 and Earlier [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting rights maximum additional award	50.00%
Awarded During Or After Two Thousand and Fourteen [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting rights maximum additional award	100.00%
sre_Awardsbetween2015-2018 [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Minimum [Member] | Restricted Stock Units, Employee Stock Options, or Restricted Stock Awards [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Maximum [Member] | Restricted Stock Units, Employee Stock Options, or Restricted Stock Awards [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	4 years

SHARE-BASED COMPENSATION - RSAs

SHARE-BASED COMPENSATION - RSAs AND RSUs (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free rate of return (as a percent)	2.49%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Maximum Performance Based RSU Target Performance Conditions Exceeded For Awards Granted during or after 2014	100.00%
Weighted average period over which unrecognized compensation cost will be recognized	2 years 10 days
Share-Based Compensation, Restricted Stock Awards And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Stock price volatility	17.74%	17.46%	17.24%
Risk-free rate of return (as a percent)	2.46%	2.00%	1.49%
Share-Based Compensation, Performance Based Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested, beginning of period (in shares)	1,242,169
Granted (in shares)	389,825
Vested (in shares)	(142,820)
Forfeited (in shares)	(402,193)
Nonvested, end of period (in shares)	1,086,981	1,242,169
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 106.11
Weighted average grant date fair value, granted (in dollars per share)	113.54	$ 105.03	$ 110.54
Weighted average grant date fair value, vested (in dollars per share)	100.28
Weighted average grant date fair value, forfeited (in dollars per share)	103.34
Weighted average grant date fair value, end of period (in dollars per share)	$ 109.85	$ 106.11
Expected to vest (in shares)	1,066,375
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 109.89
Share-Based Compensation, Service Based Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Nonvested, beginning of period (in shares)	402,361
Granted (in shares)	260,594
Vested (in shares)	(209,395)
Forfeited (in shares)	(37,773)
Nonvested, end of period (in shares)	415,787	402,361
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 105.01
Weighted average grant date fair value, granted (in dollars per share)	112.50	$ 107.60	$ 101.88
Weighted average grant date fair value, vested (in dollars per share)	102.68
Weighted average grant date fair value, forfeited (in dollars per share)	110.25
Weighted average grant date fair value, end of period (in dollars per share)	$ 119.96	$ 105.01
Expected to vest (in shares)	408,782
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 109.65
Share-Based Compensation, Restricted Stock Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward]
Equity instruments other than options, vested in the period, fair value	$ 36	$ 32	$ 45
Nonvested awards, compensation cost not yet recognized	$ 32
Weighted average period over which unrecognized compensation cost will be recognized	2 years 25 days

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - COMMODITY VOLUMES (Details)	12 Months Ended
	Dec. 31, 2019MWhMMBTU	Dec. 31, 2018MWhMMBTU
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure | MMBTU	32	35
Electric Energy Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure	2	2
Congestion Revenue Rights Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure	48	52
SDG&E [Member] | Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure | MMBTU	37	33
SDG&E [Member] | Electric Energy Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure	2	2
SDG&E [Member] | Congestion Revenue Rights Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure	48	52
SoCalGas [Member] | Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional Amount, Energy Measure | MMBTU	2	0

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - NOTIONALS AMOUNTS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Cross-currency swaps [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 306	$ 306
Other foreign currency derivatives [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	1,796	1,158
Cash Flow Hedging [Member] | Interest rate instruments [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	1,445	594
San Diego Gas and Electric Company [Member] | Cash Flow Hedging [Member] | Interest rate instruments [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 0	$ 142

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - BALANCE SHEET (Details) - USD ($)	Dec. 31, 2019	Dec. 31, 2018
Current assets: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	$ 58,000,000	$ 80,000,000
Additional margin posted for commodity contracts not subject to rate recovery	43,000,000	19,000,000
Additional margin posted for commodity contracts subject to rate recovery	25,000,000	33,000,000
Total	126,000,000	132,000,000
Other assets: Other long-term assets [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	85,000,000	235,000,000
Additional margin posted for commodity contracts not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	85,000,000	235,000,000
Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(53,000,000)	(70,000,000)
Additional margin posted for commodity contracts not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(53,000,000)	(70,000,000)
Deferred credits and other liabilities: Deferred credits and other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(192,000,000)	(218,000,000)
Additional margin posted for commodity contracts not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(192,000,000)	(218,000,000)
Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	0	2,000,000
Designated as Hedging Instrument [Member] | Other assets: Other long-term assets [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	3,000,000	0
Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	(17,000,000)	(3,000,000)
Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	(140,000,000)	(147,000,000)
Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments	41,000,000
Associated offsetting foreign exchange instruments	(20,000,000)
Commodity contracts not subject to rate recovery	34,000,000	153,000,000
Associated offsetting commodity contracts not subject to rate recovery	(32,000,000)	(133,000,000)
Commodity contracts subject to rate recovery	41,000,000	64,000,000
Associated offsetting commodity contracts subject to rate recovery	(6,000,000)	(6,000,000)
Associated cash collateral commodity contracts subject to rate recovery	0	0
Not Designated as Hedging Instrument [Member] | Other assets: Other long-term assets [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments	0
Associated offsetting foreign exchange instruments	0
Commodity contracts not subject to rate recovery	11,000,000	7,000,000
Associated offsetting commodity contracts not subject to rate recovery	(2,000,000)	(3,000,000)
Commodity contracts subject to rate recovery	76,000,000	233,000,000
Associated offsetting commodity contracts subject to rate recovery	(3,000,000)	(2,000,000)
Associated cash collateral commodity contracts subject to rate recovery	0	0
Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments	(20,000,000)
Associated offsetting foreign exchange instruments	20,000,000
Commodity contracts not subject to rate recovery	(41,000,000)	(164,000,000)
Associated offsetting commodity contracts not subject to rate recovery	32,000,000	133,000,000
Commodity contracts subject to rate recovery	(47,000,000)	(42,000,000)
Associated offsetting commodity contracts subject to rate recovery	6,000,000	6,000,000
Associated cash collateral commodity contracts subject to rate recovery	14,000,000	0
Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Foreign exchange instruments	0
Associated offsetting foreign exchange instruments	0
Commodity contracts not subject to rate recovery	(10,000,000)	(6,000,000)
Associated offsetting commodity contracts not subject to rate recovery	2,000,000	3,000,000
Commodity contracts subject to rate recovery	(47,000,000)	(72,000,000)
Associated offsetting commodity contracts subject to rate recovery	3,000,000	2,000,000
Associated cash collateral commodity contracts subject to rate recovery	0	2,000,000
San Diego Gas and Electric Company [Member] | Current assets: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	26,000,000	54,000,000
Additional margin posted for commodity contracts subject to rate recovery	16,000,000	28,000,000
Total	42,000,000	82,000,000
San Diego Gas and Electric Company [Member] | Other assets: Other long-term assets [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	73,000,000	231,000,000
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	73,000,000	231,000,000
San Diego Gas and Electric Company [Member] | Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(23,000,000)	(32,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(23,000,000)	(32,000,000)
San Diego Gas and Electric Company [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(44,000,000)	(68,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(44,000,000)	(68,000,000)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments		0
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Other assets: Other long-term assets [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments		0
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments		(1,000,000)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments		0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current assets: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	30,000,000	60,000,000
Associated offsetting commodity contracts subject to rate recovery	(4,000,000)	(6,000,000)
Associated cash collateral commodity contracts subject to rate recovery	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Other long-term assets [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	76,000,000	233,000,000
Associated offsetting commodity contracts subject to rate recovery	(3,000,000)	(2,000,000)
Associated cash collateral commodity contracts subject to rate recovery	0	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	(41,000,000)	(37,000,000)
Associated offsetting commodity contracts subject to rate recovery	4,000,000	6,000,000
Associated cash collateral commodity contracts subject to rate recovery	14,000,000	0
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	(47,000,000)	(72,000,000)
Associated offsetting commodity contracts subject to rate recovery	3,000,000	2,000,000
Associated cash collateral commodity contracts subject to rate recovery	0	2,000,000
Southern California Gas Company [Member] | Current assets: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	9,000,000	4,000,000
Additional margin posted for commodity contracts subject to rate recovery	9,000,000	5,000,000
Total	18,000,000	9,000,000
Southern California Gas Company [Member] | Other assets: Other long-term assets [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	0	0
Southern California Gas Company [Member] | Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(4,000,000)	(5,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(4,000,000)	(5,000,000)
Southern California Gas Company [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	0	0
Additional margin posted 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]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	11,000,000	4,000,000
Associated offsetting commodity contracts subject to rate recovery	(2,000,000)
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Other assets: Other long-term assets [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	0	0
Associated offsetting commodity contracts subject to rate recovery	0
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	(6,000,000)	(5,000,000)
Associated offsetting commodity contracts subject to rate recovery	2,000,000
Southern California Gas Company [Member] | Not Designated as Hedging Instrument [Member] | Deferred credits and other liabilities: Deferred credits and other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Commodity contracts subject to rate recovery	0	$ 0
Associated offsetting commodity contracts subject to rate recovery	$ 0

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - INCOME STATEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	$ (187)
Pretax (loss) gain reclassified from AOCI into earnings	(11)
Designated as Hedging Instrument [Member] | Interest Expense [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(5)
Pretax (loss) gain reclassified from AOCI into earnings	(3)
Designated as Hedging Instrument [Member] | Other Income, Net [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain reclassified from AOCI into earnings	9
Designated as Hedging Instrument [Member] | Gain on Sale of Assets [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	0
Pretax (loss) gain reclassified from AOCI into earnings	(10)
Designated as Hedging Instrument [Member] | Equity Earnings [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(174)
Pretax (loss) gain reclassified from AOCI into earnings	(5)
Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	0
Pretax (loss) gain reclassified from AOCI into earnings	0
Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(8)
Pretax (loss) gain reclassified from AOCI into earnings	(2)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		$ 68	$ (8)
Pretax gain (loss) reclassified from AOCI into earnings		(13)	(23)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		31	19
Pretax gain (loss) reclassified from AOCI into earnings		0	4
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Other Income, Net [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) reclassified from AOCI into earnings		2	0
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Gain on Sale of Assets [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		0	0
Pretax gain (loss) reclassified from AOCI into earnings		(9)	0
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Equity Earnings [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		41	(34)
Pretax gain (loss) reclassified from AOCI into earnings		(7)	(20)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		0	3
Pretax gain (loss) reclassified from AOCI into earnings		0	(9)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Revenues: Energy-Related Businesses [Member] | Foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		(4)	4
Pretax gain (loss) reclassified from AOCI into earnings		1	2
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(100)	313	117
Not Designated as Hedging Instrument [Member] | Other Income, Net [Member] | Foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	25	3	49
Not Designated as Hedging Instrument [Member] | Revenues: Energy-Related Businesses [Member] | Commodity Contracts Not Subject To Rate Recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	12	26	16
Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity contracts subject to rate recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(140)	279	54
Not Designated as Hedging Instrument [Member] | Cost of Natural Gas [Member] | Commodity contracts subject to rate recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	3	5	(2)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Interest Expense [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(1)
Pretax (loss) gain reclassified from AOCI into earnings	(3)
San Diego Gas and Electric Company [Member] | Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		1	(2)
Pretax gain (loss) reclassified from AOCI into earnings		(7)	(13)
San Diego Gas and Electric Company [Member] | Not Designated as Hedging Instrument [Member] | Cost of Electric Fuel and Purchased Power [Member] | Commodity contracts subject to rate recovery [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(140)	279	54
Southern California Gas Company [Member] | Designated as Hedging Instrument [Member] | Interest Expense [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	0
Pretax (loss) gain reclassified from AOCI into earnings	(1)
Southern California Gas Company [Member] | Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) on derivative recognized in OCI		0	0
Pretax gain (loss) reclassified from AOCI into earnings		(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 Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	$ 3	$ 5	$ (2)

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (26)
Maximum length of time hedged in cash flow hedge	15 years
Equity Method Investee [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum length of time hedged in cash flow hedge	20 years
Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (1)

DERIVATIVE FINANCIAL INSTRUME_8

DERIVATIVE FINANCIAL INSTRUMENTS - CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	$ 21	$ 16
Aggregate fair value of additional collateral	21
Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	4	$ 5
Aggregate fair value of additional collateral	$ 4

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($) $ in Millions	Dec. 31, 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]
Alternative investment	$ 5	$ 10
Fair Value, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	509	411
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	57	53
Nuclear decommissioning trusts - Municipal debt securities	282	269
Nuclear decommissioning trusts - Other debt securities	226	234
Nuclear decommissioning trusts - Total debt securities	565	556
Total nuclear decommissioning trusts	1,074	967
Assets fair value disclosure, total	1,285	1,334
Liabilities fair value disclosure, total	245	288
Fair Value, Recurring [Member] | Interest Rate and Foreign Exchange Instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	24	2
Derivative liability	157	150
Fair Value, Recurring [Member] | Commodity contracts not subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	11	24
Effect of netting and allocation of collateral	43	19
Derivative liability	17	34
Fair Value, Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	108	289
Effect of netting and allocation of collateral	25	33
Derivative liability	85	106
Effect of netting and allocation of collateral	(14)	(2)
Fair Value, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	503	407
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	46	43
Nuclear decommissioning trusts - Municipal debt securities	0	0
Nuclear decommissioning trusts - Other debt securities	0	0
Nuclear decommissioning trusts - Total debt securities	46	43
Total nuclear decommissioning trusts	549	450
Assets fair value disclosure, total	608	499
Liabilities fair value disclosure, total	0	0
Fair Value, 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 asset	0	0
Derivative liability	0	0
Fair Value, 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 asset	0	0
Effect of netting and allocation of collateral	43	19
Derivative liability	0	0
Fair Value, 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 asset	5	2
Effect of netting and allocation of collateral	11	28
Derivative liability	14	2
Effect of netting and allocation of collateral	(14)	(2)
Fair Value, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	6	4
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	11	10
Nuclear decommissioning trusts - Municipal debt securities	282	269
Nuclear decommissioning trusts - Other debt securities	226	234
Nuclear decommissioning trusts - Total debt securities	519	513
Total nuclear decommissioning trusts	525	517
Assets fair value disclosure, total	576	552
Liabilities fair value disclosure, total	178	189
Fair Value, 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 asset	24	2
Derivative liability	157	150
Fair Value, 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 asset	11	24
Effect of netting and allocation of collateral	0	0
Derivative liability	17	34
Fair Value, 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 asset	8	9
Effect of netting and allocation of collateral	8	0
Derivative liability	4	5
Effect of netting and allocation of collateral	0	0
Fair Value, 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 debt securities	0	0
Nuclear decommissioning trusts - Other debt securities	0	0
Nuclear decommissioning trusts - Total debt securities	0	0
Total nuclear decommissioning trusts	0	0
Assets fair value disclosure, total	101	283
Liabilities fair value disclosure, total	67	99
Fair Value, 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 asset	0	0
Derivative liability	0	0
Fair Value, 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 asset	0	0
Effect of netting and allocation of collateral	0	0
Derivative liability	0	0
Fair Value, 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 asset	95	278
Effect of netting and allocation of collateral	6	5
Derivative liability	67	99
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	509	411
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	57	53
Nuclear decommissioning trusts - Municipal debt securities	282	269
Nuclear decommissioning trusts - Other debt securities	226	234
Nuclear decommissioning trusts - Total debt securities	565	556
Total nuclear decommissioning trusts	1,074	967
Assets fair value disclosure, total	1,189	1,280
Liabilities fair value disclosure, total	67	100
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	99	285
Effect of netting and allocation of collateral	16	28
Derivative liability	81	101
Effect of netting and allocation of collateral	(14)	(2)
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability		1
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	503	407
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	46	43
Nuclear decommissioning trusts - Municipal debt securities	0	0
Nuclear decommissioning trusts - Other debt securities	0	0
Nuclear decommissioning trusts - Total debt securities	46	43
Total nuclear decommissioning trusts	549	450
Assets fair value disclosure, total	560	474
Liabilities fair value disclosure, total	0	0
San Diego Gas and Electric Company [Member] | Fair Value, 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 asset	1	1
Effect of netting and allocation of collateral	10	23
Derivative liability	14	2
Effect of netting and allocation of collateral	(14)	(2)
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability		0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nuclear decommissioning trusts - equity securities	6	4
Nuclear decommissioning trusts - Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	11	10
Nuclear decommissioning trusts - Municipal debt securities	282	269
Nuclear decommissioning trusts - Other debt securities	226	234
Nuclear decommissioning trusts - Total debt securities	519	513
Total nuclear decommissioning trusts	525	517
Assets fair value disclosure, total	528	523
Liabilities fair value disclosure, total	0	1
San Diego Gas and Electric Company [Member] | Fair Value, 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 asset	3	6
Effect of netting and allocation of collateral	0	0
Derivative liability	0	0
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability		1
San Diego Gas and Electric Company [Member] | Fair Value, 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 debt securities	0	0
Nuclear decommissioning trusts - Other debt securities	0	0
Nuclear decommissioning trusts - Total debt securities	0	0
Total nuclear decommissioning trusts	0	0
Assets fair value disclosure, total	101	283
Liabilities fair value disclosure, total	67	99
San Diego Gas and Electric Company [Member] | Fair Value, 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 asset	95	278
Effect of netting and allocation of collateral	6	5
Derivative liability	67	99
Effect of netting and allocation of collateral	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member] | Interest rate instruments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability		0
Southern California Gas Company [Member] | Fair Value, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	18	9
Liabilities fair value disclosure, total	4	5
Southern California Gas Company [Member] | Fair Value, Recurring [Member] | Commodity contracts subject to rate recovery [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	9	4
Effect of netting and allocation of collateral	9	5
Derivative liability	4	5
Southern California Gas Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	5	6
Liabilities fair value disclosure, total	0	0
Southern California Gas Company [Member] | Fair Value, 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 asset	4	1
Effect of netting and allocation of collateral	1	5
Derivative liability	0	0
Southern California Gas Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	13	3
Liabilities fair value disclosure, total	4	5
Southern California Gas Company [Member] | Fair Value, 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 asset	5	3
Effect of netting and allocation of collateral	8	0
Derivative liability	4	5
Southern California Gas Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets fair value disclosure, total	0	0
Liabilities fair value disclosure, total	0	0
Southern California Gas Company [Member] | Fair Value, 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 asset	0	0
Effect of netting and allocation of collateral	0	0
Derivative liability	$ 0	$ 0

FAIR VALUE MEASUREMENTS - RECON

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Balance at beginning of period	$ 179,000,000	$ (28,000,000)	$ (74,000,000)
Realized and unrealized gains (losses)	(184,000,000)	209,000,000	34,000,000
Allocated transmission instruments	6,000,000	10,000,000	6,000,000
Settlements	27,000,000	(12,000,000)	6,000,000
Balance at end of period	28,000,000	179,000,000	(28,000,000)
Change in unrealized gains (losses) relating to instruments still held at the end of the period	(139,000,000)	183,000,000	30,000,000
San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Congestion revenue rights, 2020 (price per MWh)	(3.77)
Congestion revenue rights, 2019 (price per MWh)		(8.57)
Congestion revenue rights, 2018 (price per MWh)			(7.25)
San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Congestion revenue rights, 2020 (price per MWh)	6.03
Congestion revenue rights, 2019 (price per MWh)		35.21
Congestion revenue rights, 2018 (price per MWh)			11.99
San Diego Gas and Electric Company [Member] | Median [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Congestion revenue rights, 2020 (price per MWh)	(1.58)
Congestion revenue rights, 2019 (price per MWh)		(2.94)
Congestion revenue rights, 2018 (price per MWh)			$ 0.09
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Market electricity forward price inputs (price per MWh)	21	22.20
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Market electricity forward price inputs (price per MWh)	61.15	76.85
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases, Sales, Issues, Settlements [Abstract]
Market electricity forward price inputs (price per MWh)	$ 37.92	$ 42.69

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	$ 225	$ 206
Finance lease obligations	1,289
Capital lease obligations and build-to-suit		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	742	644
Long-term amounts due to unconsolidated affiliates	195	37
Total long-term debt	21,247	21,340
Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	759	652
Long-term amounts due to unconsolidated affiliates	184	35
Total long-term debt	22,664	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 affiliates	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	759	648
Long-term amounts due to unconsolidated affiliates	184	35
Total long-term debt	22,638	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 affiliates	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	48	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	5,140	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	5,662	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	5,662	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	34	32
Finance lease obligations	19	3
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	4,189	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	4,189	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

FAIR VALUE MEASUREMENTS - NONRE

FAIR VALUE MEASUREMENTS - NONRECURRING FAIR VALUE MEASURES (Details) $ in Millions	Feb. 06, 2019USD ($)	Jun. 25, 2018USD ($)	Dec. 31, 2018USD ($)	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2019USD ($)	Apr. 22, 2019USD ($)	Feb. 07, 2019USD ($)	Jan. 01, 2019USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity method investment			$ 9,652			$ 9,652	$ 11,519
Valuation, Market Approach [Member] | TdM [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of investment					$ 62
% of fair value measurement					100.00%
Range of inputs					100.00%
Valuation, Market Approach [Member] | Non-utility Natural gas Storage Assets [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of investment			$ 337			$ 337
% of fair value measurement			100.00%			100.00%
Range of inputs			100.00%			100.00%
Valuation, Market Approach [Member] | Non-utility Natural gas Storage Assets [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range of inputs		10.00%
Valuation Technique, Discounted Cash Flow [Member] | Non-utility Natural gas Storage Assets [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of investment		$ 190
% of fair value measurement		100.00%
Valuation Technique, Discounted Cash Flow [Member] | Certain U.S. Wind Equity Method Investments [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of investment		$ 145
% of fair value measurement		100.00%
Sempra Mexico [Member] | TdM [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other than temporary impairment in investment					$ 71
Sempra Renewables [Member] | Wind Investments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other than temporary impairment						$ 200
Disposal Group Held-for-sale [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairment charges, net of taxes and noncontrolling interests				$ (900)
Assets, fair value disclosure		$ 145
Asset impairment charges				(1,500)
Disposal Group Held-for-sale [Member] | Sempra Renewables [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairment charges, net of taxes and noncontrolling interests				(145)
Asset impairment charges				(200)
Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Generation Projects [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proceeds from sale								$ 569
Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Investments [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other than temporary impairment						200
Asset impairment charges, net of taxes and noncontrolling interests						(145)
Disposal Group Held-for-sale [Member] | Sempra LNG [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairment charges, net of taxes and noncontrolling interests			$ 126	(755)		(629)
Asset impairment charges			183	$ (1,300)		(1,100)
Proceeds from sale			5			5
Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset impairment charges, net of taxes and noncontrolling interests		(755)
Asset impairment charges		(1,300)
Sempra LNG [Member] | Disposal Group Disposed of by Sale [Member] | Mississippi Hub And Bay Gas [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Proceeds from sale									$ 322	$ 332
Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets held for sale			$ 337			$ 337
Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, fair value disclosure		$ 190
Measurement Input, Commodity Market Price [Member] | Minimum [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Generation Projects [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, measurement input		29
Measurement Input, Commodity Market Price [Member] | Maximum [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Generation Projects [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, measurement input		92
Measurement Input, Storage Rate [Member] | Minimum [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, measurement input		0.06
Measurement Input, Storage Rate [Member] | Maximum [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, measurement input		0.22
Measurement Input, Storage Rate [Member] | Weighted Average [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets, measurement input		0.1
Measurement Input, Discount Rate [Member] | Minimum [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Generation Projects [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range of inputs		8.00%
Measurement Input, Discount Rate [Member] | Maximum [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Generation Projects [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range of inputs		10.00%
Measurement Input, Discount Rate [Member] | Weighted Average [Member] | Fair Value, Nonrecurring [Member] | Disposal Group Held-for-sale [Member] | Sempra Renewables [Member] | Wind Generation Projects [Member] | Valuation Technique, Discounted Cash Flow [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Range of inputs		8.70%
LA Storage [Member] | LA Storage [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Ownership interest		75.40%
Bay Gas [Member] | Sempra LNG [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash consideration (fair value of total consideration)	$ 20
Bay Gas [Member] | Bay Gas [Member] | Disposal Group Held-for-sale [Member] | Sempra LNG [Member] | Non-utility Natural gas Storage Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Ownership interest		90.90%
Bay Gas [Member] | Sempra LNG [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Ownership interest	9.10%

PREFERRED STOCK (Details)

PREFERRED STOCK (Details) $ / shares in Units, $ in Millions	Jul. 13, 2018USD ($)shares$ / sharesRate	Jan. 09, 2018USD ($)shares$ / sharesRate	Dec. 31, 2019USD ($)$ / sharesRateshares	Dec. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			50,000,000	50,000,000
Value of shares issued | $			$ 0	$ 2,258	$ 0
San Diego Gas and Electric Company [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			45,000,000	45,000,000
Number of preferred stock shares outstanding (in shares)			0	0
Sempra Energy [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			50,000,000
Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			11,000,000	11,000,000
Number of preferred stock shares outstanding (in shares)			1,000,000	1,000,000
Series A Preferred Stock [Member]
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)			17,250,000
Series A Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Shares issued (in shares)		17,250,000
Stated percentage rate		6.00%
Conversion price per share (in dollars per share) | $ / shares		$ 100	$ 100
Conversion price per share net of underwriting discount (in dollars per share) | $ / shares		98.20
Liquidation preference (in dollars per share) | $ / shares		$ 100
Value of shares issued | $	$ 565	$ 1,690
Underwriting discount | $	$ 10	$ 32
Threshold appreciation price (in dollars per share) | $ / shares		$ 131.075	$ 131.075
Number of shares issuable		13,200,000
Share dividends issued, percentage of weighted average share price		97.00%
Series B Preferred Stock [Member]
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)			5,750,000
Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Shares issued (in shares)	5,750,000
Stated percentage rate	6.75%
Conversion price per share (in dollars per share) | $ / shares	$ 100		$ 100
Conversion price per share net of underwriting discount (in dollars per share) | $ / shares	98.35
Liquidation preference (in dollars per share) | $ / shares	100
Threshold appreciation price (in dollars per share) | $ / shares	$ 136.500		$ 136.50
Number of shares issuable	4,200,000
Share dividends issued, percentage of weighted average share price	97.00%
So Cal Gas Series Preferred Stock [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			5,000,000
So Cal Gas Series Preferred Stock [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			5,000,000
Preferred stock outstanding | $			$ 22	$ 22
Twenty Five Dollar Par, Six Percent Series [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			1,000,000
Number of preferred stock shares outstanding (in shares)			79,011
Par value (in dollars per share) | $ / shares			$ 25
Preferred stock outstanding | $			$ 3	3
Twenty Five Dollar Par, Six Percent Series A [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)			783,032
Liquidation preference (in dollars per share) | $ / shares			$ 25
Par value (in dollars per share) | $ / shares			$ 25
Preferred stock outstanding | $			$ 19	19
So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member]
Preferred Stock [Line Items]
Preferred stock outstanding held by parent | $			$ (2)	(2)
So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member] | Southern California Gas Company [Member]
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)			50,970
Preferred Stock Of Subsidiaries [Member]
Preferred Stock [Line Items]
Preferred stock outstanding | $			$ 20	$ 20
Minimum [Member] | Series A Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Threshold appreciation price (in dollars per share) | $ / shares		$ 107	$ 107
Shares issuable for each instrument | Rate		76.29%	76.29%
Minimum [Member] | Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Threshold appreciation price (in dollars per share) | $ / shares	$ 113.750		$ 113.75
Shares issuable for each instrument | Rate	73.26%		73.26%
Maximum [Member] | Series A Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Threshold appreciation price (in dollars per share) | $ / shares		$ 131.075	$ 131.075
Shares issuable for each instrument | Rate		93.45%	93.45%
Maximum [Member] | Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Threshold appreciation price (in dollars per share) | $ / shares	$ 136.500		$ 136.50
Shares issuable for each instrument | Rate	87.91%		87.91%
Over-Allotment Option [Member] | Series A Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Shares issued (in shares)		2,250,000
Over-Allotment Option [Member] | Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Shares issued (in shares)	750,000

SEMPRA ENERGY - SHAREHOLDERS'_3

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE - COMMON STOCK OFFERINGS (Details) - USD ($) $ / shares in Units, $ in Millions	Mar. 08, 2018	Jul. 31, 2018	Jan. 31, 2018	Dec. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2019	Sep. 30, 2019
Issuances of common stock, net									$ 1,830	$ 2,272	$ 47
Public Offering [Member] | Common Stock [Member]
Shares issued (in shares)		11,212,500	26,869,158
Price of shares issued (in dollars per share)		$ 113.75	$ 107
Price of shares issued net of underwriting discount (in dollars per share)		$ 111.87	$ 105.07
Issuances of common stock, net												$ 1,200	$ 2,800
Common Stock Forward Sales [Member] | Common Stock [Member]
Shares issued (in shares)		9,750,000	23,364,486
Over-Allotment Option [Member] | Common Stock [Member]
Shares issued (in shares)						1,462,500		3,504,672
Price of shares issued net of underwriting discount (in dollars per share)						$ 111.87		$ 105.07
Issuances of common stock, net						$ 164		$ 367
Payments of stock issuance costs						$ 3		$ 8
Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Shares issued (in shares)	8,556,630			9,750,000	7,156,185		7,651,671	8,556,630
Price of shares issued net of underwriting discount (in dollars per share)				$ 109.33	$ 101.74			$ 105.18	$ 109.33			$ 109.33	$ 101.74
Issuances of common stock, net	$ 900			$ 1,066	$ 728		$ 800	$ 900
Payments of stock issuance costs	$ 16			$ 18	$ 13		$ 14	$ 16
Minimum [Member] | Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Price of shares issued net of underwriting discount (in dollars per share)							$ 104.53
Maximum [Member] | Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Price of shares issued net of underwriting discount (in dollars per share)							$ 104.58

SEMPRA ENERGY - SHAREHOLDERS'_4

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE - EARNINGS (LOSSES) PER COMMON SHARE COMPUTATIONS (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Earnings Per Share [Abstract]
Income from continuing operations, net of income tax									$ 1,999	$ 938	$ 382
Earnings attributable to noncontrolling interests									(129)	(44)	(67)
Mandatory convertible preferred stock dividends									(142)	(125)	0
Preferred dividends of subsidiary									(1)	(1)	(1)
Earnings from continuing operations attributable to common shares									1,727	768	314
Income (loss) from discontinued operations, net of income tax									363	188	(31)
Earnings attributable to noncontrolling interests									(35)	(32)	(27)
Earnings (losses) from discontinued operations attributable to common shares	$ 71	$ 256	$ 78	$ (42)	$ 51	$ 54	$ 55	$ 28	328	156	(58)
Earnings attributable to common shares									$ 2,055	$ 924	$ 256
Weighted-average common shares outstanding for basic EPS (in shares)	284,600,000	277,400,000	275,000,000	274,700,000	274,300,000	273,900,000	265,800,000	257,900,000	277,904,000	268,072,000	251,545,000
Dilutive effect of stock options and RSUs (in shares)									1,585,000	919,000	755,000
Dilutive effect of common shares sold forward (in shares)									2,544,000	861,000	0
Weighted-average number of shares outstanding, diluted (in shares)	288,800,000	295,800,000	279,600,000	277,200,000	296,400,000	275,900,000	265,800,000	259,500,000	282,033,000	269,852,000	252,300,000
Earnings from continuing operations attributable to common shares	$ 1.36	$ 2.04	$ 1.03	$ 1.79	$ 3	$ 0.83	$ (2.29)	$ 1.26	$ 6.22	$ 2.86	$ 1.25
Earnings (losses) from discontinued operations attributable to common shares									1.18	0.59	(0.23)
Basic earnings per common share (in shares)	0.21	0.89	0.26	(0.19)	0.15	0.17	0.18	0.08	7.40	3.45	1.02
Earnings from continuing operations (in dollars per share)	1.34	2	1.01	1.78	2.89	0.82	(2.29)	1.25	6.13	2.84	1.24
Earnings (losses) from discontinued operations (in dollars per share)									1.16	0.58	(0.23)
Diluted earnings per common share (in dollars per share)	$ 0.21	$ 0.84	$ 0.25	$ (0.19)	$ 0.14	$ 0.17	$ 0.18	$ 0.08	$ 7.29	$ 3.42	$ 1.01
Fully vested RSUs included in the computation of EPS									617	641	609

SEMPRA ENERGY - SHAREHOLDERS'_5

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE - ANTIDILUTIVE SECURITIES EXCLUDED FROM COMPUTATION OF EPS (Details) - shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Stock options, RSAs and RSUs [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	80,281	20,814	237,741
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	17,471,375	17,197,035

SEMPRA ENERGY - SHAREHOLDERS'_6

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE - COMMON STOCK ACTIVITY (Details) - $ / shares	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Earnings Per Share [Abstract]
Common stock, shares authorized (in shares)	750,000,000	750,000,000
Common stock par value (in dollars per share)	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares outstanding, January 1	273,769,513	251,358,977	250,152,514
Shares issued under forward sale agreements	16,906,185	21,175,473	0
RSUs vesting	463,012	509,042	362,022
Stock options exercised	52,540	138,861	164,454
Savings plan issuance	475,774	553,036	567,428
Common stock investment plan	199,253	231,242	254,047
Issuance of RSUs held in our Deferred Compensation Plan	59,470	3,357	7,811
Shares repurchased	(212,822)	(200,475)	(149,299)
Common shares outstanding, December 31	291,712,925	273,769,513	251,358,977

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - USD ($) $ in Millions	Mar. 13, 2017	Dec. 31, 2019	Dec. 31, 2018	Dec. 19, 2017
Jointly Owned Utility Plant Interests [Line Items]
Litigation settlement payable	$ 24
Percent of arbitration expenses awarded	95.00%
Settlement payable net of arbitration expense	$ 60
Regulatory asset, current		$ 222	$ 138
Regulatory asset, noncurrent		$ 1,930	1,589
Period of environmental exit		10 years
San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Litigation settlement payable	118
Settlement payable net of arbitration expense	12
Arbitration expense	12
Legal fees	11
Litigation settlement amount allocated to ratepayers and shareholders	$ 1
Regulatory asset threshold to cease rate recovery				$ 152
Regulatory asset, current		$ 209	123
Regulatory asset, noncurrent		$ 440	$ 454
Percentage of environmental exit costs incurred		20.00%
San Diego Gas and Electric Company [Member] | Nuclear Plant Closure [Member]
Jointly Owned Utility Plant Interests [Line Items]
Regulatory asset threshold to cease rate recovery				$ 775
Receivable for nuclear plant closure		$ 86
Regulatory asset, current		38
Regulatory asset, noncurrent		$ 48
San Diego Gas and Electric Company [Member] | San Onofre Nuclear Generating Station (SONGS) [Member]
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage		20.00%
SONGS 1 Decommissioning [Member] | San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 455
SONGS 2 and 3 Decommissioning [Member] | San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount		$ 109

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Debt Securities, Available-for-sale [Line Items]
Cost	$ 729,000,000	$ 731,000,000
Gross unrealized gains	360,000,000	259,000,000
Gross unrealized losses	(7,000,000)	(16,000,000)
Estimated fair value	1,082,000,000	974,000,000
Proceeds from sales	914,000,000	890,000,000	$ 1,314,000,000
Gross realized gains	24,000,000	42,000,000	157,000,000
Gross realized losses	(5,000,000)	(10,000,000)	$ (14,000,000)
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	57,000,000	52,000,000
Gross unrealized gains	0	1,000,000
Gross unrealized losses	0	0
Estimated fair value	57,000,000	53,000,000
Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	270,000,000	266,000,000
Gross unrealized gains	12,000,000	4,000,000
Gross unrealized losses	0	(1,000,000)
Estimated fair value	282,000,000	269,000,000
Other securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	218,000,000	238,000,000
Gross unrealized gains	9,000,000	1,000,000
Gross unrealized losses	(1,000,000)	(5,000,000)
Estimated fair value	226,000,000	234,000,000
Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	545,000,000	556,000,000
Gross unrealized gains	21,000,000	6,000,000
Gross unrealized losses	(1,000,000)	(6,000,000)
Estimated fair value	565,000,000	556,000,000
Equity securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	176,000,000	168,000,000
Gross unrealized gains	339,000,000	253,000,000
Gross unrealized losses	(6,000,000)	(10,000,000)
Estimated fair value	509,000,000	411,000,000
Cash and cash equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	8,000,000	7,000,000
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Estimated fair value	$ 8,000,000	$ 7,000,000

SAN ONOFRE NUCLEAR GENERATING_5

SAN ONOFRE NUCLEAR GENERATING STATION - ASSET RETIREMENT OBLIGATION AND SPENT NUCLEAR FUEL (Details) - San Diego Gas and Electric Company [Member] $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Decommissioning liability	$ 611
Cost study estimate decommissioning escalated	834
2020	89
2021	82
2022	83
2023	63
2024	46
Thereafter	$ 739

SAN ONOFRE NUCLEAR GENERATING_6

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	Dec. 31, 2019USD ($)
Public Utilities, General Disclosures [Line Items]
Maximum required nuclear liability insurance available	$ 450
Maximum secondary financial protection available	110
Maximum nuclear liability loss coverage per incident	560
Federal 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) proof_of_claim in Thousands, £ in Millions

Feb. 21, 2020plaintifflawsuit

Oct. 31, 2018plaintiff

Aug. 31, 2018USD ($)

Jan. 31, 2017lawsuit

Sep. 30, 2016USD ($)

Jun. 30, 2019lawsuit

Sep. 30, 2019proof_of_claim

Dec. 31, 2019USD ($)lawsuit

Dec. 31, 2019GBP (£)

Dec. 31, 2018USD ($)

Dec. 31, 2017USD ($)

Sep. 30, 2018USD ($)

Aug. 31, 2017lawsuit

Oct. 01, 2014USD ($)

Oct. 01, 2014GBP (£)

Loss Contingencies [Line Items]

Write-off of wildfire regulatory asset

$ 0

$ 0

$ 351,000,000

Reserve for Aliso Canyon costs

9,000,000

160,000,000

Sempra Energy [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

68,000,000

San Diego Gas and Electric Company [Member]

Loss Contingencies [Line Items]

Write-off of wildfire regulatory asset

0

0

$ 351,000,000

Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

21,000,000

Recoverable costs through insurance settlement

1,086,000,000

Reserve for Aliso Canyon costs

9,000,000

160,000,000

Energy Future Holdings Corp. [Member]

Loss Contingencies [Line Items]

Proof of claims | proof_of_claim

28

Loss from Catastrophes, 2007 Wildfire [Member] | San Diego Gas and Electric Company [Member]

Loss Contingencies [Line Items]

Write-off of wildfire regulatory asset

351,000,000

Write-off of wildfire regulatory asset net of tax

$ 208,000,000

Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

10,000,000

Net book value Of Aliso Canyon Natural Gas Storage Facility

769,000,000

Recorded estimated costs

$ 1,116,000,000

Percentage of recorded estimated costs allocated to temporary relocation program

51.00%

Reserve for Aliso Canyon costs

$ 9,000,000

Insurance receivable for Aliso Canyon costs

339,000,000

Proceeds from insurance settlement

$ 747,000,000

Shareholder Derivative Complaint [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

5

4

Damages from Product Defects [Member] | Southern California Gas Company [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

HMRC VAT Claim [Member] | R B S Sempra Commodities [Member]

Loss Contingencies [Line Items]

VAT tax claim paid upon appeal

$ 138,000,000

HMRC VAT Claim [Member] | Plaintiffs [Member]

Loss Contingencies [Line Items]

Damages sought

$ 95,000,000

£ 71.5

HMRC VAT Claim [Member] | Parent Company [Member]

Loss Contingencies [Line Items]

VAT tax claim paid upon appeal | £

£ 86

Minimum [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Liability insurance coverage

1,200,000,000

Maximum [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Liability insurance coverage

$ 1,400,000,000

Consolidated Class Action Complaints [Member]

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

2

Property Class Action [Member]

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

1

Complaints Filed by Firefighters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Number of plaintiffs | plaintiff

51

Complaints Filed by Public Entities [Member]

Loss Contingencies [Line Items]

Number of lawsuits | lawsuit

3

R B S Sempra Commodities [Member]

Loss Contingencies [Line Items]

Investment in RBS Sempra Commodities LLP

$ 65,000,000

Funding for Environmental Projects [Member] | Complaints Filed by Public Entities [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Settlement amount payable

$ 120,000,000

Civil Penalties [Member] | Complaints Filed by Public Entities [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Settlement amount payable

$ 21,000,000

Subsequent Event [Member] | Energy Future Holdings Corp. [Member]

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

275

Number of lawsuits | lawsuit

182

Subsequent Event [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

393

Number of plaintiffs | plaintiff

36,000

Sempra Mexico [Member] | Infraestructura Marina del Golfo [Member]

Loss Contingencies [Line Items]

Ownership percentage in equity method investee

40.00%

Sempra Mexico [Member] | Infraestructura Marina del Golfo [Member] | Corporate Joint Venture [Member]

Loss Contingencies [Line Items]

Ownership percentage in equity method investee

40.00%

Service Agreement, Term

25 years

Deferred Credits and Other [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Reserve for Aliso Canyon costs

$ 7,000,000

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - LEASES BALANCE SHEET INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 591
Finance leases, property plant and equipment	1,353
Finance leases, accumulated depreciation	(64)
Finance leases, property plant and equipment, net	1,289
Total right-of-use assets	1,880
Operating lease, other current liabilities	52
Operating lease, deferred credits and other	445
Total lease liabilities	497
Finance lease, current portion of long-term debt and finance leases	26
Long-term lease liabilities	1,263
Total finance leases	1,289
Lease liabilities	$ 1,786
Operating lease, weighted-average remaining lease term	13 years
Finance lease, weighted-average remaining lease term	19 years
Operating lease, weighted-average discount rate (as a percent)	6.01%
Finance lease, weighted-average discount rate (as a percent)	14.76%
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 130
Finance leases, property plant and equipment	1,326
Finance leases, accumulated depreciation	(57)
Finance leases, property plant and equipment, net	1,269
Total right-of-use assets	1,399
Operating lease, other current liabilities	27
Operating lease, deferred credits and other	102
Total lease liabilities	129
Finance lease, current portion of long-term debt and finance leases	20
Long-term lease liabilities	1,250
Total finance leases	1,270
Lease liabilities	$ 1,399
Operating lease, weighted-average remaining lease term	6 years
Finance lease, weighted-average remaining lease term	20 years
Operating lease, weighted-average discount rate (as a percent)	3.55%
Finance lease, weighted-average discount rate (as a percent)	14.83%
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 94
Finance leases, property plant and equipment	27
Finance leases, accumulated depreciation	(7)
Finance leases, property plant and equipment, net	20
Total right-of-use assets	114
Operating lease, other current liabilities	18
Operating lease, deferred credits and other	75
Total lease liabilities	93
Finance lease, current portion of long-term debt and finance leases	6
Long-term lease liabilities	13
Total finance leases	19	$ 3
Lease liabilities	$ 112
Operating lease, weighted-average remaining lease term	6 years
Finance lease, weighted-average remaining lease term	6 years
Operating lease, weighted-average discount rate (as a percent)	3.73%
Finance lease, weighted-average discount rate (as a percent)	3.23%
Maximum [Member]
Lessee, Lease, Description [Line Items]
Operating lease renewal period	25 years
Annual increase in rent, percent	4.00%
Minimum [Member]
Lessee, Lease, Description [Line Items]
Operating lease termination period	1 year
Annual increase in rent, percent	2.00%

COMMITMENTS AND CONTINGENCIES_3

COMMITMENTS AND CONTINGENCIES - LEASE INCOME STATEMENT INFORMATION (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 96
Amortization of ROU assets	24
Interest on lease liabilities	173
Total finance lease costs	197
Short-term lease costs	6
Variable lease costs	482
Total lease costs	781
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	27
Amortization of ROU assets	6
Interest on lease liabilities	0
Total finance lease costs	6
Short-term lease costs	0
Variable lease costs	10
Total lease costs	43
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	33
Amortization of ROU assets	18
Interest on lease liabilities	173
Total finance lease costs	191
Short-term lease costs	2
Variable lease costs	471
Total lease costs	$ 697

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - LEASES CASH FLOW INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	$ 101
Cash paid for finance leases	173
Cash paid for finance leases	24
Increase in operating lease obligations for right-of-use assets	585
Increase in finance lease obligations for investment in property, plant and equipment	38	$ 556	$ 503
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	27
Cash paid for finance leases	0
Cash paid for finance leases	6
Increase in operating lease obligations for right-of-use assets	118
Increase in finance lease obligations for investment in property, plant and equipment	22	6	3
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	33
Cash paid for finance leases	173
Cash paid for finance leases	18
Increase in operating lease obligations for right-of-use assets	158
Increase in finance lease obligations for investment in property, plant and equipment	$ 16	$ 550	$ 500

COMMITMENTS AND CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY ANALYSIS OF LIABILITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Operating leases
2020	$ 75
2021	75
2022	63
2023	54
2024	50
Thereafter	452
Total undiscounted lease payments	769
Less: imputed interest	(272)
Total lease liabilities	497
Less: current lease liabilities	(52)
Long-term lease liabilities	445
Finance leases
2020	198
2021	193
2022	192
2023	192
2024	187
Thereafter	2,629
Total undiscounted lease payments	3,591
Less: imputed interest	(2,302)
Total lease liabilities	1,289
Less: current lease liabilities	(26)
Long-term lease liabilities	1,263
Southern California Gas Company [Member]
Operating leases
2020	22
2021	20
2022	18
2023	13
2024	12
Thereafter	19
Total undiscounted lease payments	104
Less: imputed interest	(11)
Total lease liabilities	93
Less: current lease liabilities	(18)
Long-term lease liabilities	75
Finance leases
2020	6
2021	3
2022	2
2023	2
2024	2
Thereafter	5
Total undiscounted lease payments	20
Less: imputed interest	(1)
Total lease liabilities	19	$ 3
Less: current lease liabilities	(6)
Long-term lease liabilities	13
San Diego Gas and Electric Company [Member]
Operating leases
2020	30
2021	32
2022	22
2023	17
2024	15
Thereafter	28
Total undiscounted lease payments	144
Less: imputed interest	(15)
Total lease liabilities	129
Less: current lease liabilities	(27)
Long-term lease liabilities	102
Finance leases
2020	192
2021	190
2022	190
2023	190
2024	185
Thereafter	2,624
Total undiscounted lease payments	3,571
Less: imputed interest	(2,301)
Total lease liabilities	1,270
Less: current lease liabilities	(20)
Long-term lease liabilities	1,250
Variable lease payments, due in 2020	326
Variable lease payments, due in 2021	328
Variable lease payments, due in 2022	328
Variable lease payments, due in 2023	327
Variable lease payments, due in 2024	328
Variable lease payments, due thereafter	$ 3,707

COMMITMENTS AND CONTINGENCIES_6

COMMITMENTS AND CONTINGENCIES - LEASES THAT HAVE NOT YET COMMENCED (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)
Lessee, Lease, Description [Line Items]
Lease not yet commenced, aggregate maximum lease limit	$ 174
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Lease not yet commenced, aggregate maximum lease limit, amount utilized	54
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Lease not yet commenced, aggregate maximum lease limit, amount utilized	72
Sempra LNG [Member]
Lessee, Lease, Description [Line Items]
Lease not yet commenced, due in 2021	1
Lease not yet commenced, due 2022 through 2024	2
Lease not yet commenced, due after year 2024	$ 16

COMMITMENTS AND CONTINGENCIES_7

COMMITMENTS AND CONTINGENCIES - RENT EXPENSE OPERATING LEASES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017
Operating Leased Assets [Line Items]
Rent expense	$ 122	$ 107
Capital lease depreciation expense	11	8
Depreciation expense on leases	8	3
San Diego Gas and Electric Company [Member]
Operating Leased Assets [Line Items]
Rent expense	27	28
Depreciation expense on leases	2	1
Southern California Gas Company [Member]
Operating Leased Assets [Line Items]
Rent expense	41	43
Depreciation expense on leases	$ 6	$ 2

COMMITMENTS AND CONTINGENCIES_8

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

COMMITMENTS AND CONTINGENCIES_9

COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Lessor, Lease, Description [Line Items]
Property, plant and equipment	$ 49,329	$ 46,615
Accumulated depreciation	(12,877)	(12,176)
Property, plant and equipment, net	36,452	34,439
2020	201
2021	193
2022	193
2023	193
2024	193
Thereafter	2,402
Total undiscounted cash flows	3,375
Fixed lease payments	200	194	$ 193
Variable lease payments	6	72	44
Total revenues from operating leases	206	266	237
Depreciation expense	1,551	1,470	1,368
Assets Leased to Others [Member]
Lessor, Lease, Description [Line Items]
Assets held for sale	0	172
Property, plant and equipment	1,038	1,022
Accumulated depreciation	(179)	(142)
Property, plant and equipment, net	859	880
Depreciation expense	$ 38	$ 72	$ 57

COMMITMENTS AND CONTINGENCIE_10

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Millions	Mar. 13, 2017	May 31, 2017	May 31, 2016	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Long-term Purchase Commitment [Line Items]
Litigation settlement payable	$ 24
Sempra LNG [Member]
Long-term Purchase Commitment [Line Items]
Litigation settlement payable		$ 57	$ 47
San Diego Gas and Electric Company [Member]
Long-term Purchase Commitment [Line Items]
Litigation settlement payable	$ 118
Natural Gas Storage and Transportation Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				$ 169
2021				161
2022				76
2023				54
2024				43
Thereafter				297
Total minimum payments				800
Natural Gas Supply Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				23
2021				15
2022				11
2023				11
2024				12
Thereafter				7
Total minimum payments				79
Natural Gas Supply Contracts [Member] | SoCalGas [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				2
2021				1
2022				0
2023				0
2024				0
Thereafter				0
Total minimum payments				3
Natural Gas Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				192
2021				176
2022				87
2023				65
2024				55
Thereafter				304
Total minimum payments				879
Payments				1,326	$ 1,345	$ 1,429
Natural Gas Contracts [Member] | SoCalGas [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				124
2021				118
2022				36
2023				23
2024				13
Thereafter				35
Total minimum payments				349
Payments				1,181	1,169	1,213
Natural Gas Transportation Contracts [Member] | SoCalGas [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				122
2021				117
2022				36
2023				23
2024				13
Thereafter				35
Total minimum payments				346
Liquefied Natural Gas Contracts [Member] | Sempra LNG [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				265
2021				368
2022				370
2023				374
2024				387
Thereafter				1,842
Total minimum payments				$ 3,606
Long-term Contracts [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage				27.00%
Renewable Energy Contracts Expiring Through 2041 [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage				26.00%
Other Owned Generation [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage				59.00%
Spot Market Purchases [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage				14.00%
Purchased-Power Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				$ 233
2021				229
2022				233
2023				194
2024				166
Thereafter				904
Total minimum payments				1,959
Payments				744	712	781
Purchased-Power Contracts [Member] | SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				233
2021				229
2022				233
2023				194
2024				166
Thereafter				904
Total minimum payments				1,959
Payments				744	$ 712	$ 781
Infrastructure Construction And Improvements [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				990
2021				56
2022				33
2023				18
2024				14
Thereafter				101
Total minimum payments				1,212
Infrastructure Construction And Improvements [Member] | SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				20
2021				19
2022				14
2023				1
2024				1
Thereafter				2
Construction projects, payable				57
Infrastructure Improvements For Natural Gas And Electric Transmission And Distribution [Member] | SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable				49
Nuclear Plant Maintenance [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable				8
Pipelines [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				791
2021				37
2022				19
2023				17
2024				13
Thereafter				99
Total minimum payments				976
Natural Gas Pipelines and Ongoing Maintenance Services [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments				283
Liquid Fuels Terminals [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments				567
Renewables Projects [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments				126
Sempra LNG & Midstream Construction [Member] | Sempra LNG [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2020				$ 179

COMMITMENTS AND CONTINGENCIE_11

COMMITMENTS AND CONTINGENCIES - OTHER COMMITMENTS (Details)	12 Months Ended
	Dec. 31, 2019USD ($)	Dec. 31, 2011USD ($)MMcf
Sunrise Powerlink Construction [Member] | SDG&E [Member]
Loss Contingencies [Line Items]
Expected payment	$ 4,000,000
Expected payment, due in second year	4,000,000
Expected payment, due in third year	4,000,000
Expected payment, due in fourth year	4,000,000
Expected payment, due in fifth year	4,000,000
Expected payment, thereafter	$ 282,000,000
Estimated annual escalation	2.00%
Purchase commitment period	50 years
Present value of future payments	$ 121,000,000
Continental Forge [Member] | Sempra LNG [Member]
Loss Contingencies [Line Items]
Purchase commitment period		18 years
Amount o natural gas to be sold (MMcf per day) | MMcf		500
Price index		$ 0.02

COMMITMENTS AND CONTINGENCIE_12

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Environmental Issues [Line Items]
Capital expendistures for environmental issues	$ 80	$ 100	$ 91
Accrued liability for environmental matters, discount	15
San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Capital expendistures for environmental issues	39	38	46
Southern California Gas Company [Member]
Environmental Issues [Line Items]
Capital expendistures for environmental issues	$ 41	$ 62	$ 45
Minimum [Member]
Environmental Issues [Line Items]
Accrued liability for environmental matters, discount rate (as a percent)	1.50%
Maximum [Member]
Environmental Issues [Line Items]
Accrued liability for environmental matters, discount rate (as a percent)	3.00%

COMMITMENTS AND CONTINGENCIE_13

COMMITMENTS AND CONTINGENCIES - SITE CONTINGENCY (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)site
Site Contingency [Line Items]
Accrual for environmental loss contingencies	$ 51
Expected future payments for accruals, 2020	9
Expected future payments for accruals, 2021	32
Expected future payments for accruals, 2022	2
Expected future payments for accruals, 2023	2
Expected future payments for accruals, 2024	1
Payments For Accrued Environmental Loss Contingencies, After Year Five	50
Manufactured Gas Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	43
Waste Disposal Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	5
Other Hazardous Waste Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	3
San Diego Gas and Electric Company [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	5
Accrual for environmental loss contingencies, current	1
Accrual for environmental loss contingencies, noncurrent	$ 4
San Diego Gas and Electric Company [Member] | Manufactured Gas Sites [Member]
Site Contingency [Line Items]
Site Contingency, Sites Completed | site	3
Site Contingency, Sites In Process | site	0
Accrual for environmental loss contingencies	$ 0
San Diego Gas and Electric Company [Member] | Waste Disposal Sites [Member]
Site Contingency [Line Items]
Site Contingency, Sites Completed | site	2
Site Contingency, Sites In Process | site	1
Accrual for environmental loss contingencies	$ 2
San Diego Gas and Electric Company [Member] | Other Hazardous Waste Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	3
San Diego Gas and Electric Company [Member] | California Coastal Reef Expansion [Member]
Site Contingency [Line Items]
Estimated SONGS mitigation costs, recoverable in rates	4
SONGS mitigation costs incurred	3
SONGS mitigation costs remaining	1
San Diego Gas and Electric Company [Member] | SONGS Sites [Member]
Site Contingency [Line Items]
Estimated SONGS mitigation costs, recoverable in rates	85
SONGS mitigation costs incurred	46
SONGS mitigation costs remaining	39
Southern California Gas Company [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	45
Accrual for environmental loss contingencies, current	6
Accrual for environmental loss contingencies, noncurrent	$ 39
Southern California Gas Company [Member] | Manufactured Gas Sites [Member]
Site Contingency [Line Items]
Site Contingency, Sites Completed | site	39
Site Contingency, Sites In Process | site	3
Accrual for environmental loss contingencies	$ 43
Southern California Gas Company [Member] | Waste Disposal Sites [Member]
Site Contingency [Line Items]
Site Contingency, Sites Completed | site	5
Site Contingency, Sites In Process | site	2
Accrual for environmental loss contingencies	$ 2
Southern California Gas Company [Member] | Other Hazardous Waste Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	0
Other Sempra Energy [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	1
Other Sempra Energy [Member] | Manufactured Gas Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	0
Other Sempra Energy [Member] | Waste Disposal Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	1
Other Sempra Energy [Member] | Other Hazardous Waste Sites [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies	0
Sempra Energy [Member]
Site Contingency [Line Items]
Accrual for environmental loss contingencies, current	7
Accrual for environmental loss contingencies, noncurrent	$ 44

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended								9 Months Ended	12 Months Ended
	Dec. 31, 2019USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)segment	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)segment	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	May 16, 2019	Mar. 09, 2018
Segment Reporting Information [Line Items]
Number of reportable segments | segment				6					5
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										$ 10,829	$ 10,102	$ 9,640
Segment reporting information, Interest Expense										1,077	886	622
Segment reporting information, Interest Income										87	85	24
Segment reporting information, Depreciation and Amortization										1,569	1,491	1,436
Income tax expense (benefit) from continuing operations										315	(49)	938
Earnings attributable to common shares										2,055	924	256
(Loss) income from discontinued operations, net of income tax	$ 71	$ 256	$ 78	$ (42)	$ 51	$ 54	$ 55	$ 28		328	156	(58)
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										3,708	3,544	3,705
Segment reporting information, Assets	65,665				60,638				$ 65,665	65,665	60,638	50,454
Assets, geographical	50,074				46,411				50,074	50,074	46,411	36,850
Entity-Wide Disclosure On Geographic Areas, United States [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										9,574	8,840	8,547
Segment Reporting Information, Additional Information [Abstract]
Assets, geographical	43,719				40,611				43,719	43,719	40,611	31,487
Entity-Wide Disclosure On Geographic Areas Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										1,255	1,262	1,093
Segment Reporting Information, Additional Information [Abstract]
Assets, geographical	6,355				5,800				6,355	6,355	5,800	5,363
Operating Segments [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										4,925	4,568	4,476
Segment reporting information, Interest Expense										411	221	203
Segment reporting information, Interest Income										4	4	0
Segment reporting information, Depreciation and Amortization										760	688	670
Income tax expense (benefit) from continuing operations										171	173	155
Earnings attributable to common shares										767	669	407
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										1,522	1,542	1,555
Segment reporting information, Assets	20,560				19,225				20,560	20,560	19,225	17,844
Operating Segments [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										4,525	3,962	3,785
Segment reporting information, Interest Expense										141	115	102
Segment reporting information, Interest Income										2	2	1
Segment reporting information, Depreciation and Amortization										602	556	515
Income tax expense (benefit) from continuing operations										120	92	160
Earnings attributable to common shares										641	400	396
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										1,439	1,538	1,367
Segment reporting information, Assets	17,077				15,389				17,077	17,077	15,389	14,159
Operating Segments [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Earnings attributable to common shares										528	371	0
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Assets	11,619				9,652				11,619	11,619	9,652	0
Operating Segments [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										1,375	1,376	1,196
Segment reporting information, Interest Expense										119	120	97
Segment reporting information, Interest Income										78	65	23
Segment reporting information, Depreciation and Amortization										183	175	156
Income tax expense (benefit) from continuing operations										227	185	227
Earnings attributable to common shares										253	237	169
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										624	368	248
Segment reporting information, Assets	9,938				9,165				9,938	9,938	9,165	8,554
Operating Segments [Member] | Sempra Renewables [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										10	124	94
Segment reporting information, Interest Expense										3	19	15
Segment reporting information, Interest Income										11	12	7
Segment reporting information, Depreciation and Amortization										0	27	38
Income tax expense (benefit) from continuing operations										4	71	(226)
Earnings attributable to common shares										59	328	252
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										2	51	497
Segment reporting information, Assets	0				2,549				0	0	2,549	2,898
Operating Segments [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										410	472	540
Segment reporting information, Interest Expense										35	21	39
Segment reporting information, Interest Income										61	49	56
Segment reporting information, Depreciation and Amortization										10	26	42
Income tax expense (benefit) from continuing operations										(5)	(435)	(119)
Earnings attributable to common shares										(6)	(617)	150
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										112	31	20
Segment reporting information, Assets	3,901				4,060				3,901	3,901	4,060	4,872
Adjustment and Elimination [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										(3)	(3)	(1)
(Loss) income from discontinued operations, net of income tax										328	156	(58)
Segment Reporting Information, Additional Information [Abstract]
Assets held for sale	3,958				3,718				3,958	3,958	3,718	3,561
Intersegment Eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										(416)	(397)	(450)
Segment reporting information, Interest Expense										(82)	(106)	(118)
Segment reporting information, Interest Income										(73)	(61)	(63)
Segment Reporting Information, Additional Information [Abstract]
Segment reporting information, Assets	(2,137)				(4,190)				(2,137)	(2,137)	(4,190)	(2,785)
Intersegment Eliminations [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										5	4	7
Intersegment Eliminations [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										69	64	74
Intersegment Eliminations [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										120	114	103
Intersegment Eliminations [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										222	215	266
All Other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
Segment reporting information, Revenue										3	0	0
Segment reporting information, Interest Expense										450	496	284
Segment reporting information, Interest Income										4	14	0
Segment reporting information, Depreciation and Amortization										14	19	15
Income tax expense (benefit) from continuing operations										(202)	(135)	741
Earnings attributable to common shares										(515)	(620)	(1,060)
Segment Reporting Information, Additional Information [Abstract]
Segment Reporting Information Expenditures For Property Plant and Equipment										9	14	18
Segment reporting information, Assets	$ 749				$ 1,070				$ 749	$ 749	$ 1,070	$ 1,351
Oncor Electric Delivery Company LLC [Member]
Segment Reporting Information [Line Items]
Acquired percentage interest														80.25%
Oncor Electric Delivery Holdings Company LLC [Member] | Oncor Electric Delivery Company LLC [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%

QUARTERLY FINANCIAL DATA (UNA_3

QUARTERLY FINANCIAL DATA (UNAUDITED) (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Selected Quarterly Financial Information [Line Items]
Revenues	$ 2,943	$ 2,758	$ 2,230	$ 2,898	$ 2,826	$ 2,565	$ 2,175	$ 2,536	$ 10,829	$ 10,102	$ 9,640
Expenses and other income	2,444	2,310	1,944	2,397	1,867	2,220	3,358	1,943
Income from continuing operations, net of income tax	429	653	357	560	913	280	(585)	330
(Loss) income from discontinued operations, net of income tax	71	256	78	(42)	51	54	55	28	328	156	(58)
Operating revenues									9,448	8,539	8,290
Net income	500	909	435	518	964	334	(530)	358	2,362	1,126	351
Earnings attributable to noncontrolling interest									(164)	(76)	(94)
Earnings attributable to common shares									$ 2,055	$ 924	$ 256
Earnings	$ 447	$ 813	$ 354	$ 441	$ 864	$ 274	$ (561)	$ 347
Earnings from continuing operations - Basic EPS (in dollars per share)	$ 1.36	$ 2.04	$ 1.03	$ 1.79	$ 3	$ 0.83	$ (2.29)	$ 1.26	$ 6.22	$ 2.86	$ 1.25
Basic earnings per common share (in shares)	0.21	0.89	0.26	(0.19)	0.15	0.17	0.18	0.08	$ 7.40	$ 3.45	$ 1.02
Basic earnings per common share attributable to Sempra Energy (in dollars per share)	$ 1.57	$ 2.93	$ 1.29	$ 1.60	$ 3.15	$ 1	$ (2.11)	$ 1.34
Weighted-average number of shares outstanding, basic (in shares)	284,600	277,400	275,000	274,700	274,300	273,900	265,800	257,900	277,904	268,072	251,545
Earnings from continuing operations - Diluted EPS (in dollars per share)	$ 1.34	$ 2	$ 1.01	$ 1.78	$ 2.89	$ 0.82	$ (2.29)	$ 1.25	$ 6.13	$ 2.84	$ 1.24
Diluted earnings per common share (in dollars per share)	0.21	0.84	0.25	(0.19)	0.14	0.17	0.18	0.08	$ 7.29	$ 3.42	$ 1.01
Diluted earnings per common share attributable to Sempra Energy (in dollars per share)	$ 1.55	$ 2.84	$ 1.26	$ 1.59	$ 3.03	$ 0.99	$ (2.11)	$ 1.33
Weighted-average number of shares outstanding, diluted (in shares)	288,800	295,800	279,600	277,200	296,400	275,900	265,800	259,500	282,033	269,852	252,300
Dividends on preferred stock									$ (1)	$ (1)	$ (1)
San Diego Gas and Electric Company [Member]
Selected Quarterly Financial Information [Line Items]
Operating revenues	$ 1,259	$ 1,427	$ 1,094	$ 1,145	$ 1,163	$ 1,299	$ 1,051	$ 1,055	4,925	4,568	4,476
Operating expenses	894	1,004	831	883	916	999	836	807	3,612	3,558	3,767
Operating income	365	423	263	262	247	300	215	248	1,313	1,010	709
Net income	185	266	146	177	145	216	146	169	774	676	421
Earnings attributable to noncontrolling interest	0	(3)	(3)	(1)	3	(11)	0	1	(7)	(7)	(14)
Earnings attributable to common shares	185	263	143	176	148	205	146	170	767	669	407
Southern California Gas Company [Member]
Selected Quarterly Financial Information [Line Items]
Operating revenues	1,383	975	806	1,361	1,262	802	772	1,126	4,525	3,962	3,785
Operating expenses	1,000	762	747	1,060	1,023	797	703	848	3,569	3,371	3,158
Operating income	383	213	59	301	239	5	69	278	956	591	627
Net income	204	143	31	264	156	(14)	34	225	642	401	397
Earnings attributable to common shares	204	143	30	264	156	(14)	33	225	641	400	396
Dividends on preferred stock	$ 0	$ 0	$ (1)	$ 0	$ 0	$ 0	$ (1)	$ 0	$ (1)	$ (1)	$ (1)

QUARTERLY FINANCIAL DATA (UNA_4

QUARTERLY FINANCIAL DATA (UNAUDITED) - Narrative (Details) - USD ($) $ in Millions	Apr. 22, 2019	Apr. 30, 2019	Dec. 31, 2018	Jun. 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Sep. 30, 2018
Significant Items Affecting Quarterly Results [Line Items]
Gain on sale of assets			$ 513		$ 63	$ 513	$ 2
Gain on sale of assets, net of tax			367
Disposal Group Held-for-sale [Member]
Significant Items Affecting Quarterly Results [Line Items]
Asset impairment charges				$ (1,500)
Asset impairment charges, net of taxes and noncontrolling interests				(900)
Disposal Group Held-for-sale [Member] | Sempra Renewables [Member]
Significant Items Affecting Quarterly Results [Line Items]
Asset impairment charges				(200)
Asset impairment charges, net of taxes and noncontrolling interests				(145)
Disposal Group Held-for-sale [Member] | Sempra LNG [Member]
Significant Items Affecting Quarterly Results [Line Items]
Asset impairment charges			183	(1,300)		(1,100)
Asset impairment charges, net of taxes and noncontrolling interests			$ 126	$ (755)		$ (629)
Disposal Group Held-for-sale [Member] | Wind Generation Projects [Member] | Sempra Renewables [Member]
Significant Items Affecting Quarterly Results [Line Items]
Gain on sale of assets	$ 61	$ 61
Gain on sale of assets, after tax	$ 45	$ 45
R B S Sempra Commodities [Member]
Significant Items Affecting Quarterly Results [Line Items]
Investment in RBS Sempra Commodities								$ 65

SCHEDULE I - CONDENSED FINANC_4

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF OPERATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Income Statements, Captions [Line Items]
Interest income									$ 87	$ 85	$ 24
Interest expense									(1,077)	(886)	(622)
Other (expense) income, net									77	58	220
Income tax benefit									(315)	49	(938)
Net of income tax									1,999	938	382
Net income	$ 500	$ 909	$ 435	$ 518	$ 964	$ 334	$ (530)	$ 358	2,362	1,126	351
Mandatory convertible preferred stock dividends									$ (142)	$ (125)	$ 0
Earnings attributable to common shares	$ 447	$ 813	$ 354	$ 441	$ 864	$ 274	$ (561)	$ 347
Basic earnings per common share (in shares)	$ 0.21	$ 0.89	$ 0.26	$ (0.19)	$ 0.15	$ 0.17	$ 0.18	$ 0.08	$ 7.40	$ 3.45	$ 1.02
Weighted-average number of shares outstanding, basic (in shares)	284,600	277,400	275,000	274,700	274,300	273,900	265,800	257,900	277,904	268,072	251,545
Diluted earnings per common share (in dollars per share)	$ 0.21	$ 0.84	$ 0.25	$ (0.19)	$ 0.14	$ 0.17	$ 0.18	$ 0.08	$ 7.29	$ 3.42	$ 1.01
Weighted-average number of shares outstanding, diluted (in shares)	288,800	295,800	279,600	277,200	296,400	275,900	265,800	259,500	282,033	269,852	252,300
Parent Company [Member]
Condensed Income Statements, Captions [Line Items]
Interest income									$ 3	$ 14	$ 0
Interest expense									(521)	(495)	(293)
Operating expenses									(124)	(82)	(80)
Other (expense) income, net									59	(16)	100
Income tax benefit									163	154	33
Net of income tax									(420)	(425)	(240)
Equity in earnings of subsidiaries, net of income taxes									2,617	1,474	496
Net income									2,197	1,049	256
Mandatory convertible preferred stock dividends									(142)	(125)	0
Earnings attributable to common shares									$ 2,055	$ 924	$ 256
Basic earnings per common share (in shares)									$ 7.40	$ 3.45	$ 1.02
Weighted-average number of shares outstanding, basic (in shares)									277,904	268,072	251,545
Diluted earnings per common share (in dollars per share)									$ 7.29	$ 3.42	$ 1.01
Weighted-average number of shares outstanding, diluted (in shares)									282,033	269,852	252,300

SCHEDULE I - CONDENSED FINANC_5

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Condensed Statement of Income Captions [Line Items]
Net income	$ 500	$ 909	$ 435	$ 518	$ 964	$ 334	$ (530)	$ 358	$ 2,362	$ 1,126	$ 351
Total other comprehensive (loss) income									(140)	(133)	142
Pretax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									2,585	1,146	1,533
Foreign currency translation adjustments									(43)	(144)	107
Financial instruments									(161)
Financial instruments										64	2
Pension and other postretirement benefits									25	(38)	20
Total other comprehensive (loss) income									(179)	(118)	129
Total comprehensive income, after preferred dividends of subsidiaries									2,405	1,027	1,661
Income tax benefit [Member]
Condensed Statement of Income Captions [Line Items]
Net income									(387)	(96)	(1,276)
Foreign currency translation adjustments									0	0	0
Financial instruments									53
Financial instruments										(21)	1
Pension and other postretirement benefits									(7)	4	(8)
Total other comprehensive (loss) income									46	(17)	(7)
Total comprehensive income, after preferred dividends of subsidiaries									(341)	(113)	(1,283)
Net-of-tax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									2,198	1,050	257
Foreign currency translation adjustments									(43)	(144)	107
Financial instruments									(108)
Financial instruments										43	3
Pension and other postretirement benefits									18	(34)	12
Total other comprehensive (loss) income									(133)	(135)	122
Total comprehensive income, after preferred dividends of subsidiaries									2,064	914	378
Parent Company [Member]
Condensed Statement of Income Captions [Line Items]
Net income									2,197	1,049	256
Parent Company [Member] | Pretax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									2,034	895	223
Foreign currency translation adjustments									(43)	(144)	107
Financial instruments									(161)
Financial instruments										64	2
Pension and other postretirement benefits									25	(38)	20
Total other comprehensive (loss) income									(179)	(118)	129
Total comprehensive income, after preferred dividends of subsidiaries									1,855	777	352
Parent Company [Member] | Income tax benefit [Member]
Condensed Statement of Income Captions [Line Items]
Net income									163	154	33
Foreign currency translation adjustments									0	0	0
Financial instruments									53
Financial instruments										(21)	1
Pension and other postretirement benefits									(7)	4	(8)
Total other comprehensive (loss) income									46	(17)	(7)
Total comprehensive income, after preferred dividends of subsidiaries									209	137	26
Parent Company [Member] | Net-of-tax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									2,197	1,049	256
Foreign currency translation adjustments									(43)	(144)	107
Financial instruments									(108)
Financial instruments										43	3
Pension and other postretirement benefits									18	(34)	12
Total other comprehensive (loss) income									(133)	(135)	122
Total comprehensive income, after preferred dividends of subsidiaries									$ 2,064	$ 914	$ 378

SCHEDULE I - CONDENSED FINANC_6

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
ASSETS
Cash and cash equivalents	$ 108	$ 102
Due from affiliates	32	37
Income taxes receivable	112	60
Other current assets	324	249
Total current assets	3,339	3,645
Due from affiliates	742	644
Deferred income taxes	155	141
Other long-term assets	732	962
Total assets	65,665	60,638	$ 50,454
Liabilities and shareholders’ equity:
Current portion of long-term debt	1,526	1,644
Due to affiliates	5	10
Other current liabilities	866	935
Total current liabilities	9,150	7,523
Long-term debt	20,785	20,903
Due to affiliates	195	37
Commitments and contingencies (Note 4)
Total shareholders’ equity	19,929	17,138
Total liabilities and equity	65,665	60,638
Parent Company [Member]
ASSETS
Cash and cash equivalents	6	14	$ 104	$ 12
Due from affiliates	98	93
Income taxes receivable	0	397
Other current assets	34	9
Total current assets	138	513
Investments in subsidiaries	32,604	28,778
Due from affiliates	3	3
Deferred income taxes	1,766	1,554
Other long-term assets	682	572
Total assets	35,193	31,420
Liabilities and shareholders’ equity:
Current portion of long-term debt	1,399	1,498
Due to affiliates	369	287
Income taxes payable, net	274	0
Other current liabilities	561	527
Total current liabilities	2,603	2,312
Long-term debt	8,856	9,647
Due to affiliates	3,138	1,812
Other long-term liabilities	667	511
Commitments and contingencies (Note 4)
Total shareholders’ equity	19,929	17,138
Total liabilities and equity	$ 35,193	$ 31,420

SCHEDULE I - CONDENSED FINANC_7

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - CASH FLOWS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Condensed Cash Flow Statements, Captions [Line Items]
Net cash used in operating activities	$ 3,088	$ 3,516	$ 3,625
Expenditures for property, plant and equipment	(3,708)	(3,544)	(3,705)
Expenditures for acquisition	0	(9,568)	(147)
Other	30	41	24
Net cash used in investing activities	(4,593)	(12,470)	(4,885)
Common stock dividends paid	(993)	(877)	(755)
Preferred dividends paid	(142)	(89)	0
Issuances of mandatory convertible preferred stock, net	0	2,258	0
Issuances of common stock, net	1,830	2,272	47
Repurchases of common stock	(26)	(21)	(15)
Issuances of long-term debt	4,296	8,927	4,260
Payments on long-term debt	(3,667)	(3,342)	(2,587)
Increase (decrease) in loans from affiliates, net	3	3	9
Increase (decrease) in loans from affiliates, net	(16)	(95)	(505)
Net cash provided by financing activities	1,475	8,850	1,192
Cash and cash equivalents, January 1	102
Cash and cash equivalents, December 31	108	102
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Common dividends issued in stock	55	54	53
Parent Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash used in operating activities	294	213	89
Expenditures for property, plant and equipment	(8)	(11)	(11)
Expenditures for acquisition	0	(329)	0
Capital contributions to investees	(1,528)	(9,457)	0
Decrease in loans to affiliate, net	0	(1)	0
Expenditures for Merger-related costs	0	0	(12)
Other	4	0	0
Net cash used in investing activities	(1,532)	(9,798)	(23)
Common stock dividends paid	(993)	(877)	(755)
Preferred dividends paid	(142)	(89)	0
Issuances of mandatory convertible preferred stock, net	0	2,258	0
Issuances of common stock, net	1,830	2,272	47
Repurchases of common stock	(26)	(21)	(15)
Issuances of long-term debt	758	4,969	1,595
Payments on long-term debt	(1,500)	(500)	(600)
Increase (decrease) in loans from affiliates, net	1,328	1,520
Increase (decrease) in loans from affiliates, net			(239)
Payments of Debt Issuance Costs	(25)	(37)	(7)
Net cash provided by financing activities	1,230	9,495	26
(Decrease) increase in cash and cash equivalents	(8)	(90)	92
Cash and cash equivalents, January 1	14	104	12
Cash and cash equivalents, December 31	6	14	104
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Accrued Merger-related transaction costs	0	0	31
Preferred dividends declared but not paid	36	36	0
Common dividends issued in stock	55	54	53
Common dividends declared but not paid	$ 283	$ 245	$ 207

SCHEDULE I - CONDENSED FINANC_8

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - FOOTNOTES (Details) - USD ($) $ in Millions	Jan. 01, 2019	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Basis of Presentation
Investment gains (losses) on Rabbi Trust		$ 61	$ (6)	$ 56
New Accounting Standards
Right-of-use assets - operating leases		591
Deferred income taxes		155	141
Property, plant and equipment, net		36,452	34,439
Other current liabilities		866	935
Retained earnings		11,130	10,104
Debt Instruments [Abstract]
Current portion of long-term debt		(1,526)	(1,644)
Long-term debt		20,785	20,903
Long-term Debt, Fiscal Year Maturity [Abstract]
2020		1,501
2021		2,005
2022		594
2023		1,735
2024		1,045
Thereafter		14,367
Operating leases
Total operating lease commitments		769
2020		75
2021		75
2022		63
2023		54
2024		50
Thereafter		452
Accounting Standards Update 2016-02 [Member]
New Accounting Standards
Right-of-use assets - operating leases	$ 603
Property, plant and equipment, net	(147)
Other current liabilities	80
Retained earnings	17
Accounting Standards Update 2018-02 [Member]
New Accounting Standards
Retained earnings	40
Parent Company [Member]
Basis of Presentation
Investment gains (losses) on Rabbi Trust		61	(6)	56
New Accounting Standards
Deferred income taxes		1,766	1,554
Other current liabilities		561	527
Other long-term liabilities		667	511
Debt Instruments [Abstract]
Gross long-term debt		10,358	11,238
Build-to-suit arrangement		0	138
Current portion of long-term debt		(1,399)	(1,498)
Unamortized discount on long-term debt		(35)	(38)
Unamortized debt issuance costs		(68)	(55)
Long-term debt		8,856	9,647
Long-term Debt, Fiscal Year Maturity [Abstract]
2020		1,400
2021		1,600
2022		500
2023		1,000
2024		500
Thereafter		5,400
Operating leases
Total operating lease commitments		267
2020		10
2021		11
2022		11
2023		11
2024		12
Thereafter		212
Parent Company [Member] | Other Long-term Debt, Due February 2019 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 0	500
Stated percentage rate		9.80%
Parent Company [Member] | Other Long-term Debt, Due July 2019 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 0	500
Parent Company [Member] | Other Long-term Debt, October 2019 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 0	500
Stated percentage rate		1.625%
Parent Company [Member] | Other Long Term Debt Due February 2020 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.40%
Parent Company [Member] | Other Long Term Debt Due March 2020 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.40%
Parent Company [Member] | Other Long Term Debt, Due November 2020 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 400	400
Stated percentage rate		2.85%
Parent Company [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 700	700
Parent Company [Member] | Other Long Term Debt, Due March 2021 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 850	850
Fixed interest rate after floating to fixed interest rate swaps		3.069%
Parent Company [Member] | Other Long-term Debt, Due October 2022 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.875%
Parent Company [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.90%
Parent Company [Member] | Other Long-term Debt, Due December 2023 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		4.05%
Parent Company [Member] | Other Long Term Debt Due June 2024 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		3.55%
Parent Company [Member] | Other Long-term Debt, Due November 2025 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 350	350
Stated percentage rate		3.75%
Parent Company [Member] | Other Long Term Debt Due June 2027 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 750	750
Stated percentage rate		3.25%
Parent Company [Member] | Other Long Term Debt Due February 2028 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 1,000	1,000
Stated percentage rate		3.40%
Parent Company [Member] | Other Long Term Debt Due February 2038 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 1,000	1,000
Stated percentage rate		3.80%
Parent Company [Member] | Other Long-term Debt, Due October 2039 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 750	750
Stated percentage rate		6.00%
Parent Company [Member] | Other Long Term Debt Due February 2048 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 800	800
Stated percentage rate		4.00%
Parent Company [Member] | Other Long-term Debt, Junior Subordinated Notes, Due July 2079 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 758	0
Stated percentage rate		5.75%
Parent Company [Member] | Accounting Standards Update 2016-02 [Member]
New Accounting Standards
Right-of-use assets - operating leases	191
Deferred income taxes	(3)
Property, plant and equipment, net	(147)
Other current liabilities	3
Long-term debt	(138)
Other long-term liabilities	159
Retained earnings	17
Parent Company [Member] | Accounting Standards Update 2018-02 [Member]
New Accounting Standards
Tax Cuts and Jobs Act of 2017, reclassification From AOCI to retained earnings, tax effect	$ 14
Parent Company [Member] | Foreign exchange instruments [Member]
Basis of Presentation
Gain (loss) on settlement			(3)	(50)
PERU | Parent Company [Member] | Foreign exchange instruments [Member]
Basis of Presentation
Gain (loss) on settlement		$ 15
Sempra Energy [Member]
Debt Instruments [Abstract]
Build-to-suit arrangement		0	138
Sempra Energy [Member] | Other Long-term Debt, Due February 2019 [Member]
Debt Instruments [Abstract]
Gross long-term debt		0	$ 500
Stated percentage rate			9.80%
Sempra Energy [Member] | Other Long-term Debt, Due July 2019 [Member]
Debt Instruments [Abstract]
Gross long-term debt		0	$ 500
Sempra Energy [Member] | Other Long-term Debt, October 2019 [Member]
Debt Instruments [Abstract]
Gross long-term debt		0	$ 500
Stated percentage rate			1.625%
Sempra Energy [Member] | Other Long Term Debt Due February 2020 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	$ 500
Stated percentage rate		2.40%
Sempra Energy [Member] | Other Long Term Debt Due March 2020 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.40%
Sempra Energy [Member] | Other Long Term Debt, Due November 2020 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 400	400
Stated percentage rate		2.85%
Sempra Energy [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 700	700
Sempra Energy [Member] | Other Long Term Debt, Due March 2021 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 850	850
Fixed interest rate after floating to fixed interest rate swaps		3.069%
Sempra Energy [Member] | Other Long-term Debt, Due October 2022 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.875%
Sempra Energy [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		2.90%
Sempra Energy [Member] | Other Long-term Debt, Due December 2023 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		4.05%
Sempra Energy [Member] | Other Long Term Debt Due June 2024 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 500	500
Stated percentage rate		3.55%
Sempra Energy [Member] | Other Long-term Debt, Due November 2025 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 350	350
Stated percentage rate		3.75%
Sempra Energy [Member] | Other Long Term Debt Due June 2027 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 750	750
Stated percentage rate		3.25%
Sempra Energy [Member] | Other Long Term Debt Due February 2028 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 1,000	1,000
Stated percentage rate		3.40%
Sempra Energy [Member] | Other Long Term Debt Due February 2038 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 1,000	1,000
Stated percentage rate		3.80%
Sempra Energy [Member] | Other Long-term Debt, Due October 2039 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 750	750
Stated percentage rate		6.00%
Sempra Energy [Member] | Other Long Term Debt Due February 2048 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 800	800
Stated percentage rate		4.00%
Sempra Energy [Member] | Other Long-term Debt, Junior Subordinated Notes, Due July 2079 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 758	0
Stated percentage rate		5.75%
Sempra Energy [Member] | Parent Company [Member]
Basis of Presentation
Cash dividends received		$ 150	$ 300	$ 450
LIBOR [Member] | Parent Company [Member] | Other Long-term Debt, Due July 2019 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.69%
LIBOR [Member] | Parent Company [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.50%
LIBOR [Member] | Sempra Energy [Member] | Other Long-term Debt, Due July 2019 [Member]
Debt Instruments [Abstract]
Stated percentage rate			2.69%
LIBOR [Member] | Sempra Energy [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.50%

Uncategorized Items - sre201912

Label	Element	Value
Parent [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ 15,000,000
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	(1,000,000)
Retained Earnings [Member]
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	57,000,000
Cumulative Effect of New Accounting Principle in Period of Adoption	us-gaap_CumulativeEffectOfNewAccountingPrincipleInPeriodOfAdoption	$ 2,000,000