Southern California Gas Company PFD 6% (SOCGM) 10-K 25 Feb 21 2020 FY Annual report Financial data

Cover

Cover - USD ($)	12 Months Ended
	Dec. 31, 2020	Feb. 22, 2021	Jun. 30, 2020
Document And Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Current Fiscal Year End Date	--12-31
Document Period End Date	Dec. 31, 2020
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
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 34,300,000,000
Entity Common Stock, Shares Outstanding		302,591,374
Documents Incorporated by Reference	DOCUMENTS INCORPORATED BY REFERENCE: Portions of the Sempra Energy proxy statement to be filed for its May 2021 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 June 2021 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	2020
Document Fiscal Period Focus	FY
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
ICFR Auditor Attestation Flag	true
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
ICFR Auditor Attestation Flag	true
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 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
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenues
Energy-related businesses	$ 1,345	$ 1,381	$ 1,563
Utilities	10,025	9,448	8,539
Total revenues	11,370	10,829	10,102
Operating expenses
Operation and maintenance	(3,940)	(3,466)	(3,150)
Aliso canyon litigation and regulatory matters	(307)	0	0
Depreciation and amortization	(1,666)	(1,569)	(1,491)
Franchise fees and other taxes	(543)	(496)	(472)
Impairment losses	(1)	(43)	(1,122)
(Loss) gain on sale of assets	(3)	63	513
Operating expenses
Aliso canyon litigation and regulatory matters	307	0	0
Impairment losses	1	43	1,122
Other (expense) income, net	(48)	77	58
Interest income	96	87	85
Interest expense	(1,081)	(1,077)	(886)
Income before income taxes	1,489	1,734	714
Income tax (expense) benefit	(249)	(315)	49
Equity earnings	1,015	580	175
Net of income tax	2,255	1,999	938
Income from discontinued operations, net of income tax	1,850	363	188
Net income	4,105	2,362	1,126
Earnings attributable to noncontrolling interest	(172)	(164)	(76)
Preferred dividends	(168)	(142)	(125)
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings attributable to common shares	$ 3,764	$ 2,055	$ 924
Basic EPS:
Earnings from continuing operations attributable to common shares	$ 6.61	$ 6.22	$ 2.86
Earnings (losses) from discontinued operations attributable to common shares	6.32	1.18	0.59
Basic earnings per common share (in shares)	$ 12.93	$ 7.40	$ 3.45
Weighted-average number of shares outstanding, basic (in shares)	291,077	277,904	268,072
Diluted EPS:
Earnings from continuing operations (in dollars per share)	$ 6.58	$ 6.13	$ 2.84
Earnings (losses) from discontinued operations (in dollars per share)	6.30	1.16	0.58
Diluted earnings per common share (in dollars per share)	$ 12.88	$ 7.29	$ 3.42
Weighted-average number of shares outstanding, diluted (in shares)	292,252	282,033	269,852
San Diego Gas and Electric Company [Member]
Revenues
Electric	$ 4,619	$ 4,267	$ 4,003
Natural Gas	694	658	565
Utilities	5,313	4,925	4,568
Operating expenses
Cost of electric fuel and purchased power	1,191	1,194	1,370
Cost of natural gas	162	176	152
Operation and maintenance	1,455	1,181	1,058
Depreciation and amortization	801	760	688
Franchise fees and other taxes	331	301	290
Total operating expenses	3,940	3,612	3,558
Operating income	1,373	1,313	1,010
Other (expense) income, net	52	39	56
Interest income	2	4	4
Interest expense	(413)	(411)	(221)
Income before income taxes	1,014	945	849
Income tax (expense) benefit	(190)	(171)	(173)
Net income	824	774	676
Earnings attributable to noncontrolling interest	0	(7)	(7)
Earnings attributable to common shares	824	767	669
Southern California Gas Company [Member]
Revenues
Utilities	4,748	4,525	3,962
Operating expenses
Aliso canyon litigation and regulatory matters	(307)	0	0
Impairment losses	0	(37)	0
Operating expenses
Cost of natural gas	783	977	1,048
Operation and maintenance	2,029	1,780	1,613
Aliso canyon litigation and regulatory matters	307	0	0
Depreciation and amortization	654	602	556
Franchise fees and other taxes	190	173	154
Impairment losses	0	37	0
Total operating expenses	3,963	3,569	3,371
Operating income	785	956	591
Other (expense) income, net	(28)	(55)	15
Interest income	2	2	2
Interest expense	(158)	(141)	(115)
Income before income taxes	601	762	493
Income tax (expense) benefit	(96)	(120)	(92)
Net income	505	642	401
Preferred dividends	(1)	(1)	(1)
Earnings attributable to common shares	504	641	400
Cost of natural gas [Member]
Operating expenses
Operating expenses	(925)	(1,139)	(1,208)
Cost of electric fuel and purchased power [Member]
Operating expenses
Operating expenses	(1,187)	(1,188)	(1,358)
Energy-related businesses cost of sales [Member]
Operating expenses
Operating expenses	$ (276)	$ (344)	$ (357)

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Net income	$ 4,105	$ 2,362	$ 1,126
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Total other comprehensive (loss) income	422	(140)	(133)
Preferred dividends of subsidiary	(1)	(1)	(1)
Pretax amount [Member]
Net income	5,368	2,585	1,146
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Foreign currency translation adjustments	547	(43)	(144)
Financial instruments	(146)	(161)	64
Pension and other postretirement benefits	11	25	(38)
Total other comprehensive (loss) income	412	(179)	(118)
Comprehensive income	5,780	2,406	1,028
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	5,779	2,405	1,027
Income tax (expense) benefit [Member]
Net income	(1,435)	(387)	(96)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Foreign currency translation adjustments	0	0	0
Financial instruments	33	53	(21)
Pension and other postretirement benefits	1	(7)	4
Total other comprehensive (loss) income	34	46	(17)
Comprehensive income	(1,401)	(341)	(113)
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	(1,401)	(341)	(113)
Net-of-tax amount [Member]
Net income	3,933	2,198	1,050
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Foreign currency translation adjustments	547	(43)	(144)
Financial instruments	(113)	(108)	43
Pension and other postretirement benefits	12	18	(34)
Total other comprehensive (loss) income	446	(133)	(135)
Comprehensive income	4,379	2,065	915
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	4,378	2,064	914
Noncontrolling interests (after-tax) [Member]
Net income	172	164	76
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Foreign currency translation adjustments	(12)	3	(11)
Financial instruments	(12)	(10)	13
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	(24)	(7)	2
Comprehensive income	148	157	78
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	148	157	78
Total [Member]
Net income	4,105	2,362	1,126
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Foreign currency translation adjustments	535	(40)	(155)
Financial instruments	(125)	(118)	56
Pension and other postretirement benefits	12	18	(34)
Total other comprehensive (loss) income	422	(140)	(133)
Comprehensive income	4,527	2,222	993
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	4,526	2,221	992
San Diego Gas and Electric Company [Member]
Net income	824	774	676
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Total other comprehensive (loss) income	6	(2)	6
San Diego Gas and Electric Company [Member] | Pretax amount [Member]
Net income	1,014	938	842
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		0	0
Pension and other postretirement benefits	8	(6)	(2)
Total other comprehensive (loss) income	8	(6)	(2)
Comprehensive income	1,022	932	840
San Diego Gas and Electric Company [Member] | Income tax (expense) benefit [Member]
Net income	(190)	(171)	(173)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		0	0
Pension and other postretirement benefits	(2)	2	0
Total other comprehensive (loss) income	(2)	2	0
Comprehensive income	(192)	(169)	(173)
San Diego Gas and Electric Company [Member] | Net-of-tax amount [Member]
Net income	824	767	669
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		0	0
Pension and other postretirement benefits	6	(4)	(2)
Total other comprehensive (loss) income	6	(4)	(2)
Comprehensive income	830	763	667
San Diego Gas and Electric Company [Member] | Noncontrolling interests (after-tax) [Member]
Net income	0	7	7
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		2	8
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	0	2	8
Comprehensive income	0	9	15
San Diego Gas and Electric Company [Member] | Total [Member]
Net income	824	774	676
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		2	8
Pension and other postretirement benefits	6	(4)	(2)
Total other comprehensive (loss) income	6	(2)	6
Comprehensive income	830	772	682
Southern California Gas Company [Member]
Net income	505	642	401
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Total other comprehensive (loss) income	(8)	1	1
Southern California Gas Company [Member] | Pretax amount [Member]
Net income	601	762	493
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		1	1
Pension and other postretirement benefits	(12)	1
Total other comprehensive (loss) income	(12)	2	1
Comprehensive income	589	764	494
Southern California Gas Company [Member] | Income tax (expense) benefit [Member]
Net income	(96)	(120)	(92)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		0	0
Pension and other postretirement benefits	4	(1)
Total other comprehensive (loss) income	4	(1)	0
Comprehensive income	(92)	(121)	(92)
Southern California Gas Company [Member] | Net-of-tax amount [Member]
Net income	505	642	401
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Financial instruments		1	1
Pension and other postretirement benefits	(8)	0
Total other comprehensive (loss) income	(8)	1	1
Comprehensive income	$ 497	$ 643	$ 402

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 960	$ 108
Restricted cash	22	31
Accounts receivable – trade, net	1,578	1,261
Accounts receivable – other, net	403	455
Due from unconsolidated affiliates	20	32
Income taxes receivable	113	112
Inventories	308	277
Regulatory assets	190	222
Greenhouse gas allowances	553	72
Assets held for sale in discontinued operations	0	445
Other current assets	364	324
Total current assets	4,511	3,339
Other assets:
Restricted cash	3	3
Due from unconsolidated affiliates	780	742
Regulatory assets	1,822	1,930
Nuclear decommissioning trusts	1,019	1,082
Investment in Oncor Holdings	12,440	11,519
Other investments	1,388	2,103
Goodwill	1,602	1,602
Other intangible assets	202	213
Dedicated assets in support of certain benefit plans	512	488
Insurance receivable for Aliso Canyon costs	445	339
Deferred income taxes	136	155
Greenhouse gas allowances	101	470
Right-of-use assets	543	591
Wildfire fund	363	392
Assets held for sale in discontinued operations	0	3,513
Other long-term assets	753	732
Total other assets	22,109	25,874
Property, plant and equipment:
Property, plant and equipment	53,928	49,329
Less accumulated depreciation and amortization	(13,925)	(12,877)
Property, plant and equipment, net	40,003	36,452
Total assets	66,623	65,665
Liabilities, Current [Abstract]
Short-term debt	885	3,505
Accounts payable – trade	1,359	1,234
Accounts payable – other	154	179
Due to unconsolidated affiliates	45	5
Dividends and interest payable	551	515
Accrued compensation and benefits	446	476
Regulatory liabilities	140	319
Current portion of long-term debt and finance leases	1,540	1,526
Reserve for Aliso Canyon costs	150	9
Greenhouse gas obligations	553	72
Liabilities held for sale in discontinued operations	0	444
Other current liabilities	1,016	866
Total current liabilities	6,839	9,150
Long-term debt and finance leases	21,781	20,785
Deferred Credits and Other Liabilities [Abstract]
Due to unconsolidated affiliates	234	195
Pension and other postretirement benefit plan obligations, net of plan assets	1,059	1,067
Deferred Income Tax Liabilities, Net	2,871	2,577
Regulatory liabilities	3,372	3,741
Reserve for Aliso Canyon costs	301	7
Asset retirement obligations	3,113	2,923
Greenhouse gas obligations	0	301
Liabilities held for sale in discontinued operations	0	1,052
Deferred credits and other	2,119	2,062
Total deferred credits and other liabilities	13,069	13,925
Commitments and contingencies (Note 16)
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Common stock	7,053	7,480
Retained earnings	13,673	11,130
Accumulated other comprehensive income (loss)	(500)	(939)
Total shareholders’ equity	23,373	19,929
Preferred stock of subsidiary	20	20
Other noncontrolling interests	1,541	1,856
Total equity	24,934	21,805
Total liabilities and shareholders’ equity	$ 66,623	$ 65,665
Preferred stock, shares authorized (in shares)	50,000,000	50,000,000
Common stock, shares outstanding (in shares)	288,470,244	291,712,925
Common stock, shares authorized (in shares)	750,000,000	750,000,000
San Diego Gas and Electric Company [Member]
Current assets:
Cash and cash equivalents	$ 262	$ 10
Accounts receivable – trade, net	573	398
Accounts receivable – other, net	143	119
Income taxes receivable	0	128
Inventories	104	94
Prepaid expenses	153	120
Regulatory assets	174	209
Fixed-price contracts and other derivatives	56	43
Greenhouse gas allowances	113	13
Other current assets	22	24
Total current assets	1,600	1,158
Other assets:
Regulatory assets	534	440
Nuclear decommissioning trusts	1,019	1,082
Greenhouse gas allowances	83	189
Right-of-use assets	102	130
Wildfire fund	363	392
Other long-term assets	189	202
Total other assets	2,290	2,435
Property, plant and equipment:
Property, plant and equipment	24,436	22,504
Less accumulated depreciation and amortization	(6,015)	(5,537)
Property, plant and equipment, net	18,421	16,967
Total assets	22,311	20,560
Liabilities, Current [Abstract]
Short-term debt	0	80
Accounts payable – trade	553	496
Due to unconsolidated affiliates	64	53
Interest payable	46	43
Accrued compensation and benefits	135	138
Regulatory liabilities	61	76
Accrued franchise fees	56	53
Current portion of long-term debt and finance leases	611	56
Customer deposits	56	74
Asset retirement obligations	117	95
Greenhouse gas obligations	113	13
Other current liabilities	199	133
Total current liabilities	2,011	1,310
Long-term debt and finance leases	6,866	6,306
Deferred Credits and Other Liabilities [Abstract]
Pension and other postretirement benefit plan obligations, net of plan assets	92	153
Deferred Income Tax Liabilities, Net	2,019	1,848
Deferred investment tax credits	13	14
Regulatory liabilities	2,195	2,319
Asset retirement obligations	759	771
Greenhouse gas obligations	0	62
Deferred credits and other	626	677
Total deferred credits and other liabilities	5,704	5,844
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	0	0
Common stock	1,660	1,660
Retained earnings	6,080	5,456
Accumulated other comprehensive income (loss)	(10)	(16)
Total shareholders’ equity	7,730	7,100
Total equity	7,730	7,100
Total liabilities and shareholders’ equity	$ 22,311	$ 20,560
Preferred stock, shares issued (in shares)	0	0
Preferred stock, shares authorized (in shares)	45,000,000	45,000,000
Preferred stock, shares outstanding (in shares)	0	0
Common stock, shares outstanding (in shares)	117,000,000	117,000,000
Common stock, shares authorized (in shares)	255,000,000	255,000,000
Southern California Gas Company [Member]
Current assets:
Cash and cash equivalents	$ 4	$ 10
Accounts receivable – trade, net	786	710
Accounts receivable – other, net	64	87
Due from unconsolidated affiliates	22	11
Income taxes receivable	0	161
Inventories	153	136
Regulatory assets	16	7
Greenhouse gas allowances	390	52
Other current assets	47	44
Total current assets	1,482	1,218
Other assets:
Regulatory assets	1,208	1,407
Insurance receivable for Aliso Canyon costs	445	339
Greenhouse gas allowances	9	248
Right-of-use assets	74	94
Other long-term assets	499	447
Total other assets	2,235	2,535
Property, plant and equipment:
Property, plant and equipment	21,180	19,362
Less accumulated depreciation and amortization	(6,437)	(6,038)
Property, plant and equipment, net	14,743	13,324
Total assets	18,460	17,077
Liabilities, Current [Abstract]
Short-term debt	113	630
Accounts payable – trade	600	545
Accounts payable – other	122	110
Due to unconsolidated affiliates	31	47
Accrued compensation and benefits	189	182
Regulatory liabilities	79	243
Current portion of long-term debt and finance leases	10	6
Customer deposits	48	71
Asset retirement obligations	59	65
Reserve for Aliso Canyon costs	150	9
Greenhouse gas obligations	390	52
Other current liabilities	291	222
Total current liabilities	2,082	2,182
Long-term debt and finance leases	4,763	3,788
Deferred Credits and Other Liabilities [Abstract]
Pension obligation, net of plan assets	853	785
Deferred Income Tax Liabilities, Net	1,406	1,403
Deferred investment tax credits	8	7
Regulatory liabilities	1,177	1,422
Reserve for Aliso Canyon costs	301	7
Asset retirement obligations	2,309	2,112
Greenhouse gas obligations	0	208
Deferred credits and other	417	415
Total deferred credits and other liabilities	6,471	6,359
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	22	22
Common stock	866	866
Retained earnings	4,287	3,883
Accumulated other comprehensive income (loss)	(31)	(23)
Total shareholders’ equity	5,144	4,748
Total equity	5,144	4,748
Total liabilities and shareholders’ equity	$ 18,460	$ 17,077
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 outstanding (in shares)	91,000,000	91,000,000
Common stock, shares authorized (in shares)	100,000,000	100,000,000
Convertible Preferred Stock Series A [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	$ 1,693	$ 1,693
Preferred stock, shares outstanding (in shares)	17,250,000	17,250,000
Convertible Preferred Stock Series B [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	$ 565	$ 565
Preferred stock, shares outstanding (in shares)	5,750,000	5,750,000
Series C Preferred Stock [Member]
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest [Abstract]
Preferred stock	$ 889	$ 0
Preferred stock, shares outstanding (in shares)	900,000

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Dec. 31, 2020	Dec. 31, 2019
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)	288,470,244	291,712,925
San Diego Gas and Electric Company [Member]
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]
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

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ 4,105	$ 2,362	$ 1,126
Less: Income from discontinued operations, net of income tax	(1,850)	(363)	(188)
Income from continuing operations, net of income tax	2,255	1,999	938
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	1,666	1,569	1,491
Deferred income taxes and investment tax credits	159	189	(242)
Impairment losses	1	43	1,122
Loss (gain) on sale of assets	3	(63)	(513)
Equity earnings	(1,015)	(580)	(175)
Foreign currency transaction losses (gains), net	25	(21)	6
Share-based compensation expense	71	75	83
Other	132	47	106
Net change in other working capital components:
Accounts receivable	(315)	(91)	(145)
Income taxes receivable/payable, net	(94)	(166)	88
Inventories	(35)	(22)	32
Other current assets	38	(88)	(79)
Accounts payable	73	12	96
Regulatory balancing accounts	(231)	13	263
Reserve for Aliso Canyon costs	141	(144)	56
Other current liabilities	(127)	(99)	52
Intercompany activities with discontinued operations, net	0	378	70
Distributions from investments	651	247	202
Insurance receivable for Aliso Canyon costs	(106)	122	(43)
Wildfire fund, current and noncurrent	0	(323)	0
Reserve for Aliso Canyon costs, noncurrent	294	0	0
Changes in other noncurrent assets and liabilities, net	56	(399)	(188)
Net cash provided by continuing operations	3,642	2,698	3,220
Net cash (used in) provided by discontinued operations	(1,051)	390	296
Net cash provided by operating activities	2,591	3,088	3,516
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(4,676)	(3,708)	(3,544)
Expenditures for investments and acquisitions	(652)	(1,797)	(10,168)
Proceeds from sale of assets	19	899	1,580
Distributions from investments	761	9	10
Purchases of nuclear decommissioning trust assets	(1,439)	(914)	(890)
Proceeds from sales of nuclear decommissioning trust assets	1,439	914	890
Advances to unconsolidated affiliates	(92)	(16)	(95)
Repayments of advances to unconsolidated affiliates	7	3	3
Intercompany activities with discontinued operations, net	0	8	(22)
Other	15	21	31
Net cash used in continuing operations	(4,618)	(4,581)	(12,205)
Net cash provided by (used in) discontinued operations	5,171	(12)	(265)
Net cash provided by (used in) investing activities	553	(4,593)	(12,470)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(1,174)	(993)	(877)
Preferred dividends paid	(157)	(142)	(89)
Proceeds from Issuance of Preferred Stock and Preference Stock	891	0	2,258
Issuances of common stock, net	11	1,830	2,272
Repurchases of common stock	(566)	(26)	(21)
Issuances of debt (maturities greater than 90 days)	6,051	4,296	8,927
Payments on debt (maturities greater than 90 days) and finance leases	(5,864)	(3,667)	(3,342)
(Decrease) increase in short-term debt, net	(1,759)	656	(84)
Advances from unconsolidated affiliates	64	155	0
Proceeds from sale of noncontrolling interests, net	26	5	90
Purchases of noncontrolling interests	(248)	(30)	(7)
Contributions from (distributions to) noncontrolling interests, net	1	98
Contributions from (distributions to) noncontrolling interests, net			(26)
Intercompany activities with discontinued operations, net	0	(266)	(109)
Other	(50)	(49)	(117)
Net cash (used in) provided by continuing operations	(2,774)	1,867	8,875
Net cash provided by (used in) discontinued operations	401	(392)	(25)
Net cash (used in) provided by financing activities	(2,373)	1,475	8,850
Effect of exchange rate changes on cash, cash equivalents and restricted cash	0	0	(2)
Effect of exchange rate changes in discontinued operations	(3)	1	(12)
Effect of exchange rate changes on cash, cash equivalents and restricted cash	(3)	1	(14)
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations	768	(29)	(118)
Cash, cash equivalents and restricted cash, including discontinued operations, January 1	217	246	364
Cash, cash equivalents and restricted cash, including discontinued operations, December 31	985	217	246
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	1,046	1,051	773
Income tax payments (refunds), net	1,385	360	174
Noncash acquisition of businesses:
Assets acquired	0	0	9,670
Liabilities assumed	0	0	(102)
Cash paid	0	0	(9,568)
Other Noncash Investing and Financing Items [Abstract]
Accrued interest receivable from unconsolidated affiliate	0	55	62
Accrued capital expenditures	535	515	425
Accrued commercial paper proceeds	0	67	0
Increase in finance lease obligations for investment in property, plant and equipment	77	38	556
Increase in ARO for investment in PP&E	142	36	78
Debt instrument converted	22	0	0
Contribution to Cameron LNG JV	50	0	0
Distribution from Cameron LNG JV	50	0	0
Common dividends issued in stock	22	55	54
San Diego Gas and Electric Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	824	774	676
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	801	760	688
Deferred income taxes and investment tax credits	35	105	39
Other	27	13	(17)
Net change in other working capital components:
Accounts receivable	(134)	(15)	30
Due to/from affiliates, net	11	(8)	(2)
Income taxes receivable/payable, net	129	(126)	23
Inventories	(10)	4	3
Other current assets	4	(19)	(6)
Accounts payable	31	32	(1)
Regulatory balancing accounts	(71)	(101)	138
Other current liabilities	(100)	4	4
Wildfire fund, current and noncurrent	0	(323)	0
Changes in other noncurrent assets and liabilities, net	(158)	(10)	9
Net cash provided by operating activities	1,389	1,090	1,584
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,942)	(1,522)	(1,542)
Decrease in cash from deconsolidation of Otay Mesa VIE	0	(8)	0
Purchases of nuclear decommissioning trust assets	(1,439)	(914)	(890)
Proceeds from sales of nuclear decommissioning trust assets	1,439	914	890
Other	8	8	0
Net cash provided by (used in) investing activities	(1,934)	(1,522)	(1,542)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(200)	0	(250)
Equity contribution from Sempra Energy	0	322	0
Issuances of debt (maturities greater than 90 days)	1,598	400	618
Payments on debt (maturities greater than 90 days) and finance leases	(510)	(274)	(492)
(Decrease) increase in short-term debt, net	(80)	(211)	38
Contributions from (distributions to) noncontrolling interests, net	0	172	57
Debt issuance costs	(11)	(4)	(5)
Net cash (used in) provided by financing activities	797	405	(34)
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations	252	(27)	8
Cash, cash equivalents and restricted cash, January 1	10	37	29
Cash, cash equivalents and restricted cash, December 31	262	10	37
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	404	405	214
Income tax payments (refunds), net	25	191	112
Other Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	199	174	159
Increase in finance lease obligations for investment in property, plant and equipment	30	16	550
Increase in ARO for investment in PP&E	31	(1)	35
Southern California Gas Company [Member]
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	505	642	401
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	654	602	556
Deferred income taxes and investment tax credits	(112)	88	78
Impairment losses	0	37	0
Other	59	(5)	(7)
Net change in other working capital components:
Accounts receivable	(101)	(73)	(87)
Due to/from affiliates, net	(27)	(1)	(10)
Income taxes receivable/payable, net	189	(156)	14
Inventories	(19)	1	(2)
Other current assets	(12)	(9)	11
Accounts payable	64	(7)	71
Regulatory balancing accounts	(160)	114	125
Reserve for Aliso Canyon costs	141	(144)	56
Other current liabilities	(21)	(21)	(6)
Insurance receivable for Aliso Canyon costs	(106)	122	(43)
Reserve for Aliso Canyon costs, noncurrent	294	0	0
Changes in other noncurrent assets and liabilities, net	178	(322)	(144)
Net cash provided by operating activities	1,526	868	1,013
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,843)	(1,439)	(1,538)
Other	0	1	7
Net cash provided by (used in) investing activities	(1,843)	(1,438)	(1,531)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(100)	(150)	(50)
Preferred dividends paid	(1)	(1)	(1)
Issuances of debt (maturities greater than 90 days)	949	349	949
Payments on debt (maturities greater than 90 days) and finance leases	(12)	(6)	(500)
(Decrease) increase in short-term debt, net	(517)	374	140
Debt issuance costs	(8)	(4)	(10)
Net cash (used in) provided by financing activities	311	562	528
Increase (decrease) in cash, cash equivalents and restricted cash, including discontinued operations	(6)	(8)	10
Cash, cash equivalents and restricted cash, January 1	10	18	8
Cash, cash equivalents and restricted cash, December 31	4	10	18
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	146	126	105
Income tax payments (refunds), net	19	188	0
Other Noncash Investing and Financing Items [Abstract]
Accrued capital expenditures	208	205	191
Increase in finance lease obligations for investment in property, plant and equipment	47	22	6
Increase in ARO for investment in PP&E	107	35	35
Preferred Stock [Member]
Other Noncash Investing and Financing Items [Abstract]
Dividends declared but not paid	47	36	36
Common Stock [Member]
Other Noncash Investing and Financing Items [Abstract]
Dividends declared but not paid	$ 301	$ 283	$ 245

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Preferred Stock [Member]	Preferred Stock [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Common Stock [Member]	Common Stock [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Retained earnings [Member]	Retained earnings [Member]Cumulative Effect, Period of Adoption, Adjustment	Retained earnings [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Accumulated other comprehensive income (loss) [Member]	Accumulated other comprehensive income (loss) [Member]Cumulative Effect, Period of Adoption, Adjustment	Accumulated other comprehensive income (loss) [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Shareholders' equity [Member]	Shareholders' equity [Member]Cumulative Effect, Period of Adoption, Adjustment	Shareholders' equity [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Non-controlling interests [Member]	Non-controlling interests [Member]Cumulative Effect, Period of Adoption, Adjustment	Non-controlling interests [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]	San Diego Gas and Electric Company [Member]Cumulative Effect, Period of Adoption, Adjustment	San Diego Gas and Electric Company [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Common Stock [Member]	San Diego Gas and Electric Company [Member]Common Stock [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Retained earnings [Member]	San Diego Gas and Electric Company [Member]Retained earnings [Member]Cumulative Effect, Period of Adoption, Adjustment	San Diego Gas and Electric Company [Member]Retained earnings [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss) [Member]	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss) [Member]Cumulative Effect, Period of Adoption, Adjustment	San Diego Gas and Electric Company [Member]Accumulated other comprehensive income (loss) [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Shareholders' equity [Member]	San Diego Gas and Electric Company [Member]Shareholders' equity [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	San Diego Gas and Electric Company [Member]Non-controlling interests [Member]	San Diego Gas and Electric Company [Member]Non-controlling interests [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Southern California Gas Company [Member]	Southern California Gas Company [Member]Cumulative Effect, Period of Adoption, Adjustment	Southern California Gas Company [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Southern California Gas Company [Member]Preferred Stock [Member]	Southern California Gas Company [Member]Preferred Stock [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Southern California Gas Company [Member]Common Stock [Member]	Southern California Gas Company [Member]Common Stock [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Southern California Gas Company [Member]Retained earnings [Member]	Southern California Gas Company [Member]Retained earnings [Member]Cumulative Effect, Period of Adoption, Adjustment	Southern California Gas Company [Member]Retained earnings [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	Southern California Gas Company [Member]Accumulated other comprehensive income (loss) [Member]	Southern California Gas Company [Member]Accumulated other comprehensive income (loss) [Member]Cumulative Effect, Period of Adoption, Adjustment	Southern California Gas Company [Member]Accumulated other comprehensive income (loss) [Member]Cumulative Effect, Period of Adoption, Adjusted Balance	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]	Series C Preferred Stock [Member]	Series C Preferred Stock [Member]Preferred Stock [Member]	Series C Preferred Stock [Member]Retained earnings [Member]	Series C Preferred Stock [Member]Shareholders' equity [Member]
Beginning Balance at Dec. 31, 2017	$ 15,140	$ (1)	$ 15,139	$ 0	$ 0	$ 3,149	$ 3,149	$ 10,147	$ 2	$ 10,149	$ (626)	$ (3)	$ (629)	$ 12,670	$ (1)	$ 12,669	$ 2,470		$ 2,470	$ 5,626			$ 1,338		$ 4,268			$ (8)			$ 5,598		$ 28		$ 3,907			$ 22		$ 866		$ 3,040			$ (21)
Accounting Standards Update [Extensible List]																				us-gaap:AccountingStandardsUpdate201802Member															us-gaap:AccountingStandardsUpdate201802Member
Net income	1,126							1,050						1,050			76			$ 676					669						669		7		$ 401							401
Other comprehensive income (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)
Contributions	66																66			65													65
Distributions	(110)																(110)			(8)													(8)
Purchases	(8)					(1)								(1)			(7)
Sales, net of offering costs	90					4								4			86
Acquisition	13																13
Deconsolidations	(486)																(486)
Ending balance at Dec. 31, 2018	19,248		19,263	2,258	2,258	5,540	5,540	10,104		10,161	(764)		(806)	17,138		17,153	2,110		2,110	6,115	$ 0	$ 6,115	1,338	$ 1,338	4,687	$ 2	$ 4,689	(10)	$ (2)	$ (12)	6,015	$ 6,015	100	$ 100	4,258	$ (2)	$ 4,256	22	$ 22	866	$ 866	3,390	$ 2	$ 3,392	(20)	$ (4)	$ (24)
Ending balance (Accounting Standards Update 2016-02 [Member]) at Dec. 31, 2018		17							17						17
Ending balance (Accounting Standards Update 2018-02 [Member]) at Dec. 31, 2018		(2)							40			$ (42)			(2)
Net income	2,362							2,198						2,198			164			774					767						767		7		642							642
Other comprehensive income (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)
Contributions	175																175			175													175
Distributions	(98)					5								5			(103)			(3)													(3)
Purchases	(30)					(3)								(3)			(27)
Sales, net of offering costs	5					4								4			1
Acquisition	3																3
Deconsolidations	(440)																(440)			(281)													(281)
Ending balance at Dec. 31, 2019	21,805	$ (9)	$ 21,796	2,258	$ 2,258	7,480	$ 7,480	11,130	$ (7)	$ 11,123	(939)		$ (939)	19,929	$ (7)	$ 19,922	1,876	$ (2)	$ 1,874	7,100			1,660		5,456			(16)			7,100		0		4,748			22		866		3,883			(23)
Net income	4,105							3,933						3,933			172			824					824						824		0		505							505
Other comprehensive income (loss)	422										446			446			(24)			6								6			6		0		(8)										(8)
Share-based compensation expense	71					71								71
Preferred stock dividends declared																																			(1)							(1)						$ (104)		$ (104)	$ (104)	$ (39)		$ (39)	$ (39)	$ (25)		$ (25)	$ (25)
Common stock dividends declared	(1,214)							(1,214)						(1,214)						(200)					(200)						(200)				(100)							(100)
Preferred dividends of subsidiary	(1)							(1)						(1)
Issuances of stock	33					33								33																																										$ 889	$ 889		$ 889
Repurchases of common stock	(566)					(566)								(566)
Contributions	1																1
Distributions	(1)																(1)
Purchases	(248)					34					(7)			27			(275)
Sales, net of offering costs	28					1								1			27
Acquisition	1																1
Equitization of long-term debt for deficit held by NCI	22																22
Deconsolidations	(236)																(236)
Ending balance at Dec. 31, 2020	$ 24,934			$ 3,147		$ 7,053		$ 13,673			$ (500)			$ 23,373			$ 1,561			$ 7,730			$ 1,660		$ 6,080			$ (10)			$ 7,730		$ 0		$ 5,144			$ 22		$ 866		$ 4,287			$ (31)

CONSOLIDATED STATEMENTS OF CH_2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Common stock dividends declared (USD per share)	$ 4.18	$ 3.87	$ 3.58
Sales, net of offering costs	$ 28	$ 5	$ 90
Shareholders' equity [Member]
Sales, net of offering costs	1	4	4
Non-controlling interests [Member]
Sales, net of offering costs	$ 27	$ 1	$ 86
Preferred Class A [Member]
Preferred stock, dividends declared per share (USD per share)	$ 6	$ 6	$ 6.10
Preferred Class B [Member]
Preferred stock, dividends declared per share (USD per share)	6.75	6.75	3.41
Series C Preferred Stock [Member]
Preferred stock, dividends declared per share (USD per share)	27.90
Southern California Gas Company [Member]
Preferred stock, dividends declared per share (USD per share)	1.50	1.50	1.50
Common stock dividends declared (USD per share)	1.10	$ 1.64	0.55
San Diego Gas and Electric Company [Member]
Common stock dividends declared (USD per share)	$ 1.72		$ 2.14

SIGNIFICANT ACCOUNTING POLICIES

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA	12 Months Ended
	Dec. 31, 2020
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 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. 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,” “us” 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 these Notes, 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, which we discuss further in Note 5. We completed the sales in the second quarter of 2020. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted. Subsequent Events 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, 2020, 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 NDT 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 and the Support Agreement at Sempra LNG. 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 includes 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 at Sempra Mexico. 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, 2020 2019 Sempra Energy Consolidated: Cash and cash equivalents $ 960 $ 108 Restricted cash, current 22 31 Restricted cash, noncurrent 3 3 Cash, cash equivalents and restricted cash in discontinued operations — 75 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 985 $ 217 In the Sempra Energy Consolidated Statement of Cash Flows for the year ended December 31, 2020, the ending cash, cash equivalents and restricted cash balance in discontinued operations of $4.6 billion is considered to be cash, cash equivalents and restricted cash for continuing operations following the sales of the South American businesses. CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable and amounts due from unconsolidated affiliates. We are also exposed to credit losses from off-balance sheet arrangements through our guarantees of Cameron LNG JV’s debt. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivable, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered. In connection with the COVID-19 pandemic, the California Utilities have implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for residential and small business customers, waiving late payment fees for business customers, and offering flexible payment plans to customers experiencing difficulty paying their electric or gas bills. As we discuss in Note 4, the CPUC authorized each of the California Utilities to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with residential and small business customer protection measures implemented by the CPUC related to the COVID-19 pandemic. In June 2020, the CPUC issued a decision in a separate proceeding addressing service disconnections that, among other things, allows each of the California Utilities to establish a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills. This decision also directs the California Utilities to establish an AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts. Refer to Note 4 for further discussion. The California Utilities have recorded increases in their allowances for expected credit losses as of December 31, 2020 primarily related to expected forgiveness of outstanding utility bill amounts, including increases due to the effect of the COVID-19 pandemic, for residential customers eligible under the AMP. Our businesses will continue to monitor macroeconomic factors and customer payment patterns when evaluating their allowances for credit losses in future reporting periods, which may increase significantly due to the effects of the COVID-19 pandemic or other factors. We provide below allowances and changes in allowances for credit losses for trade and other accounts receivable, excluding allowances related to amounts due from unconsolidated affiliates and off-balance sheet arrangements, which we discuss separately below the table. The California Utilities record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts. TRADE AND OTHER ACCOUNTS RECEIVABLE – ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated: Allowances for credit losses at January 1 $ 29 $ 21 $ 25 Incremental allowance upon adoption of ASU 2016-13 1 — — Provisions for expected credit losses 124 22 10 Write-offs (16) (14) (14) Allowances for credit losses at December 31 (1) $ 138 $ 29 $ 21 SDG&E: Allowances for credit losses at January 1 $ 14 $ 11 $ 9 Provisions for expected credit losses 65 10 9 Write-offs (10) (7) (7) Allowances for credit losses at December 31 (2) $ 69 $ 14 $ 11 SoCalGas: Allowances for credit losses at January 1 $ 15 $ 10 $ 16 Provisions for expected credit losses 59 12 1 Write-offs (6) (7) (7) Allowances for credit losses at December 31 (3) $ 68 $ 15 $ 10 (1) Balances at December 31, 2020 and 2019 include $111 million and $7 million, respectively, in Accounts Receivable – Trade, Net and $27 million and $22 million, respectively, in Accounts Receivable – Other, Net. (2) Balances at December 31, 2020 and 2019 include $55 million and $4 million, respectively, in Accounts Receivable – Trade, Net and $14 million and $10 million, respectively, in Accounts Receivable – Other, Net. (3) Balances at December 31, 2020 and 2019 include $55 million and $3 million, respectively, in Accounts Receivable – Trade, Net and $13 million and $12 million, respectively, in Accounts Receivable – Other, Net. For amounts due from unconsolidated affiliates and off-balance sheet arrangements, on a quarterly basis, we evaluate credit losses and record allowances for expected credit losses, if necessary, based on credit quality indicators such as external credit ratings, published default rate studies, the maturity date of the instrument and past delinquencies. However, we do not record allowances for expected credit losses related to accrued interest receivable on loans due from unconsolidated affiliates because we write off such amounts, if any, through a reversal of interest income in the period we determine such amounts are uncollectible. In the absence of external credit ratings, we may utilize an internally developed credit rating based on our analysis of a counterparty’s financial statements to determine our expected credit losses. As we discuss below in “Transactions with Affiliates,” we have loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. We provide below the changes in allowances for credit losses for loans and other amounts due from unconsolidated affiliates. AMOUNTS DUE FROM UNCONSOLIDATED AFFILIATES – ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) Sempra Energy Consolidated (1) Allowances for credit losses at January 1, 2020 $ — Allowance established upon adoption of ASU 2016-13 6 Reduction to expected credit losses (3) Allowances for credit losses at December 31, 2020 $ 3 (1) Balance at December 31, 2020 includes negligible amounts and $3 million in Due from Unconsolidated Affiliates – Current and Due from Unconsolidated Affiliates – Noncurrent, respectively. As we discuss in Note 6, Sempra Energy has provided guarantees for the benefit of Cameron LNG JV related to its debt obligations for a maximum aggregate amount of $4.0 billion. We established a liability for credit losses of $6 million for this off-balance sheet arrangement upon adoption of ASU 2016-13 on January 1, 2020 and we subsequently reduced this liability by $4 million in the year ended December 31, 2020 through a reduction to credit loss expense, which is included in O&M on the Sempra Energy Consolidated Statement of Operations. At December 31, 2020, expected credit losses of $2 million are included in Other Current Liabilities on the Sempra Energy Consolidated Balance Sheet. 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 at each of our segments and overseen by their separate risk management committees. This oversight includes calculating current and potential credit risk on a regular 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 in our allowances for credit losses. 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 last-in first-out method. As inventories are sold, differences between the last-in first-out 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 2020 2019 2020 2019 2020 2019 2020 2019 Sempra Energy Consolidated $ 118 $ 110 $ 7 $ 9 $ 183 $ 158 $ 308 $ 277 SDG&E — 1 — — 104 93 104 94 SoCalGas 94 90 — — 59 46 153 136 WILDFIRE FUND In July 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 provided that SDG&E would not recover the ROE on its first $215 million of fire risk mitigation capital expenditures. 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) designed 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, primary insurance coverage is exceeded and certain other conditions are satisfied. A 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. Based on its 2020 rate base, the liability cap for SDG&E is approximately $950 million, which is 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, if any, will be transferred to California’s general fund to be used for fire risk mitigation programs. In June 2020, the CPUC approved SDG&E’s 2020 wildfire mitigation plan, which is effective until the CPUC approves a new plan. In addition, on September 14, 2020, SDG&E received its 2020 safety certification from the Wildfire Safety Division of the CPUC. The certificate is valid for 12 months from the issue date. The Wildfire Fund has been initially funded up to $10.5 billion by a loan from the State of California Surplus Money Investment Fund. The loan is financed through a DWR bond, which was put in place on October 1, 2020 and is 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. The Wildfire Fund has also been funded $7.5 billion from initial shareholder contributions from the IOUs (SDG&E’s share was $322.5 million, PG&E’s share was $4.8 billion and Edison’s share was $2.4 billion). The IOUs are also required to make annual shareholder contributions to the Wildfire Fund with an aggregate value of $3 billion over a 10-year period starting in 2019 (SDG&E’s share is $129 million, PG&E’s share is $1.9 billion and Edison’s share is $945 million). The contributions are not subject to rate recovery. 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. That court dismissed the complaint and the plaintiffs have petitioned the U.S. Court of Appeals for the Ninth Circuit to review the dismissal. Wildfire Fund Asset and Obligation In the third quarter of 2019, SDG&E recorded both a Wildfire Fund asset and a related obligation of $451.5 million for its commitment to make shareholder contributions to the Wildfire Fund, 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. 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 and PG&E paid its initial shareholder contribution in July 2020 after receiving bankruptcy court approval to participate in the Wildfire Fund. SDG&E expects to make annual shareholder contributions of $12.9 million through December 31, 2028. SDG&E accretes the present value of the Wildfire Fund obligation until the liability is settled. SDG&E is amortizing the Wildfire Fund asset 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 is 15 years and 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. SDG&E periodically evaluates the estimated period of benefit of the Wildfire Fund asset based on actual experience and changes in these 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 any of the participating IOUs. 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. Although California experienced some of the largest wildfires in its history in 2020 (measured by acres burned), including fires in each participating IOU’s service territory, SDG&E is not aware of any claims made by any participating IOU requiring a reduction of the Wildfire Fund asset as of December 31, 2020. The following table summarizes the location of balances related to the Wildfire Fund on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations. WILDFIRE FUND (Dollars in millions) December 31, Location 2020 2019 Wildfire Fund asset: Current Other Current Assets (1) $ 29 $ 29 Noncurrent Wildfire Fund 363 392 Wildfire Fund obligation: Current Other Current Liabilities $ 13 $ 13 Noncurrent Deferred Credits and Other 75 86 Years ended December 31, 2020 2019 Amortization of Wildfire Fund asset Operation and Maintenance $ 29 $ 12 Accretion of Wildfire Fund obligation Operation and Maintenance 2 1 (1) Included in Prepaid Expenses for SDG&E. 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. Investment tax credits 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. We accrue income tax to the extent we intend to repatriate cash to the U.S. from our continuing international operations. 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

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS	12 Months Ended
	Dec. 31, 2020
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 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13, as amended by subsequently issued ASUs, changes how entities 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 receivables and 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. We adopted the standard on January 1, 2020 using a modified retrospective approach through a cumulative-effect adjustment to retained earnings. The adoption primarily impacted the expected credit losses associated with accounts receivable balances, amounts due from unconsolidated affiliates and off-balance sheet financial guarantees. There was an insignificant impact to SDG&E’s and SoCalGas’ balance sheets from adoption. The following table shows the initial (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. 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. We adopted ASU 2017-04 on January 1, 2020 and are applying the standard on a prospective basis to our goodwill impairment tests. ASU 2020-04, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting”: ASU 2020-04 provides optional expedients and exceptions for applying U.S. GAAP to contract modifications that replace LIBOR or another reference rate affected by reference rate reform and to hedging relationships that reference LIBOR or another reference rate affected or expected to be affected by reference rate reform. ASU 2020-04 was effective March 12, 2020 and can be applied through December 31, 2022, with certain exceptions for hedging relationships that continue to exist after this date, and may be applied from January 1, 2020. For contract modifications, the standard allows entities to account for modifications as an event that does not require reassessment or remeasurement (i.e., as a continuation of the existing contract). The standard also allows entities to amend their formal designation and documentation of hedging relationships affected or expected to be affected by reference rate reform, without having to de-designate the hedging relationship. Entities may elect the optional expedients and exceptions on an individual hedging relationship basis and independently from one another. We elected the optional expedients for contract modifications. We elected the cash flow hedging expedients to disregard the potential discontinuation of a reference rate when assessing whether a hedged forecasted interest payment is probable and to disregard certain mismatches between the designated hedging instrument and the hedged item when assessing the hedge effectiveness. We are applying these expedients prospectively from January 1, 2020. Application of these expedients preserves the presentation of derivatives consistent with the past presentation. ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial conversion features and cash conversion features. The standard also amends ASC 260, “Earnings Per Share,” as follows: ▪ requires an entity to apply the if-converted method when calculating diluted EPS for convertible instruments and no longer use the treasury stock method, which was previously allowed for certain convertible instruments; ▪ requires an entity to include the effect of potential share settlement in the diluted EPS calculation when an instrument may be settled in cash or shares, and no longer allows an entity to rebut the presumption of share settlement if it has a history or policy of cash settlement; ▪ requires an entity to include equity-classified convertible preferred stock that contains down-round features whereby, if the down-round feature is triggered, its effect is treated as a dividend and as a reduction of income available to common shareholders in basic EPS; ▪ clarifies that the average market price should be used to calculate the diluted EPS denominator when the exercise price or the number of shares that may be issued is variable, except for certain contingently issuable shares; and ▪ clarifies that the weighted-average share count from each quarter should be used when calculating the year-to-date weighted-average share count.

REVENUES

REVENUES	12 Months Ended
	Dec. 31, 2020
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) SDG&E SoCalGas Sempra Mexico Sempra LNG Sempra Renewables Consolidating adjustments and Parent and other Sempra Energy Consolidated Year ended December 31, 2020 By major service line: Utilities $ 4,920 $ 4,571 $ 58 $ — $ — $ (94) $ 9,455 Energy-related businesses — — 834 92 — (71) 855 Revenues from contracts with customers $ 4,920 $ 4,571 $ 892 $ 92 $ — $ (165) $ 10,310 By market: Gas $ 692 $ 4,571 $ 603 $ 86 $ — $ (156) $ 5,796 Electric 4,228 — 289 6 — (9) 4,514 Revenues from contracts with customers $ 4,920 $ 4,571 $ 892 $ 92 $ — $ (165) $ 10,310 Revenues from contracts with customers $ 4,920 $ 4,571 $ 892 $ 92 $ — $ (165) $ 10,310 Utilities regulatory revenues 393 177 — — — — 570 Other revenues — — 364 282 — (156) 490 Total revenues $ 5,313 $ 4,748 $ 1,256 $ 374 $ — $ (321) $ 11,370 Year ended December 31, 2019 By major service line: Utilities $ 4,819 $ 4,367 $ 73 $ — $ — $ (75) $ 9,184 Energy-related businesses — — 919 176 5 (143) 957 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 176 $ 5 $ (218) $ 10,141 By market: Gas $ 587 $ 4,367 $ 680 $ 170 $ — $ (208) $ 5,596 Electric 4,232 — 312 6 5 (10) 4,545 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 176 $ 5 $ (218) $ 10,141 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 176 $ 5 $ (218) $ 10,141 Utilities regulatory revenues 106 158 — — — — 264 Other revenues — — 383 234 5 (198) 424 Total revenues $ 4,925 $ 4,525 $ 1,375 $ 410 $ 10 $ (416) $ 10,829 Year ended December 31, 2018 By major service line: Utilities $ 4,788 $ 3,577 $ 78 $ — $ — $ (69) $ 8,374 Energy-related businesses — — 941 232 46 (146) 1,073 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 232 $ 46 $ (215) $ 9,447 By market: Gas $ 491 $ 3,577 $ 711 $ 224 $ — $ (203) $ 4,800 Electric 4,297 — 308 8 46 (12) 4,647 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 232 $ 46 $ (215) $ 9,447 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 232 $ 46 $ (215) $ 9,447 Utilities regulatory revenues (220) 385 — — — — 165 Other revenues — — 357 240 78 (185) 490 Total revenues $ 4,568 $ 3,962 $ 1,376 $ 472 $ 124 $ (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 we 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, resulting in a significant portion of earnings being 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. In connection with the COVID-19 pandemic, the California Utilities and the CPUC have implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for residential and small business customers, waiving late payment fees for business customers, and offering flexible payment plans to customers experiencing difficulty paying their electric or gas bills. Additional measures could be mandated or voluntarily implemented in the future. Under the regulatory compact applicable to the California Utilities, including decoupling of rates, recovery of uncollectible expenses, and other recovery mechanisms potentially available, which we discuss in Note 4, the California Utilities have continued to recognize revenues under ASC 606, “Revenue from Contracts with Customers,” in the year ended December 31, 2020. 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 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, in February 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 Mexico and, previously, Sempra Renewables 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 and delivered. 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, Sempra Renewables completed the sale of its 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 has a contractual agreement to provide scheduling and marketing of renewable power for Sempra Mexico’s ESJ JV. 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, 2020, 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, 2020. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E 2021 $ 387 $ 4 2022 406 4 2023 407 4 2024 348 4 2025 351 4 Thereafter 4,361 67 Total revenues to be recognized $ 6,260 $ 87 (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 liabilities at SDG&E in 2018 or at SoCalGas in 2020, 2019 or 2018. CONTRACT LIABILITIES (Dollars in millions) 2020 2019 2018 Sempra Energy Consolidated: Contract liabilities at January 1 $ (163) $ (70) $ — Adoption of ASC 606 — — (61) Revenue from performance obligations satisfied during reporting period 4 2 7 Payments received in advance (48) (95) (16) Contract liabilities at December 31 (1) $ (207) $ (163) $ (70) SDG&E: Contract liabilities at January 1 $ (91) $ — Revenue from performance obligations satisfied during reporting period 4 1 Payments received in advance — (92) Contract liabilities at December 31 (2) $ (87) $ (91) (1) Balances at December 31, 2020 and 2019 include $52 million and $4 million, respectively, in Other Current Liabilities and $155 million and $159 million, respectively, in Deferred Credits and Other. (2) Balances at December 31, 2020 and 2019 include $4 million and $4 million, respectively, in Other Current Liabilities and $83 million and $87 million, respectively, in Deferred Credits and Other. Receivables from Revenues from Contracts with Customers The table below shows receivable balances associated with revenues from contracts with customers on the Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2020 2019 Sempra Energy Consolidated: Accounts receivable – trade, net $ 1,447 $ 1,163 Accounts receivable – other, net 12 16 Due from unconsolidated affiliates – current (1) 3 5 Total $ 1,462 $ 1,184 SDG&E: Accounts receivable – trade, net $ 573 $ 398 Accounts receivable – other, net 8 5 Due from unconsolidated affiliates – current (1) 2 2 Total $ 583 $ 405 SoCalGas: Accounts receivable – trade, net $ 786 $ 710 Accounts receivable – other, net 4 11 Total $ 790 $ 721 (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 ratepayers. We discuss balancing accounts and their effects further in Note 4. Other Revenues 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 has an agreement to supply LNG to Sempra Mexico’s ECA Regas Facility. 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 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, 2020
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, 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 22 (108) Pension and other postretirement benefit plan obligations 50 103 Removal obligations (2,121) (2,056) Environmental costs 56 45 Sunrise Powerlink fire mitigation 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 72 102 Gas transportation 35 22 Safety and reliability 67 77 Public purpose programs (158) (124) 2019 GRC retroactive impacts 56 111 Other balancing accounts 233 106 Other regulatory assets (liabilities), net (2) 72 (153) Total SDG&E (1,548) (1,746) SoCalGas: Deferred income taxes refundable in rates (82) (203) Pension and other postretirement benefit plan obligations 417 400 Employee benefit costs 37 44 Removal obligations (685) (728) Environmental costs 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (56) (118) Safety and reliability 335 295 Public purpose programs (253) (273) 2019 GRC retroactive impacts 202 400 Other balancing accounts (58) (7) Other regulatory assets (liabilities), net (2) 75 (101) Total SoCalGas (32) (251) Sempra Mexico: Deferred income taxes recoverable in rates 80 83 Other regulatory assets — 6 Total Sempra Energy Consolidated $ (1,500) $ (1,908) (1) At December 31, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $139 million and $108 million, respectively, and for SoCalGas was $218 million and $500 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 excess deferred income taxes resulting from statutory income tax rate changes and 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 49-year period. ▪ Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, including commodity costs. Depreciation, taxes 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. The adopted revenue requirements in the 2019 GRC FD associated with the period from January 1, 2019 through December 31, 2019 are being recovered in rates over a 24-month period that began in January 2020. Amortization expense on regulatory assets for the years ended December 31, 2020, 2019 and 2018 was $9 million, $7 million and $5 million, respectively, at Sempra Energy Consolidated, $4 million, $3 million and $2 million, respectively, at SDG&E, and $5 million, $4 million and $3 million, respectively, at SoCalGas. CALIFORNIA UTILITIES COVID-19 Pandemic Protections In March 2020, the CPUC required that all energy companies under its jurisdiction, including the California Utilities, take action to implement several emergency customer protection measures to support California customers in light of the COVID-19 pandemic for up to one year. Currently, the customer protection measures are mandatory for all residential and small business customers. In February 2021, the CPUC extended the customer protection measures through June 2021 and may extend them further. Each of the California Utilities was authorized to track and request recovery of incremental costs associated with complying with residential and small business customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated with suspending service disconnections and uncollectible expenses that arise from these customers’ failure to pay. The California Utilities expect to pursue recovery of tracked costs in rates in a future CPUC proceeding, which recovery is not assured. Disconnection OIR In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. The decision allows each of the California Utilities to establish a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. 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 In September 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, which was effective retroactively to January 1, 2019. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD approved 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) and $2,770 million for SoCalGas. 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 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 California Utilities filed the petition in April 2020 and requested authorization of their post-test year ratemaking mechanism for two additional years. We subsequently requested an updated increase in the revenue requirement for SDG&E and SoCalGas of approximately $91 million and $150 million, respectively, for 2022, and $104 million and $131 million, respectively, for 2023, reflecting certain adjustments. These amounts include revenues for both O&M and capital cost attrition. In June 2020, the CPUC issued a ruling to further clarify the issues for review in the California Utilities’ petition, which are mainly whether the proposed revenue requirements and mechanisms for the two proposed additional attrition years are just and reasonable. In September 2020, the California Utilities filed a status report to summarize positions on how impacts of the COVID-19 pandemic should be incorporated into the proposed attrition rates. The California Utilities proposed to continue with the adopted attrition mechanism using the second quarter 2020 Global Insight utility cost forecast, which incorporates impacts of the COVID-19 pandemic. Intervenors have proposed other alternatives, including using escalation factors based on the Consumer Price Index. We expect a proposed decision in the first quarter of 2021. The 2019 GRC FD approved the California Utilities’ 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. The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time the California Utilities released these regulatory liability balances to revenues and regulatory interest. CPUC Cost of Capital In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that became effective on 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 the CPUC approved in March 2020. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on Weighted 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 Equity 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. SDG&E’s CCM benchmark rate is 4.498%, based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029%, 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. For the 12 months ended September 2020, the first “CCM Period,” the trigger did not occur for SDG&E or SoCalGas. The next CCM Period is from October 2020 to September 2021. The CCM, if triggered in 2021, would be effective January 1, 2022, and would automatically update the authorized cost of debt based on actual costs and update the authorized ROE upward or downward by one-half of the difference between the CCM benchmark and the applicable 12-month average Moody’s utility bond index. 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 TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided 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. If the FERC issues an order ruling that California IOUs are no longer eligible for the additional California ISO ROE, SDG&E would refund the additional 50 bps of ROE associated with the California ISO as of the refund effective date (June 1, 2019) in this proceeding. The TO5 term is effective June 1, 2019 and shall remain in effect indefinitely, with parties having the annual right to terminate the agreement beginning in 2022. In 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. Energy Efficiency Program Inquiry In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive. Pursuant to the CPUC ruling, intervenors representing ratepayers have questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review and discussions with intervenors, SDG&E concluded that some concessions were appropriate, which include refunding certain costs and certain performance-based incentives to customers and incurring a fine. Accordingly, in the year ended December 31, 2020, SDG&E reduced revenues by $51 million and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Energy Consolidated Statements of Operations. The after-tax impact for the year ended December 31, 2020 was $44 million. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. We expect CPUC approval of the settlement agreement in 2021. SOCALGAS OSCs – Energy Efficiency and Advocacy In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders. The OSC stemmed from approximately 40 days and $9,000 of transitional energy efficiency (EE) codes and standards advocacy activities undertaken by SoCalGas in 2018, following a CPUC decision disallowing SoCalGas’ future engagement in EE statewide codes and standards advocacy. In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017, whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. The scope of this OSC was later expanded to include EE program years 2014 and 2015, and SoCalGas’ engagement with local governments on proposed reach codes. Intervenors in these OSCs have suggested the CPUC order various financial and non-financial penalties. If the CPUC were to assess fines or penalties on SoCalGas associated with these OSCs, they could be material. We expect CPUC decisions on these OSCs in the first half of 2021. Billing Practices OII NOTE 15. SAN ONOFRE NUCLEAR GENERATING STATION 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. 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 July 2018, the CPUC approved a settlement agreement and, in August 2018, SDG&E, Edison, Cal PA, TURN and other intervenors submitted a notice that they accepted the settlement agreement, which provided for various disallowances, refunds and rate recoveries. In connection with the settlement agreement, and in exchange for the release of certain SONGS-related claims, in January 2018, SDG&E and Edison entered into a utility shareholder agreement, which became effective upon CPUC approval of the settlement agreement in July 2018, 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 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. Edison’s payment obligation commenced in October 2018, and amounts are due to SDG&E quarterly thereafter until April 2022. At December 31, 2020, SDG&E has a receivable from Edison, including accrued interest, totaling $49 million, with $37 million classified as current and $12 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 work to take 10 years after receipt of all the required permits. The coastal development permit, the last permit required to be obtained, 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 seeking to invalidate this permit and to obtain injunctive relief to stop decommissioning work. In September 2020, the Samuel Lawrence Foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the CCC’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. Major decommissioning work began in 2020 and has not been interrupted by the writ petitions filed by the Samuel Lawrence Foundation. 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 decommissioning costs. 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. In December 2020, SDG&E received authorization from the CPUC to access NDT funds of up to $89 million for forecasted 2021 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final 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 final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage 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. 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 Gross Estimated At December 31, 2020: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 64 $ 1 $ — $ 65 Municipal bonds (2) 308 18 — 326 Other securities (3) 253 17 — 270 Total debt securities 625 36 — 661 Equity securities 112 254 (2) 364 Cash and cash equivalents 3 — — 3 Receivables (payables), net (9) — — (9) Total $ 731 $ 290 $ (2) $ 1,019 At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 57 $ — $ — $ 57 Municipal bonds 270 12 — 282 Other securities 218 9 (1) 226 Total debt securities 545 21 (1) 565 Equity securities 176 339 (6) 509 Cash and cash equivalents 16 — — 16 Receivables (payables), net (8) — — (8) Total $ 729 $ 360 $ (7) $ 1,082 (1) Maturity dates are 2022-2051. (2) Maturity dates are 2021-2056. (3) Maturity dates are 2021-2072. 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, 2020 2019 2018 Proceeds from sales $ 1,439 $ 914 $ 890 Gross realized gains 156 24 42 Gross realized losses (17) (5) (10) 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 $579 million at December 31, 2020. 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 2020 dollars is approximately $860 million. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $110 million in 2021, $83 million in 2022, $63 million in 2023, $45 million in 2024, $44 million in 2025, and $697 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. In October 2015, the CCC approved Edison’s application to expand the ISFSI. 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 and was completed in August 2020. 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. As a result of updated coverage assessments, the SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced 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 $3.5 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, 2020
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, STIH acquired an additional indirect, 0.1975% interest in Oncor through its acquisition of a 1% interest in TTHC from Hunt Strategic Utility Investment, L.L.C. (Hunt), including notes receivable due from TTHC with an aggregate outstanding balance of approximately $6 million, for a total purchase price of approximately $23 million in cash, bringing Sempra Energy’s indirect ownership interest in Oncor to approximately 80.45%. TTHC indirectly owns 100% of TTI, which owns 19.75% of Oncor’s outstanding membership interests. At the acquisition date, we determined the fair value of the notes receivable was $7 million based on a discounted cash flow model, and attributed $16 million to the investment in TTHC, which we recorded as an equity method investment. STIH’s acquisition of the 1% interest was the subject of a lawsuit filed in the Delaware Court of Chancery by the owners of the remaining 99% ownership interest in TTHC. STIH purchased its 1% interest in TTHC in February 2020 after the Delaware Court of Chancery decided, among other things, that STIH’s right to purchase the 1% interest was superior to that of the remaining owners of TTHC. The remaining owners appealed that decision and, in May 2020, the Delaware Supreme Court reversed the Delaware Court of Chancery’s ruling and remanded the case back to the Delaware Court of Chancery. In September 2020, the Delaware Court of Chancery ordered, among other things, the rescission of STIH’s purchase of the 1% interest in TTHC. The parties have complied with the court’s order and Sempra Energy’s indirect ownership in Oncor has returned to 80.25%. We received a full refund of the purchase price from Hunt in September 2020 and have fully unwound the acquisition. 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. We paid 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 Oncor Management Investment LLC 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. 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. 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 Oncor Management Investment LLC; 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. Other EFH assets and liabilities unrelated to Oncor that were acquired have been subsumed into our parent organization, Parent and other. 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) As adjusted for post-closing items. 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. Oncor paid 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. 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 acquisition, SDTS accepted and assumed certain assets and liabilities of Sharyland Utilities, LP in exchange for certain SDTS assets. 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. Immediately prior to the completion of the exchange, SDTS became a wholly owned, indirect subsidiary of InfraREIT Partners, LP. Sharyland Holdings In May 2019, Sempra Energy acquired an indirect, 50% interest in Sharyland Holdings for $95 million (net of $7 million in post-closing adjustments). In connection with and prior to the consummation of the acquisition, 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 indirect, 50% interest in Sharyland Holdings as an equity method investment. Sempra South American Utilities Compañía Transmisora del Norte Grande S.A. In December 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 and was included as part of the sale of 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. PENDING ACQUISITION Sempra Mexico ESJ In February 2021, IEnova agreed to acquire Saavi Energía’s 50% interest in ESJ for approximately $83 million. At December 31, 2020, IEnova owned a 50% interest in ESJ, which is accounted for as an equity method investment. Upon completion of the acquisition, IEnova will own 100% of ESJ and will consolidate it. ESJ owns a fully operating wind power generation facility with a nameplate capacity of 155 MW that is fully contracted by SDG&E. ESJ is constructing a second wind power generation facility, which we expect will be completed in late 2021 or in the first quarter of 2022 and will have a nameplate capacity of 108 MW. We expect to complete the acquisition in the first half of 2021, subject to various closing conditions, including authorizations from the FERC and COFECE. 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 LNG In February 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, 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. Sempra Renewables In December 2018, Sempra Renewables completed the sale of the following assets 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 In April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments 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 Sempra Energy 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. DISCONTINUED OPERATIONS In January 2019, our board of directors approved a plan to sell our South American businesses. We present these businesses, which previously constituted the Sempra South American Utilities segment, and certain activities associated with those businesses as discontinued operations. In April 2020, we completed the sale of our equity interests in our Peruvian businesses, including our 83.6% interest in Luz del Sur and our interest in Tecsur, to an affiliate of China Yangtze Power International (Hongkong) Co., Limited for cash proceeds of $3,549 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $2,271 million ($1,499 million after tax). In June 2020, we completed the sale of our equity interests in our Chilean businesses, including our 100% interest in Chilquinta Energía and Tecnored and our 50% interest in Eletrans, to State Grid International Development Limited for cash proceeds of $2,216 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $628 million ($248 million after tax). In the year ended December 31, 2020, the pretax gains from the sales of our South American businesses are included in Gain on Sale of Discontinued Operations in the table below and the after-tax gains are included in Income from Discontinued Operations, Net of Income Tax, on the Sempra Energy Consolidated Statements of Operations. Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Years ended December 31, 2020 (1) 2019 2018 Revenues $ 570 $ 1,614 $ 1,585 Cost of sales (364) (1,012) (1,041) Gain on sale of discontinued operations 2,899 — — Operating expenses (66) (159) (206) Interest and other (3) (11) (6) Income before income taxes and equity earnings 3,036 432 332 Income tax expense (1,186) (72) (145) Equity earnings — 3 1 Income from discontinued operations, net of income tax 1,850 363 188 Earnings attributable to noncontrolling interests (10) (35) (32) Earnings from discontinued operations attributable to common shares $ 1,840 $ 328 $ 156 (1) Results include activity until deconsolidation of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020 and post-closing adjustments related to the sales of these businesses. 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 Cash and cash equivalents $ 74 Restricted cash (1) 1 Accounts receivable, net 303 Due from unconsolidated affiliates 2 Inventories 36 Other current assets 29 Current assets $ 445 Due from unconsolidated affiliates $ 54 Goodwill and other intangible assets 801 Property, plant and equipment, net 2,618 Other noncurrent assets 40 Noncurrent assets $ 3,513 Short-term debt $ 52 Accounts payable 201 Current portion of long-term debt and finance leases 85 Other current liabilities 106 Current liabilities $ 444 Long-term debt and finance leases $ 702 Deferred income taxes 284 Other noncurrent liabilities 66 Noncurrent liabilities $ 1,052 (1) Primarily represents funds held in accordance with Peruvian tax law.

INVESTMENTS IN UNCONSOLIDATED E

INVESTMENTS IN UNCONSOLIDATED ENTITIES	12 Months Ended
	Dec. 31, 2020
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 Statements of Operations. Our foreign equity method investees are generally corporations whose operations are 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, 2020 2019 2020 2019 Sempra Texas Utilities: Oncor Holdings (1) 100 % 100 % $ 12,440 $ 11,519 Sempra Texas Utilities: Sharyland Holdings (2) 50 50 $ 102 $ 100 Sempra Mexico: ESJ (3) 50 50 34 39 IMG JV (4) 40 40 440 337 TAG JV (5) 50 50 378 365 Sempra LNG: Cameron LNG JV (6) 50.2 50.2 433 1,256 Total other equity method investments 1,387 2,097 Other 1 6 Total other investments $ 1,388 $ 2,103 (1) The carrying value of our equity method investment is $2,833 million and $2,823 million higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019, respectively, due to $2,868 million of equity method goodwill and $69 million in basis differences in AOCI, offset by $104 million at December 31, 2020 and $114 million at December 31, 2019 due to a tax sharing liability to TTI under a 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 is $259 million and $263 million higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019, 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, 2020 2019 2018 EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX (1) : Sempra Texas Utilities: Sharyland Holdings $ 3 $ 2 $ — Sempra LNG: Cameron LNG JV 391 24 — Sempra Renewables: Wind: Auwahi Wind — — 3 Broken Bow 2 Wind — — (2) Cedar Creek 2 Wind — — (1) Flat Ridge 2 Wind (2) — (3) (178) Fowler Ridge 2 Wind — 5 3 Mehoopany Wind (2) — 1 (30) Solar: California solar partnership — — 8 Copper Mountain Solar 2 — — 5 Copper Mountain Solar 3 — — 8 Mesquite Solar 1 — — 18 Other — 2 (3) Parent and other: RBS Sempra Commodities (2) (100) — (67) Other — (1) — 294 30 (236) EARNINGS RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 577 526 371 Sempra Mexico: ESJ 5 2 2 IMG JV 103 9 29 TAG JV 36 13 9 721 550 411 Total $ 1,015 $ 580 $ 175 (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, 2020 2019 2018 Sempra Texas Utilities $ 286 $ 246 $ 149 Sempra Mexico 8 2 — Sempra LNG 1,168 — — Sempra Renewables — 1 63 Parent and other — 7 — Total $ 1,462 $ 256 $ 212 At December 31, 2020 and 2019, our share of the undistributed earnings of equity method investments was $1.1 billion and $634 million, respectively, including $792 million at December 31, 2020 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, in March 2018, we completed the acquisition of an indirect, 100% interest in Oncor Holdings, which 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, March 9 - December 31, 2020 2019 2018 Operating revenues $ 4,511 $ 4,347 $ 3,347 Operating expense (3,224) (3,135) (2,434) Income from operations 1,287 1,212 913 Interest expense (405) (375) (285) Income tax expense (146) (131) (119) Net income 703 643 455 Noncontrolling interest held by TTI (141) (129) (94) Earnings attributable to Sempra Energy 562 514 360 At December 31, 2020 2019 Current assets $ 1,045 $ 913 Noncurrent assets 28,022 26,012 Current liabilities 1,120 1,626 Noncurrent liabilities 15,611 14,125 Noncontrolling interest held by TTI 2,737 2,473 In 2020 and 2019, Sempra Energy contributed $632 million and $1,587 million, respectively, to Oncor Holdings, including $1,067 million in 2019 to fund Oncor’s May 2019 acquisition of interests in InfraREIT and certain acquisition-related expenses. In 2018, Sempra Energy contributed $230 million in cash to Oncor Holdings. Sharyland Holdings As we discuss in Note 5, in May 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 ESJ As we discuss in Note 5, in February 2021, IEnova agreed to acquire Saavi Energía’s 50% interest in ESJ for approximately $83 million. At December 31, 2020, IEnova owned a 50% interest in ESJ, which is accounted for as an equity method investment. Upon completion of the acquisition, IEnova will own 100% of ESJ and will consolidate it. We expect to complete the acquisition in the first half of 2021, subject to various closing conditions, including authorizations from the FERC and COFECE. 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, Sempra Mexico invested cash of $80 million in IMG JV. SEMPRA LNG Cameron LNG JV Cameron LNG JV was formed in October 2014 among Sempra Energy and three project partners, TOTAL SE, 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 operates a three-train natural gas liquefaction export facility with a nameplate capacity of 13.9 Mtpa of LNG, with an export capacity of 12 Mtpa of LNG, or approximately 1.7 Bcf per day. Cameron LNG JV achieved commercial operations of Train 1, Train 2 and Train 3 under its tolling agreements in August 2019, February 2020 and August 2020, respectively. Prior to commencing full commercial operation, Sempra LNG capitalized interest of $33 million in 2019 and $47 million in 2018 related to this equity method investment. In 2020, 2019 and 2018, Sempra LNG contributed $54 million, $77 million and $228 million, respectively, to 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 were 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 the commercial bank portion of the Loan Facility Agreements not covered by NEXI with $3.0 billion of senior secured notes issued in a private placement bond offering. The senior secured notes bear interest at a weighted-average fixed rate of 3.39% at December 31, 2020 with a weighted-average tenor of 15.4 years. 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 liquefaction project, which is subject to satisfaction of certain conditions, including all three trains achieving commercial operations and meeting certain operational performance tests that are currently underway. We expect the project to achieve financial completion and the guarantees to be terminated in the first half of 2021, but this timing could be delayed, perhaps substantially, if these operational performance tests are not completed due to weather-related events, other events or other factors beyond our control. 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, with an associated carrying value of $1 million at December 31, 2020, 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 decreasing 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 that results in failure to achieve financial completion by September 30, 2021 would result in an event of default under Cameron LNG JV’s financing agreements and a potential demand of up to $4.0 billion on Sempra Energy’s guarantees. Further, pursuant to the financing agreements, Cameron LNG JV is restricted from making distributions to its project owners, including Sempra LNG, from January 1, 2021 until the earlier of September 30, 2021 and the achievement of financial completion. 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). Sempra Energy Support Agreement for CFIN In July 2020, CFIN entered into a financing arrangement with Cameron LNG JV’s four project owners and received aggregate proceeds of $1.5 billion from two project owners and from external lenders on behalf of the other two project owners (collectively, the affiliate loans), based on their proportionate ownership interest in Cameron LNG JV. CFIN used the proceeds from the affiliate loans to provide a loan to Cameron LNG JV. The affiliate loans mature in 2039. Principal and interest will be paid from Cameron LNG JV’s project cash flows from its three-train natural gas liquefaction facility. Cameron LNG JV used the proceeds from its loan to return equity to its project owners. Sempra Energy used its $753 million share of the proceeds for working capital and other general corporate purposes, including the repayment of indebtedness. Sempra Energy’s $753 million proportionate share of the affiliate loans, based on its 50.2% ownership interest in Cameron LNG JV, was funded by external lenders comprised of a syndicate of eight banks (the bank debt) to whom Sempra Energy has provided a guarantee pursuant to a Support Agreement. Under the terms of the Support Agreement, Sempra Energy has severally guaranteed repayment of the bank debt plus accrued and unpaid interest if CFIN fails to pay the external lenders. Additionally, the external lenders may exercise an option to put the bank debt to Sempra Energy on every one-year anniversary of the closing of the affiliate loans, as well as upon the occurrence of certain events, including a failure by CFIN to meet its payment obligations under the bank debt. In addition, some or all of the bank debt will be transferred by each external lender back to Sempra Energy on the five-year anniversary of the affiliate loans, unless the external lenders elect to waive their transfer rights six months prior to the five-year anniversary of the affiliate loans. Sempra Energy also has a right to call the bank debt back from, or to refinance the bank debt with, the external lenders at any time. The Support Agreement will terminate upon full repayment of the bank debt, including repayment following an event in which the bank debt is put to Sempra Energy. In exchange for this guarantee, the external lenders will pay a guarantee fee that is based on the credit rating of Sempra Energy’s long-term senior unsecured non-credit enhanced debt rating, which guarantee fee Sempra LNG will recognize as interest income as earned. Sempra Energy’s maximum exposure to loss is the bank debt plus any accrued and unpaid interest and related fees, subject to a liability cap of 130% of the bank debt, or $979 million. We measure the Support Agreement at fair value, net of related guarantee fees, on a recurring basis (see Note 12). At December 31, 2020, the fair value of the Support Agreement was $3 million, of which $7 million is included in Other Current Assets offset by $4 million included in Deferred Credits and Other on the Sempra Energy Consolidated Balance Sheet. SEMPRA RENEWABLES As a result of the plan of sale, Sempra Renewables recorded an other-than-temporary impairment on certain of its 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. 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. In 2020, we recorded a charge of $100 million in Equity Earnings on Sempra Energy’s Consolidated Statement of Operations for losses from our investment in RBS Sempra Commodities. We recognized a corresponding liability of $25 million in Other Current Liabilities and $75 million in Deferred Credits and Other for our share of estimated losses in excess of the carrying value of our equity method investment. 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, 2020 2019 (1) 2018 (2) Gross revenues $ 2,341 $ 798 $ 706 Operating expense (706) (372) (609) Income from operations 1,635 426 97 Interest expense (514) (401) (322) Net income (loss)/Earnings (losses) (3) 1,132 85 (36) At December 31, 2020 2019 (1) Current assets $ 1,035 $ 1,124 Noncurrent assets 15,304 15,039 Current liabilities 1,342 1,232 Noncurrent liabilities 12,863 11,438 (1) On April 22, 2019, Sempra Renewables sold its remaining wind assets and investments. 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. As of December 13, 2018, the solar equity method investments and Broken Bow 2 are no longer equity method investments. (3) 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, 2020
Debt Disclosure [Abstract]
Debt and Credit Facilities	DEBT AND CREDIT FACILITIES LINES OF CREDIT Primary U.S. Committed Lines of Credit At December 31, 2020, Sempra Energy Consolidated had an aggregate capacity 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, 2020 Total facility Commercial paper outstanding (1) Available unused credit Sempra Energy (2) $ 1,250 $ — 1,250 Sempra Global 3,185 — 3,185 SDG&E (3) 1,500 — 1,500 SoCalGas (3)(4) 750 (113) 637 Total $ 6,685 $ (113) $ 6,572 (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, 2020. (3) 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, 2020. (4) Commercial paper outstanding is before reductions of a negligible amount of unamortized discount. 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, 2020, 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 committed lines of credit aggregating $1.8 billion at December 31, 2020. The principal terms of these credit facilities are described below. FOREIGN COMMITTED LINES OF CREDIT (U.S. dollar equivalent in millions) December 31, 2020 Expiration date of facility Total facility Amounts outstanding Available unused credit February 2024 (1) $ 1,500 $ (392) $ 1,108 September 2021 (2) 280 (280) — Total $ 1,780 $ (672) $ 1,108 (1) Five-year revolving credit facility with a syndicate of 10 lenders. Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 80 bps. (2) Two-year revolving credit facility with The Bank of Nova Scotia. Borrowings may be made for up to two years from September 23, 2019 in U.S. dollars. Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps. In addition to its committed lines of credit, in October 2020, IEnova entered into a three-year $20 million uncommitted revolving credit facility with Scotiabank Inverlat S.A. (borrowings may be made in either U.S. dollars or Mexican pesos) and a three-year $100 million uncommitted revolving credit facility with The Bank of Nova Scotia (borrowings may only be made in U.S. dollars). At December 31, 2020, available unused credit on these lines was $20 million. 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, 2020, we had approximately $508 million in standby letters of credit outstanding under these agreements. TERM LOAN In March 2020 and April 2020, Sempra Energy borrowed a total of $1,599 million, net of $1 million of debt discounts and issuance costs, under a 364-day term loan, which had a maturity date of March 16, 2021 with an option to extend the maturity date to September 16, 2021, subject to receiving the consent of the lenders. Sempra Energy used the proceeds from the term loan to repay borrowings on its committed lines of credit and for other general corporate purposes. This term loan was repaid in full in September 2020. WEIGHTED-AVERAGE INTEREST RATES The weighted-average interest rates on the total short-term debt at December 31, 2020 and 2019 were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2020 2019 Sempra Energy Consolidated 0.83 % 2.31 % SDG&E — 1.97 SoCalGas 0.14 1.86 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, 2020 2019 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ 350 $ 350 1.914% payable 2015 through February 2022 53 89 3.6% September 1, 2023 450 450 2.5% May 15, 2026 500 500 6% June 1, 2026 250 250 1.7% October 1, 2030 800 — 5.875% January and February 2034 (1) — 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039 (1) — 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 400 400 3.32% April 15, 2050 400 — 6,053 5,140 Other long-term debt (uncollateralized): Variable rate (0.95% at December 31, 2020) 364-day term loan March 18, 2021 (1) 200 — Finance lease obligations: Purchased-power contracts 1,237 1,255 Other 39 15 1,476 1,270 7,529 6,410 Current portion of long-term debt (611) (56) Unamortized discount on long-term debt (13) (12) Unamortized debt issuance costs (39) (36) Total SDG&E 6,866 6,306 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 2.55% February 1, 2030 650 — 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 350 350 4,450 3,800 Other long-term debt (uncollateralized): Notes at variable rates (0.57% at December 31, 2020) September 14, 2023 (1) 300 — 1.875% Notes May 14, 2026 (1) 4 4 5.67% Notes January 18, 2028 5 5 Finance lease obligations 54 19 363 28 4,813 3,828 Current portion of long-term debt (10) (6) Unamortized discount on long-term debt (8) (7) Unamortized debt issuance costs (32) (27) Total SoCalGas 4,763 3,788 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2020 2019 Sempra Energy: Other long-term debt (uncollateralized): 2.4% Notes February 1, 2020 — 500 2.4% Notes March 15, 2020 — 500 2.85% Notes November 15, 2020 — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — 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) 758 758 Sempra Mexico Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 197 207 Notes at variable rates (4.88% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets 196 237 3.75% Notes January 14, 2028 300 300 Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets 398 423 4.875% Notes January 14, 2048 540 540 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) — 11 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 200 4.75% notes January 15, 2051 800 — Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034 (1) 100 — 2.90% loan November 15, 2034 (1) 241 — Sempra LNG Other long-term debt (uncollateralized): Notes at 2.87% to 3.51% October 1, 2026 (1) — 22 Loan at variable rates (2.82% at December 31, 2020) December 9, 2025 (1) 17 — 11,247 12,298 Current portion of long-term debt (919) (1,464) Unamortized discount on long-term debt (55) (35) Unamortized debt issuance costs (121) (108) Total other Sempra Energy 10,152 10,691 Total Sempra Energy Consolidated $ 21,781 $ 20,785 (1) Callable long-term debt not subject to make-whole provisions. MATURITIES OF LONG-TERM DEBT (1) (Dollars in millions) SDG&E SoCalGas Other Sempra Energy Total Sempra Energy Consolidated 2021 $ 585 $ — $ 919 $ 1,504 2022 18 — 583 601 2023 450 300 1,281 2,031 2024 — 500 564 1,064 2025 — 350 461 811 Thereafter 5,200 3,609 7,439 16,248 Total $ 6,253 $ 4,759 $ 11,247 $ 22,259 (1) Excludes finance lease obligations, discounts, and debt issuance costs. Various long-term obligations totaling $11.2 billion at Sempra Energy Consolidated at December 31, 2020 are unsecured. This includes unsecured long-term obligations totaling $200 million at SDG&E and $309 million at SoCalGas. Callable Long-Term Debt At the option of Sempra Energy, SDG&E and SoCalGas, certain debt at December 31, 2020 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ 200 $ 304 $ 1,299 $ 1,803 Subject to make-whole provisions 6,053 4,450 8,503 19,006 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 $6.5 billion at SDG&E and $1.2 billion at SoCalGas at December 31, 2020. SDG&E In September 2020, SDG&E issued $800 million of 1.70% first mortgage bonds maturing in 2030 and received proceeds of $792 million (net of debt discount, underwriting discounts and debt issuance costs of $8 million). SDG&E used a portion of the proceeds from the offering to redeem $176 million, prior to a scheduled maturity in 2034, and $75 million, prior to a scheduled maturity in 2039, of tax-exempt industrial development revenue refunding bonds in December 2020. SDG&E used the remaining proceeds for general corporate purposes, including repayment of commercial paper. In April 2020, SDG&E issued $400 million of 3.32% first mortgage bonds maturing in 2050 and received proceeds of $395 million (net of debt discount, underwriting discounts and debt issuance costs of $5 million). SDG&E used $200 million of the proceeds from the offering to repay line of credit borrowings, and the remaining proceeds for working capital and other general corporate purposes. SoCalGas In January 2020, SoCalGas issued $650 million of 2.55% first mortgage bonds maturing in 2030 and 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 October 2020, Sempra Energy redeemed $700 million of floating-rate notes, prior to a scheduled maturity in January 2021, utilizing a portion of the proceeds received from the sales of our South American businesses. SDG&E In March 2020, SDG&E borrowed $200 million under a 364-day term loan, which has a maturity date of March 18, 2021 with an option to extend the maturity date to September 17, 2021, subject to receiving the consent of the lenders. Borrowings bear interest at benchmark rates plus 80 bps (0.95% at December 31, 2020). The term loan provides SDG&E with additional liquidity outside of its committed line of credit. SDG&E classified this term loan as long-term debt based on management’s intent and ability to maintain this level of borrowing on a long-term basis by issuing long-term debt. At December 31, 2020, this term loan was included in Current Portion of Long-Term Debt and Finance Leases on SDG&E’s and Sempra Energy’s Consolidated Balance Sheets. In the first quarter of 2020, SDG&E borrowed $200 million from its line of credit and classified it as long-term debt based on management’s intent and ability to maintain this level of borrowing on a long-term basis either supported by this credit facility or by issuing long-term debt. In the second quarter of 2020, SDG&E repaid these borrowings with proceeds from the issuance of first mortgage bonds, which we discuss above. SoCalGas In September 2020, SoCalGas issued $300 million of senior unsecured floating rate notes maturing in 2023 and received proceeds of $298 million (net of underwriting discounts and debt issuance costs of $2 million). The notes bear interest at a per annum rate equal to the 3-month LIBOR rate (or, under certain circumstances, a benchmark replacement rate), reset quarterly, plus 35 bps. SoCalGas may, at its option, redeem some or all of the floating rate notes at any time on or after March 14, 2021 at a redemption price equal to 100% of the principal amount of, plus accrued and unpaid interest on, the notes being redeemed. SoCalGas used the proceeds from the offering for general corporate purposes, including repayment of commercial paper. Sempra Mexico In September 2020, IEnova offered and sold in a private placement $800 million of 4.75% senior unsecured notes maturing in 2051 and received proceeds of $770 million (net of debt discount, underwriting discounts and debt issuance costs of $30 million). IEnova used the proceeds from the offering to repay line of credit borrowings and for other general corporate purposes. In November 2019, IEnova entered into a financing agreement with International Finance Corporation and North American Development Bank to finance and/or refinance the construction of solar generation projects in Mexico. Under this agreement, in April 2020, IEnova borrowed $100 million from Japan International Cooperation Agency, with loan proceeds of $98 million (net of debt issuance costs of $2 million). The loan matures in November 2034 and bears interest based on 6-month LIBOR plus 150 bps. In April 2020, IEnova entered into a floating-to-fixed interest rate swap, resulting in a fixed rate of 2.38%. Also under the financing agreement, in June 2020, IEnova borrowed $241 million from U.S. International Development Finance Corporation, with loan proceeds of $236 million (net of debt issuance costs of $5 million). The loan matures in November 2034 and bears interest at a fixed rate of 2.90%. Sempra LNG In December 2020, ECA LNG Phase 1 entered into a five-year loan agreement with a syndicate of nine banks for an aggregate principal amount of up to $1.6 billion, of which $17 million was outstanding as of December 31, 2020. Proceeds from the loan are being used to finance the cost of development and construction of a one-train natural gas liquefaction export facility with a name-plate capacity of 3.25 Mtpa and initial offtake capacity of approximately 2.5 Mtpa. The loan matures in December 2025 and bears interest at a weighted-average blended rate of 2.70% plus a benchmark interest rate per annum equal to (a) the LIBOR for such interest period divided by (b) one minus the Eurodollar Reserve Percentage; provided that in no event shall the benchmark at any time be less than 0% per annum. ECA LNG Phase 1 may elect for each calendar quarter (i) three successive interest periods of one month or (ii) a single interest period of three months. Sempra Energy, IEnova and TOTAL SE have provided guarantees for repayment of the loans plus accrued and unpaid interest based on their proportionate ownership interest in ECA LNG Phase 1 of 41.7%, 41.7% and 16.6%, respectively. The effective interest rate of the loan is based on the interest payments made to external lenders and guarantee payments made to TOTAL SE as a guarantor. As we discuss in “Shareholders’ Equity and Noncontrolling Interests – Other Noncontrolling Interests – Sempra LNG” in Note 14, notes payable totaling $22 million due October 1, 2026 were converted to equity by the minority partner in Liberty Gas Storage LLC and are no longer outstanding.

INCOME TAXES

INCOME TAXES	12 Months Ended
	Dec. 31, 2020
Income Tax Disclosure [Abstract]
Income Taxes	INCOME TAXESWe 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, 2020 2019 2018 Sempra Energy Consolidated: Income tax expense (benefit) from continuing operations $ 249 $ 315 $ (49) Income from continuing operations before income taxes and equity earnings $ 1,489 $ 1,734 $ 714 Equity earnings (losses), before income tax (1) 294 30 (236) Pretax income $ 1,783 $ 1,764 $ 478 Effective income tax rate 14 % 18 % (10) % SDG&E: Income tax expense $ 190 $ 171 $ 173 Income before income taxes $ 1,014 $ 945 $ 849 Effective income tax rate 19 % 18 % 20 % SoCalGas: Income tax expense $ 96 $ 120 $ 92 Income before income taxes $ 601 $ 762 $ 493 Effective income tax rate 16 % 16 % 19 % (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 offset 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, 2020 2019 2018 Sempra Energy Consolidated: U.S. federal statutory income tax rate 21 % 21 % 21 % Utility depreciation 3 3 12 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (1) 2 3 10 State income taxes, net of federal income tax benefit 1 2 (8) Impairment losses 1 — (32) Effects of the TCJA — — 9 Unrecognized income tax benefits — — 4 Noncontrolling interests in tax equity arrangements — — 3 Resolution of prior years’ income tax items — — (1) Excess deferred income taxes outside of ratemaking — (4) — Compensation-related items (1) — 3 Valuation allowances (1) — — Allowance for equity funds used during construction (1) (1) (4) Amortization of excess deferred income taxes (1) (1) (4) Tax credits (1) (2) (10) Foreign exchange and inflation effects (2) (3) 4 6 Utility self-developed software expenditures (3) (2) (7) Utility repairs expenditures (4) (3) (13) Other, net 1 (2) 1 Effective income tax rate 14 % 18 % (10) % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 21 % State income taxes, net of federal income tax benefit 5 6 5 Depreciation 3 3 3 Excess deferred income taxes outside of ratemaking — (3) — Amortization of excess deferred income taxes (1) (1) (1) Allowance for equity funds used during construction (2) (1) (2) Repairs expenditures (3) (3) (3) Self-developed software expenditures (4) (3) (2) Other, net — (1) (1) Effective income tax rate 19 % 18 % 20 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 21 % Depreciation 5 4 7 State income taxes, net of federal income tax benefit 2 4 2 Nondeductible expenditures 2 — — Unrecognized income tax benefits — — 4 Compensation-related items — — 1 Resolution of prior years’ income tax items — — (1) Excess deferred income taxes outside of ratemaking — (5) — Allowance for equity funds used during construction (1) (1) (2) Amortization of excess deferred income taxes (1) (1) (2) Self-developed software expenditures (4) (2) (3) Repairs expenditures (7) (4) (7) Other, net (1) — (1) Effective income tax rate 16 % 16 % 19 % (1) Related to operations in Mexico. (2) 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. In January 2019, our board of directors approved a plan to sell our South American businesses and we completed the sales in the second quarter of 2020, 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. Accordingly, we recorded the following income tax impacts from changes in outside basis differences in our discontinued operations in South America: ▪ $89 million income tax benefit in 2019 primarily related to outside basis differences existing as of the January 25, 2019 approval of our plan to sell our South American businesses; and ▪ $7 million income tax benefit in 2020 compared to $51 million income tax expense in 2019 related to changes in outside basis differences from earnings and foreign currency effects since January 25, 2019. We expect to repatriate approximately $1.3 billion of foreign undistributed earnings in the foreseeable future, and have accrued $58 million of U.S. state deferred income tax liability as of December 31, 2020 for repatriations that we expect will begin in 2021 as cash is generated. We repatriated approximately $4.7 billion, $254 million and $338 million to the U.S. in 2020, 2019 and 2018, respectively. We have not recorded deferred income taxes with respect to remaining basis differences of approximately $1.1 billion 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, 2020. 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 remeasurement of deferred income tax balances at SDG&E and SoCalGas in December 2017, as a result of the TCJA, resulted in excess deferred income taxes that previously had been collected from ratepayers at the higher rate. 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, in 2019, 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 table below presents the geographic components of pretax income. PRETAX INCOME – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Years ended December 31, 2020 2019 2018 By geographic components: U.S. $ 1,461 $ 1,191 $ (102) Non-U.S. 322 573 580 Total (1) $ 1,783 $ 1,764 $ 478 (1) See the Income Tax Expense (Benefit) and Effective Income Tax Rates table above for the calculation of pretax income. U.S. pretax income was lower in 2018 compared to 2020 and 2019 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). The components of income tax expense are as follows. INCOME TAX EXPENSE (BENEFIT) (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated: Current: U.S. federal $ — $ — $ (1) U.S. state (22) (14) 67 Non-U.S. 112 140 127 Total 90 126 193 Deferred: U.S. federal 157 87 (121) U.S. state 36 21 (183) Non-U.S. (34) 84 66 Total 159 192 (238) Deferred investment tax credits — (3) (4) Total income tax expense (benefit) $ 249 $ 315 $ (49) SDG&E: Current: U.S. federal $ 121 $ 35 $ 104 U.S. state 34 31 30 Total 155 66 134 Deferred: U.S. federal 11 75 17 U.S. state 25 32 24 Total 36 107 41 Deferred investment tax credits (1) (2) (2) Total income tax expense $ 190 $ 171 $ 173 SoCalGas: Current: U.S. federal $ 163 $ 8 $ 4 U.S. state 45 24 10 Total 208 32 14 Deferred: U.S. federal (85) 79 78 U.S. state (28) 10 2 Total (113) 89 80 Deferred investment tax credits 1 (1) (2) Total income tax expense $ 96 $ 120 $ 92 The tables below present the components of deferred income taxes: DEFERRED INCOME TAXES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) December 31, 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 4,891 $ 4,052 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 46 153 Regulatory balancing accounts 587 468 Right-of-use assets – operating leases 144 131 Property taxes 51 44 Other deferred income tax liabilities 40 93 Total deferred income tax liabilities 5,759 4,941 Deferred income tax assets: Tax credits 1,161 1,136 Net operating losses 1,299 911 Postretirement benefits 162 200 Compensation-related items 169 161 Operating lease liabilities 125 131 Other deferred income tax assets 152 72 Accrued expenses not yet deductible 130 52 Deferred income tax assets before valuation allowances 3,198 2,663 Less: valuation allowances 174 144 Total deferred income tax assets 3,024 2,519 Net deferred income tax liability (2) $ 2,735 $ 2,422 (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, 2020 and 2019, includes $136 million and $155 million, respectively, recorded as a noncurrent asset and $2,871 million and $2,577 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, 2020 2019 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 1,833 $ 1,735 $ 1,322 $ 1,246 Regulatory balancing accounts 224 141 362 327 Right-of-use assets – operating leases 28 32 21 22 Property taxes 34 30 17 14 Other 2 14 1 1 Total deferred income tax liabilities 2,121 1,952 1,723 1,610 Deferred income tax assets: Tax credits 5 6 3 3 Postretirement benefits 14 37 123 120 Compensation-related items 12 6 36 25 Operating lease liabilities 28 32 21 22 Bad debt allowance 18 3 15 1 State income taxes 8 7 11 8 Accrued expenses not yet deductible 14 9 93 15 Other 3 4 15 13 Total deferred income tax assets 102 104 317 207 Net deferred income tax liability $ 2,019 $ 1,848 $ 1,406 $ 1,403 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, 2020 Year expiration begins Sempra Energy Consolidated: U.S. federal: NOLs (1) $ 5,284 2031 General business tax credits (1) 428 2032 Foreign tax credits (2) 694 2024 U.S. state (2) : NOLs 3,047 2021 General business tax credits 39 2021 Non-U.S. (2) – NOLs 126 2021 (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, 2020 2019 Sempra Energy Consolidated: U.S. federal $ 118 $ 90 U.S. state 32 33 Non-U.S. 24 21 $ 174 $ 144 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) 2020 2019 2018 Sempra Energy Consolidated: Balance at January 1 $ 93 $ 119 $ 89 Increase in prior period tax positions 3 5 7 Decrease in prior period tax positions (1) — (1) Increase in current period tax positions 4 2 24 Settlements with taxing authorities — (32) — Expiration of statutes of limitations — (1) — Balance at December 31 $ 99 $ 93 $ 119 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (87) $ (81) $ (107) increase the effective tax rate (1) 31 27 24 SDG&E: Balance at January 1 $ 12 $ 11 $ 10 Increase in prior period tax positions 1 1 1 Balance at December 31 $ 13 $ 12 $ 11 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (10) $ (9) $ (9) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 64 $ 61 $ 35 Increase in prior period tax positions 1 1 2 Increase in current period tax positions 3 2 24 Balance at December 31 $ 68 $ 64 $ 61 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (59) $ (55) $ (51) increase the effective tax rate (1) 30 26 23 (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, 2020 2019 2018 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) (8) (40) $ (8) $ (8) $ (41) 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 negligible amounts and $1 million for interest expense and penalties at December 31, 2020 and 2019, respectively, on the Consolidated Balance Sheets, and recorded $1 million of interest expense and penalties in 2018 and negligible amounts in each of 2020 and 2019 on the Consolidated Statements of Operations. SDG&E and SoCalGas each accrued negligible amounts for interest expense and penalties at December 31, 2020 and 2019 on the Consolidated Balance Sheets, and recorded negligible amounts of interest expense and penalties in each of 2020, 2019 and 2018 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 2016. We are subject to examination by major state tax jurisdictions for tax years after 2012. Certain major non-U.S. income tax returns for tax years 2013 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 2016 and state tax years after 2012. In addition, Sempra Energy has filed protests to contest proposed state audit adjustments for tax years 2009 through 2012. The pre-2013 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, 2020
Retirement Benefits [Abstract]
Employee Benefit Plans	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 a member of the Sempra Energy board of directors who was a participant 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 $512 million and $488 million at December 31, 2020 and 2019, respectively. PENSION AND OTHER POSTRETIREMENT BENEFIT PLANS Benefit Plan Amendments Affecting 2019 In 2019, 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 at Sempra Energy, $3 million at SDG&E 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 $22 million and $24 million in 2020 and 2019, respectively, and Sempra Energy Consolidated and SDG&E recorded settlement charges of $12 million and $4 million, respectively, in 2018. 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 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. Special Termination Benefits Affecting 2018 In 2018, certain nonrepresented 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 that year 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. Oncor In 2020 and in each of 2019 and 2018, we had $11 million and $27 million, respectively, in AOCI representing an actuarial loss related to Oncor’s pension plan. 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 2020 and 2019, and a statement of the funded status at December 31, 2020 and 2019: PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2020 2019 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 3,768 $ 3,339 $ 913 $ 868 Service cost 129 110 18 17 Interest cost 129 139 33 36 Contributions from plan participants — — 22 21 Actuarial loss 351 445 79 45 Plan amendments — 5 — — Benefit payments (93) (93) (74) (72) Settlements (207) (177) (2) (2) Net obligation at December 31 4,077 3,768 989 913 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,662 2,160 1,281 1,108 Actual return on plan assets 350 496 164 218 Employer contributions 290 276 8 8 Contributions from plan participants — — 22 21 Benefit payments (93) (93) (74) (72) Settlements (207) (177) (2) (2) Fair value of plan assets at December 31 3,002 2,662 1,399 1,281 Funded status at December 31 $ (1,075) $ (1,106) $ 410 $ 368 Net recorded (liability) asset at December 31 $ (1,075) $ (1,106) $ 410 $ 368 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement 2020 2019 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 895 $ 814 $ 177 $ 170 Service cost 31 30 4 4 Interest cost 30 34 6 7 Contributions from plan participants — — 8 7 Actuarial loss 37 61 17 7 Plan amendments — 3 — — Benefit payments (18) (18) (20) (18) Settlements (52) (39) — — Transfer of liability from other plans (10) 10 1 — Net obligation at December 31 913 895 193 177 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 739 600 197 172 Actual return on plan assets 94 135 26 36 Employer contributions 52 52 1 — Contributions from plan participants — — 8 7 Benefit payments (18) (18) (20) (18) Settlements (52) (39) — — Transfer of assets from other plans 4 9 1 — Fair value of plan assets at December 31 819 739 213 197 Funded status at December 31 $ (94) $ (156) $ 20 $ 20 Net recorded (liability) asset at December 31 $ (94) $ (156) $ 20 $ 20 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement (Dollars in millions) 2020 2019 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,526 $ 2,148 $ 688 $ 646 Service cost 86 68 14 12 Interest cost 88 91 25 27 Contributions from plan participants — — 14 13 Actuarial loss 282 345 57 39 Plan amendments — 2 — — Benefit payments (60) (59) (49) (49) Settlements (105) (65) — — Transfer of liability to other plans 12 (4) — — Net obligation at December 31 2,829 2,526 749 688 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,737 1,385 1,059 916 Actual return on plan assets 243 320 134 178 Employer contributions 152 152 1 1 Contributions from plan participants — — 14 13 Benefit payments (60) (59) (49) (49) Settlements (105) (65) — — Transfer of assets from other plans 2 4 — — Fair value of plan assets at December 31 1,969 1,737 1,159 1,059 Funded status at December 31 $ (860) $ (789) $ 410 $ 371 Net recorded (liability) asset at December 31 $ (860) $ (789) $ 410 $ 371 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 2020, 2019 and 2018, 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 2020 were driven primarily by a decrease in discount rates at Sempra Energy, SDG&E and SoCalGas and a decrease in the lump-sum conversion rate at SoCalGas, along with updated census data at Sempra Energy and SoCalGas. These actuarial losses were offset by actuarial gains at Sempra Energy, 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 2020 were driven primarily by a decrease in discount rates at Sempra Energy, SDG&E and SoCalGas and updated census data at SoCalGas. These actuarial losses were offset by a reduction in the 2021 expected health care costs at SoCalGas. 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. Defined benefit pension and other postretirement plans with an aggregated overfunded status are recognized as an asset and with an aggregated underfunded status are recognized as a liability; 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 2020 2019 2020 2019 Sempra Energy Consolidated: Noncurrent assets $ — $ — $ 430 $ 391 Current liabilities (35) (59) (1) (3) Noncurrent liabilities (1,040) (1,047) (19) (20) Net recorded (liability) asset $ (1,075) $ (1,106) $ 410 $ 368 SDG&E: Noncurrent assets $ — $ — $ 20 $ 20 Current liabilities (2) (3) — — Noncurrent liabilities (92) (153) — — Net recorded (liability) asset $ (94) $ (156) $ 20 $ 20 SoCalGas: Noncurrent assets $ — $ — $ 410 $ 371 Current liabilities (7) (4) — — Noncurrent liabilities (853) (785) — — Net recorded (liability) asset $ (860) $ (789) $ 410 $ 371 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 2020 2019 2020 2019 Sempra Energy Consolidated (1) : Net actuarial (loss) gain $ (102) $ (113) $ 8 $ 10 Prior service cost (11) (14) — — Total $ (113) $ (127) $ 8 $ 10 SDG&E: Net actuarial loss $ (8) $ (9) Prior service cost (2) (7) Total $ (10) $ (16) SoCalGas: Net actuarial loss $ (14) $ (7) Prior service cost (4) (3) Total $ (18) $ (10) (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) 2020 2019 Sempra Energy Consolidated: Projected benefit obligation $ 3,679 $ 3,578 Accumulated benefit obligation 3,265 3,229 Fair value of plan assets 2,788 2,662 SDG&E: Projected benefit obligation $ 887 $ 861 Accumulated benefit obligation 834 818 Fair value of plan assets 819 739 SoCalGas: Projected benefit obligation $ 2,792 $ 2,505 Accumulated benefit obligation 2,431 2,208 Fair value of plan assets 1,969 1,737 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) 2020 2019 Sempra Energy Consolidated: Projected benefit obligation $ 184 $ 190 Accumulated benefit obligation 146 158 SDG&E: Projected benefit obligation $ 26 $ 34 Accumulated benefit obligation 22 27 SoCalGas: Projected benefit obligation $ 37 $ 21 Accumulated benefit obligation 31 17 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) 2020 2019 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 33 $ 32 Fair value of plan assets 27 25 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) 2020 2019 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 14 $ 16 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 2020 2019 2018 2020 2019 2018 NET PERIODIC BENEFIT COST Service cost $ 129 $ 110 $ 124 $ 18 $ 17 $ 21 Interest cost 129 139 140 33 36 36 Expected return on assets (169) (144) (157) (55) (71) (70) Amortization of: Prior service cost (credit) 12 12 11 (2) — 1 Actuarial loss (gain) 35 36 22 (10) (10) (6) Settlement charges 22 28 66 — — — Special termination benefits — — — — — 5 Net periodic benefit cost (credit) 158 181 206 (16) (28) (13) Regulatory adjustment 91 77 (30) 16 29 17 Total expense recognized 249 258 176 — 1 4 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1) Net loss (gain) 28 17 56 1 (3) (4) Prior service cost — 5 12 — — — Amortization of actuarial (loss) gain (14) (13) (12) — — — Amortization of prior service cost (4) (3) (2) — — — Settlements (22) (28) (12) — — — Total recognized in OCI (12) (22) 42 1 (3) (4) Total recognized in net periodic benefit cost and OCI $ 237 $ 236 $ 218 $ 1 $ (2) $ — (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 2020 2019 2018 2020 2019 2018 NET PERIODIC BENEFIT COST Service cost $ 31 $ 30 $ 30 $ 4 $ 4 $ 5 Interest cost 30 34 35 6 7 7 Expected return on assets (49) (38) (47) (10) (11) (13) Amortization of: Prior service cost 2 3 2 — 2 3 Actuarial loss (gain) 3 11 1 (3) (2) (3) Settlement charges — — 26 — — — Special termination benefits — — — — — 3 Net periodic benefit cost 17 40 47 (3) — 2 Regulatory adjustment 38 14 (8) 3 — — Total expense recognized 55 54 39 — — 2 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 6 5 (1) — — — Prior service cost — 2 8 — — — Transfer of actuarial loss (7) — — — — — Transfer of prior service cost (5) — — — — — Amortization of actuarial loss (1) — (1) — — — Amortization of prior service cost (1) (1) — — — — Settlements — — (4) — — — Total recognized in OCI (8) 6 2 — — — Total recognized in net periodic benefit cost and OCI $ 47 $ 60 $ 41 $ — $ — $ 2 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2020 2019 2018 2020 2019 2018 NET PERIODIC BENEFIT COST Service cost $ 86 $ 68 $ 81 $ 14 $ 12 $ 15 Interest cost 88 91 92 25 27 27 Expected return on assets (107) (94) (98) (43) (58) (56) Amortization of: Prior service cost (credit) 8 8 8 (2) (2) (3) Actuarial loss (gain) 26 16 13 (7) (8) (2) Settlement charges — — 32 — — — Special termination benefits — — — — — 2 Net periodic benefit cost (credit) 101 89 128 (13) (29) (17) Regulatory adjustment 53 63 (22) 13 29 17 Total expense recognized 154 152 106 — — — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 6 2 1 — — — Prior service cost — 3 — — — — Transfer of actuarial loss 5 (4) — — — — Transfer of prior service cost 3 (1) — — — — Amortization of actuarial loss (1) (1) — — — — Amortization of prior service cost (1) — (1) — — — Total recognized in OCI 12 (1) — — — — Total recognized in net periodic benefit cost and OCI $ 166 $ 151 $ 106 $ — $ — $ — 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 2020 2019 2020 2019 Sempra Energy Consolidated: Discount rate 2.78 % 3.49 % 2.88 % 3.54 % Interest crediting rate (1)(2) 1.62 2.28 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 2.73 % 3.44 % 2.85 % 3.55 % Interest crediting rate (1)(2) 1.62 2.28 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SoCalGas: Discount rate 2.79 % 3.50 % 2.90 % 3.55 % Interest crediting rate (1)(2) 1.62 2.28 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (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 2020 2019 2018 2020 2019 2018 Sempra Energy Consolidated: Discount rate 3.49 % 4.29 % 3.64 % 3.54 % 4.29 % 3.68 % Expected return on plan assets 7.00 7.00 7.00 4.64 6.48 6.49 Interest crediting rate (1)(2) 2.28 3.36 2.80 2.28 3.36 2.80 Rate of compensation increase 2.70-10.00 2.00-10.00 2.00-10.00 2.70-10.00 2.00-10.00 2.00-10.00 SDG&E: Discount rate 3.44 % 4.29 % 3.64 % 3.55 % 4.30 % 3.65 % Expected return on plan assets 7.00 7.00 7.00 5.51 6.92 6.94 Interest crediting rate (1)(2) 2.28 3.36 2.80 2.28 3.36 2.80 Rate of compensation increase 2.70-10.00 2.00-10.00 2.00-10.00 2.70-10.00 2.00-10.00 2.00-10.00 SoCalGas: Discount rate 3.50 % 4.30 % 3.65 % 3.55 % 4.30 % 3.70 % Expected return on plan assets 7.00 7.00 7.00 4.41 6.38 6.38 Interest crediting rate (1)(2) 2.28 3.36 2.80 2.28 3.36 2.80 Rate of compensation increase 2.70-10.00 2.00-10.00 2.00-10.00 2.70-10.00 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 2020 2019 2018 2020 2019 2018 Health care cost trend rate assumed for next year 6.00 % 6.25 % 6.50 % 4.75 % 4.75 % 4.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2025 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: ▪ 33% domestic equity ▪ 22% international equity ▪ 21% long credit ▪ 10% diversified real assets ▪ 7% return-seeking credit ▪ 5% ultra-long duration government securities ▪ 2% other diversifying 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 6.75% 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 4% and 12% 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. Investment 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 30% to return-seeking assets and 70% 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 help 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. 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. SDG&E and SoCalGas each hold a proportionate share of investment assets in

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	12 Months Ended
	Dec. 31, 2020
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, 2020, 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 four ▪ Performance-Based Restricted Stock Units : These RSU awards generally vest in Sempra Energy common stock at the end of three four ◦ 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 2015 in connection with the creation of Cameron LNG JV. The 2015 awards vested in 2019 as both of the following were achieved: (a) the Compensation and Talent 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 ratably over three three four 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 and Talent 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, 2020, 6,927,284 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 four 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, 2020 2019 2018 Sempra Energy Consolidated: Share-based compensation expense, before income taxes (1) $ 62 $ 66 $ 76 Income tax benefit (1) (17) (18) (21) $ 45 $ 48 $ 55 Capitalized share-based compensation cost $ 11 $ 11 $ 10 Excess income tax deficiency $ 19 $ 4 $ 15 SDG&E: Share-based compensation expense, before income taxes $ 11 $ 10 $ 12 Income tax benefit (3) (3) (3) $ 8 $ 7 $ 9 Capitalized share-based compensation cost $ 7 $ 6 $ 6 Excess income tax deficiency $ 3 $ 1 $ 3 SoCalGas: Share-based compensation expense, before income taxes $ 14 $ 15 $ 16 Income tax benefit (4) (4) (5) $ 10 $ 11 $ 11 Capitalized share-based compensation cost $ 4 $ 5 $ 4 Excess income tax deficiency $ 3 $ 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. In 2020 and 2019, Sempra Energy’s board of directors granted 154,860 and 261,075 nonqualified stock options, respectively, that are exercisable over a three KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED Years ended December 31, 2020 2019 Stock price volatility 18.78 % 18.63 % Expected term 5.34 years 5.34 years Risk-free rate of return 1.68 % 2.49 % Annual dividend yield 2.60 % 3.35 % The following table shows a summary of nonqualified stock options at December 31, 2020 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, 2020 247,577 $ 105.86 Granted 154,860 $ 149.12 Exercised (4,400) $ 55.90 Forfeited/canceled (32,642) $ 149.12 Outstanding at December 31, 2020 365,395 $ 120.93 8.34 $ 2 Vested or expected to vest at December 31, 2020 349,596 $ 120.28 8.32 $ 2 Exercisable at December 31, 2020 81,061 $ 106.76 8.00 $ 2 The aggregate intrinsic value at December 31, 2020 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: ▪ $0.4 million in 2020 ▪ $4 million in 2019 ▪ $9 million in 2018 We expect a negligible amount of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2020 to be recognized over a weighted-average period of 1.3 years. The weighted-average per-share fair value for nonqualified stock options granted in 2019 was $106.76. We received cash of $0.2 million and $3 million from stock option exercises during 2020 and 2019, respectively. 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, 2020 2019 2018 Stock price volatility 16.35 % 17.74 % 17.46 % Risk-free rate of return 1.55 % 2.46 % 2.00 % The following table shows a summary of RSUs at December 31, 2020 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, 2020 1,086,981 $ 109.85 415,787 $ 119.96 Granted 265,236 $ 155.62 165,847 $ 138.91 Vested (403,302) $ 110.45 (230,612) $ 112.11 Forfeited (54,954) $ 134.90 (7,445) $ 140.18 Nonvested at December 31, 2020 (1) 893,961 $ 121.61 343,577 $ 121.59 Expected to vest at December 31, 2020 882,903 $ 121.45 339,025 $ 121.46 (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 2020, 2019 and 2018, the total fair value of RSU shares vested during the year was $70 million, $36 million and $32 million, respectively. We expect $28 million of total compensation cost related to nonvested RSUs not yet recognized as of December 31, 2020 to be recognized over a weighted-average period of 1.7 years. The weighted-average per-share fair values for performance-based RSUs granted were $113.54 and $105.03 in 2019 and 2018, respectively. The weighted-average per-share fair values for service-based RSUs granted were $112.50 and $107.60 in 2019 and 2018, respectively.

DERIVATIVE FINANCIAL INSTRUMENT

DERIVATIVE FINANCIAL INSTRUMENTS	12 Months Ended
	Dec. 31, 2020
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 could cause our asset values to fall or our liabilities to 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 and undesignated derivatives not subject to rate recovery). 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, in an effort 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 2020 2019 Sempra Energy Consolidated: Natural gas MMBtu 5 32 Electricity MWh 1 2 Congestion revenue rights MWh 43 48 SDG&E: Natural gas MMBtu 16 37 Electricity MWh 1 2 Congestion revenue rights MWh 43 48 SoCalGas: Natural gas MMBtu 1 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. The following table presents the net notional amounts of our interest rate derivatives, excluding JVs. INTEREST RATE DERIVATIVES (Dollars in millions) December 31, 2020 December 31, 2019 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges $ 1,486 2021-2034 $ 1,445 2020-2034 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 utilized foreign currency derivatives to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively. The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) December 31, 2020 December 31, 2019 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 306 2021-2023 $ 306 2020-2023 Other foreign currency derivatives 1,764 2021-2022 1,796 2020-2021 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 because the cash collateral was in excess of liability positions. DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2020 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 $ — $ 1 $ (26) $ (160) Derivatives not designated as hedging instruments: Foreign exchange instruments 24 — — — Commodity contracts not subject to rate recovery 82 17 (95) (16) Associated offsetting commodity contracts (82) (13) 82 13 Commodity contracts subject to rate recovery 35 95 (35) (25) Associated offsetting commodity contracts (2) — 2 — Net amounts presented on the balance sheet 57 100 (72) (188) Additional cash collateral for commodity contracts not subject to rate recovery 21 — — — Additional cash collateral for commodity contracts subject to rate recovery 30 — — — Total (2) $ 108 $ 100 $ (72) $ (188) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 32 $ 95 $ (28) $ (25) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 31 95 (27) (25) Additional cash collateral for commodity contracts subject to rate recovery 24 — — — Total (2) $ 55 $ 95 $ (27) $ (25) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (7) $ — Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 2 — (6) — Additional cash collateral for commodity contracts subject to rate recovery 6 — — — Total $ 8 $ — $ (6) $ — (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, 2019 Other current (1) Other long-term assets Other current 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 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. 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 Pretax (loss) gain reclassified Years ended December 31, Years ended December 31, 2020 2019 2018 Location 2020 2019 2018 Sempra Energy Consolidated: Interest rate instruments $ — $ — $ — (Loss) Gain on Sale of Assets $ — $ (10) $ (9) Interest rate instruments (1) (34) (24) 17 Interest Expense (1) (10) (3) (1) Interest rate instruments (185) (164) 44 Equity Earnings (46) (3) (9) Foreign exchange instruments (4) (8) (4) Revenues: Energy- Related Businesses 1 (2) 1 Interest rate and foreign exchange instruments (6) 19 14 Interest Expense (1) — 1 Other (Expense) Income, Net (11) 9 2 Foreign exchange instruments (3) (10) (3) Equity Earnings — (2) 2 Total $ (232) $ (187) $ 68 $ (67) $ (11) $ (13) SDG&E: Interest rate instruments (1) $ — $ (1) $ 1 Interest Expense (1) $ — $ (3) $ (7) 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 $87 million of losses, which are net of income tax benefit, that are currently recorded in AOCI related to cash flow hedges will be reclassified into earnings during the next 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, 2020 is approximately 14 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 19 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 2020 2019 2018 Sempra Energy Consolidated: Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses $ 17 $ 12 $ 26 Commodity contracts subject to rate recovery Cost of Natural Gas (7) 3 5 Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power 88 (140) 279 Foreign exchange instruments Other (Expense) Income, Net (56) 25 3 Total $ 42 $ (100) $ 313 SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ 88 $ (140) $ 279 SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (7) $ 3 $ 5 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 liability position at December 31, 2020 and 2019 was $16 million and $21 million, respectively. For SoCalGas, the total fair value of this group of derivative instruments in a liability position at December 31, 2020 and 2019 was $6 million and $4 million, respectively. At December 31, 2020, if the credit ratings of Sempra Energy or SoCalGas were reduced below investment grade, $16 million and $6 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, 2020
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, 2020 and 2019. 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 investment at December 31, 2019 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 – SDG&E.” ▪ 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 December 31, 2020, and 2019. ▪ As we discuss in Note 6, in July 2020, Sempra Energy entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra LNG.” RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 358 $ 6 $ — $ 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 399 626 — 1,025 Interest rate and foreign exchange instruments — 25 — 25 Commodity contracts not subject to rate recovery — 4 — 4 Effect of netting and allocation of collateral (2) 21 — — 21 Commodity contracts subject to rate recovery 6 1 121 128 Effect of netting and allocation of collateral (2) 19 5 6 30 Support Agreement, net of related guarantee fees — — 7 7 Total $ 445 $ 661 $ 134 $ 1,240 Liabilities: Interest rate and foreign exchange instruments $ — $ 186 $ — $ 186 Commodity contracts not subject to rate recovery — 16 — 16 Commodity contracts subject to rate recovery — 6 52 58 Support Agreement, net of related guarantee fees — — 4 4 Total $ — $ 208 $ 56 $ 264 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 (1) Excludes cash, cash equivalents and receivables (payables), net. (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, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 358 $ 6 $ — $ 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 399 626 — 1,025 Commodity contracts subject to rate recovery 5 — 121 126 Effect of netting and allocation of collateral (2) 18 — 6 24 Total $ 422 $ 626 $ 127 $ 1,175 Liabilities: Commodity contracts subject to rate recovery $ — $ — $ 52 $ 52 Total $ — $ — $ 52 $ 52 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 (1) Excludes cash, cash equivalents and receivables (payables), net. (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, 2020 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 1 $ — $ 2 Effect of netting and allocation of collateral (1) 1 5 — 6 Total $ 2 $ 6 $ — $ 8 Liabilities: Commodity contracts subject to rate recovery $ — $ 6 $ — $ 6 Total $ — $ 6 $ — $ 6 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 (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 SDG&E 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, 2020 2019 2018 Balance at January 1 $ 28 $ 179 $ (28) Realized and unrealized gains (losses) 19 (184) 209 Allocated transmission instruments 6 6 10 Settlements 16 27 (12) Balance at December 31 $ 69 $ 28 $ 179 Change in unrealized gains (losses) relating to instruments still held at December 31 $ 34 $ (139) $ 183 (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 2021 $ (1.81) to $ 14.11 $ (0.12) 2020 (3.77) to 6.03 (1.58) 2019 (8.57) to 35.21 (2.94) 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 at December 31 were as follows: LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2020 $ 19.60 to $ 78.10 $ 39.71 2019 21.00 to 61.15 37.92 A significant increase (decrease) in market electricity forward prices would result in a significantly higher (lower) fair value. We summarize long-term, fixed-price electricity position volumes in Note 11. Realized gains and losses associated with CRRs and long-term, fixed-price 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. Sempra LNG The table below sets forth a reconciliation of changes in the fair value of Sempra Energy’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated. LEVEL 3 RECONCILIATION (Dollars in millions) Year ended Balance at January 1 $ — Realized and unrealized gains (1) 6 Settlements (3) Balance at December 31 (2) $ 3 Change in unrealized gains (losses) relating to instruments still held at December 31 $ 3 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on the Sempra Energy Consolidated Statement of Operations. (2) Includes $7 million in Other Current Assets offset by $4 million in Deferred Credits and Other on the Sempra Energy Consolidated Balance Sheet. The fair value of the Support Agreement, net of related guarantee fees, is based on a discounted cash flow model using a probability of default and survival methodology. Our estimate of fair value considers inputs such as third-party default rates, credit ratings, recovery rates, and risk-adjusted discount rates, which may be readily observable, market corroborated or generally unobservable inputs. Because CFIN’s credit rating and related default and survival rates are unobservable inputs that are significant to the valuation, the Support Agreement, net of related guarantee fees, is classified as Level 3. We assigned CFIN an internally developed credit rating of A3 and relied on default rate data published by Moody’s to assign a probability of default. A hypothetical change in the credit rating up or down one notch would not result in a significant change in the fair value of the Support Agreement. 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, 2020 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates (1) $ 786 $ — $ 817 $ — $ 817 Long-term amounts due to unconsolidated affiliates 275 — 266 — 266 Total long-term debt (2) 22,259 — 25,478 — 25,478 SDG&E: Total long-term debt (3) $ 6,253 $ — $ 7,384 $ — $ 7,384 SoCalGas: Total long-term debt (4) $ 4,759 $ — $ 5,655 $ — $ 5,655 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 (2) 21,247 — 22,638 26 22,664 SDG&E: Total long-term debt (3) $ 5,140 $ — $ 5,662 $ — $ 5,662 SoCalGas: Total long-term debt (4) $ 3,809 $ — $ 4,189 $ — $ 4,189 (1) Before allowances for credit losses of $3 million. Includes $3 million of accrued interest receivable in Due From Unconsolidated Affiliate – Current. (2) Before reductions of unamortized discount and debt issuance costs of $268 million and $225 million at December 31, 2020 and 2019, respectively, and excluding finance lease obligations of $1,330 million and $1,289 million at December 31, 2020 and 2019, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $52 million and $48 million at December 31, 2020 and 2019, respectively, and excluding finance lease obligations of $1,276 million and $1,270 million at December 31, 2020 and 2019, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $40 million and $34 million at December 31, 2020 and 2019, respectively, and excluding finance lease obligations of $54 million and $19 million at December 31, 2020 and 2019, respectively. We provide the fair values for the securities held in the NDT related to SONGS in Note 15. NON-RECURRING FAIR VALUE MEASURES 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). In June 2018, we also owned a 75.4% interest in LA Storage, a salt cavern development project in Cameron Parish in 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 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. 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. 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 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 per dekatherm per month $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) (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, 2020
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, 2020 and 2019, 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. We discuss SoCalGas preferred stock below. 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), and received net proceeds of $1.69 billion (net of underwriting discounts and equity issuance costs of $32 million). Each share of series A preferred stock had a liquidation value of $100.00. 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), and received net proceeds of $565 million (net of underwriting discounts and equity issuance costs of $10 million). Each share of series B preferred stock has a liquidation value of $100.00. Mandatory Conversion Unless earlier converted, each share of the series A preferred stock and series B preferred stock is to 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 such series of preferred stock is 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. On January 15, 2021, we converted 17,250,000 shares of series A preferred stock into 13,781,025 shares of our common stock based on a conversion rate of 0.7989 shares of our common stock for each issued and outstanding share of series A preferred stock. As a consequence, no shares of series A preferred stock were outstanding after January 15, 2021 and the 17,250,000 shares that were formerly series A preferred stock have returned to the status of authorized and unissued shares of preferred stock. The terms of our series A preferred stock and series B preferred stock require a notice to holders when the aggregate adjustment to the conversion rates at which shares of series A preferred stock or series B preferred stock are convertible into shares of Sempra Energy common stock is more than 1%. On July 6, 2020, we notified the holders of the series A preferred stock of such an adjustment. These adjustments, which resulted from the incremental impact of our second quarter dividend declared on our common stock and which became effective as of June 25, 2020, the ex-dividend date for such dividend, include adjustments to the minimum and maximum conversion rates and the related initial and threshold appreciation prices. The following table illustrates the conversion rate per share of our series B 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 series B preferred stock) 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 mandatory convertible 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 were (with respect to the series A preferred stock) or are (with respect to the series B preferred stock) entitled to elect to convert each share of their preferred stock into shares of our common stock at the minimum conversion rate. No holders of the series A preferred stock elected such a conversion before the January 15, 2021 mandatory conversion of all then-outstanding shares. If all outstanding series B preferred stock were converted early, we would issue, subject to anti-dilution adjustments, 4.2 million common shares upon such conversion. In addition, if holders of the series B preferred stock elect to convert any shares during a specified period beginning on the effective date of a fundamental change, as defined in the certificate of determination of preferences of the series B 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 mandatory convertible preferred stock are (or, with respect to the series A preferred stock, were) payable quarterly on a cumulative basis when, as and if declared by our board of directors. All dividends ceased to accrue on the series A preferred stock upon their mandatory conversion on January 15, 2021. We may pay quarterly declared dividends on the series B preferred stock 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. Voting Rights The holders of the series B preferred stock do not have voting rights, except with respect to any authorization, creation or increase in the authorized amount of any class or series of capital stock ranking senior to the series B preferred stock, certain amendments to the terms of the series B preferred stock, in certain other limited circumstances and as otherwise specifically required by California law. In addition, whenever dividends on any shares of series B preferred stock have not been declared and paid or have been declared but not paid 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 the series B 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 who satisfy certain requirements to fill such newly created directorships. This voting right will terminate when all accumulated and unpaid dividends on the series B preferred stock have been paid in full and, upon such termination and the termination of the same voting rights of all other holders of outstanding series of preferred stock that have such voting rights, the term of office of each director elected pursuant to such rights will terminate and the authorized number of directors will automatically decrease by two, subject to the revesting of that right in the event of each subsequent nonpayment. Ranking The series B preferred stock ranks, with respect to dividend rights and distribution rights upon our liquidation, winding-up or dissolution: ▪ senior to our common stock and each other class or series of our capital stock established in the future, unless the terms of such capital stock expressly provide otherwise; ▪ on parity with our outstanding series C preferred stock and each class or series of our capital stock established in the future if the terms of such capital stock provide that it ranks on parity with the series B preferred stock; ▪ junior to each class or series of our capital stock established in the future, if the terms of such capital stock provide that it ranks senior to the series B preferred stock; ▪ junior to our existing and future indebtedness and other liabilities; and ▪ structurally subordinated to all existing and future indebtedness and other liabilities of our subsidiaries and capital stock of our subsidiaries held by third parties. SEMPRA ENERGY SERIES C PREFERRED STOCK In June 2020, we issued 900,000 shares of our 4.875% fixed-rate reset cumulative redeemable perpetual preferred stock, series C (series C preferred stock) in a registered public offering at a price to the public of $1,000 per share and received net proceeds of $889 million after deducting the underwriting discount and equity issuance costs of $11 million. We used the net proceeds for working capital and other general corporate purposes, including the repayment of indebtedness. Liquidation Preference Each share of series C preferred stock has a liquidation preference of $1,000 plus any accumulated and unpaid dividends (whether or not declared) on such share. Redemption at the Option of Sempra Energy The shares of series C preferred stock are perpetual and have no maturity date. However, we may, at our option, redeem the series C preferred stock in whole or in part, from time to time, on any day during the period from and including the July 15 immediately preceding October 15, 2025 and October 15 of every fifth year after 2025 through and including such October 15 at a redemption price in cash equal to $1,000 per share. Additionally, in the event that a credit rating agency then publishing a rating for us makes certain amendments, clarifications or changes to the criteria it uses to assign equity credit to securities such as the series C preferred stock (Ratings Event), we may redeem the series C preferred stock, in whole but not in part, at any time within 120 days after the conclusion of any review or appeal process instituted by us following the occurrence of the Ratings Event or, if no such review or appeal process is available or sought, the occurrence of such Ratings Event, at a redemption price in cash equal to $1,020 per share (102% of the liquidation preference per share). Dividends Dividends on the series C preferred stock, when, as and if declared by our board of directors or an authorized committee thereof, are payable in cash, on a cumulative basis, semi-annually in arrears beginning on October 15, 2020. Dividends on the series C preferred stock will be cumulative whether or not: ▪ we have earnings; ▪ the payment of such dividends is then permitted under California law; ▪ such dividends are authorized or declared; and ▪ any agreements to which we are a party prohibit the current payment of dividends, including any agreement relating to our indebtedness. We accrue dividends on the series C preferred stock on a monthly basis. The dividend rate from and including June 19, 2020 to, but excluding, October 15, 2025 is 4.875% per annum of the $1,000 liquidation preference per share. The dividend rate will reset on October 15, 2025 and on October 15 of every fifth year after 2025 and, for each five-year period following such reset dates, will be a per annum rate equal to the Five-year U.S. Treasury Rate (as defined in the certificate of determination of preferences of the series C preferred stock) as of the second business day prior to such reset date, plus a spread of 4.550%, of the $1,000 liquidation preference per share. Voting Rights The holders of series C preferred stock do not have any voting rights, except with respect to any authorization, creation or increase in the authorized amount of any class or series of capital stock ranking senior to the series C preferred stock, certain amendments to the terms of the series C preferred stock, in certain other limited circumstances and as otherwise specifically required by California law. In addition, whenever dividends on any shares of series C preferred stock have not been declared and paid or have been declared but not paid for three 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 the series C preferred stock, voting together as a single class with holders of any and all other outstanding series of preferred stock of equal rank having similar voting rights, will be entitled to elect two directors who satisfy certain requirements to fill such two newly created directorships. This voting right will terminate when all accumulated and unpaid dividends on the series C preferred stock have been paid in full and, upon such termination and the termination of the same voting rights of all other holders of outstanding series of preferred stock that have such voting rights, the term of office of each director elected pursuant to such rights will terminate and the authorized number of directors will automatically decrease by two, subject to the revesting of such rights in the event of each subsequent nonpayment. Ranking The series C preferred stock ranks, with respect to dividend rights and distribution rights upon our liquidation, winding-up or dissolution: ▪ senior to our common stock and each other class or series of our capital stock established in the future, unless the terms of such capital stock expressly provide otherwise; ▪ on parity with our formerly outstanding series A preferred stock and currently outstanding series B preferred stock and each class or series of our capital stock established in the future if the terms of such capital stock provide that it ranks on parity with the series C preferred stock; ▪ junior to each class or series of our capital stock established in the future, if the terms of such capital stock provide that it ranks senior to the series C preferred stock; ▪ junior to our existing and future indebtedness and other liabilities; and ▪ structurally subordinated to all 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, 2020 2019 $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 PE (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, 2020
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 REPURCHASES On September 11, 2007, our board of directors authorized the repurchase of shares of our common stock, provided that the amounts spent for such purpose do not exceed the greater of $2 billion or amounts spent to purchase no more than 40 million shares. On July 1, 2020, we entered into an ASR program under which we prepaid $500 million to repurchase shares of our common stock in a share forward transaction. The total number of shares purchased was determined by dividing the $500 million purchase price by the arithmetic average of the volume-weighted average trading prices of shares of our common stock during the valuation period of July 2, 2020 through August 4, 2020, minus a fixed discount. The program was completed on August 4, 2020 with an aggregate of 4,089,375 shares of Sempra Energy common stock repurchased at an average price of $122.27 per share. Following the completion of the ASR program, the aggregate dollar amount authorized by the September 11, 2007 share repurchase authorization was exhausted. On July 6, 2020, our board of directors authorized the repurchase of shares of our common stock at any time and from time to time in an aggregate amount not to exceed the lesser of $2 billion or amounts spent to purchase no more than 25 million shares. No shares have been repurchased under this authorization. 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 PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2020 2019 2018 Numerator for continuing operations: Income from continuing operations, net of income tax $ 2,255 $ 1,999 $ 938 Earnings attributable to noncontrolling interests (162) (129) (44) Preferred dividends (168) (142) (125) Preferred dividends of subsidiary (1) (1) (1) Earnings from continuing operations attributable to common shares $ 1,924 $ 1,727 $ 768 Numerator for discontinued operations: Income from discontinued operations, net of income tax $ 1,850 $ 363 $ 188 Earnings attributable to noncontrolling interests (10) (35) (32) Earnings from discontinued operations attributable to common shares $ 1,840 $ 328 $ 156 Numerator for earnings: Earnings attributable to common shares $ 3,764 $ 2,055 $ 924 Denominator: Weighted-average common shares outstanding for basic EPS (1) 291,077 277,904 268,072 Dilutive effect of stock options and RSUs (2) 1,175 1,585 919 Dilutive effect of common shares sold forward — 2,544 861 Weighted-average common shares outstanding for diluted EPS 292,252 282,033 269,852 Basic EPS: Earnings from continuing operations $ 6.61 $ 6.22 $ 2.86 Earnings from discontinued operations $ 6.32 $ 1.18 $ 0.59 Earnings $ 12.93 $ 7.40 $ 3.45 Diluted EPS: Earnings from continuing operations $ 6.58 $ 6.13 $ 2.84 Earnings from discontinued operations $ 6.30 $ 1.16 $ 0.58 Earnings $ 12.88 $ 7.29 $ 3.42 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 537 in 2020, 617 in 2019 and 641 in 2018. 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 for 2020, 2019 and 2018 excludes potentially dilutive shares of 187,028, 80,281 and 20,814, respectively, 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. We have fully settled all forward sale agreements and those shares are included in weighted-average common shares outstanding for basic EPS. The potentially dilutive impact from our mandatory convertible preferred stock is calculated under the if-converted method. The computation of diluted EPS for the years ended December 31, 2020, 2019 and 2018 excludes 17,889,365, 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 and conversion of the series A preferred stock to Sempra Energy common stock on January 15, 2021 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, 2020 2019 2018 Common shares outstanding, January 1 291,712,925 273,769,513 251,358,977 Shares issued under forward sale agreements — 16,906,185 21,175,473 RSUs vesting (1) 896,839 463,012 509,042 Stock options exercised 4,400 52,540 138,861 Savings plan issuance 201,431 475,774 553,036 Common stock investment plan (2) 42,955 199,253 231,242 Issuance of RSUs held in our Deferred Compensation Plan 103,552 59,470 3,357 Shares repurchased (3) (4,491,858) (212,822) (200,475) Common shares outstanding, December 31 288,470,244 291,712,925 273,769,513 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares.

SAN ONOFRE NUCLEAR GENERATING S

SAN ONOFRE NUCLEAR GENERATING STATION	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 22 (108) Pension and other postretirement benefit plan obligations 50 103 Removal obligations (2,121) (2,056) Environmental costs 56 45 Sunrise Powerlink fire mitigation 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 72 102 Gas transportation 35 22 Safety and reliability 67 77 Public purpose programs (158) (124) 2019 GRC retroactive impacts 56 111 Other balancing accounts 233 106 Other regulatory assets (liabilities), net (2) 72 (153) Total SDG&E (1,548) (1,746) SoCalGas: Deferred income taxes refundable in rates (82) (203) Pension and other postretirement benefit plan obligations 417 400 Employee benefit costs 37 44 Removal obligations (685) (728) Environmental costs 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (56) (118) Safety and reliability 335 295 Public purpose programs (253) (273) 2019 GRC retroactive impacts 202 400 Other balancing accounts (58) (7) Other regulatory assets (liabilities), net (2) 75 (101) Total SoCalGas (32) (251) Sempra Mexico: Deferred income taxes recoverable in rates 80 83 Other regulatory assets — 6 Total Sempra Energy Consolidated $ (1,500) $ (1,908) (1) At December 31, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $139 million and $108 million, respectively, and for SoCalGas was $218 million and $500 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 excess deferred income taxes resulting from statutory income tax rate changes and 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 49-year period. ▪ Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized costs, including commodity costs. Depreciation, taxes 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. The adopted revenue requirements in the 2019 GRC FD associated with the period from January 1, 2019 through December 31, 2019 are being recovered in rates over a 24-month period that began in January 2020. Amortization expense on regulatory assets for the years ended December 31, 2020, 2019 and 2018 was $9 million, $7 million and $5 million, respectively, at Sempra Energy Consolidated, $4 million, $3 million and $2 million, respectively, at SDG&E, and $5 million, $4 million and $3 million, respectively, at SoCalGas. CALIFORNIA UTILITIES COVID-19 Pandemic Protections In March 2020, the CPUC required that all energy companies under its jurisdiction, including the California Utilities, take action to implement several emergency customer protection measures to support California customers in light of the COVID-19 pandemic for up to one year. Currently, the customer protection measures are mandatory for all residential and small business customers. In February 2021, the CPUC extended the customer protection measures through June 2021 and may extend them further. Each of the California Utilities was authorized to track and request recovery of incremental costs associated with complying with residential and small business customer protection measures implemented by the CPUC related to the COVID-19 pandemic, including costs associated with suspending service disconnections and uncollectible expenses that arise from these customers’ failure to pay. The California Utilities expect to pursue recovery of tracked costs in rates in a future CPUC proceeding, which recovery is not assured. Disconnection OIR In June 2020, the CPUC issued a decision to adopt certain customer protections to reduce residential customer disconnections and improve reconnection processes, including, among other things, imposing limitations on service disconnections, elimination of deposit requirements and reconnection fees, establishment of the AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts, and increased outreach and marketing efforts. The decision allows each of the California Utilities to establish a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills, including as a result of the relief from outstanding utility bill amounts provided under the AMP. 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 In September 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, which was effective retroactively to January 1, 2019. This is the first GRC that includes revenues authorized for risk assessment mitigation phase activities. The 2019 GRC FD approved 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) and $2,770 million for SoCalGas. 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 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 California Utilities filed the petition in April 2020 and requested authorization of their post-test year ratemaking mechanism for two additional years. We subsequently requested an updated increase in the revenue requirement for SDG&E and SoCalGas of approximately $91 million and $150 million, respectively, for 2022, and $104 million and $131 million, respectively, for 2023, reflecting certain adjustments. These amounts include revenues for both O&M and capital cost attrition. In June 2020, the CPUC issued a ruling to further clarify the issues for review in the California Utilities’ petition, which are mainly whether the proposed revenue requirements and mechanisms for the two proposed additional attrition years are just and reasonable. In September 2020, the California Utilities filed a status report to summarize positions on how impacts of the COVID-19 pandemic should be incorporated into the proposed attrition rates. The California Utilities proposed to continue with the adopted attrition mechanism using the second quarter 2020 Global Insight utility cost forecast, which incorporates impacts of the COVID-19 pandemic. Intervenors have proposed other alternatives, including using escalation factors based on the Consumer Price Index. We expect a proposed decision in the first quarter of 2021. The 2019 GRC FD approved the California Utilities’ 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. The 2019 GRC FD clarified that differences between incurred and forecasted income tax expense due to forecasting differences are not subject to tracking in the income tax expense memorandum account beginning in 2019. SDG&E and SoCalGas previously recorded regulatory liabilities, inclusive of interest, associated with the 2016 through 2018 tracked forecasting differences of $86 million and $89 million, respectively. In April 2020, the CPUC confirmed treatment of the two-way income tax expense memorandum account for these 2016 through 2018 balances, at which time the California Utilities released these regulatory liability balances to revenues and regulatory interest. CPUC Cost of Capital In December 2019, the CPUC approved the cost of capital and rate structures (shown in the table below) for SDG&E and SoCalGas that became effective on 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 the CPUC approved in March 2020. CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on Weighted 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 Equity 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. SDG&E’s CCM benchmark rate is 4.498%, based on Moody’s Baa- utility bond index, and SoCalGas’ CCM benchmark rate is 4.029%, 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. For the 12 months ended September 2020, the first “CCM Period,” the trigger did not occur for SDG&E or SoCalGas. The next CCM Period is from October 2020 to September 2021. The CCM, if triggered in 2021, would be effective January 1, 2022, and would automatically update the authorized cost of debt based on actual costs and update the authorized ROE upward or downward by one-half of the difference between the CCM benchmark and the applicable 12-month average Moody’s utility bond index. 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 TO4 ROE of 10.05% was the basis of SDG&E’s FERC-related revenue recognition until March 2020, when the FERC approved the settlement terms that SDG&E and all settling parties reached in October 2019 on SDG&E’s TO5 filing. The settlement agreement provided 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. If the FERC issues an order ruling that California IOUs are no longer eligible for the additional California ISO ROE, SDG&E would refund the additional 50 bps of ROE associated with the California ISO as of the refund effective date (June 1, 2019) in this proceeding. The TO5 term is effective June 1, 2019 and shall remain in effect indefinitely, with parties having the annual right to terminate the agreement beginning in 2022. In 2020, SDG&E recorded retroactive revenues of $12 million related to 2019, and additional FERC revenues of $17 million to conclude a rate base matter, net of certain refunds to be paid to CPUC-jurisdictional customers. Energy Efficiency Program Inquiry In January 2020, the CPUC issued a ruling seeking comments on a report prepared by its consultant regarding SDG&E’s Upstream Lighting Program for the program year 2017. The CPUC subsequently expanded the scope of the comments to cover the program year 2018. The Upstream Lighting Program was one of SDG&E’s Energy Efficiency programs designed to produce energy efficiency savings for which SDG&E could earn a performance-based incentive. Pursuant to the CPUC ruling, intervenors representing ratepayers have questioned SDG&E’s management of the program and alleged that certain program expenditures did not benefit the purpose of the program. As a result of the inquiry, SDG&E voluntarily expanded its review to include the program year 2019. Based on this review and discussions with intervenors, SDG&E concluded that some concessions were appropriate, which include refunding certain costs and certain performance-based incentives to customers and incurring a fine. Accordingly, in the year ended December 31, 2020, SDG&E reduced revenues by $51 million and recorded a fine of $6 million in Other (Expense) Income, Net, on the SDG&E and Sempra Energy Consolidated Statements of Operations. The after-tax impact for the year ended December 31, 2020 was $44 million. In October 2020, SDG&E executed a settlement agreement with intervenors consistent with these concessions. We expect CPUC approval of the settlement agreement in 2021. SOCALGAS OSCs – Energy Efficiency and Advocacy In October 2019, the CPUC issued an OSC to determine whether SoCalGas should be sanctioned for violation of certain CPUC code sections and orders. The OSC stemmed from approximately 40 days and $9,000 of transitional energy efficiency (EE) codes and standards advocacy activities undertaken by SoCalGas in 2018, following a CPUC decision disallowing SoCalGas’ future engagement in EE statewide codes and standards advocacy. In December 2019, the CPUC issued a second OSC to determine whether SoCalGas is entitled to the EE program’s shareholder incentives for codes and standards advocacy in 2016 and 2017, whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. The scope of this OSC was later expanded to include EE program years 2014 and 2015, and SoCalGas’ engagement with local governments on proposed reach codes. Intervenors in these OSCs have suggested the CPUC order various financial and non-financial penalties. If the CPUC were to assess fines or penalties on SoCalGas associated with these OSCs, they could be material. We expect CPUC decisions on these OSCs in the first half of 2021. Billing Practices OII NOTE 15. SAN ONOFRE NUCLEAR GENERATING STATION 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. 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 July 2018, the CPUC approved a settlement agreement and, in August 2018, SDG&E, Edison, Cal PA, TURN and other intervenors submitted a notice that they accepted the settlement agreement, which provided for various disallowances, refunds and rate recoveries. In connection with the settlement agreement, and in exchange for the release of certain SONGS-related claims, in January 2018, SDG&E and Edison entered into a utility shareholder agreement, which became effective upon CPUC approval of the settlement agreement in July 2018, 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 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. Edison’s payment obligation commenced in October 2018, and amounts are due to SDG&E quarterly thereafter until April 2022. At December 31, 2020, SDG&E has a receivable from Edison, including accrued interest, totaling $49 million, with $37 million classified as current and $12 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 work to take 10 years after receipt of all the required permits. The coastal development permit, the last permit required to be obtained, 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 seeking to invalidate this permit and to obtain injunctive relief to stop decommissioning work. In September 2020, the Samuel Lawrence Foundation filed another writ petition under the California Coastal Act in LA Superior Court seeking to set aside the CCC’s July 2020 approval of the inspection and maintenance plan for the SONGS’ canisters and to obtain injunctive relief to stop decommissioning work. Major decommissioning work began in 2020 and has not been interrupted by the writ petitions filed by the Samuel Lawrence Foundation. 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 decommissioning costs. 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. In December 2020, SDG&E received authorization from the CPUC to access NDT funds of up to $89 million for forecasted 2021 costs. In September 2020, the IRS and the U.S. Department of the Treasury published final 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 final regulations adopted most of the provisions of the proposed regulations issued in December 2016. The final regulations apply to taxable years ending on or after September 4, 2020 and confirm that the definition of “nuclear decommissioning costs” includes amounts related to the storage of spent nuclear fuel at both on-site and off-site ISFSIs. The final regulations also clarify that costs incurred for ISFSIs that may be or are expected to be reimbursed by the DOE may be paid or reimbursed from a qualified trust fund. Accordingly, the final regulations allow SDG&E the option to access qualified trust funds to recover spent fuel storage 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. 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 Gross Estimated At December 31, 2020: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 64 $ 1 $ — $ 65 Municipal bonds (2) 308 18 — 326 Other securities (3) 253 17 — 270 Total debt securities 625 36 — 661 Equity securities 112 254 (2) 364 Cash and cash equivalents 3 — — 3 Receivables (payables), net (9) — — (9) Total $ 731 $ 290 $ (2) $ 1,019 At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 57 $ — $ — $ 57 Municipal bonds 270 12 — 282 Other securities 218 9 (1) 226 Total debt securities 545 21 (1) 565 Equity securities 176 339 (6) 509 Cash and cash equivalents 16 — — 16 Receivables (payables), net (8) — — (8) Total $ 729 $ 360 $ (7) $ 1,082 (1) Maturity dates are 2022-2051. (2) Maturity dates are 2021-2056. (3) Maturity dates are 2021-2072. 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, 2020 2019 2018 Proceeds from sales $ 1,439 $ 914 $ 890 Gross realized gains 156 24 42 Gross realized losses (17) (5) (10) 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 $579 million at December 31, 2020. 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 2020 dollars is approximately $860 million. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $110 million in 2021, $83 million in 2022, $63 million in 2023, $45 million in 2024, $44 million in 2025, and $697 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. In October 2015, the CCC approved Edison’s application to expand the ISFSI. 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 and was completed in August 2020. 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. As a result of updated coverage assessments, the SONGS owners have nuclear property damage insurance of $130 million, which exceeds the minimum federal requirements of $50 million. This insurance coverage is provided through NEIL. The NEIL policies have specific exclusions and limitations that can result in reduced 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 $3.5 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, 2020
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, 2020, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $616 million for Sempra Energy Consolidated and $471 million for SoCalGas. Amounts for Sempra Energy Consolidated and SoCalGas include $445 million for matters related to the Leak, which we discuss below. We discuss our policy regarding accrual of legal fees in Note 1. 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, Accounting Impact and Insurance.” Civil and Criminal Litigation. As of February 22, 2021, 395 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 and 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 initial trial previously scheduled for June 2020 for a small number of randomly selected individual plaintiffs was postponed, with a new trial date yet to be determined by the court. 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). The Property Class Action asserts claims for strict liability for ultra-hazardous activities, negligence, negligence per se, violation of the California Unfair Competition Law, trespass, permanent and continuing public and private nuisance, and inverse condemnation. The Business Class Action asserts a claim for violation of the California Unfair Competition Law. Both complaints seek compensatory, statutory and punitive damages, injunctive relief and attorneys’ fees. 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. Four shareholder derivative actions were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra Energy and/or SoCalGas. Three of the actions were joined in an Amended Consolidated Shareholder Derivative Complaint, which was dismissed with prejudice in January 2021. The remaining action was also dismissed but plaintiffs were given leave to amend their complaint. 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. 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 of three actions filed by these entities 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 September 2016, SoCalGas settled a misdemeanor criminal complaint filed in February 2016 by the Los Angeles County District Attorney’s Office against SoCalGas, pleading no contest to a charge that it failed 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). In November 2016, the LA Superior Court approved the settlement and entered judgment on the notice charge. Under the settlement, SoCalGas paid a $75,000 fine, $233,500 in penalties, and $246,673 to reimburse costs incurred by Los Angeles County Fire Department’s Health and Hazardous Materials Division, as well as completed operational commitments estimated to cost approximately $6 million. 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. Following the hearing, the trial court denied restitution. In December 2020, the California Supreme Court denied review of the ruling. 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 California 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 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, the 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 on a subset of issues are scheduled to begin in March 2021. The second phase will consider whether SoCalGas should be sanctioned for the Leak and what damages, fines or other penalties or sanctions, if any, should be imposed for any violations, unreasonable or imprudent practices, or failure to sufficiently cooperate with the SED as determined by the CPUC in the first phase. In addition, the second phase will 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, which could result in little or no recovery of such costs by SoCalGas. SoCalGas has engaged in settlement discussions with the SED in connection with this proceeding. In February 2017, the CPUC opened a proceeding pursuant to SB 380 OII 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 CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility in November 2020 with a final determination to be made within the SB 380 OII proceeding. The first phase of the proceeding 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. In December 2019, the CPUC added a third phase of the proceeding and engaged a consultant to consider alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either the 2027 or 2045 timeframe, which is currently underway. 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, 2020, the Aliso Canyon natural gas storage facility had a net book value of $821 million. Any significant impairment of this asset, or higher operating costs and additional capital expenditures incurred by SoCalGas that 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, Accounting Impact and Insurance. 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, 2020, SoCalGas estimates its costs related to the Leak are $1,627 million (the cost estimate), which includes $1,279 million of costs recovered or probable of recovery from insurance. This cost estimate may increase significantly as more information becomes available. A substantial portion of the cost estimate has been paid, and $451 million is accrued as Reserve for Aliso Canyon Costs as of December 31, 2020 on SoCalGas’ and Sempra Energy’s Consolidated Balance Sheets. In 2020, SoCalGas recorded $484 million in costs, inclusive of estimated legal costs, related to settlement discussions in connection with civil litigation and regulatory matters described above in “Civil and Criminal Litigation” and “Regulatory Proceedings.” Of this amount, $177 million was recorded in Insurance Receivable for Aliso Canyon Costs on the SoCalGas and Sempra Energy Consolidated Balance Sheets and $307 million ($233 million after tax) was recorded in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Energy Consolidated Statements of Operations. These accruals are included in the cost estimate that we describe above. Except for the amounts paid or estimated to settle certain actions, as described in “Civil and Criminal Litigation” and “Regulatory Proceedings” above, the cost estimate does not include litigation, regulatory proceedings or regulatory costs to the extent it is not possible to predict at this time 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. 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. These costs not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra Energy’s cash flows, financial condition and results of operations. We have received insurance payments for many of the costs included in the cost estimate, including temporary relocation and associated processing costs, control-of-well expenses, costs of the government-ordered response to the Leak, certain legal costs and lost gas. As of December 31, 2020, we recorded the expected recovery of the cost estimate related to the Leak of $445 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra Energy’s Consolidated Balance Sheets. This amount is exclusive of insurance retentions and $834 million of insurance proceeds we received through December 31, 2020. We intend to pursue the full extent of our insurance coverage for the costs we have incurred. Other than insurance for certain future defense costs we may incur as well as directors’ and officers’ liability, we have exhausted all of our insurance in this matter. We continue to pursue other sources of insurance coverage for costs related to this matter, but we may not be successful in obtaining additional insurance recovery for any of these costs. If we are not able to secure additional insurance recovery, if any costs we have recorded as an insurance receivable are not collected, if there are 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, which could be significant, 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 Regas Facility that allegedly overlaps with land owned by the ECA Regas Facility (the facility, however, is not situated on the land that is the subject of this dispute). A claimant to the adjacent property filed complaints in the federal Agrarian Court challenging the refusal of SEDATU in 2006 to issue 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 and ordered a retrial. Four other cases involving two adjacent areas of real property on which part of the ECA Regas Facility is situated, each brought by a single plaintiff or her descendants, remain pending against the facility. The first disputed area is subject to a claim in the federal Agrarian Court that has been ongoing since 2006, in which the plaintiffs seek to annul the property title for a portion of the land on which the ECA Regas Facility is situated and to obtain possession of a different parcel that allegedly overlaps with the site of the ECA Regas Facility. The second disputed area is one parcel adjacent to the ECA Regas Facility that allegedly overlaps with land on which the ECA Regas Facility is situated, which is subject to a claim in the Agrarian Court and two claims in civil courts. The Agrarian Court proceeding, which seeks an order that SEDATU issue title to the plaintiff, was initiated in 2013 and the parties are awaiting a final decision. The two civil court proceedings, which seek to invalidate the contract by which the ECA Regas Facility purchased the applicable parcel of land on which the ECA Regas Facility is situated on the grounds that the purchase price was allegedly unfair, are progressing at different stages. In the first, initiated in 2013, a lower court ruled in favor of the ECA Regas Facility and the ruling has been appealed by the plaintiff. The same plaintiff filed the second civil case in 2019, which is in its initial stages. Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities are proposed to be situated or on which portions of the ECA Regas Facility that would be necessary for the operation of the proposed ECA LNG liquefaction facilities are situated. Several administrative challenges are pending before Mexico’s Secretariat of Environment and Natural Resources (the Mexican environmental protection agency) and Federal Tax and Administrative Courts, seeking revocation of the environmental impact authorization issued to the ECA Regas 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. In 2018, two related claimants filed separate challenges in the federal district court in Ensenada, Baja California in relation to the environmental and social impact permits issued by each of Agencia de Seguridad, Energía y Ambiente (ASEA) and SENER to ECA LNG authorizing natural gas liquefaction activities at the ECA Regas Facility. In the first case, the court issued a provisional injunction in September 2018. In December 2018, ASEA approved modifications to the environmental permit that facilitate the development of the proposed natural gas liquefaction facility in two phases. In May 2019, the court canceled the provisional injunction. The claimant appealed the court’s decision canceling the injunction, but was not successful. The claimant’s underlying challenge to the permits remains pending. In the second case, the initial request for a provisional injunction was denied. That decision was reversed on appeal in January 2020, resulting in the issuance of a new injunction against the same environmental and social impact permits that were already issued by ASEA and SENER. This injunction has uncertain application absent clarification by the court. The reversal and issuance of the injunction in the second case is under further appeal. In September 2020, parties claiming a property interest in the land on which the ECA Regas Facility is situated and the proposed ECA LNG liquefaction facilities are anticipated to be situated filed an administrative proceeding with the Municipality of Ensenada against the permit for the construction of the proposed liquefaction export projects at the ECA Regas Facility. The ECA Regas Facility and ECA LNG contested the validity of the claim and the Municipality of Ensenada has confirmed the validity of the construction permit and closed the proceeding. In May 2020, the two third-party capacity customers at the ECA Regas Facility, Shell Mexico and Gazprom, asserted that a 2019 update of the general terms and conditions for service at the facility, as approved by the CRE, resulted in a breach of contract by IEnova and a force majeure event. Citing these circumstances, the customers subsequently stopped making payments of amounts due under their respective LNG storage and regasification agreements. IEnova has rejected the customers’ assertions and has drawn (and expects to continue to draw) on the customers’ letters of credit provided as payment security. The parties engaged in discussions under the applicable contractual dispute resolution procedures without coming to a mutually acceptable resolution. In July 2020, Shell Mexico submitted a request for arbitration of the dispute and although Gazprom has joined the proceeding, Gazprom has replenished the amounts drawn on its letter of credit and has resumed making regular monthly payments under its LNG storage and regasification agreement. IEnova intends to avail itself of its available claims, defenses, rights and remedies in the arbitration proceeding, including seeking dismissal of the customers’ claims. In addition to the arbitration proceeding, Shell Mexico also filed a constitutional challenge to the CRE’s approval of the update to the general terms and conditions. In October 2020, Shell Mexico’s request to stay CRE’s approval was denied and, subsequently, Shell Mexico filed an appeal of that decision. One or more unfavorable final decisions on these disputes or challenges could materially and adversely affect our existing natural gas regasification operations and proposed natural gas liquefaction projects at the site of the ECA Regas Facility. 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 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 in August 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. Subsequently, IEnova and the CFE agreed to extend the service start date to May 15, 2020 and then again to September 15, 2020. In the third quarter of 2020, the parties agreed to further extend the service start date to March 14, 2021. 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 March 14, 2021 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. At December 31, 2020, the Guaymas-El Oro segment of the Sonora pipeline had a net book value of $447 million. The Sasabe-Puerto Libertad-Guaymas segment of the Sonora pipeline remains in full operation and is not impacted by these developments. Regulatory Actions by the Mexican Government that Impact Renewable Energy Facilities In April 2020, Mexico’s CENACE issued an order that it claims would safeguard Mexico’s national power grid from interruptions that may be caused by renewable energy projects. The main provision of the order suspends all legally mandated pre-operative testing that would be needed for new renewable energy projects to commence operations and prevents such projects from connecting to the national power grid until further notice. IEnova’s renewable energy projects affected by the order filed for legal protection through amparo claims (constitutional protection lawsuits) and, in June 2020, received injunctive relief until the claims are resolved by the courts. We have since achieved commercial operations on two solar power generation projects, Tepezalá and Don Diego, and expect to achieve commercial operations on Border Solar in the first half of 2021. The second phase of ESJ is not impacted by the order because it is not interconnected to the Mexican electric grid. In May 2020, Mexico’s SENER published a resolution to establish guidelines intended to guarantee the security and reliability of the national grid’s electricity supply by reducing the threat that it claims is caused by clean, intermittent energy. IEnova’s renewable energy projects, including those in construction and in service, filed amparo claims against the SENER resolution in June 2020 and received injunctive relief in July 2020. In addition, in June 2020, COFECE, Mexico’s antitrust regulator, filed a complaint with Mexico’s Supreme Court against the SENER resolution. The court accepted COFECE’s complaint and, in February 2021, issued its final ruling that the main proposed changes in the SENER resolution are unconstitutional. In May 2020, the CRE approved an update to the transmission rates included in legacy renewables and cogeneration energy contracts, based on the claim that the legacy transmission rates did not reflect fair and proportional costs for providing the applicable services and, therefore, created inequitable competitive conditions. Three of IEnova’s renewables facilities are currently holders of contracts with such legacy rates, and any increases in the transmission rates would be passed through directly to their customers. IEnova filed amparo claims for its affected facilities and, in August 2020, was granted injunctive relief. IEnova and other companies affected by these new orders and regulations have challenged the orders and regulations by filing amparo claims, some of which have been granted injunctive relief. The court-ordered injunctions provide relief until Mexico’s Federal District Court ultimately resolves the amparo claims. An unfavorable final decision on these amparo challenges, or the potential for an extended dispute, could impact our ability to successfully complete construction of our Border Solar project, which is not yet commercially operating, or to complete such construction in a timely manner and within expected budgets, may impact our ability to operate our wind and solar facilities already in service at existing levels or at all, and may adversely affect our ability to develop new projects, any of which may have a material adverse impact on our results of operations and cash flows and our ability to recover the carrying values of our renewable energy investments in Mexico. In October 2020, the CRE approved a resolution to amend the rules for the inclusion of new offtakers of legacy generation and self-supply permits (the Offtaker Resolution), which became effective immediately. The Offtaker Resolution prohibits self-supply permit holders from adding new offtakers that were not included in the original development or expansion plans, making modifications to the amount of energy allocated to the named offtakers, and including load centers that have entered into a supply arrangement under Mexico’s Electricity Industry Law. Don Diego Solar and Border Solar (two of IEnova’s projects, the first of which has achieved commercial operations and the second of which is currently in construction) and the Ventika wind power generation facilities are holders of legacy self-supply permits and are impacted by the Offtaker Resolution. If IEnova is not able to obtain legal protection for these impacted facilities, IEnova expects it will sell Border Solar’s capacity and a portion of Don Diego Solar’s capacity affected by the Offtaker Resolution into the spot market. Currently, prices in the spot market are significantly Other Litigation RBS Sempra Commodities Sempra Energy holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in

SEGMENT INFORMATION

SEGMENT INFORMATION	12 Months Ended
	Dec. 31, 2020
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 owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings, which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. As we discuss in Note 5, we acquired our investment in Sharyland Holdings in May 2019. ▪ Sempra Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. ▪ Sempra LNG develops and builds natural gas liquefaction export facilities, 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 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 is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020. 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, 2020 2019 2018 REVENUES SDG&E $ 5,313 $ 4,925 $ 4,568 SoCalGas 4,748 4,525 3,962 Sempra Mexico 1,256 1,375 1,376 Sempra LNG 374 410 472 Sempra Renewables — 10 124 All other 2 3 — Adjustments and eliminations (3) (3) (3) Intersegment revenues (1) (320) (416) (397) Total $ 11,370 $ 10,829 $ 10,102 INTEREST EXPENSE SDG&E (2) $ 413 $ 411 $ 221 SoCalGas 158 141 115 Sempra Mexico 132 119 120 Sempra LNG 43 35 21 Sempra Renewables — 3 19 All other 389 450 496 Intercompany eliminations (54) (82) (106) Total $ 1,081 $ 1,077 $ 886 INTEREST INCOME SDG&E $ 2 $ 4 $ 4 SoCalGas 2 2 2 Sempra Mexico 60 78 65 Sempra LNG 81 61 49 Sempra Renewables — 11 12 All other 7 4 14 Intercompany eliminations (56) (73) (61) Total $ 96 $ 87 $ 85 DEPRECIATION AND AMORTIZATION SDG&E $ 801 $ 760 $ 688 SoCalGas 654 602 556 Sempra Mexico 189 183 175 Sempra LNG 9 10 26 Sempra Renewables — — 27 All other 13 14 19 Total $ 1,666 $ 1,569 $ 1,491 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 190 $ 171 $ 173 SoCalGas 96 120 92 Sempra Texas Utilities 1 — — Sempra Mexico 57 227 185 Sempra LNG 92 (5) (435) Sempra Renewables — 4 71 All other (187) (202) (135) Total $ 249 $ 315 $ (49) SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Years ended December 31 or at December 31, 2020 2019 2018 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 824 $ 767 $ 669 SoCalGas 504 641 400 Sempra Texas Utilities 579 528 371 Sempra Mexico 259 253 237 Sempra LNG 320 (6) (617) Sempra Renewables — 59 328 Discontinued operations 1,840 328 156 All other (562) (515) (620) Total $ 3,764 $ 2,055 $ 924 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,942 $ 1,522 $ 1,542 SoCalGas 1,843 1,439 1,538 Sempra Mexico 611 624 368 Sempra LNG 268 112 31 Sempra Renewables — 2 51 All other 12 9 14 Total $ 4,676 $ 3,708 $ 3,544 ASSETS SDG&E $ 22,311 $ 20,560 $ 19,225 SoCalGas 18,460 17,077 15,389 Sempra Texas Utilities 12,542 11,619 9,652 Sempra Mexico 10,752 9,938 9,165 Sempra LNG 2,205 3,901 4,060 Sempra Renewables — — 2,549 Discontinued operations — 3,958 3,718 All other 1,209 749 1,070 Intersegment receivables (856) (2,137) (4,190) Total $ 66,623 $ 65,665 $ 60,638 GEOGRAPHIC INFORMATION Long-lived assets (3) : United States $ 46,902 $ 43,719 $ 40,611 Mexico 6,929 6,355 5,800 Total $ 53,831 $ 50,074 $ 46,411 Revenues (4) : United States $ 10,205 $ 9,574 $ 8,840 Mexico 1,165 1,255 1,262 Total $ 11,370 $ 10,829 $ 10,102 (1) Revenues for reportable segments include intersegment revenues of $5 million, $88 million, $91 million and $136 million for 2020; $5 million, $69 million, $120 million and $222 million for 2019; and $4 million, $64 million, $114 million and $215 million for 2018 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively. (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, 2020
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 2020: Revenues $ 3,029 $ 2,526 $ 2,644 $ 3,171 Expenses and other income $ 2,632 $ 2,063 $ 2,443 $ 2,743 Income from continuing operations, net of income tax $ 867 $ 528 $ 428 $ 432 Income (loss) from discontinued operations, net of income tax 80 1,777 (7) — Net income $ 947 $ 2,305 $ 421 $ 432 Earnings attributable to common shares $ 760 $ 2,239 $ 351 $ 414 Basic EPS (1) : Earnings from continuing operations $ 2.35 $ 1.58 $ 1.23 $ 1.43 Earnings (losses) from discontinued operations $ 0.25 $ 6.06 $ (0.02) $ — Earnings $ 2.60 $ 7.64 $ 1.21 $ 1.43 Weighted-average common shares outstanding 292.8 293.1 289.5 289.0 Diluted EPS (1) : Earnings from continuing operations (2) $ 2.30 $ 1.58 $ 1.23 $ 1.43 Earnings (losses) from discontinued operations $ 0.23 $ 6.03 $ (0.02) $ — Earnings (2) $ 2.53 $ 7.61 $ 1.21 $ 1.43 Weighted-average common shares outstanding 313.9 294.2 290.6 290.2 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 (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 March 31, 2020 and September 30, 2019, 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 dividends declared in those quarters. In April 2020, we completed the sale of our equity interests in our Peruvian businesses for cash proceeds of $3,549 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $2,271 million ($1,499 million after tax). In June 2020, we completed the sale of our equity interests in our Chilean businesses for cash proceeds of $2,216 million, net of transaction costs and as adjusted for post-closing adjustments, and recorded a pretax gain of $628 million ($248 million after tax). We discuss the sale of these discontinued operations and related gains in Note 5. In March, September and December of 2020, SoCalGas recorded charges of $100 million ($72 million after tax), $27 million ($22 million after tax) and $180 million ($139 million after tax), respectively, in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Energy Consolidated Statements of Operations related to settlement discussions in connection with civil litigation and regulatory matters. We discuss these matters in Note 16. 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. SDG&E (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2020: Operating revenues $ 1,269 $ 1,235 $ 1,472 $ 1,337 Operating expenses 880 887 1,157 1,016 Operating income $ 389 $ 348 $ 315 $ 321 Net income/Earnings attributable to common shares $ 262 $ 193 $ 178 $ 191 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 SOCALGAS (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2020: Operating revenues $ 1,395 $ 1,010 $ 842 $ 1,501 Operating expenses 1,031 773 826 1,333 Operating income $ 364 $ 237 $ 16 $ 168 Net income (loss) $ 303 $ 147 $ (24) $ 79 Dividends on preferred stock — (1) — — Earnings (losses) attributable to common shares $ 303 $ 146 $ (24) $ 79 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 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, 2020
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, 2020 2019 2018 Interest income $ 4 $ 3 $ 14 Interest expense (495) (521) (495) Operating expenses (86) (124) (82) Other (expense) income, net (38) 59 (16) Income tax benefit 176 163 154 Loss before equity in earnings of subsidiaries (439) (420) (425) Equity in earnings of subsidiaries, net of income taxes 4,371 2,617 1,474 Net income 3,932 2,197 1,049 Preferred dividends (168) (142) (125) Earnings $ 3,764 $ 2,055 $ 924 Basic EPS: Earnings $ 12.93 $ 7.40 $ 3.45 Weighted-average common shares outstanding 291,077 277,904 268,072 Diluted EPS: Earnings $ 12.88 $ 7.29 $ 3.42 Weighted-average common shares outstanding 292,252 282,033 269,852 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Years ended December 31, 2020, 2019 and 2018 Pretax Income tax benefit (expense) Net-of-tax 2020: Net income $ 3,756 $ 176 $ 3,932 Other comprehensive income (loss): Foreign currency translation adjustments 547 — 547 Financial instruments (146) 33 (113) Pension and other postretirement benefits 11 1 12 Total other comprehensive income 412 34 446 Comprehensive income $ 4,168 $ 210 $ 4,378 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 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 $ 366 $ 6 Due from affiliates 58 98 Income taxes receivable, net 42 — Other current assets 26 34 Total current assets 492 138 Investments in subsidiaries 33,898 32,604 Due from affiliates 1 3 Deferred income taxes 2,187 1,766 Other long-term assets 717 682 Total assets $ 37,295 $ 35,193 Liabilities and shareholders’ equity: Current portion of long-term debt $ 850 $ 1,399 Due to affiliates 224 369 Income taxes payable, net — 274 Other current liabilities 536 561 Total current liabilities 1,610 2,603 Long-term debt 7,317 8,856 Due to affiliates 4,375 3,138 Other long-term liabilities 620 667 Commitments and contingencies (Note 4) Shareholders’ equity 23,373 19,929 Total liabilities and shareholders’ equity $ 37,295 $ 35,193 See Notes to Condensed Financial Information of Parent. SEMPRA ENERGY CONDENSED STATEMENTS OF CASH FLOWS (Dollars in millions) Years ended December 31, 2020 2019 2018 Net cash (used in) provided by operating activities (978) $ 294 $ 213 Expenditures for property, plant and equipment (9) (8) (11) Expenditures for acquisition — — (329) Capital contributions to investees (364) (1,528) (9,457) Distribution from investments 3,616 — — Decrease (increase) in loans to affiliates, net 2 — (1) Other — 4 — Net cash provided by (used in) investing activities 3,245 (1,532) (9,798) Common stock dividends paid (1,174) (993) (877) Preferred dividends paid (157) (142) (89) Issuances of preferred stock, net 891 — 2,258 Issuances of common stock, net 11 1,830 2,272 Repurchases of common stock (566) (26) (21) Issuances of long-term debt 1,599 758 4,969 Payments on long-term debt (3,700) (1,500) (500) Increase in loans from affiliates, net 1,194 1,328 1,520 Equity transaction costs with third parties (4) — — Debt issuance costs (1) (25) (37) Net cash (used in) provided by financing activities (1,907) 1,230 9,495 Increase (decrease) in cash and cash equivalents 360 (8) (90) Cash and cash equivalents, January 1 6 14 104 Cash and cash equivalents, December 31 $ 366 $ 6 $ 14 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Preferred dividends declared but not paid $ 47 $ 36 $ 36 Common dividends issued in stock 22 55 54 Common dividends declared but not paid 301 283 245 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 (Expense) Income, Net, on the Condensed Statements of Operations includes: ▪ $41 million, $61 million and $(6) million of gains (losses) on dedicated assets in support of our executive retirement and deferred compensation plans in 2020, 2019 and 2018, respectively; ▪ $3 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 ▪ $3 million and $15 million of losses in 2020 and 2019, respectively, from foreign currency derivatives used to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sale of our operations in Peru and Chile. Sempra Energy received cash dividends from its consolidated subsidiaries totaling $300 million, $150 million and $300 million in 2020, 2019 and 2018, 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 2020-04, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting”: ASU 2020-04 provides optional expedients and exceptions for applying U.S. GAAP to contract modifications that replace LIBOR or another reference rate affected by reference rate reform and to hedging relationships that reference LIBOR or another reference rate affected or expected to be affected by reference rate reform. ASU 2020-04 was effective March 12, 2020 and can be applied through December 31, 2022, with certain exceptions for hedging relationships that continue to exist after this date, and may be applied from January 1, 2020. For contract modifications, the standard allows entities to account for modifications as an event that does not require reassessment or remeasurement (i.e., as a continuation of the existing contract). The standard also allows entities to amend their formal designation and documentation of hedging relationships affected or expected to be affected by reference rate reform, without having to de-designate the hedging relationship. Entities may elect the optional expedients and exceptions on an individual hedging relationship basis and independently from one another. We elected the optional expedients for contract modifications. We elected the cash flow hedging expedients to disregard the potential discontinuation of a reference rate when assessing whether a hedged forecasted interest payment is probable and to disregard certain mismatches between the designated hedging instrument and the hedged item when assessing the hedge effectiveness. We are applying these expedients prospectively from January 1, 2020. Application of these expedients preserves the presentation of derivatives consistent with the past presentation. ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial conversion features and cash conversion features. The standard also amends ASC 260, “Earnings Per Share,” as follows: ▪ requires an entity to apply the if-converted method when calculating diluted EPS for convertible instruments and no longer use the treasury stock method, which was previously allowed for certain convertible instruments; ▪ requires an entity to include the effect of potential share settlement in the diluted EPS calculation when an instrument may be settled in cash or shares, and no longer allows an entity to rebut the presumption of share settlement if it has a history or policy of cash settlement; ▪ requires an entity to include equity-classified convertible preferred stock that contains down-round features whereby, if the down-round feature is triggered, its effect is treated as a dividend and as a reduction of income available to common shareholders in basic EPS; ▪ clarifies that the average market price should be used to calculate the diluted EPS denominator when the exercise price or the number of shares that may be issued is variable, except for certain contingently issuable shares; and ▪ clarifies that the weighted-average share count from each quarter should be used when calculating the year-to-date weighted-average share count. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, including interim periods therein, with early adoption permitted for fiscal years beginning after December 15, 2020. An entity can use either a full or modified retrospective approach to adopt ASU 2020-06 and must disclose, in the period of adoption, EPS transition information about the effect of the change on affected per-share amounts. We plan to adopt the standard on January 1, 2022 and are currently evaluating 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, 2020 2019 2.4% Notes February 1, 2020 $ — $ 500 2.4% Notes March 15, 2020 — 500 2.85% Notes November 15, 2020 — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — 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) 758 758 8,258 10,358 Current portion of long-term debt (850) (1,399) Unamortized discount on long-term debt (32) (35) Unamortized debt issuance costs (59) (68) Total long-term debt $ 7,317 $ 8,856 (1) Callable long-term debt not subject to make-whole provisions. In October 2020, Sempra Energy redeemed $700 million of floating-rate notes, prior to a scheduled maturity in January 2021, utilizing a portion of the proceeds received from the sales of our South American businesses. Maturities of long-term debt at December 31, 2020 are $850 million in 2021, $500 million in 2022, $1.0 billion in 2023, $500 million in 2024, $350 million in 2025 and $5.1 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 $257 million. Sempra Energy expects payments for its operating lease to be $10 million in 2021, $11 million in 2022, $12 million in 2023, $12 million in 2024, $12 million in 2025 and $200 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, 2020
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 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. 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,” “us” 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 these Notes, 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 EventsWe evaluated events and transactions that occurred after December 31, 2020 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, which we discuss further in Note 5. We completed the sales in the second quarter of 2020. 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, 2020, 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 NDT 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 and the Support Agreement at Sempra LNG. 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, 2020 and 2019. 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 investment at December 31, 2019 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 – SDG&E.” ▪ 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 December 31, 2020, and 2019. ▪ As we discuss in Note 6, in July 2020, Sempra Energy entered into a Support Agreement for the benefit of CFIN. We measure the Support Agreement, which includes a guarantee obligation, a put option and a call option, net of related guarantee fees, at fair value on a recurring basis. We use a discounted cash flow model to value the Support Agreement, net of related guarantee fees. Because some of the inputs that are significant to the valuation are less observable, the Support Agreement is classified as Level 3, as we describe below in “Level 3 Information – Sempra LNG.”
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. Restricted cash includes 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 at Sempra Mexico.
Collection Allowances	CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable and amounts due from unconsolidated affiliates. We are also exposed to credit losses from off-balance sheet arrangements through our guarantees of Cameron LNG JV’s debt. We regularly monitor and evaluate credit losses and record allowances for expected credit losses, if necessary, for trade and other accounts receivable using a combination of factors, including past-due status based on contractual terms, trends in write-offs, the age of the receivable, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies. We write off financial assets measured at amortized cost in the period in which we determine they are not recoverable. We record recoveries of amounts previously written off when it is known that they will be recovered. In connection with the COVID-19 pandemic, the California Utilities have implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for residential and small business customers, waiving late payment fees for business customers, and offering flexible payment plans to customers experiencing difficulty paying their electric or gas bills. As we discuss in Note 4, the CPUC authorized each of the California Utilities to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with residential and small business customer protection measures implemented by the CPUC related to the COVID-19 pandemic. In June 2020, the CPUC issued a decision in a separate proceeding addressing service disconnections that, among other things, allows each of the California Utilities to establish a two-way balancing account to record the uncollectible expenses associated with residential customers’ inability to pay their electric or gas bills. This decision also directs the California Utilities to establish an AMP that provides successfully participating, income-qualified residential customers with relief from outstanding utility bill amounts. Refer to Note 4 for further discussion. The California Utilities have recorded increases in their allowances for expected credit losses as of December 31, 2020 primarily related to expected forgiveness of outstanding utility bill amounts, including increases due to the effect of the COVID-19 pandemic, for residential customers eligible under the AMP. Our businesses will continue to monitor macroeconomic factors and customer payment patterns when evaluating their allowances for credit losses in future reporting periods, which may increase significantly due to the effects of the COVID-19 pandemic or other factors. We provide below allowances and changes in allowances for credit losses for trade and other accounts receivable, excluding allowances related to amounts due from unconsolidated affiliates and off-balance sheet arrangements, which we discuss separately below the table. The California Utilities record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts.
Inventories	INVENTORIES The California Utilities value natural gas inventory using the last-in first-out method. As inventories are sold, differences between the last-in first-out 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. Investment tax credits 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. We accrue income tax to the extent we intend to repatriate cash to the U.S. from our continuing international operations. 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 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 Program 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 Program. 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)	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 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. 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.
Goodwill and Other Intangible Assets	GOODWILL AND OTHER INTANGIBLE ASSETS Goodwill 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, we record a goodwill impairment loss as the excess of a reporting unit’s carrying amount over its fair value, not to exceed the carrying amount of goodwill. Other Intangible Assets at December 31, 2020 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.
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. 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.
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, insurance, rent and litigation expense (except for litigation expense included in Aliso Canyon Litigation and Regulatory Matters).
Foreign Currency Translation	FOREIGN CURRENCY TRANSLATION AND TRANSACTIONS Our natural gas distribution utility in Mexico, Ecogas, and the majority of our former operations in South America (until our sale of these operations in the second quarter of 2020) 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 2016-13, “Measurement of Credit Losses on Financial Instruments”: ASU 2016-13, as amended by subsequently issued ASUs, changes how entities 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 receivables and 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. We adopted the standard on January 1, 2020 using a modified retrospective approach through a cumulative-effect adjustment to retained earnings. The adoption primarily impacted the expected credit losses associated with accounts receivable balances, amounts due from unconsolidated affiliates and off-balance sheet financial guarantees. There was an insignificant impact to SDG&E’s and SoCalGas’ balance sheets from adoption. The following table shows the initial (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. 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. We adopted ASU 2017-04 on January 1, 2020 and are applying the standard on a prospective basis to our goodwill impairment tests. ASU 2020-04, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting”: ASU 2020-04 provides optional expedients and exceptions for applying U.S. GAAP to contract modifications that replace LIBOR or another reference rate affected by reference rate reform and to hedging relationships that reference LIBOR or another reference rate affected or expected to be affected by reference rate reform. ASU 2020-04 was effective March 12, 2020 and can be applied through December 31, 2022, with certain exceptions for hedging relationships that continue to exist after this date, and may be applied from January 1, 2020. For contract modifications, the standard allows entities to account for modifications as an event that does not require reassessment or remeasurement (i.e., as a continuation of the existing contract). The standard also allows entities to amend their formal designation and documentation of hedging relationships affected or expected to be affected by reference rate reform, without having to de-designate the hedging relationship. Entities may elect the optional expedients and exceptions on an individual hedging relationship basis and independently from one another. We elected the optional expedients for contract modifications. We elected the cash flow hedging expedients to disregard the potential discontinuation of a reference rate when assessing whether a hedged forecasted interest payment is probable and to disregard certain mismatches between the designated hedging instrument and the hedged item when assessing the hedge effectiveness. We are applying these expedients prospectively from January 1, 2020. Application of these expedients preserves the presentation of derivatives consistent with the past presentation. ASU 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity’s Own Equity”: ASU 2020-06 simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts on an entity’s own equity. In addition to other changes, this standard amends ASC 470-20, “Debt with Conversion and Other Options,” by removing the accounting models for instruments with beneficial conversion features and cash conversion features. The standard also amends ASC 260, “Earnings Per Share,” as follows: ▪ requires an entity to apply the if-converted method when calculating diluted EPS for convertible instruments and no longer use the treasury stock method, which was previously allowed for certain convertible instruments; ▪ requires an entity to include the effect of potential share settlement in the diluted EPS calculation when an instrument may be settled in cash or shares, and no longer allows an entity to rebut the presumption of share settlement if it has a history or policy of cash settlement; ▪ requires an entity to include equity-classified convertible preferred stock that contains down-round features whereby, if the down-round feature is triggered, its effect is treated as a dividend and as a reduction of income available to common shareholders in basic EPS; ▪ clarifies that the average market price should be used to calculate the diluted EPS denominator when the exercise price or the number of shares that may be issued is variable, except for certain contingently issuable shares; and ▪ clarifies that the weighted-average share count from each quarter should be used when calculating the year-to-date weighted-average share count.
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 we 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, resulting in a significant portion of earnings being 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. In connection with the COVID-19 pandemic, the California Utilities and the CPUC have implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for residential and small business customers, waiving late payment fees for business customers, and offering flexible payment plans to customers experiencing difficulty paying their electric or gas bills. Additional measures could be mandated or voluntarily implemented in the future. Under the regulatory compact applicable to the California Utilities, including decoupling of rates, recovery of uncollectible expenses, and other recovery mechanisms potentially available, which we discuss in Note 4, the California Utilities have continued to recognize revenues under ASC 606, “Revenue from Contracts with Customers,” in the year ended December 31, 2020. 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 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, in February 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 Mexico and, previously, Sempra Renewables 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 and delivered. 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, Sempra Renewables completed the sale of its 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 has a contractual agreement to provide scheduling and marketing of renewable power for Sempra Mexico’s ESJ JV. 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, 2020, 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, 2020. 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 ratepayers. We discuss balancing accounts and their effects further in Note 4. Other Revenues 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 has an agreement to supply LNG to Sempra Mexico’s ECA Regas Facility. 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 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	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	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 Statements of Operations. Our foreign equity method investees are generally corporations whose operations are 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	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: ▪ 33% domestic equity ▪ 22% international equity ▪ 21% long credit ▪ 10% diversified real assets ▪ 7% return-seeking credit ▪ 5% ultra-long duration government securities ▪ 2% other diversifying 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 6.75% 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 4% and 12% 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. Investment 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 30% to return-seeking assets and 70% 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 help ensure that plan assets are best positioned to meet plan obligations.
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 four
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 could cause our asset values to fall or our liabilities to 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 and undesignated derivatives not subject to rate recovery). 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, in an effort 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. 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. 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 utilized foreign currency derivatives to hedge exposure to fluctuations in the Peruvian sol and Chilean peso related to the sales of our operations in Peru and Chile, respectively.
Earnings Per 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.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.
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 corresponding ROU asset, initially equal to the lease liability and adjusted for lease payments made at or before lease commencement, lease incentives, and any initial direct costs. 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 in amount 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 owns an 80.25% interest in Oncor, a regulated electric transmission and distribution utility serving customers in the north-central, eastern, western and panhandle regions of Texas; and our indirect, 50% interest in Sharyland Holdings, which owns Sharyland Utilities, a regulated electric transmission utility serving customers near the Texas-Mexico border. As we discuss in Note 5, we acquired our investment in Sharyland Holdings in May 2019. ▪ Sempra Mexico develops, owns and operates, or holds interests in, natural gas, electric, LNG, LPG, ethane and liquid fuels infrastructure, and has marketing operations for the purchase of LNG and the purchase and sale of natural gas in Mexico. ▪ Sempra LNG develops and builds natural gas liquefaction export facilities, 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 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 is presented as discontinued operations for all periods presented. The information in the tables below excludes amounts from discontinued operations unless otherwise noted. We completed the sales of our discontinued operations in the second quarter of 2020. 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.

SIGNIFICANT ACCOUNTING POLICI_3

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 Sempra Energy Consolidated: Cash and cash equivalents $ 960 $ 108 Restricted cash, current 22 31 Restricted cash, noncurrent 3 3 Cash, cash equivalents and restricted cash in discontinued operations — 75 Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows $ 985 $ 217
Schedule of Accounts Receivable, Allowance for Credit Loss	TRADE AND OTHER ACCOUNTS RECEIVABLE – ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated: Allowances for credit losses at January 1 $ 29 $ 21 $ 25 Incremental allowance upon adoption of ASU 2016-13 1 — — Provisions for expected credit losses 124 22 10 Write-offs (16) (14) (14) Allowances for credit losses at December 31 (1) $ 138 $ 29 $ 21 SDG&E: Allowances for credit losses at January 1 $ 14 $ 11 $ 9 Provisions for expected credit losses 65 10 9 Write-offs (10) (7) (7) Allowances for credit losses at December 31 (2) $ 69 $ 14 $ 11 SoCalGas: Allowances for credit losses at January 1 $ 15 $ 10 $ 16 Provisions for expected credit losses 59 12 1 Write-offs (6) (7) (7) Allowances for credit losses at December 31 (3) $ 68 $ 15 $ 10 (1) Balances at December 31, 2020 and 2019 include $111 million and $7 million, respectively, in Accounts Receivable – Trade, Net and $27 million and $22 million, respectively, in Accounts Receivable – Other, Net. (2) Balances at December 31, 2020 and 2019 include $55 million and $4 million, respectively, in Accounts Receivable – Trade, Net and $14 million and $10 million, respectively, in Accounts Receivable – Other, Net. (3)
Financing Receivable, Allowance for Credit Loss	We provide below the changes in allowances for credit losses for loans and other amounts due from unconsolidated affiliates. AMOUNTS DUE FROM UNCONSOLIDATED AFFILIATES – ALLOWANCES FOR CREDIT LOSSES (Dollars in millions) Sempra Energy Consolidated (1) Allowances for credit losses at January 1, 2020 $ — Allowance established upon adoption of ASU 2016-13 6 Reduction to expected credit losses (3) Allowances for credit losses at December 31, 2020 $ 3 (1) Balance at December 31, 2020 includes negligible amounts and $3 million in Due from Unconsolidated Affiliates – Current and Due from Unconsolidated Affiliates – Noncurrent, respectively.
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 2020 2019 2020 2019 2020 2019 2020 2019 Sempra Energy Consolidated $ 118 $ 110 $ 7 $ 9 $ 183 $ 158 $ 308 $ 277 SDG&E — 1 — — 104 93 104 94 SoCalGas 94 90 — — 59 46 153 136
Wildfire Fund	The following table summarizes the location of balances related to the Wildfire Fund on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations. WILDFIRE FUND (Dollars in millions) December 31, Location 2020 2019 Wildfire Fund asset: Current Other Current Assets (1) $ 29 $ 29 Noncurrent Wildfire Fund 363 392 Wildfire Fund obligation: Current Other Current Liabilities $ 13 $ 13 Noncurrent Deferred Credits and Other 75 86 Years ended December 31, 2020 2019 Amortization of Wildfire Fund asset Operation and Maintenance $ 29 $ 12 Accretion of Wildfire Fund obligation Operation and Maintenance 2 1 (1) Included in Prepaid Expenses for SDG&E. 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 CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on Weighted 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 Equity 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 Property, Plant and Equipment	PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY (Dollars in millions) December 31, Depreciation rates for years ended 2020 2019 2020 2019 2018 SDG&E: Natural gas operations $ 2,805 $ 2,534 2.51 % 2.47 % 2.44 % Electric distribution 8,592 7,985 3.90 3.94 3.91 Electric transmission (1) 7,156 6,577 3.10 2.79 2.76 Electric generation 2,440 2,415 4.56 4.50 4.12 Other electric 1,743 1,492 6.92 6.61 6.43 Construction work in progress (1) 1,700 1,501 NA NA NA Total SDG&E 24,436 22,504 SoCalGas: Natural gas operations 19,961 18,370 3.63 3.60 3.60 Other non-utility 45 34 3.80 5.08 5.39 Construction work in progress 1,174 958 NA NA NA Total SoCalGas 21,180 19,362 Other operating units and parent (2) : Estimated useful lives Weighted-average useful life Land and land rights 283 278 16 to 50 years (3) 31 Machinery and equipment: Generating plants 1,288 1,154 11 to 25 years 22 LNG terminals 1,138 1,134 43 years 43 Pipelines and storage 3,482 3,596 5 to 50 years 44 Other 359 180 1 to 50 years 14 Construction work in progress 1,514 895 NA NA Other 248 226 4 to 50 years 23 8,312 7,463 Total Sempra Energy Consolidated $ 53,928 $ 49,329 (1) At December 31, 2020, includes $505 million in electric transmission assets and $9 million in construction work in progress related to SDG&E’s 88% 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 $191 million and $178 million at December 31, 2020 and 2019, respectively, of utility plant, primarily pipelines and other distribution assets at Ecogas. (3) Estimated useful lives are for land rights. DEPRECIATION EXPENSE (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated $ 1,646 $ 1,551 $ 1,470 SDG&E 797 757 686 SoCalGas 649 598 553 ACCUMULATED DEPRECIATION AND AMORTIZATION (Dollars in millions) December 31, 2020 2019 SDG&E: Accumulated depreciation: Natural gas operations $ 870 $ 832 Electric transmission, distribution and generation (1) 5,145 4,705 Total SDG&E 6,015 5,537 SoCalGas: Accumulated depreciation: Natural gas operations 6,422 6,023 Other non-utility 15 15 Total SoCalGas 6,437 6,038 Other operating units and parent and other: Accumulated depreciation – other (2) 1,473 1,302 Total Sempra Energy Consolidated $ 13,925 $ 12,877 (1) Includes $277 million at December 31, 2020 related to SDG&E’s 88% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities.
Schedule Of Capitalized Financing Costs	The table below summarizes capitalized interest and AFUDC. CAPITALIZED FINANCING COSTS (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated $ 202 $ 183 $ 193 SDG&E 104 75 82 SoCalGas 55 47 48
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 December 31, 2020 2019 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 (32) (24) O&M agreement (9) (6) Other (7) (7) (48) (37) $ 202 $ 213
Schedule Of Asset Retirement Obligations	The changes in AROs are as follows: CHANGES IN ASSET RETIREMENT OBLIGATIONS (Dollars in millions) Sempra Energy SDG&E SoCalGas 2020 2019 2020 2019 2020 2019 Balance as of January 1 (1) $ 3,083 $ 2,972 $ 866 $ 874 $ 2,177 $ 2,063 Accretion expense 127 123 39 39 86 81 Liabilities incurred 2 2 — — — — Deconsolidation — (2) — (2) — — Payments (63) (46) (60) (44) (2) (2) Revisions 140 34 31 (1) 107 35 Balance at December 31 (1) $ 3,289 $ 3,083 $ 876 $ 866 $ 2,368 $ 2,177 (1) Current portion of the ARO for Sempra Energy Consolidated is included in Other Current Liabilities on the 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 Financial Pension Total Sempra Energy Consolidated (2) : Balance as of December 31, 2017 $ (420) $ (122) $ (84) $ (626) Adoption of ASU 2017-12 — (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) Adoption of ASU 2018-02 — (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) OCI before reclassifications (3) (102) (163) (26) (291) Amounts reclassified from AOCI (3) 645 47 38 730 Net OCI (4) 543 (116) 12 439 Balance as of December 31, 2020 $ (64) $ (331) $ (105) $ (500) SDG&E: 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) Adoption of ASU 2018-02 (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) OCI before reclassifications (3) (4) (4) Amounts reclassified from AOCI (3) 10 10 Net OCI 6 6 Balance as of December 31, 2020 $ (10) $ (10) SoCalGas: 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) Adoption of ASU 2018-02 (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) OCI before reclassifications (3) — (10) (10) Amounts reclassified from AOCI — 2 2 Net OCI — (8) (8) Balance as of December 31, 2020 $ (13) $ (18) $ (31) (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 $6 million in transfers of liabilities from SDG&E to SoCalGas and $3 million in transfers of liabilities from SDG&E to Sempra Energy in 2020 and $4 million in transfers of liabilities from SoCalGas to Sempra Energy in 2019 related to the nonqualified pension plans. (4) Total AOCI includes $4 million of foreign currency translation adjustments and $3 million of financial instruments associated with purchases of NCI, which we discuss below in “Other Noncontrolling Interests – Sempra Mexico,” and which does not impact the Consolidated Statement of Comprehensive Income (Loss).
Schedule Of Reclassifications Out Of Accumulated Other Comprehensive Income	RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) (Dollars in millions) Details about accumulated Amounts reclassified from accumulated Affected line item on Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated: Foreign currency translation adjustments $ 645 $ — $ — Income from Discontinued Operations, Net of Income Tax Financial instruments: Interest rate instruments $ — $ 10 $ 9 (Loss) Gain on Sale of Assets Interest rate instruments (1) 10 3 1 Interest Expense Interest rate instruments 46 3 9 Equity Earnings Foreign exchange instruments (1) 2 (1) Revenues: Energy-Related Businesses Interest rate and foreign exchange instruments 1 — (1) Interest Expense 11 (9) (2) Other (Expense) Income, Net Foreign exchange instruments — 2 (2) Equity Earnings Total before income tax 67 11 13 (19) (2) (4) Income Tax (Expense) Benefit Net of income tax 48 9 9 (1) (1) (6) Earnings Attributable to Noncontrolling Interests $ 47 $ 8 $ 3 Pension and other postretirement benefits (2) : Amortization of actuarial loss $ 8 $ 12 $ 11 Other (Expense) Income, Net Amortization of actuarial loss 6 1 1 Income from Discontinued Operations, Net of Income Tax Amortization of prior service cost 4 3 2 Other (Expense) Income, Net Settlement charges 22 28 12 Other (Expense) Income, Net Total before income tax 40 44 26 (2) — — Income from Discontinued Operations, Net of Income Tax (9) (12) (8) Income Tax (Expense) Benefit Net of income tax $ 29 $ 32 $ 18 Total reclassifications for the period, net of tax $ 721 $ 40 $ 21 SDG&E: Financial instruments: Interest rate instruments (1) $ — $ 3 $ 7 Interest Expense — (3) (7) 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 1 — Other Income, Net Settlement charges — — 4 Other Income, Net Total before income tax 2 1 5 (1) — (1) Income Tax Expense Net of income tax $ 1 $ 1 $ 4 Total reclassifications for the period, net of tax $ 1 $ 1 $ 4 SoCalGas: Financial instruments: Interest rate instruments $ — $ 1 $ 1 Interest Expense Pension and other postretirement benefits (2) : Amortization of actuarial loss $ 1 $ 1 $ — Other (Expense) Income, Net Amortization of prior service cost 1 — 1 Other (Expense) Income, Net Total before income tax 2 1 1 — (1) — Income Tax Expense Net of income tax $ 2 $ — $ 1 Total reclassifications for the period, net of tax $ 2 $ 1 $ 2 (1) Amounts in 2019 and 2018 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	OTHER NONCONTROLLING INTERESTS (Dollars in millions) Percent ownership held by noncontrolling interests Equity (deficit) held by December 31, December 31, 2020 2019 2020 2019 Sempra Mexico: IEnova 29.8 % 33.4 % $ 1,487 $ 1,608 IEnova subsidiaries (1) 17.5 10.0 - 46.3 7 15 Sempra LNG: Liberty Gas Storage, LLC — 24.6 — (13) ECA LNG Phase 1 29.0 16.7 46 12 Parent and other: PXiSE Energy Solutions, LLC 20.0 20.0 1 1 Discontinued Operations: Chilquinta Energía subsidiaries (1) — 19.7 - 43.4 — 23 Luz del Sur — 16.4 — 205 Tecsur — 9.8 — 5 Total Sempra Energy $ 1,541 $ 1,856 (1) IEnova and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.
Schedule of Related Party Transactions	TRANSACTIONS WITH AFFILIATES 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, 2020 2019 Sempra Energy Consolidated: Total due from various unconsolidated affiliates – current $ 20 $ 32 Sempra Mexico (1) : ESJ – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020 (2) $ 85 $ — IMG JV – Note due March 15, 2022, net of allowance for credit losses of $3 at December 31, 2020 (3) 695 742 Total due from unconsolidated affiliates – noncurrent $ 780 $ 742 Sempra Mexico – TAG Pipelines Norte, S. de R.L. de C.V. – Note due December 20, 2021 (1)(4) $ (41) $ — Various affiliates (4) (5) Total due to unconsolidated affiliates – current $ (45) $ (5) Sempra Mexico (1) : TAG Pipelines Norte, S. de R.L. de C.V. Note due December 20, 2021 (4) $ — $ (39) 5.5% Note due January 9, 2024 (5) (68) — TAG JV – 5.74% Note due December 17, 2029 (5) (166) (156) Total due to unconsolidated affiliates – noncurrent $ (234) $ (195) SDG&E: Sempra Energy $ (38) $ (37) SoCalGas (21) (10) Various affiliates (5) (6) Total due to unconsolidated affiliates – current $ (64) $ (53) Income taxes due from Sempra Energy (6) $ — $ 130 SoCalGas: SDG&E $ 21 $ 10 Various affiliates 1 1 Total due from unconsolidated affiliates – current $ 22 $ 11 Sempra Energy $ (31) $ (45) Various affiliates — (2) Total due to unconsolidated affiliates – current $ (31) $ (47) Income taxes due (to) from Sempra Energy (6) $ (37) $ 152 (1) Amounts include principal balances plus accumulated interest outstanding. (2) U.S. dollar-denominated loan at a variable interest rate based on 1-month LIBOR plus 196 bps (2.11% at December 31, 2020). At December 31, 2020, $1 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. (3) Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $712 million U.S. dollar-equivalent, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (6.66% at December 31, 2020), to finance construction of the natural gas marine pipeline. At December 31, 2020, $2 million of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. (4) U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.16% at December 31, 2020). (5) U.S. dollar-denominated loan at a fixed interest rate. (6) SDG&E and SoCalGas are included in the consolidated income tax return of Sempra Energy and their respective income tax expense is computed as an amount equal to that which would result from each company having always filed a separate return. The following table summarizes income statement information from unconsolidated affiliates. INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated Revenue $ 37 $ 52 $ 64 Cost of Sales 45 50 46 Interest Income 56 74 62 Interest Expense 14 2 2 SDG&E: Revenue $ 6 $ 6 $ 5 Cost of Sales 79 74 73 SoCalGas: Revenue $ 88 $ 69 $ 64 Cost of Sales — 8 —
Schedule Of Other Income (Expense)	Other (Expense) Income, Net on the Consolidated Statements of Operations consists of the following: OTHER (EXPENSE) INCOME, NET (Dollars in millions) Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated: Allowance for equity funds used during construction $ 128 $ 94 $ 98 Investment gains (losses) (1) 41 61 (6) (Losses) gains on interest rate and foreign exchange instruments, net (67) 34 7 Foreign currency transaction (losses) gains, net (2) (25) 21 (6) Non-service component of net periodic benefit cost (102) (132) (35) Fine related to Energy Efficiency Program Inquiry (6) — — Penalties related to billing practices OII — (8) — Interest on regulatory balancing accounts, net 14 14 2 Sundry, net (31) (7) (2) Total $ (48) $ 77 $ 58 SDG&E: Allowance for equity funds used during construction $ 79 $ 56 $ 61 Non-service component of net periodic benefit cost (20) (20) (6) Fine related to Energy Efficiency Program Inquiry (6) — — Interest on regulatory balancing accounts, net 9 13 4 Sundry, net (10) (10) (3) Total $ 52 $ 39 $ 56 SoCalGas: Allowance for equity funds used during construction $ 41 $ 34 $ 36 Non-service component of net periodic benefit cost (54) (72) (10) Penalties related to billing practices OII — (8) — Interest on regulatory balancing accounts, net 5 1 (2) Sundry, net (20) (10) (9) Total $ (28) $ (55) $ 15 (1) Represents investment gains (losses) on dedicated assets in support of our executive retirement and deferred compensation plans. These amounts are offset by corresponding changes in compensation expense related to the plans, recorded in O&M on the Consolidated Statements of Operations. (2) Includes losses of $42 million in 2020, gains of $30 million in 2019 and losses of $3 million in 2018 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, 2020
Accounting Changes and Error Corrections [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The following table shows the initial (decreases) increases on Sempra Energy’s balance sheet at January 1, 2020 from adoption of ASU 2016-13. 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)

REVENUES (Tables)

REVENUES (Tables)	12 Months Ended
	Dec. 31, 2020
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) SDG&E SoCalGas Sempra Mexico Sempra LNG Sempra Renewables Consolidating adjustments and Parent and other Sempra Energy Consolidated Year ended December 31, 2020 By major service line: Utilities $ 4,920 $ 4,571 $ 58 $ — $ — $ (94) $ 9,455 Energy-related businesses — — 834 92 — (71) 855 Revenues from contracts with customers $ 4,920 $ 4,571 $ 892 $ 92 $ — $ (165) $ 10,310 By market: Gas $ 692 $ 4,571 $ 603 $ 86 $ — $ (156) $ 5,796 Electric 4,228 — 289 6 — (9) 4,514 Revenues from contracts with customers $ 4,920 $ 4,571 $ 892 $ 92 $ — $ (165) $ 10,310 Revenues from contracts with customers $ 4,920 $ 4,571 $ 892 $ 92 $ — $ (165) $ 10,310 Utilities regulatory revenues 393 177 — — — — 570 Other revenues — — 364 282 — (156) 490 Total revenues $ 5,313 $ 4,748 $ 1,256 $ 374 $ — $ (321) $ 11,370 Year ended December 31, 2019 By major service line: Utilities $ 4,819 $ 4,367 $ 73 $ — $ — $ (75) $ 9,184 Energy-related businesses — — 919 176 5 (143) 957 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 176 $ 5 $ (218) $ 10,141 By market: Gas $ 587 $ 4,367 $ 680 $ 170 $ — $ (208) $ 5,596 Electric 4,232 — 312 6 5 (10) 4,545 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 176 $ 5 $ (218) $ 10,141 Revenues from contracts with customers $ 4,819 $ 4,367 $ 992 $ 176 $ 5 $ (218) $ 10,141 Utilities regulatory revenues 106 158 — — — — 264 Other revenues — — 383 234 5 (198) 424 Total revenues $ 4,925 $ 4,525 $ 1,375 $ 410 $ 10 $ (416) $ 10,829 Year ended December 31, 2018 By major service line: Utilities $ 4,788 $ 3,577 $ 78 $ — $ — $ (69) $ 8,374 Energy-related businesses — — 941 232 46 (146) 1,073 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 232 $ 46 $ (215) $ 9,447 By market: Gas $ 491 $ 3,577 $ 711 $ 224 $ — $ (203) $ 4,800 Electric 4,297 — 308 8 46 (12) 4,647 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 232 $ 46 $ (215) $ 9,447 Revenues from contracts with customers $ 4,788 $ 3,577 $ 1,019 $ 232 $ 46 $ (215) $ 9,447 Utilities regulatory revenues (220) 385 — — — — 165 Other revenues — — 357 240 78 (185) 490 Total revenues $ 4,568 $ 3,962 $ 1,376 $ 472 $ 124 $ (400) $ 10,102
Schedule of Timing of Remaining Performance Obligations	For contracts greater than one year, at December 31, 2020, 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, 2020. REMAINING PERFORMANCE OBLIGATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E 2021 $ 387 $ 4 2022 406 4 2023 407 4 2024 348 4 2025 351 4 Thereafter 4,361 67 Total revenues to be recognized $ 6,260 $ 87
Schedule of Contract Liabilities	Activities within Sempra Energy’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SDG&E in 2018 or at SoCalGas in 2020, 2019 or 2018. CONTRACT LIABILITIES (Dollars in millions) 2020 2019 2018 Sempra Energy Consolidated: Contract liabilities at January 1 $ (163) $ (70) $ — Adoption of ASC 606 — — (61) Revenue from performance obligations satisfied during reporting period 4 2 7 Payments received in advance (48) (95) (16) Contract liabilities at December 31 (1) $ (207) $ (163) $ (70) SDG&E: Contract liabilities at January 1 $ (91) $ — Revenue from performance obligations satisfied during reporting period 4 1 Payments received in advance — (92) Contract liabilities at December 31 (2) $ (87) $ (91) (1) Balances at December 31, 2020 and 2019 include $52 million and $4 million, respectively, in Other Current Liabilities and $155 million and $159 million, respectively, in Deferred Credits and Other. (2)
Schedule of Contract Accounts Receivable	The table below shows receivable balances associated with revenues from contracts with customers on the Consolidated Balance Sheets. RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Dollars in millions) December 31, 2020 2019 Sempra Energy Consolidated: Accounts receivable – trade, net $ 1,447 $ 1,163 Accounts receivable – other, net 12 16 Due from unconsolidated affiliates – current (1) 3 5 Total $ 1,462 $ 1,184 SDG&E: Accounts receivable – trade, net $ 573 $ 398 Accounts receivable – other, net 8 5 Due from unconsolidated affiliates – current (1) 2 2 Total $ 583 $ 405 SoCalGas: Accounts receivable – trade, net $ 786 $ 710 Accounts receivable – other, net 4 11 Total $ 790 $ 721 (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, 2020
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, 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 22 (108) Pension and other postretirement benefit plan obligations 50 103 Removal obligations (2,121) (2,056) Environmental costs 56 45 Sunrise Powerlink fire mitigation 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 72 102 Gas transportation 35 22 Safety and reliability 67 77 Public purpose programs (158) (124) 2019 GRC retroactive impacts 56 111 Other balancing accounts 233 106 Other regulatory assets (liabilities), net (2) 72 (153) Total SDG&E (1,548) (1,746) SoCalGas: Deferred income taxes refundable in rates (82) (203) Pension and other postretirement benefit plan obligations 417 400 Employee benefit costs 37 44 Removal obligations (685) (728) Environmental costs 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (56) (118) Safety and reliability 335 295 Public purpose programs (253) (273) 2019 GRC retroactive impacts 202 400 Other balancing accounts (58) (7) Other regulatory assets (liabilities), net (2) 75 (101) Total SoCalGas (32) (251) Sempra Mexico: Deferred income taxes recoverable in rates 80 83 Other regulatory assets — 6 Total Sempra Energy Consolidated $ (1,500) $ (1,908) (1) At December 31, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $139 million and $108 million, respectively, and for SoCalGas was $218 million and $500 million, respectively.
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, 2020 2019 SDG&E: Fixed-price contracts and other derivatives $ (53) $ 8 Deferred income taxes recoverable (refundable) in rates 22 (108) Pension and other postretirement benefit plan obligations 50 103 Removal obligations (2,121) (2,056) Environmental costs 56 45 Sunrise Powerlink fire mitigation 121 121 Regulatory balancing accounts (1)(2) Commodity – electric 72 102 Gas transportation 35 22 Safety and reliability 67 77 Public purpose programs (158) (124) 2019 GRC retroactive impacts 56 111 Other balancing accounts 233 106 Other regulatory assets (liabilities), net (2) 72 (153) Total SDG&E (1,548) (1,746) SoCalGas: Deferred income taxes refundable in rates (82) (203) Pension and other postretirement benefit plan obligations 417 400 Employee benefit costs 37 44 Removal obligations (685) (728) Environmental costs 36 40 Regulatory balancing accounts (1)(2) Commodity – gas, including transportation (56) (118) Safety and reliability 335 295 Public purpose programs (253) (273) 2019 GRC retroactive impacts 202 400 Other balancing accounts (58) (7) Other regulatory assets (liabilities), net (2) 75 (101) Total SoCalGas (32) (251) Sempra Mexico: Deferred income taxes recoverable in rates 80 83 Other regulatory assets — 6 Total Sempra Energy Consolidated $ (1,500) $ (1,908) (1) At December 31, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $139 million and $108 million, respectively, and for SoCalGas was $218 million and $500 million, respectively.
Proposed Revenue Requirement	The following table summarizes the location of balances related to the Wildfire Fund on Sempra Energy’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations. WILDFIRE FUND (Dollars in millions) December 31, Location 2020 2019 Wildfire Fund asset: Current Other Current Assets (1) $ 29 $ 29 Noncurrent Wildfire Fund 363 392 Wildfire Fund obligation: Current Other Current Liabilities $ 13 $ 13 Noncurrent Deferred Credits and Other 75 86 Years ended December 31, 2020 2019 Amortization of Wildfire Fund asset Operation and Maintenance $ 29 $ 12 Accretion of Wildfire Fund obligation Operation and Maintenance 2 1 (1) Included in Prepaid Expenses for SDG&E. 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 CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE SDG&E SoCalGas Authorized weighting Return on Weighted 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 Equity 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 %

ACQUISTIONS, DIVESTITURES AND_2

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	12 Months Ended
	Dec. 31, 2020
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) As adjusted for post-closing items.
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 Summarized results from discontinued operations were as follows: DISCONTINUED OPERATIONS (Dollars in millions) Years ended December 31, 2020 (1) 2019 2018 Revenues $ 570 $ 1,614 $ 1,585 Cost of sales (364) (1,012) (1,041) Gain on sale of discontinued operations 2,899 — — Operating expenses (66) (159) (206) Interest and other (3) (11) (6) Income before income taxes and equity earnings 3,036 432 332 Income tax expense (1,186) (72) (145) Equity earnings — 3 1 Income from discontinued operations, net of income tax 1,850 363 188 Earnings attributable to noncontrolling interests (10) (35) (32) Earnings from discontinued operations attributable to common shares $ 1,840 $ 328 $ 156 (1) Results include activity until deconsolidation of our Peruvian businesses on April 24, 2020 and Chilean businesses on June 24, 2020 and post-closing adjustments related to the sales of these businesses. 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 Cash and cash equivalents $ 74 Restricted cash (1) 1 Accounts receivable, net 303 Due from unconsolidated affiliates 2 Inventories 36 Other current assets 29 Current assets $ 445 Due from unconsolidated affiliates $ 54 Goodwill and other intangible assets 801 Property, plant and equipment, net 2,618 Other noncurrent assets 40 Noncurrent assets $ 3,513 Short-term debt $ 52 Accounts payable 201 Current portion of long-term debt and finance leases 85 Other current liabilities 106 Current liabilities $ 444 Long-term debt and finance leases $ 702 Deferred income taxes 284 Other noncurrent liabilities 66 Noncurrent liabilities $ 1,052 (1) Primarily represents funds held in accordance with Peruvian tax law.

INVESTMENTS IN UNCONSOLIDATED_2

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)	12 Months Ended
	Dec. 31, 2020
Investments [Abstract]
Equity Method 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, 2020 2019 2020 2019 Sempra Texas Utilities: Oncor Holdings (1) 100 % 100 % $ 12,440 $ 11,519 Sempra Texas Utilities: Sharyland Holdings (2) 50 50 $ 102 $ 100 Sempra Mexico: ESJ (3) 50 50 34 39 IMG JV (4) 40 40 440 337 TAG JV (5) 50 50 378 365 Sempra LNG: Cameron LNG JV (6) 50.2 50.2 433 1,256 Total other equity method investments 1,387 2,097 Other 1 6 Total other investments $ 1,388 $ 2,103 (1) The carrying value of our equity method investment is $2,833 million and $2,823 million higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019, respectively, due to $2,868 million of equity method goodwill and $69 million in basis differences in AOCI, offset by $104 million at December 31, 2020 and $114 million at December 31, 2019 due to a tax sharing liability to TTI under a 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 is $259 million and $263 million higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019, 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, 2020 2019 2018 EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX (1) : Sempra Texas Utilities: Sharyland Holdings $ 3 $ 2 $ — Sempra LNG: Cameron LNG JV 391 24 — Sempra Renewables: Wind: Auwahi Wind — — 3 Broken Bow 2 Wind — — (2) Cedar Creek 2 Wind — — (1) Flat Ridge 2 Wind (2) — (3) (178) Fowler Ridge 2 Wind — 5 3 Mehoopany Wind (2) — 1 (30) Solar: California solar partnership — — 8 Copper Mountain Solar 2 — — 5 Copper Mountain Solar 3 — — 8 Mesquite Solar 1 — — 18 Other — 2 (3) Parent and other: RBS Sempra Commodities (2) (100) — (67) Other — (1) — 294 30 (236) EARNINGS RECORDED NET OF INCOME TAX: Sempra Texas Utilities: Oncor Holdings 577 526 371 Sempra Mexico: ESJ 5 2 2 IMG JV 103 9 29 TAG JV 36 13 9 721 550 411 Total $ 1,015 $ 580 $ 175 (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, 2020 2019 2018 Sempra Texas Utilities $ 286 $ 246 $ 149 Sempra Mexico 8 2 — Sempra LNG 1,168 — — Sempra Renewables — 1 63 Parent and other — 7 — Total $ 1,462 $ 256 $ 212
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, March 9 - December 31, 2020 2019 2018 Operating revenues $ 4,511 $ 4,347 $ 3,347 Operating expense (3,224) (3,135) (2,434) Income from operations 1,287 1,212 913 Interest expense (405) (375) (285) Income tax expense (146) (131) (119) Net income 703 643 455 Noncontrolling interest held by TTI (141) (129) (94) Earnings attributable to Sempra Energy 562 514 360 At December 31, 2020 2019 Current assets $ 1,045 $ 913 Noncurrent assets 28,022 26,012 Current liabilities 1,120 1,626 Noncurrent liabilities 15,611 14,125 Noncontrolling interest held by TTI 2,737 2,473 SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS (Dollars in millions) Years ended December 31, 2020 2019 (1) 2018 (2) Gross revenues $ 2,341 $ 798 $ 706 Operating expense (706) (372) (609) Income from operations 1,635 426 97 Interest expense (514) (401) (322) Net income (loss)/Earnings (losses) (3) 1,132 85 (36) At December 31, 2020 2019 (1) Current assets $ 1,035 $ 1,124 Noncurrent assets 15,304 15,039 Current liabilities 1,342 1,232 Noncurrent liabilities 12,863 11,438 (1) On April 22, 2019, Sempra Renewables sold its remaining wind assets and investments. 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. As of December 13, 2018, the solar equity method investments and Broken Bow 2 are no longer equity method investments. (3) 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, 2020
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	PRIMARY U.S. COMMITTED LINES OF CREDIT (Dollars in millions) At December 31, 2020 Total facility Commercial paper outstanding (1) Available unused credit Sempra Energy (2) $ 1,250 $ — 1,250 Sempra Global 3,185 — 3,185 SDG&E (3) 1,500 — 1,500 SoCalGas (3)(4) 750 (113) 637 Total $ 6,685 $ (113) $ 6,572 (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, 2020. (3) 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, 2020. (4) Commercial paper outstanding is before reductions of a negligible amount of unamortized discount. FOREIGN COMMITTED LINES OF CREDIT (U.S. dollar equivalent in millions) December 31, 2020 Expiration date of facility Total facility Amounts outstanding Available unused credit February 2024 (1) $ 1,500 $ (392) $ 1,108 September 2021 (2) 280 (280) — Total $ 1,780 $ (672) $ 1,108 (1) Five-year revolving credit facility with a syndicate of 10 lenders. Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 80 bps. (2) Two-year revolving credit facility with The Bank of Nova Scotia. Borrowings may be made for up to two years from September 23, 2019 in U.S. dollars. Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps. The weighted-average interest rates on the total short-term debt at December 31, 2020 and 2019 were as follows: WEIGHTED-AVERAGE INTEREST RATES December 31, 2020 2019 Sempra Energy Consolidated 0.83 % 2.31 % SDG&E — 1.97 SoCalGas 0.14 1.86
Schedule Of 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, 2020 2019 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ 350 $ 350 1.914% payable 2015 through February 2022 53 89 3.6% September 1, 2023 450 450 2.5% May 15, 2026 500 500 6% June 1, 2026 250 250 1.7% October 1, 2030 800 — 5.875% January and February 2034 (1) — 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039 (1) — 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 400 400 3.32% April 15, 2050 400 — 6,053 5,140 Other long-term debt (uncollateralized): Variable rate (0.95% at December 31, 2020) 364-day term loan March 18, 2021 (1) 200 — Finance lease obligations: Purchased-power contracts 1,237 1,255 Other 39 15 1,476 1,270 7,529 6,410 Current portion of long-term debt (611) (56) Unamortized discount on long-term debt (13) (12) Unamortized debt issuance costs (39) (36) Total SDG&E 6,866 6,306 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 2.55% February 1, 2030 650 — 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 350 350 4,450 3,800 Other long-term debt (uncollateralized): Notes at variable rates (0.57% at December 31, 2020) September 14, 2023 (1) 300 — 1.875% Notes May 14, 2026 (1) 4 4 5.67% Notes January 18, 2028 5 5 Finance lease obligations 54 19 363 28 4,813 3,828 Current portion of long-term debt (10) (6) Unamortized discount on long-term debt (8) (7) Unamortized debt issuance costs (32) (27) Total SoCalGas 4,763 3,788 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2020 2019 Sempra Energy: Other long-term debt (uncollateralized): 2.4% Notes February 1, 2020 — 500 2.4% Notes March 15, 2020 — 500 2.85% Notes November 15, 2020 — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — 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) 758 758 Sempra Mexico Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 197 207 Notes at variable rates (4.88% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets 196 237 3.75% Notes January 14, 2028 300 300 Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets 398 423 4.875% Notes January 14, 2048 540 540 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) — 11 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 200 4.75% notes January 15, 2051 800 — Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034 (1) 100 — 2.90% loan November 15, 2034 (1) 241 — Sempra LNG Other long-term debt (uncollateralized): Notes at 2.87% to 3.51% October 1, 2026 (1) — 22 Loan at variable rates (2.82% at December 31, 2020) December 9, 2025 (1) 17 — 11,247 12,298 Current portion of long-term debt (919) (1,464) Unamortized discount on long-term debt (55) (35) Unamortized debt issuance costs (121) (108) Total other Sempra Energy 10,152 10,691 Total Sempra Energy Consolidated $ 21,781 $ 20,785 (1) Callable long-term debt not subject to make-whole provisions. The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2020 2019 2.4% Notes February 1, 2020 $ — $ 500 2.4% Notes March 15, 2020 — 500 2.85% Notes November 15, 2020 — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — 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) 758 758 8,258 10,358 Current portion of long-term debt (850) (1,399) Unamortized discount on long-term debt (32) (35) Unamortized debt issuance costs (59) (68) Total long-term debt $ 7,317 $ 8,856
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 2021 $ 585 $ — $ 919 $ 1,504 2022 18 — 583 601 2023 450 300 1,281 2,031 2024 — 500 564 1,064 2025 — 350 461 811 Thereafter 5,200 3,609 7,439 16,248 Total $ 6,253 $ 4,759 $ 11,247 $ 22,259
Schedule Of Callable Long Term Debt	At the option of Sempra Energy, SDG&E and SoCalGas, certain debt at December 31, 2020 is callable subject to premiums: CALLABLE LONG-TERM DEBT (Dollars in millions) SDG&E SoCalGas Other Total Not subject to make-whole provisions $ 200 $ 304 $ 1,299 $ 1,803 Subject to make-whole provisions 6,053 4,450 8,503 19,006

INCOME TAXES (Tables)

INCOME TAXES (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 Sempra Energy Consolidated: Income tax expense (benefit) from continuing operations $ 249 $ 315 $ (49) Income from continuing operations before income taxes and equity earnings $ 1,489 $ 1,734 $ 714 Equity earnings (losses), before income tax (1) 294 30 (236) Pretax income $ 1,783 $ 1,764 $ 478 Effective income tax rate 14 % 18 % (10) % SDG&E: Income tax expense $ 190 $ 171 $ 173 Income before income taxes $ 1,014 $ 945 $ 849 Effective income tax rate 19 % 18 % 20 % SoCalGas: Income tax expense $ 96 $ 120 $ 92 Income before income taxes $ 601 $ 762 $ 493 Effective income tax rate 16 % 16 % 19 % (1) We discuss how we recognize equity earnings in Note 6. RECONCILIATION OF FEDERAL INCOME TAX RATES TO EFFECTIVE INCOME TAX RATES Years ended December 31, 2020 2019 2018 Sempra Energy Consolidated: U.S. federal statutory income tax rate 21 % 21 % 21 % Utility depreciation 3 3 12 Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate (1) 2 3 10 State income taxes, net of federal income tax benefit 1 2 (8) Impairment losses 1 — (32) Effects of the TCJA — — 9 Unrecognized income tax benefits — — 4 Noncontrolling interests in tax equity arrangements — — 3 Resolution of prior years’ income tax items — — (1) Excess deferred income taxes outside of ratemaking — (4) — Compensation-related items (1) — 3 Valuation allowances (1) — — Allowance for equity funds used during construction (1) (1) (4) Amortization of excess deferred income taxes (1) (1) (4) Tax credits (1) (2) (10) Foreign exchange and inflation effects (2) (3) 4 6 Utility self-developed software expenditures (3) (2) (7) Utility repairs expenditures (4) (3) (13) Other, net 1 (2) 1 Effective income tax rate 14 % 18 % (10) % SDG&E: U.S. federal statutory income tax rate 21 % 21 % 21 % State income taxes, net of federal income tax benefit 5 6 5 Depreciation 3 3 3 Excess deferred income taxes outside of ratemaking — (3) — Amortization of excess deferred income taxes (1) (1) (1) Allowance for equity funds used during construction (2) (1) (2) Repairs expenditures (3) (3) (3) Self-developed software expenditures (4) (3) (2) Other, net — (1) (1) Effective income tax rate 19 % 18 % 20 % SoCalGas: U.S. federal statutory income tax rate 21 % 21 % 21 % Depreciation 5 4 7 State income taxes, net of federal income tax benefit 2 4 2 Nondeductible expenditures 2 — — Unrecognized income tax benefits — — 4 Compensation-related items — — 1 Resolution of prior years’ income tax items — — (1) Excess deferred income taxes outside of ratemaking — (5) — Allowance for equity funds used during construction (1) (1) (2) Amortization of excess deferred income taxes (1) (1) (2) Self-developed software expenditures (4) (2) (3) Repairs expenditures (7) (4) (7) Other, net (1) — (1) Effective income tax rate 16 % 16 % 19 % (1) Related to operations in Mexico. (2) 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.
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, 2020 2019 2018 By geographic components: U.S. $ 1,461 $ 1,191 $ (102) Non-U.S. 322 573 580 Total (1) $ 1,783 $ 1,764 $ 478 (1) See the Income Tax Expense (Benefit) and Effective Income Tax Rates table above for the 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, 2020 2019 2018 Sempra Energy Consolidated: Current: U.S. federal $ — $ — $ (1) U.S. state (22) (14) 67 Non-U.S. 112 140 127 Total 90 126 193 Deferred: U.S. federal 157 87 (121) U.S. state 36 21 (183) Non-U.S. (34) 84 66 Total 159 192 (238) Deferred investment tax credits — (3) (4) Total income tax expense (benefit) $ 249 $ 315 $ (49) SDG&E: Current: U.S. federal $ 121 $ 35 $ 104 U.S. state 34 31 30 Total 155 66 134 Deferred: U.S. federal 11 75 17 U.S. state 25 32 24 Total 36 107 41 Deferred investment tax credits (1) (2) (2) Total income tax expense $ 190 $ 171 $ 173 SoCalGas: Current: U.S. federal $ 163 $ 8 $ 4 U.S. state 45 24 10 Total 208 32 14 Deferred: U.S. federal (85) 79 78 U.S. state (28) 10 2 Total (113) 89 80 Deferred investment tax credits 1 (1) (2) Total income tax expense $ 96 $ 120 $ 92
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, 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of fixed assets, investments and other assets (1) $ 4,891 $ 4,052 U.S. state and non-U.S. withholding tax on repatriation of foreign earnings 46 153 Regulatory balancing accounts 587 468 Right-of-use assets – operating leases 144 131 Property taxes 51 44 Other deferred income tax liabilities 40 93 Total deferred income tax liabilities 5,759 4,941 Deferred income tax assets: Tax credits 1,161 1,136 Net operating losses 1,299 911 Postretirement benefits 162 200 Compensation-related items 169 161 Operating lease liabilities 125 131 Other deferred income tax assets 152 72 Accrued expenses not yet deductible 130 52 Deferred income tax assets before valuation allowances 3,198 2,663 Less: valuation allowances 174 144 Total deferred income tax assets 3,024 2,519 Net deferred income tax liability (2) $ 2,735 $ 2,422 (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, 2020 and 2019, includes $136 million and $155 million, respectively, recorded as a noncurrent asset and $2,871 million and $2,577 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, 2020 2019 2020 2019 Deferred income tax liabilities: Differences in financial and tax bases of utility plant and other assets $ 1,833 $ 1,735 $ 1,322 $ 1,246 Regulatory balancing accounts 224 141 362 327 Right-of-use assets – operating leases 28 32 21 22 Property taxes 34 30 17 14 Other 2 14 1 1 Total deferred income tax liabilities 2,121 1,952 1,723 1,610 Deferred income tax assets: Tax credits 5 6 3 3 Postretirement benefits 14 37 123 120 Compensation-related items 12 6 36 25 Operating lease liabilities 28 32 21 22 Bad debt allowance 18 3 15 1 State income taxes 8 7 11 8 Accrued expenses not yet deductible 14 9 93 15 Other 3 4 15 13 Total deferred income tax assets 102 104 317 207 Net deferred income tax liability $ 2,019 $ 1,848 $ 1,406 $ 1,403
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, 2020 Year expiration begins Sempra Energy Consolidated: U.S. federal: NOLs (1) $ 5,284 2031 General business tax credits (1) 428 2032 Foreign tax credits (2) 694 2024 U.S. state (2) : NOLs 3,047 2021 General business tax credits 39 2021 Non-U.S. (2) – NOLs 126 2021 (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, 2020 Year expiration begins Sempra Energy Consolidated: U.S. federal: NOLs (1) $ 5,284 2031 General business tax credits (1) 428 2032 Foreign tax credits (2) 694 2024 U.S. state (2) : NOLs 3,047 2021 General business tax credits 39 2021 Non-U.S. (2) – NOLs 126 2021 (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 Valuation Allowance	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, 2020 2019 Sempra Energy Consolidated: U.S. federal $ 118 $ 90 U.S. state 32 33 Non-U.S. 24 21 $ 174 $ 144
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) 2020 2019 2018 Sempra Energy Consolidated: Balance at January 1 $ 93 $ 119 $ 89 Increase in prior period tax positions 3 5 7 Decrease in prior period tax positions (1) — (1) Increase in current period tax positions 4 2 24 Settlements with taxing authorities — (32) — Expiration of statutes of limitations — (1) — Balance at December 31 $ 99 $ 93 $ 119 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (87) $ (81) $ (107) increase the effective tax rate (1) 31 27 24 SDG&E: Balance at January 1 $ 12 $ 11 $ 10 Increase in prior period tax positions 1 1 1 Balance at December 31 $ 13 $ 12 $ 11 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (10) $ (9) $ (9) increase the effective tax rate (1) 1 1 1 SoCalGas: Balance at January 1 $ 64 $ 61 $ 35 Increase in prior period tax positions 1 1 2 Increase in current period tax positions 3 2 24 Balance at December 31 $ 68 $ 64 $ 61 Of December 31 balance, amounts related to tax positions that if recognized in future years would decrease the effective tax rate (1) $ (59) $ (55) $ (51) increase the effective tax rate (1) 30 26 23 (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, 2020 2019 2018 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) (8) (40) $ (8) $ (8) $ (41) 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, 2020
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 2020 and 2019, and a statement of the funded status at December 31, 2020 and 2019: PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Pension benefits Other postretirement benefits 2020 2019 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 3,768 $ 3,339 $ 913 $ 868 Service cost 129 110 18 17 Interest cost 129 139 33 36 Contributions from plan participants — — 22 21 Actuarial loss 351 445 79 45 Plan amendments — 5 — — Benefit payments (93) (93) (74) (72) Settlements (207) (177) (2) (2) Net obligation at December 31 4,077 3,768 989 913 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 2,662 2,160 1,281 1,108 Actual return on plan assets 350 496 164 218 Employer contributions 290 276 8 8 Contributions from plan participants — — 22 21 Benefit payments (93) (93) (74) (72) Settlements (207) (177) (2) (2) Fair value of plan assets at December 31 3,002 2,662 1,399 1,281 Funded status at December 31 $ (1,075) $ (1,106) $ 410 $ 368 Net recorded (liability) asset at December 31 $ (1,075) $ (1,106) $ 410 $ 368 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SAN DIEGO GAS & ELECTRIC COMPANY (Dollars in millions) Pension benefits Other postretirement 2020 2019 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 895 $ 814 $ 177 $ 170 Service cost 31 30 4 4 Interest cost 30 34 6 7 Contributions from plan participants — — 8 7 Actuarial loss 37 61 17 7 Plan amendments — 3 — — Benefit payments (18) (18) (20) (18) Settlements (52) (39) — — Transfer of liability from other plans (10) 10 1 — Net obligation at December 31 913 895 193 177 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 739 600 197 172 Actual return on plan assets 94 135 26 36 Employer contributions 52 52 1 — Contributions from plan participants — — 8 7 Benefit payments (18) (18) (20) (18) Settlements (52) (39) — — Transfer of assets from other plans 4 9 1 — Fair value of plan assets at December 31 819 739 213 197 Funded status at December 31 $ (94) $ (156) $ 20 $ 20 Net recorded (liability) asset at December 31 $ (94) $ (156) $ 20 $ 20 PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement (Dollars in millions) 2020 2019 2020 2019 CHANGE IN PROJECTED BENEFIT OBLIGATION Net obligation at January 1 $ 2,526 $ 2,148 $ 688 $ 646 Service cost 86 68 14 12 Interest cost 88 91 25 27 Contributions from plan participants — — 14 13 Actuarial loss 282 345 57 39 Plan amendments — 2 — — Benefit payments (60) (59) (49) (49) Settlements (105) (65) — — Transfer of liability to other plans 12 (4) — — Net obligation at December 31 2,829 2,526 749 688 CHANGE IN PLAN ASSETS Fair value of plan assets at January 1 1,737 1,385 1,059 916 Actual return on plan assets 243 320 134 178 Employer contributions 152 152 1 1 Contributions from plan participants — — 14 13 Benefit payments (60) (59) (49) (49) Settlements (105) (65) — — Transfer of assets from other plans 2 4 — — Fair value of plan assets at December 31 1,969 1,737 1,159 1,059 Funded status at December 31 $ (860) $ (789) $ 410 $ 371 Net recorded (liability) asset at December 31 $ (860) $ (789) $ 410 $ 371
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 2020 2019 2020 2019 Sempra Energy Consolidated: Noncurrent assets $ — $ — $ 430 $ 391 Current liabilities (35) (59) (1) (3) Noncurrent liabilities (1,040) (1,047) (19) (20) Net recorded (liability) asset $ (1,075) $ (1,106) $ 410 $ 368 SDG&E: Noncurrent assets $ — $ — $ 20 $ 20 Current liabilities (2) (3) — — Noncurrent liabilities (92) (153) — — Net recorded (liability) asset $ (94) $ (156) $ 20 $ 20 SoCalGas: Noncurrent assets $ — $ — $ 410 $ 371 Current liabilities (7) (4) — — Noncurrent liabilities (853) (785) — — Net recorded (liability) asset $ (860) $ (789) $ 410 $ 371
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 2020 2019 2020 2019 Sempra Energy Consolidated (1) : Net actuarial (loss) gain $ (102) $ (113) $ 8 $ 10 Prior service cost (11) (14) — — Total $ (113) $ (127) $ 8 $ 10 SDG&E: Net actuarial loss $ (8) $ (9) Prior service cost (2) (7) Total $ (10) $ (16) SoCalGas: Net actuarial loss $ (14) $ (7) Prior service cost (4) (3) Total $ (18) $ (10)
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) 2020 2019 Sempra Energy Consolidated: Projected benefit obligation $ 3,679 $ 3,578 Accumulated benefit obligation 3,265 3,229 Fair value of plan assets 2,788 2,662 SDG&E: Projected benefit obligation $ 887 $ 861 Accumulated benefit obligation 834 818 Fair value of plan assets 819 739 SoCalGas: Projected benefit obligation $ 2,792 $ 2,505 Accumulated benefit obligation 2,431 2,208 Fair value of plan assets 1,969 1,737 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) 2020 2019 Sempra Energy Consolidated: Projected benefit obligation $ 184 $ 190 Accumulated benefit obligation 146 158 SDG&E: Projected benefit obligation $ 26 $ 34 Accumulated benefit obligation 22 27 SoCalGas: Projected benefit obligation $ 37 $ 21 Accumulated benefit obligation 31 17 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) 2020 2019 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 33 $ 32 Fair value of plan assets 27 25 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) 2020 2019 Sempra Energy Consolidated: Accumulated postretirement benefit obligation $ 14 $ 16
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 2020 2019 2018 2020 2019 2018 NET PERIODIC BENEFIT COST Service cost $ 129 $ 110 $ 124 $ 18 $ 17 $ 21 Interest cost 129 139 140 33 36 36 Expected return on assets (169) (144) (157) (55) (71) (70) Amortization of: Prior service cost (credit) 12 12 11 (2) — 1 Actuarial loss (gain) 35 36 22 (10) (10) (6) Settlement charges 22 28 66 — — — Special termination benefits — — — — — 5 Net periodic benefit cost (credit) 158 181 206 (16) (28) (13) Regulatory adjustment 91 77 (30) 16 29 17 Total expense recognized 249 258 176 — 1 4 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1) Net loss (gain) 28 17 56 1 (3) (4) Prior service cost — 5 12 — — — Amortization of actuarial (loss) gain (14) (13) (12) — — — Amortization of prior service cost (4) (3) (2) — — — Settlements (22) (28) (12) — — — Total recognized in OCI (12) (22) 42 1 (3) (4) Total recognized in net periodic benefit cost and OCI $ 237 $ 236 $ 218 $ 1 $ (2) $ — (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 2020 2019 2018 2020 2019 2018 NET PERIODIC BENEFIT COST Service cost $ 31 $ 30 $ 30 $ 4 $ 4 $ 5 Interest cost 30 34 35 6 7 7 Expected return on assets (49) (38) (47) (10) (11) (13) Amortization of: Prior service cost 2 3 2 — 2 3 Actuarial loss (gain) 3 11 1 (3) (2) (3) Settlement charges — — 26 — — — Special termination benefits — — — — — 3 Net periodic benefit cost 17 40 47 (3) — 2 Regulatory adjustment 38 14 (8) 3 — — Total expense recognized 55 54 39 — — 2 CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss (gain) 6 5 (1) — — — Prior service cost — 2 8 — — — Transfer of actuarial loss (7) — — — — — Transfer of prior service cost (5) — — — — — Amortization of actuarial loss (1) — (1) — — — Amortization of prior service cost (1) (1) — — — — Settlements — — (4) — — — Total recognized in OCI (8) 6 2 — — — Total recognized in net periodic benefit cost and OCI $ 47 $ 60 $ 41 $ — $ — $ 2 NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI SOUTHERN CALIFORNIA GAS COMPANY (Dollars in millions) Pension benefits Other postretirement benefits 2020 2019 2018 2020 2019 2018 NET PERIODIC BENEFIT COST Service cost $ 86 $ 68 $ 81 $ 14 $ 12 $ 15 Interest cost 88 91 92 25 27 27 Expected return on assets (107) (94) (98) (43) (58) (56) Amortization of: Prior service cost (credit) 8 8 8 (2) (2) (3) Actuarial loss (gain) 26 16 13 (7) (8) (2) Settlement charges — — 32 — — — Special termination benefits — — — — — 2 Net periodic benefit cost (credit) 101 89 128 (13) (29) (17) Regulatory adjustment 53 63 (22) 13 29 17 Total expense recognized 154 152 106 — — — CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI Net loss 6 2 1 — — — Prior service cost — 3 — — — — Transfer of actuarial loss 5 (4) — — — — Transfer of prior service cost 3 (1) — — — — Amortization of actuarial loss (1) (1) — — — — Amortization of prior service cost (1) — (1) — — — Total recognized in OCI 12 (1) — — — — Total recognized in net periodic benefit cost and OCI $ 166 $ 151 $ 106 $ — $ — $ —
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 2020 2019 2020 2019 Sempra Energy Consolidated: Discount rate 2.78 % 3.49 % 2.88 % 3.54 % Interest crediting rate (1)(2) 1.62 2.28 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SDG&E: Discount rate 2.73 % 3.44 % 2.85 % 3.55 % Interest crediting rate (1)(2) 1.62 2.28 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 SoCalGas: Discount rate 2.79 % 3.50 % 2.90 % 3.55 % Interest crediting rate (1)(2) 1.62 2.28 1.62 2.28 Rate of compensation increase 2.70-10.00 2.70-10.00 2.70-10.00 2.70-10.00 (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 2020 2019 2018 2020 2019 2018 Sempra Energy Consolidated: Discount rate 3.49 % 4.29 % 3.64 % 3.54 % 4.29 % 3.68 % Expected return on plan assets 7.00 7.00 7.00 4.64 6.48 6.49 Interest crediting rate (1)(2) 2.28 3.36 2.80 2.28 3.36 2.80 Rate of compensation increase 2.70-10.00 2.00-10.00 2.00-10.00 2.70-10.00 2.00-10.00 2.00-10.00 SDG&E: Discount rate 3.44 % 4.29 % 3.64 % 3.55 % 4.30 % 3.65 % Expected return on plan assets 7.00 7.00 7.00 5.51 6.92 6.94 Interest crediting rate (1)(2) 2.28 3.36 2.80 2.28 3.36 2.80 Rate of compensation increase 2.70-10.00 2.00-10.00 2.00-10.00 2.70-10.00 2.00-10.00 2.00-10.00 SoCalGas: Discount rate 3.50 % 4.30 % 3.65 % 3.55 % 4.30 % 3.70 % Expected return on plan assets 7.00 7.00 7.00 4.41 6.38 6.38 Interest crediting rate (1)(2) 2.28 3.36 2.80 2.28 3.36 2.80 Rate of compensation increase 2.70-10.00 2.00-10.00 2.00-10.00 2.70-10.00 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 2020 2019 2018 2020 2019 2018 Health care cost trend rate assumed for next year 6.00 % 6.25 % 6.50 % 4.75 % 4.75 % 4.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2025 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 2020 2019 2018 2020 2019 2018 Health care cost trend rate assumed for next year 6.00 % 6.25 % 6.50 % 4.75 % 4.75 % 4.75 % Rate to which the cost trend rate is assumed to decline (the ultimate trend) 4.75 % 4.75 % 4.75 % 4.50 % 4.50 % 4.50 % Year the rate reaches the ultimate trend 2025 2025 2025 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, 2020 Level 1 Level 2 Total Sempra Energy Consolidated: Cash and cash equivalents $ 7 $ — $ 7 Equity securities: Domestic 931 — 931 International 563 — 563 Registered investment companies 183 — 183 Fixed income securities: Domestic government and government agencies 238 34 272 International government bonds — 13 13 Domestic corporate bonds — 418 418 International corporate bonds — 61 61 Registered investment companies — 37 37 Other 2 (1) 1 Total investment assets in the fair value hierarchy $ 1,924 $ 562 2,486 Accounts receivable/payable, net 13 Investments measured at NAV: Common/collective trusts 493 Private equity funds 10 Total investment assets $ 3,002 SDG&E’s proportionate share of investment assets $ 819 SoCalGas’ proportionate share of investment assets $ 1,969 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 and government agencies 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 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, 2020 Level 1 Level 2 Total SDG&E: Equity securities: Domestic $ 17 $ — $ 17 International 11 — 11 Registered investment companies 80 — 80 Fixed income securities: Domestic government and government agencies 38 2 40 Domestic corporate bonds — 8 8 International corporate bonds — 1 1 Registered investment companies — 7 7 Total investment assets in the fair value hierarchy 146 18 164 Accounts receivable/payable, net (2) Investments measured at NAV – Common/collective trusts 51 Total investment assets 213 SoCalGas: Cash and cash equivalents 1 — 1 Equity securities: Domestic 76 — 76 International 46 — 46 Registered investment companies 61 — 61 Fixed income securities: Domestic government and government agencies 273 25 298 International government bonds 1 14 15 Domestic corporate bonds — 349 349 International corporate bonds — 42 42 Registered investment companies — 81 81 Derivative financial instruments 1 — 1 Total investment assets in the fair value hierarchy 459 511 970 Investments measured at NAV: Common/collective trusts 188 Venture capital funds and real estate funds 1 Total investment assets 1,159 Other Sempra Energy: Equity securities: Domestic 10 — 10 International 6 — 6 Registered investment companies 1 — 1 Fixed income securities: Domestic government and government agencies 2 — 2 Domestic corporate bonds — 4 4 International corporate bonds — 1 1 Registered investment companies — (1) (1) Total investment assets in the fair value hierarchy 19 4 23 Investments measured at NAV – Common/collective trusts 4 Total other Sempra Energy investment assets 27 Total Sempra Energy Consolidated investment assets in the fair value hierarchy $ 624 $ 533 Total Sempra Energy Consolidated investment assets $ 1,399 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 and government agencies 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 and government agencies 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 and government agencies 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
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 2021: EXPECTED CONTRIBUTIONS (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Pension plans $ 246 $ 53 $ 157 Other postretirement benefit plans 5 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 2021 $ 389 $ 47 $ 112 $ 10 $ 226 $ 34 2022 268 47 68 10 172 34 2023 255 48 65 10 166 35 2024 246 48 61 10 159 35 2025 239 47 60 10 157 35 2026-2030 1,130 235 263 47 752 172
Schedule Of Defined Benefit Plans Contributions	Employer contributions to the savings plans were as follows: EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS (Dollars in millions) 2020 2019 2018 Sempra Energy Consolidated $ 47 $ 44 $ 43 SDG&E 16 15 15 SoCalGas 25 24 23

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 Sempra Energy Consolidated: Share-based compensation expense, before income taxes (1) $ 62 $ 66 $ 76 Income tax benefit (1) (17) (18) (21) $ 45 $ 48 $ 55 Capitalized share-based compensation cost $ 11 $ 11 $ 10 Excess income tax deficiency $ 19 $ 4 $ 15 SDG&E: Share-based compensation expense, before income taxes $ 11 $ 10 $ 12 Income tax benefit (3) (3) (3) $ 8 $ 7 $ 9 Capitalized share-based compensation cost $ 7 $ 6 $ 6 Excess income tax deficiency $ 3 $ 1 $ 3 SoCalGas: Share-based compensation expense, before income taxes $ 14 $ 15 $ 16 Income tax benefit (4) (4) (5) $ 10 $ 11 $ 11 Capitalized share-based compensation cost $ 4 $ 5 $ 4 Excess income tax deficiency $ 3 $ 1 $ 2
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 Years ended December 31, 2020 2019 Stock price volatility 18.78 % 18.63 % Expected term 5.34 years 5.34 years Risk-free rate of return 1.68 % 2.49 % Annual dividend yield 2.60 % 3.35 %
Schedule Of Non-qualified Stock Options	The following table shows a summary of nonqualified stock options at December 31, 2020 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, 2020 247,577 $ 105.86 Granted 154,860 $ 149.12 Exercised (4,400) $ 55.90 Forfeited/canceled (32,642) $ 149.12 Outstanding at December 31, 2020 365,395 $ 120.93 8.34 $ 2 Vested or expected to vest at December 31, 2020 349,596 $ 120.28 8.32 $ 2 Exercisable at December 31, 2020 81,061 $ 106.76 8.00 $ 2
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, 2020 2019 2018 Stock price volatility 16.35 % 17.74 % 17.46 % Risk-free rate of return 1.55 % 2.46 % 2.00 %
Schedule Of Restricted Stock Units	The following table shows a summary of RSUs at December 31, 2020 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, 2020 1,086,981 $ 109.85 415,787 $ 119.96 Granted 265,236 $ 155.62 165,847 $ 138.91 Vested (403,302) $ 110.45 (230,612) $ 112.11 Forfeited (54,954) $ 134.90 (7,445) $ 140.18 Nonvested at December 31, 2020 (1) 893,961 $ 121.61 343,577 $ 121.59 Expected to vest at December 31, 2020 882,903 $ 121.45 339,025 $ 121.46 (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, 2020
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 2020 2019 Sempra Energy Consolidated: Natural gas MMBtu 5 32 Electricity MWh 1 2 Congestion revenue rights MWh 43 48 SDG&E: Natural gas MMBtu 16 37 Electricity MWh 1 2 Congestion revenue rights MWh 43 48 SoCalGas: Natural gas MMBtu 1 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, 2020 December 31, 2019 Notional debt Maturities Notional debt Maturities Sempra Energy Consolidated: Cash flow hedges $ 1,486 2021-2034 $ 1,445 2020-2034 The following table presents the net notional amounts of our foreign currency derivatives, excluding JVs. FOREIGN CURRENCY DERIVATIVES (Dollars in millions) December 31, 2020 December 31, 2019 Notional amount Maturities Notional amount Maturities Sempra Energy Consolidated: Cross-currency swaps $ 306 2021-2023 $ 306 2020-2023 Other foreign currency derivatives 1,764 2021-2022 1,796 2020-2021
Derivative Instruments on the Consolidated Balance Sheet Table	DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS (Dollars in millions) December 31, 2020 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 $ — $ 1 $ (26) $ (160) Derivatives not designated as hedging instruments: Foreign exchange instruments 24 — — — Commodity contracts not subject to rate recovery 82 17 (95) (16) Associated offsetting commodity contracts (82) (13) 82 13 Commodity contracts subject to rate recovery 35 95 (35) (25) Associated offsetting commodity contracts (2) — 2 — Net amounts presented on the balance sheet 57 100 (72) (188) Additional cash collateral for commodity contracts not subject to rate recovery 21 — — — Additional cash collateral for commodity contracts subject to rate recovery 30 — — — Total (2) $ 108 $ 100 $ (72) $ (188) SDG&E: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 32 $ 95 $ (28) $ (25) Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 31 95 (27) (25) Additional cash collateral for commodity contracts subject to rate recovery 24 — — — Total (2) $ 55 $ 95 $ (27) $ (25) SoCalGas: Derivatives not designated as hedging instruments: Commodity contracts subject to rate recovery $ 3 $ — $ (7) $ — Associated offsetting commodity contracts (1) — 1 — Net amounts presented on the balance sheet 2 — (6) — Additional cash collateral for commodity contracts subject to rate recovery 6 — — — Total $ 8 $ — $ (6) $ — (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, 2019 Other current (1) Other long-term assets Other current 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 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.
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 Pretax (loss) gain reclassified Years ended December 31, Years ended December 31, 2020 2019 2018 Location 2020 2019 2018 Sempra Energy Consolidated: Interest rate instruments $ — $ — $ — (Loss) Gain on Sale of Assets $ — $ (10) $ (9) Interest rate instruments (1) (34) (24) 17 Interest Expense (1) (10) (3) (1) Interest rate instruments (185) (164) 44 Equity Earnings (46) (3) (9) Foreign exchange instruments (4) (8) (4) Revenues: Energy- Related Businesses 1 (2) 1 Interest rate and foreign exchange instruments (6) 19 14 Interest Expense (1) — 1 Other (Expense) Income, Net (11) 9 2 Foreign exchange instruments (3) (10) (3) Equity Earnings — (2) 2 Total $ (232) $ (187) $ 68 $ (67) $ (11) $ (13) SDG&E: Interest rate instruments (1) $ — $ (1) $ 1 Interest Expense (1) $ — $ (3) $ (7) 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 2020 2019 2018 Sempra Energy Consolidated: Commodity contracts not subject to rate recovery Revenues: Energy-Related Businesses $ 17 $ 12 $ 26 Commodity contracts subject to rate recovery Cost of Natural Gas (7) 3 5 Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power 88 (140) 279 Foreign exchange instruments Other (Expense) Income, Net (56) 25 3 Total $ 42 $ (100) $ 313 SDG&E: Commodity contracts subject to rate recovery Cost of Electric Fuel and Purchased Power $ 88 $ (140) $ 279 SoCalGas: Commodity contracts subject to rate recovery Cost of Natural Gas $ (7) $ 3 $ 5

FAIR VALUE MEASUREMENTS (Tables

FAIR VALUE MEASUREMENTS (Tables)	12 Months Ended
	Dec. 31, 2020
Fair Value Disclosures [Abstract]
Recurring Fair Value Measures Table	RECURRING FAIR VALUE MEASURES – SEMPRA ENERGY CONSOLIDATED (Dollars in millions) Fair value at December 31, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 358 $ 6 $ — $ 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 399 626 — 1,025 Interest rate and foreign exchange instruments — 25 — 25 Commodity contracts not subject to rate recovery — 4 — 4 Effect of netting and allocation of collateral (2) 21 — — 21 Commodity contracts subject to rate recovery 6 1 121 128 Effect of netting and allocation of collateral (2) 19 5 6 30 Support Agreement, net of related guarantee fees — — 7 7 Total $ 445 $ 661 $ 134 $ 1,240 Liabilities: Interest rate and foreign exchange instruments $ — $ 186 $ — $ 186 Commodity contracts not subject to rate recovery — 16 — 16 Commodity contracts subject to rate recovery — 6 52 58 Support Agreement, net of related guarantee fees — — 4 4 Total $ — $ 208 $ 56 $ 264 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 (1) Excludes cash, cash equivalents and receivables (payables), net. (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, 2020 Level 1 Level 2 Level 3 Total Assets: Nuclear decommissioning trusts: Equity securities $ 358 $ 6 $ — $ 364 Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies 41 24 — 65 Municipal bonds — 326 — 326 Other securities — 270 — 270 Total debt securities 41 620 — 661 Total nuclear decommissioning trusts (1) 399 626 — 1,025 Commodity contracts subject to rate recovery 5 — 121 126 Effect of netting and allocation of collateral (2) 18 — 6 24 Total $ 422 $ 626 $ 127 $ 1,175 Liabilities: Commodity contracts subject to rate recovery $ — $ — $ 52 $ 52 Total $ — $ — $ 52 $ 52 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 (1) Excludes cash, cash equivalents and receivables (payables), net. (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, 2020 Level 1 Level 2 Level 3 Total Assets: Commodity contracts subject to rate recovery $ 1 $ 1 $ — $ 2 Effect of netting and allocation of collateral (1) 1 5 — 6 Total $ 2 $ 6 $ — $ 8 Liabilities: Commodity contracts subject to rate recovery $ — $ 6 $ — $ 6 Total $ — $ 6 $ — $ 6 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 (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, 2020 2019 2018 Balance at January 1 $ 28 $ 179 $ (28) Realized and unrealized gains (losses) 19 (184) 209 Allocated transmission instruments 6 6 10 Settlements 16 27 (12) Balance at December 31 $ 69 $ 28 $ 179 Change in unrealized gains (losses) relating to instruments still held at December 31 $ 34 $ (139) $ 183 (1) Excludes the effect of the contractual ability to settle contracts under master netting agreements. The table below sets forth a reconciliation of changes in the fair value of Sempra Energy’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra Energy Consolidated. LEVEL 3 RECONCILIATION (Dollars in millions) Year ended Balance at January 1 $ — Realized and unrealized gains (1) 6 Settlements (3) Balance at December 31 (2) $ 3 Change in unrealized gains (losses) relating to instruments still held at December 31 $ 3 (1) Net gains are included in Interest Income and net losses are included in Interest Expense on the Sempra Energy Consolidated Statement of Operations. (2) Includes $7 million in Other Current Assets offset by $4 million in Deferred Credits and Other on the Sempra Energy Consolidated Balance Sheet.
Schedule of Auction Price Inputs	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 2021 $ (1.81) to $ 14.11 $ (0.12) 2020 (3.77) to 6.03 (1.58) 2019 (8.57) to 35.21 (2.94) LONG-TERM, FIXED-PRICE ELECTRICITY POSITIONS PRICE INPUTS Settlement year Price per MWh Weighted-average price per MWh 2020 $ 19.60 to $ 78.10 $ 39.71 2019 21.00 to 61.15 37.92
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, 2020 Carrying Fair value amount Level 1 Level 2 Level 3 Total Sempra Energy Consolidated: Long-term amounts due from unconsolidated affiliates (1) $ 786 $ — $ 817 $ — $ 817 Long-term amounts due to unconsolidated affiliates 275 — 266 — 266 Total long-term debt (2) 22,259 — 25,478 — 25,478 SDG&E: Total long-term debt (3) $ 6,253 $ — $ 7,384 $ — $ 7,384 SoCalGas: Total long-term debt (4) $ 4,759 $ — $ 5,655 $ — $ 5,655 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 (2) 21,247 — 22,638 26 22,664 SDG&E: Total long-term debt (3) $ 5,140 $ — $ 5,662 $ — $ 5,662 SoCalGas: Total long-term debt (4) $ 3,809 $ — $ 4,189 $ — $ 4,189 (1) Before allowances for credit losses of $3 million. Includes $3 million of accrued interest receivable in Due From Unconsolidated Affiliate – Current. (2) Before reductions of unamortized discount and debt issuance costs of $268 million and $225 million at December 31, 2020 and 2019, respectively, and excluding finance lease obligations of $1,330 million and $1,289 million at December 31, 2020 and 2019, respectively. (3) Before reductions of unamortized discount and debt issuance costs of $52 million and $48 million at December 31, 2020 and 2019, respectively, and excluding finance lease obligations of $1,276 million and $1,270 million at December 31, 2020 and 2019, respectively. (4) Before reductions of unamortized discount and debt issuance costs of $40 million and $34 million at December 31, 2020 and 2019, respectively, and excluding finance lease obligations of $54 million and $19 million at December 31, 2020 and 2019, respectively.
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 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 per dekatherm per month $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) (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, 2020
Equity [Abstract]
Schedule of Conversions of Stock	The following table illustrates the conversion rate per share of our series B 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 series B preferred stock) 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)
Schedule Of Preferred Stock	The table below presents preferred stock outstanding at SoCalGas: PREFERRED STOCK OUTSTANDING (Dollars in millions, except per share amounts) December 31, 2020 2019 $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 PE (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, 2020
Earnings Per Share [Abstract]
Schedule Of Earnings Per Share Computations	EARNINGS PER COMMON SHARE COMPUTATIONS (Dollars in millions, except per share amounts; shares in thousands) Years ended December 31, 2020 2019 2018 Numerator for continuing operations: Income from continuing operations, net of income tax $ 2,255 $ 1,999 $ 938 Earnings attributable to noncontrolling interests (162) (129) (44) Preferred dividends (168) (142) (125) Preferred dividends of subsidiary (1) (1) (1) Earnings from continuing operations attributable to common shares $ 1,924 $ 1,727 $ 768 Numerator for discontinued operations: Income from discontinued operations, net of income tax $ 1,850 $ 363 $ 188 Earnings attributable to noncontrolling interests (10) (35) (32) Earnings from discontinued operations attributable to common shares $ 1,840 $ 328 $ 156 Numerator for earnings: Earnings attributable to common shares $ 3,764 $ 2,055 $ 924 Denominator: Weighted-average common shares outstanding for basic EPS (1) 291,077 277,904 268,072 Dilutive effect of stock options and RSUs (2) 1,175 1,585 919 Dilutive effect of common shares sold forward — 2,544 861 Weighted-average common shares outstanding for diluted EPS 292,252 282,033 269,852 Basic EPS: Earnings from continuing operations $ 6.61 $ 6.22 $ 2.86 Earnings from discontinued operations $ 6.32 $ 1.18 $ 0.59 Earnings $ 12.93 $ 7.40 $ 3.45 Diluted EPS: Earnings from continuing operations $ 6.58 $ 6.13 $ 2.84 Earnings from discontinued operations $ 6.30 $ 1.16 $ 0.58 Earnings $ 12.88 $ 7.29 $ 3.42 (1) Includes fully vested RSUs held in our Deferred Compensation Plan of 537 in 2020, 617 in 2019 and 641 in 2018. 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)
Schedule Of Common Stock Activity	The following table provides common stock activity for the last three years. COMMON STOCK ACTIVITY Years ended December 31, 2020 2019 2018 Common shares outstanding, January 1 291,712,925 273,769,513 251,358,977 Shares issued under forward sale agreements — 16,906,185 21,175,473 RSUs vesting (1) 896,839 463,012 509,042 Stock options exercised 4,400 52,540 138,861 Savings plan issuance 201,431 475,774 553,036 Common stock investment plan (2) 42,955 199,253 231,242 Issuance of RSUs held in our Deferred Compensation Plan 103,552 59,470 3,357 Shares repurchased (3) (4,491,858) (212,822) (200,475) Common shares outstanding, December 31 288,470,244 291,712,925 273,769,513 (1) Includes dividend equivalents. (2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares.

SAN ONOFRE NUCLEAR GENERATING_2

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)	12 Months Ended
	Dec. 31, 2020
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 Gross Estimated At December 31, 2020: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies (1) $ 64 $ 1 $ — $ 65 Municipal bonds (2) 308 18 — 326 Other securities (3) 253 17 — 270 Total debt securities 625 36 — 661 Equity securities 112 254 (2) 364 Cash and cash equivalents 3 — — 3 Receivables (payables), net (9) — — (9) Total $ 731 $ 290 $ (2) $ 1,019 At December 31, 2019: Debt securities: Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies $ 57 $ — $ — $ 57 Municipal bonds 270 12 — 282 Other securities 218 9 (1) 226 Total debt securities 545 21 (1) 565 Equity securities 176 339 (6) 509 Cash and cash equivalents 16 — — 16 Receivables (payables), net (8) — — (8) Total $ 729 $ 360 $ (7) $ 1,082 (1) Maturity dates are 2022-2051. (2) Maturity dates are 2021-2056. (3) Maturity dates are 2021-2072.
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, 2020 2019 2018 Proceeds from sales $ 1,439 $ 914 $ 890 Gross realized gains 156 24 42 Gross realized losses (17) (5) (10)

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Tables)	12 Months Ended
	Dec. 31, 2020
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) Sempra Energy Consolidated SDG&E SoCalGas December 31, 2020 2019 2020 2019 2020 2019 Right-of-use assets: Operating leases: Right-of-use assets $ 543 $ 591 $ 102 $ 130 $ 74 $ 94 Finance leases: Property, plant and equipment 1,429 1,353 1,356 1,326 73 27 Accumulated depreciation (99) (64) (80) (57) (19) (7) Property, plant and equipment, net 1,330 1,289 1,276 1,269 54 20 Total right-of-use assets $ 1,873 $ 1,880 $ 1,378 $ 1,399 $ 128 $ 114 Lease liabilities: Operating leases: Other current liabilities $ 52 $ 52 $ 27 $ 27 $ 18 $ 18 Deferred credits and other 407 445 73 102 56 75 459 497 100 129 74 93 Finance leases: Current portion of long-term debt and finance leases 36 26 26 20 10 6 Long-term debt and finance leases 1,294 1,263 1,250 1,250 44 13 1,330 1,289 1,276 1,270 54 19 Total lease liabilities $ 1,789 $ 1,786 $ 1,376 $ 1,399 $ 128 $ 112 Weighted-average remaining lease term (in years): Operating leases 13 13 6 6 5 6 Finance leases 18 19 19 20 7 6 Weighted-average discount rate: Operating leases 5.81 % 6.01 % 3.62 % 3.55 % 2.03 % 3.73 % Finance leases 14.45 % 14.76 % 14.65 % 14.83 % 2.83 % 3.23 %
Lease, Cost	The components of lease costs were as follows: LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS (1) (Dollars in millions) Sempra Energy Consolidated SDG&E SoCalGas Years ended December 31, 2020 2019 2020 2019 2020 2019 Operating lease costs $ 92 $ 96 $ 31 $ 33 $ 24 $ 27 Finance lease costs: Amortization of ROU assets (2) 35 24 23 18 12 6 Interest on lease liabilities 188 173 186 173 2 — Total finance lease costs 223 197 209 191 14 6 Short-term lease costs (3) 7 6 3 2 — — Variable lease costs (3) 477 482 467 471 10 10 Total lease costs $ 799 $ 781 $ 710 $ 697 $ 48 $ 43 (1) Includes costs capitalized in PP&E. (2) Included in O&M, except for $18 million in 2020 and $15 million in 2019, which is included in Depreciation and Amortization Expense at Sempra Energy Consolidated and SDG&E. (3) 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) Sempra Energy Consolidated SDG&E SoCalGas Years ended December 31 2020 2019 2020 2019 2020 2019 Operating activities: Cash paid for operating leases $ 79 $ 101 $ 31 $ 33 $ 24 $ 27 Cash paid for finance leases 173 173 171 173 2 — Financing activities: Cash paid for finance leases 35 24 23 18 12 6 Increase (decrease) in operating lease obligations for right-of-use assets 20 585 (1) 158 1 118 Increase in finance lease obligations for investment in PP&E 77 38 30 16 47 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, 2020 Sempra Energy Consolidated SDG&E SoCalGas Operating leases Finance leases (1) Operating leases Finance leases (1) Operating leases Finance leases 2021 $ 73 $ 206 $ 30 $ 194 $ 19 $ 12 2022 64 203 22 194 17 9 2023 55 203 17 194 13 9 2024 51 198 15 189 11 9 2025 40 193 5 185 9 8 Thereafter 415 2,465 22 2,453 8 12 Total undiscounted lease payments 698 3,468 111 3,409 77 59 Less: imputed interest (239) (2,138) (11) (2,133) (3) (5) Total lease liabilities 459 1,330 100 1,276 74 54 Less: current lease liabilities (52) (36) (27) (26) (18) (10) Long-term lease liabilities $ 407 $ 1,294 $ 73 $ 1,250 $ 56 $ 44 (1) Substantially all amounts are related to purchased-power contracts.
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, 2020 Sempra Energy Consolidated SDG&E SoCalGas Operating leases Finance leases (1) Operating leases Finance leases (1) Operating leases Finance leases 2021 $ 73 $ 206 $ 30 $ 194 $ 19 $ 12 2022 64 203 22 194 17 9 2023 55 203 17 194 13 9 2024 51 198 15 189 11 9 2025 40 193 5 185 9 8 Thereafter 415 2,465 22 2,453 8 12 Total undiscounted lease payments 698 3,468 111 3,409 77 59 Less: imputed interest (239) (2,138) (11) (2,133) (3) (5) Total lease liabilities 459 1,330 100 1,276 74 54 Less: current lease liabilities (52) (36) (27) (26) (18) (10) Long-term lease liabilities $ 407 $ 1,294 $ 73 $ 1,250 $ 56 $ 44 (1) Substantially all amounts are related to purchased-power contracts.
Schedule of Rent Expense	Rent expense for operating leases was as follows: RENT EXPENSE – OPERATING LEASES (Dollars in millions) Year ended December 31, 2018 Sempra Energy Consolidated $ 122 SDG&E 27 SoCalGas 41
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, 2020 2019 Assets subject to operating leases: Property, plant and equipment (1) $ 1,092 $ 1,038 Accumulated depreciation (228) (179) Property, plant and equipment, net $ 864 $ 859 December 31, 2020 Maturity analysis of operating lease payments: 2021 $ 207 2022 202 2023 202 2024 202 2025 202 Thereafter 2,344 Total undiscounted cash flows $ 3,359 (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, 2020 2019 2018 Fixed lease payments $ 195 $ 200 $ 194 Variable lease payments 1 6 72 Total revenues from operating leases (1) $ 196 $ 206 $ 266 Depreciation expense $ 39 $ 38 $ 72 (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, 2020, 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 Natural gas (1) Total (1) 2021 $ 216 $ 61 $ 277 2022 203 13 216 2023 189 12 201 2024 166 12 178 2025 131 6 137 Thereafter 1,014 — 1,014 Total minimum payments $ 1,919 $ 104 $ 2,023 (1) Excludes amounts related to the LNG purchase agreement discussed below. FUTURE MINIMUM PAYMENTS – SOCALGAS (Dollars in millions) Transportation Natural gas Total 2021 $ 134 $ 41 $ 175 2022 126 — 126 2023 123 — 123 2024 103 — 103 2025 68 — 68 Thereafter 359 — 359 Total minimum payments $ 913 $ 41 $ 954
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, 2020 2019 2018 Sempra Energy Consolidated $ 989 $ 1,326 $ 1,345 SoCalGas 935 1,181 1,169
Schedule Of L N G Commitment Amounts	At December 31, 2020, 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) 2021 $ 320 2022 422 2023 389 2024 386 2025 390 Thereafter 1,452 Total $ 3,359
Schedule Of Estimated Future Payments Under Purchased Power Contracts	At December 31, 2020, 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) 2021 $ 222 2022 208 2023 173 2024 145 2025 88 Thereafter 794 Total minimum payments (1) $ 1,630 (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, 2020 2019 2018 Sempra Energy Consolidated $ 76 $ 80 $ 100 SDG&E 39 39 38 SoCalGas 37 41 62
Schedule Of Environmental Remediation Costs, Status Of Remediation Sites	The table below shows the status at December 31, 2020 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 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, 2020. Of the total liability, $9 million at SoCalGas is recorded on a discounted basis, with a discount rate of 1.5%. ACCRUED LIABILITIES FOR ENVIRONMENTAL MATTERS (Dollars in millions) Manufactured- Waste disposal sites (PRP) (1) Other Total (2) SDG&E (3) $ — $ 6 $ 13 $ 19 SoCalGas (4) 36 3 1 40 Other — 1 — 1 Total Sempra Energy $ 36 $ 10 $ 14 $ 60 (1) Sites for which we have been identified as a PRP. (2) Includes $11 million, $1 million and $10 million classified as current liabilities, and $49 million, $18 million and $30 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. 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, 2020
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, 2020 2019 2018 REVENUES SDG&E $ 5,313 $ 4,925 $ 4,568 SoCalGas 4,748 4,525 3,962 Sempra Mexico 1,256 1,375 1,376 Sempra LNG 374 410 472 Sempra Renewables — 10 124 All other 2 3 — Adjustments and eliminations (3) (3) (3) Intersegment revenues (1) (320) (416) (397) Total $ 11,370 $ 10,829 $ 10,102 INTEREST EXPENSE SDG&E (2) $ 413 $ 411 $ 221 SoCalGas 158 141 115 Sempra Mexico 132 119 120 Sempra LNG 43 35 21 Sempra Renewables — 3 19 All other 389 450 496 Intercompany eliminations (54) (82) (106) Total $ 1,081 $ 1,077 $ 886 INTEREST INCOME SDG&E $ 2 $ 4 $ 4 SoCalGas 2 2 2 Sempra Mexico 60 78 65 Sempra LNG 81 61 49 Sempra Renewables — 11 12 All other 7 4 14 Intercompany eliminations (56) (73) (61) Total $ 96 $ 87 $ 85 DEPRECIATION AND AMORTIZATION SDG&E $ 801 $ 760 $ 688 SoCalGas 654 602 556 Sempra Mexico 189 183 175 Sempra LNG 9 10 26 Sempra Renewables — — 27 All other 13 14 19 Total $ 1,666 $ 1,569 $ 1,491 INCOME TAX EXPENSE (BENEFIT) SDG&E $ 190 $ 171 $ 173 SoCalGas 96 120 92 Sempra Texas Utilities 1 — — Sempra Mexico 57 227 185 Sempra LNG 92 (5) (435) Sempra Renewables — 4 71 All other (187) (202) (135) Total $ 249 $ 315 $ (49) SEGMENT INFORMATION (CONTINUED) (Dollars in millions) Years ended December 31 or at December 31, 2020 2019 2018 EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES SDG&E $ 824 $ 767 $ 669 SoCalGas 504 641 400 Sempra Texas Utilities 579 528 371 Sempra Mexico 259 253 237 Sempra LNG 320 (6) (617) Sempra Renewables — 59 328 Discontinued operations 1,840 328 156 All other (562) (515) (620) Total $ 3,764 $ 2,055 $ 924 EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT SDG&E $ 1,942 $ 1,522 $ 1,542 SoCalGas 1,843 1,439 1,538 Sempra Mexico 611 624 368 Sempra LNG 268 112 31 Sempra Renewables — 2 51 All other 12 9 14 Total $ 4,676 $ 3,708 $ 3,544 ASSETS SDG&E $ 22,311 $ 20,560 $ 19,225 SoCalGas 18,460 17,077 15,389 Sempra Texas Utilities 12,542 11,619 9,652 Sempra Mexico 10,752 9,938 9,165 Sempra LNG 2,205 3,901 4,060 Sempra Renewables — — 2,549 Discontinued operations — 3,958 3,718 All other 1,209 749 1,070 Intersegment receivables (856) (2,137) (4,190) Total $ 66,623 $ 65,665 $ 60,638 GEOGRAPHIC INFORMATION Long-lived assets (3) : United States $ 46,902 $ 43,719 $ 40,611 Mexico 6,929 6,355 5,800 Total $ 53,831 $ 50,074 $ 46,411 Revenues (4) : United States $ 10,205 $ 9,574 $ 8,840 Mexico 1,165 1,255 1,262 Total $ 11,370 $ 10,829 $ 10,102 (1) Revenues for reportable segments include intersegment revenues of $5 million, $88 million, $91 million and $136 million for 2020; $5 million, $69 million, $120 million and $222 million for 2019; and $4 million, $64 million, $114 million and $215 million for 2018 for SDG&E, SoCalGas, Sempra Mexico and Sempra LNG, respectively. (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, 2020
Quarterly Financial Data [Abstract]
Schedule Of Quarterly Financial Data Table	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 2020: Revenues $ 3,029 $ 2,526 $ 2,644 $ 3,171 Expenses and other income $ 2,632 $ 2,063 $ 2,443 $ 2,743 Income from continuing operations, net of income tax $ 867 $ 528 $ 428 $ 432 Income (loss) from discontinued operations, net of income tax 80 1,777 (7) — Net income $ 947 $ 2,305 $ 421 $ 432 Earnings attributable to common shares $ 760 $ 2,239 $ 351 $ 414 Basic EPS (1) : Earnings from continuing operations $ 2.35 $ 1.58 $ 1.23 $ 1.43 Earnings (losses) from discontinued operations $ 0.25 $ 6.06 $ (0.02) $ — Earnings $ 2.60 $ 7.64 $ 1.21 $ 1.43 Weighted-average common shares outstanding 292.8 293.1 289.5 289.0 Diluted EPS (1) : Earnings from continuing operations (2) $ 2.30 $ 1.58 $ 1.23 $ 1.43 Earnings (losses) from discontinued operations $ 0.23 $ 6.03 $ (0.02) $ — Earnings (2) $ 2.53 $ 7.61 $ 1.21 $ 1.43 Weighted-average common shares outstanding 313.9 294.2 290.6 290.2 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 (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 March 31, 2020 and September 30, 2019, 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 dividends declared in those quarters. SDG&E (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2020: Operating revenues $ 1,269 $ 1,235 $ 1,472 $ 1,337 Operating expenses 880 887 1,157 1,016 Operating income $ 389 $ 348 $ 315 $ 321 Net income/Earnings attributable to common shares $ 262 $ 193 $ 178 $ 191 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 SOCALGAS (Dollars in millions) Quarters ended March 31 June 30 September 30 December 31 2020: Operating revenues $ 1,395 $ 1,010 $ 842 $ 1,501 Operating expenses 1,031 773 826 1,333 Operating income $ 364 $ 237 $ 16 $ 168 Net income (loss) $ 303 $ 147 $ (24) $ 79 Dividends on preferred stock — (1) — — Earnings (losses) attributable to common shares $ 303 $ 146 $ (24) $ 79 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

SCHEDULE I - CONDENSED FINANC_2

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)	12 Months Ended
	Dec. 31, 2020
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, 2020 2019 2018 Interest income $ 4 $ 3 $ 14 Interest expense (495) (521) (495) Operating expenses (86) (124) (82) Other (expense) income, net (38) 59 (16) Income tax benefit 176 163 154 Loss before equity in earnings of subsidiaries (439) (420) (425) Equity in earnings of subsidiaries, net of income taxes 4,371 2,617 1,474 Net income 3,932 2,197 1,049 Preferred dividends (168) (142) (125) Earnings $ 3,764 $ 2,055 $ 924 Basic EPS: Earnings $ 12.93 $ 7.40 $ 3.45 Weighted-average common shares outstanding 291,077 277,904 268,072 Diluted EPS: Earnings $ 12.88 $ 7.29 $ 3.42 Weighted-average common shares outstanding 292,252 282,033 269,852 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, 2020, 2019 and 2018 Pretax Income tax benefit (expense) Net-of-tax 2020: Net income $ 3,756 $ 176 $ 3,932 Other comprehensive income (loss): Foreign currency translation adjustments 547 — 547 Financial instruments (146) 33 (113) Pension and other postretirement benefits 11 1 12 Total other comprehensive income 412 34 446 Comprehensive income $ 4,168 $ 210 $ 4,378 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 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 $ 366 $ 6 Due from affiliates 58 98 Income taxes receivable, net 42 — Other current assets 26 34 Total current assets 492 138 Investments in subsidiaries 33,898 32,604 Due from affiliates 1 3 Deferred income taxes 2,187 1,766 Other long-term assets 717 682 Total assets $ 37,295 $ 35,193 Liabilities and shareholders’ equity: Current portion of long-term debt $ 850 $ 1,399 Due to affiliates 224 369 Income taxes payable, net — 274 Other current liabilities 536 561 Total current liabilities 1,610 2,603 Long-term debt 7,317 8,856 Due to affiliates 4,375 3,138 Other long-term liabilities 620 667 Commitments and contingencies (Note 4) Shareholders’ equity 23,373 19,929 Total liabilities and shareholders’ equity $ 37,295 $ 35,193 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, 2020 2019 2018 Net cash (used in) provided by operating activities (978) $ 294 $ 213 Expenditures for property, plant and equipment (9) (8) (11) Expenditures for acquisition — — (329) Capital contributions to investees (364) (1,528) (9,457) Distribution from investments 3,616 — — Decrease (increase) in loans to affiliates, net 2 — (1) Other — 4 — Net cash provided by (used in) investing activities 3,245 (1,532) (9,798) Common stock dividends paid (1,174) (993) (877) Preferred dividends paid (157) (142) (89) Issuances of preferred stock, net 891 — 2,258 Issuances of common stock, net 11 1,830 2,272 Repurchases of common stock (566) (26) (21) Issuances of long-term debt 1,599 758 4,969 Payments on long-term debt (3,700) (1,500) (500) Increase in loans from affiliates, net 1,194 1,328 1,520 Equity transaction costs with third parties (4) — — Debt issuance costs (1) (25) (37) Net cash (used in) provided by financing activities (1,907) 1,230 9,495 Increase (decrease) in cash and cash equivalents 360 (8) (90) Cash and cash equivalents, January 1 6 14 104 Cash and cash equivalents, December 31 $ 366 $ 6 $ 14 SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES Preferred dividends declared but not paid $ 47 $ 36 $ 36 Common dividends issued in stock 22 55 54 Common dividends declared but not paid 301 283 245
Schedule Of 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, 2020 2019 SDG&E: First mortgage bonds (collateralized by plant assets): 3% August 15, 2021 $ 350 $ 350 1.914% payable 2015 through February 2022 53 89 3.6% September 1, 2023 450 450 2.5% May 15, 2026 500 500 6% June 1, 2026 250 250 1.7% October 1, 2030 800 — 5.875% January and February 2034 (1) — 176 5.35% May 15, 2035 250 250 6.125% September 15, 2037 250 250 4% May 1, 2039 (1) — 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 400 400 3.32% April 15, 2050 400 — 6,053 5,140 Other long-term debt (uncollateralized): Variable rate (0.95% at December 31, 2020) 364-day term loan March 18, 2021 (1) 200 — Finance lease obligations: Purchased-power contracts 1,237 1,255 Other 39 15 1,476 1,270 7,529 6,410 Current portion of long-term debt (611) (56) Unamortized discount on long-term debt (13) (12) Unamortized debt issuance costs (39) (36) Total SDG&E 6,866 6,306 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 2.55% February 1, 2030 650 — 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 350 350 4,450 3,800 Other long-term debt (uncollateralized): Notes at variable rates (0.57% at December 31, 2020) September 14, 2023 (1) 300 — 1.875% Notes May 14, 2026 (1) 4 4 5.67% Notes January 18, 2028 5 5 Finance lease obligations 54 19 363 28 4,813 3,828 Current portion of long-term debt (10) (6) Unamortized discount on long-term debt (8) (7) Unamortized debt issuance costs (32) (27) Total SoCalGas 4,763 3,788 LONG-TERM DEBT AND FINANCE LEASES (CONTINUED) (Dollars in millions) December 31, 2020 2019 Sempra Energy: Other long-term debt (uncollateralized): 2.4% Notes February 1, 2020 — 500 2.4% Notes March 15, 2020 — 500 2.85% Notes November 15, 2020 — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — 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) 758 758 Sempra Mexico Other long-term debt (uncollateralized unless otherwise noted): 6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013) 197 207 Notes at variable rates (4.88% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets 196 237 3.75% Notes January 14, 2028 300 300 Bank loans including $234 at a weighted-average fixed rate of 6.87%, $130 at variable rates (weighted-average rate of 6.54% after floating-to-fixed rate swaps effective 2014) and $34 at variable rates (3.45% at December 31, 2020), payable 2016 through March 2032, collateralized by plant assets 398 423 4.875% Notes January 14, 2048 540 540 Loan at variable rates (5.75% at December 31, 2019) July 31, 2028 (1) — 11 Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034 (1) 200 200 4.75% notes January 15, 2051 800 — Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034 (1) 100 — 2.90% loan November 15, 2034 (1) 241 — Sempra LNG Other long-term debt (uncollateralized): Notes at 2.87% to 3.51% October 1, 2026 (1) — 22 Loan at variable rates (2.82% at December 31, 2020) December 9, 2025 (1) 17 — 11,247 12,298 Current portion of long-term debt (919) (1,464) Unamortized discount on long-term debt (55) (35) Unamortized debt issuance costs (121) (108) Total other Sempra Energy 10,152 10,691 Total Sempra Energy Consolidated $ 21,781 $ 20,785 (1) Callable long-term debt not subject to make-whole provisions. The following table shows the detail and maturities of long-term debt outstanding: LONG-TERM DEBT (Dollars in millions) December 31, 2020 2019 2.4% Notes February 1, 2020 $ — $ 500 2.4% Notes March 15, 2020 — 500 2.85% Notes November 15, 2020 — 400 Notes at variable rates (2.50% at December 31, 2019) January 15, 2021 (1) — 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) 758 758 8,258 10,358 Current portion of long-term debt (850) (1,399) Unamortized discount on long-term debt (32) (35) Unamortized debt issuance costs (59) (68) Total long-term debt $ 7,317 $ 8,856

SIGNIFICANT ACCOUNTING POLICI_4

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details) - segment	3 Months Ended	21 Months Ended
	Mar. 31, 2019	Dec. 31, 2020
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, 2020
Oncor Electric Delivery Company LLC [Member] | Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Utilities [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	80.25%
Sharyland Utilities, 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, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Presentation Of Restricted Cash [Line Items]
Cash and cash equivalents	$ 960	$ 108
Restricted cash, current	22	31
Restricted cash, noncurrent	3	3
Cash, cash equivalents and restricted cash in discontinued operations	0	75
Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows	985	217	$ 246	$ 364
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Presentation Of Restricted Cash [Line Items]
Cash, cash equivalents and restricted cash in discontinued operations		1
Cash and cash equivalents	$ 4,600	$ 74

SIGNIFICANT ACCOUNTING POLICI_7

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	$ 29	$ 21	$ 25
Provisions for expected credit losses	124	22	10
Write-offs	(16)	(14)	(14)
Allowances for credit losses at December 31	138	29	21
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1, 2020	0
Reduction to expected credit losses	(3)
Allowances for credit losses at December 31, 2020	3	0
Sempra LNG [Member]
Off-Balance Sheet, Credit Loss, Liability [Roll Forward]
Maximum exposure of guarantor obligations	4,000
Reduction of credit loss liability	(4)
Accounts Receivable, Trade, Net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	7
Allowances for credit losses at December 31	111	7
Accounts receivable – other, net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	22
Allowances for credit losses at December 31	27	22
Due from Unconsolidated Affiliates - Noncurrent [Member]
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at December 31, 2020	3
Current liabilities: Other [Member] | Sempra LNG [Member]
Off-Balance Sheet, Credit Loss, Liability [Roll Forward]
Liability for credit losses	2
Cumulative Effect, Period of Adoption, Adjustment
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	1	0	0
Allowances for credit losses at December 31		1	0
Financing Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1, 2020	6
Allowances for credit losses at December 31, 2020		6
Cumulative Effect, Period of Adoption, Adjustment | Sempra LNG [Member]
Off-Balance Sheet, Credit Loss, Liability [Roll Forward]
Liability for credit losses		6
San Diego Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	14	11	9
Provisions for expected credit losses	65	10	9
Write-offs	(10)	(7)	(7)
Allowances for credit losses at December 31	69	14	11
San Diego Gas and Electric Company [Member] | Accounts Receivable, Trade, Net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	4
Allowances for credit losses at December 31	55	4
San Diego Gas and Electric Company [Member] | Accounts receivable – other, net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	10
Allowances for credit losses at December 31	14	10
Southern California Gas Company [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	15	10	16
Provisions for expected credit losses	59	12	1
Write-offs	(6)	(7)	(7)
Allowances for credit losses at December 31	68	15	$ 10
Southern California Gas Company [Member] | Accounts Receivable, Trade, Net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	3
Allowances for credit losses at December 31	55	3
Southern California Gas Company [Member] | Accounts receivable – other, net [Member]
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowances for credit losses at January 1	12
Allowances for credit losses at December 31	$ 13	$ 12

SIGNIFICANT ACCOUNTING POLICI_8

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Inventory [Line Items]
Natural gas	$ 118	$ 110
LNG	7	9
Materials and supplies	183	158
Inventories	308	277
SDG&E [Member]
Inventory [Line Items]
Natural gas	0	1
LNG	0	0
Materials and supplies	104	93
Inventories	104	94
SoCalGas [Member]
Inventory [Line Items]
Natural gas	94	90
LNG	0	0
Materials and supplies	59	46
Inventories	$ 153	$ 136

SIGNIFICANT ACCOUNTING POLICI_9

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details) - USD ($)	1 Months Ended	12 Months Ended
	Jul. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Loss Contingencies [Line Items]
Noncurrent portion of the Wildfire Fund asset		$ 363,000,000	$ 392,000,000
San Diego Gas and Electric Company [Member]
Loss Contingencies [Line Items]
Initial liability cap		950,000,000
Initial shareholder contributions		322,500,000		$ 322,500,000
Additional annual contributions, aggregate value		129,000,000
Wildfire fund asset				$ 451,500,000
Annual contributions		12,900,000
Wildfire fund obligations in current liabilities		$ 13,000,000	13,000,000
Amortization of wildfire fund asset		15 years
Current portion of Wildfire fund		$ 29,000,000	29,000,000
Noncurrent portion of the Wildfire Fund asset		363,000,000	392,000,000
Noncurrent Wildfire Fund obligation		75,000,000	86,000,000
Amortization of Wildfire Fund asset		29,000,000	12,000,000
Accretion of Wildfire Fund obligation		2,000,000	$ 1,000,000
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]
Wildfire fund, threshold amount to seek payment	$ 1,000,000,000
Wildfire fund, threshold percentage of equity portion of electric transmission	20.00%
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
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

SIGNIFICANT ACCOUNTING POLIC_10

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PROPERTY, PLANT, AND EQUIPMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 53,928	$ 49,329
Depreciation expense	1,646	1,551	$ 1,470
Accumulated depreciation	13,925	12,877
San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	24,436	22,504
Depreciation expense	797	757	686
Accumulated depreciation	6,015	5,537
Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	21,180	19,362
Depreciation expense	649	598	$ 553
Accumulated depreciation	6,437	6,038
Natural gas operations [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,805	$ 2,534
Depreciation rates (percentage)	2.51%	2.47%	2.44%
Accumulated depreciation	$ 870	$ 832
Natural gas operations [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 19,961	$ 18,370
Depreciation rates (percentage)	3.63%	3.60%	3.60%
Accumulated depreciation	$ 6,422	$ 6,023
Electric distribution [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 8,592	$ 7,985
Depreciation rates (percentage)	3.90%	3.94%	3.91%
Electric transmission [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 7,156	$ 6,577
Depreciation rates (percentage)	3.10%	2.79%	2.76%
Electric generation [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 2,440	$ 2,415
Depreciation rates (percentage)	4.56%	4.50%	4.12%
Other electric [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,743	$ 1,492
Depreciation rates (percentage)	6.92%	6.61%	6.43%
Construction work in progress [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,700	$ 1,501
Construction work in progress [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	1,174	958
Other non-utility [Member] | Southern California Gas Company [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 45	$ 34
Depreciation rates (percentage)	3.80%	5.08%	5.39%
Accumulated depreciation	$ 15	$ 15
Other non-utility [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	1,473	1,302
Land and land rights [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 283	278
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	$ 1,288	1,154
Generating plants [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	11 years
Generating plants [Member] | Maximum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	25 years
Generating plants [Member] | Weighted Average [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	22 years
LNG terminals [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,138	1,134
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	$ 3,482	3,596
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	44 years
Other [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 359	180
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	14 years
Construction work in progress [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 1,514	895
Other [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 248	226
Other [Member] | Minimum [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Estimated useful life	4 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	23 years
Total Other Operating Units And Parent [Member] | Other Operating Units and Parent [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment	$ 8,312	7,463
Plant, pipeline and other distribution assets of ecogas [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	51	49
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	191	178
Electricity [Member] | San Diego Gas and Electric Company [Member]
Property, Plant and Equipment [Line Items]
Accumulated depreciation	5,145	$ 4,705
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	505
Accumulated depreciation	277
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	$ 9
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 (as a percent)	88.00%

SIGNIFICANT ACCOUNTING POLIC_11

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CAPITALIZED FINANCING COSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 202	$ 183	$ 193
San Diego Gas and Electric Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	104	75	82
Southern California Gas Company [Member]
Capitalized Financing Costs Disclosure [Line Items]
Total capitalized financing costs	$ 55	$ 47	$ 48

SIGNIFICANT ACCOUNTING POLIC_12

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 1,602	$ 1,602
Total intangible assets, gross	250	250
Accumulated amortization	(48)	(37)
Other intangible assets	202	213
Intangible assets amortization expense	11	11	$ 16
Expected amortization, year one	12
Expected amortization, year two	12
Expected amortization, year three	12
Expected amortization, year four	12
Expected amortization, year five	$ 12
Renewable energy and consumption permit [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period	19 years
Intangible assets, gross	$ 154	154
Accumulated amortization	$ (32)	(24)
O&M agreement [Member]
Finite-Lived Intangible Assets [Line Items]
Amortization period	23 years
Intangible assets, gross	$ 66	66
Accumulated amortization	(9)	(6)
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)	Mar. 09, 2018	Oct. 03, 2019MW	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Variable Interest Entity [Line Items]
Total finance leases			$ 1,330,000,000	$ 1,289,000,000
Property, plant and equipment, net			40,003,000,000	36,452,000,000
Equity method investment			12,440,000,000	11,519,000,000
Assets			66,623,000,000	65,665,000,000	$ 60,638,000,000
San Diego Gas and Electric Company [Member]
Variable Interest Entity [Line Items]
Total finance leases			1,276,000,000	1,270,000,000
Property, plant and equipment, net			18,421,000,000	16,967,000,000
Assets			22,311,000,000	20,560,000,000
San Diego Gas and Electric Company [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total finance leases			1,237,000,000	1,255,000,000
Property, plant and equipment, net			1,237,000,000	1,255,000,000
Sempra Energy [Member] | ECA LNG JV [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Assets			207,000,000
Liabilities			49,000,000
Sempra Mexico [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Assets				126,000,000
Sempra LNG [Member]
Variable Interest Entity [Line Items]
Debt instrument, maximum borrowing amount			4,000,000,000
Sempra LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Debt instrument, maximum borrowing amount			979,000,000
Sempra LNG [Member] | Cameron LNG Holdings [Member]
Variable Interest Entity [Line Items]
Equity method investment			433,000,000	1,256,000,000
Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Utilities [Member]
Variable Interest Entity [Line Items]
Equity method investment			$ 12,440,000,000	$ 11,519,000,000
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Variable Interest Entity [Line Items]
Ownership percentage in consolidated entity	100.00%		100.00%
Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Variable Interest Entity [Line Items]
Ownership percentage in consolidated entity	100.00%
Otay Mesa VIE [Member] | San Diego Gas and Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Generating capacity (in mw) | MW		605

SIGNIFICANT ACCOUNTING POLIC_14

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 3,083	$ 2,972
Accretion expense	127	123
Liabilities incurred	2	2
Deconsolidation	0	(2)
Payments	(63)	(46)
Revisions	140	34
Ending Balance	3,289	3,083
San Diego Gas and Electric Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	866	874
Accretion expense	39	39
Liabilities incurred	0	0
Deconsolidation	0	(2)
Payments	(60)	(44)
Revisions	31	(1)
Ending Balance	876	866
Southern California Gas Company [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	2,177	2,063
Accretion expense	86	81
Liabilities incurred	0	0
Deconsolidation	0	0
Payments	(2)	(2)
Revisions	107	35
Ending Balance	$ 2,368	$ 2,177

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, 2020	Dec. 31, 2019	Dec. 31, 2018
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	$ 19,929
AOCI, ending balance	23,373	$ 19,929
San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	7,100
AOCI, ending balance	7,730	7,100
Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	4,748
AOCI, ending balance	5,144	4,748
Foreign currency translation adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(607)	(564)	$ (420)
OCI before reclassifications	(102)	(43)	(144)
Amounts reclassified from AOCI	645	0	0
Total other comprehensive income (loss)	543	(43)	(144)
AOCI, ending balance	(64)	(607)	(564)
Foreign currency translation adjustments [Member] | Sempra Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI associated with noncontrolling interests	4
Foreign currency translation adjustments [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		0	0
AOCI, ending balance			0
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(215)	(82)	(122)
OCI before reclassifications	(163)	(116)	40
Amounts reclassified from AOCI	47	8	3
Total other comprehensive income (loss)	(116)	(108)	43
AOCI, ending balance	(331)	(215)	(82)
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | Sempra Mexico [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI associated with noncontrolling interests	3
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(25)	(3)
AOCI, ending balance			(25)
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(13)	(12)	(13)
OCI before reclassifications	0	0	0
Amounts reclassified from AOCI	0	1	1
Total other comprehensive income (loss)	0	1	1
AOCI, ending balance	(13)	(13)	(12)
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | Southern California Gas Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(2)
AOCI, ending balance			(2)
Pension and other postretirement benefits [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(117)	(118)	(84)
OCI before reclassifications	(26)	(18)	(52)
Amounts reclassified from AOCI	38	36	18
Total other comprehensive income (loss)	12	18	(34)
AOCI, ending balance	(105)	(117)	(118)
Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI	3
Pension and other postretirement benefits [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI		4
Pension and other postretirement benefits [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(17)	0
AOCI, ending balance			(17)
Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(16)	(10)	(8)
OCI before reclassifications	(4)	(5)	(6)
Amounts reclassified from AOCI	10	1	4
Total other comprehensive income (loss)	6	(4)	(2)
AOCI, ending balance	(10)	(16)	(10)
Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI	6
Pension and other postretirement benefits [Member] | San Diego Gas and Electric Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(2)
AOCI, ending balance			(2)
Pension and other postretirement benefits [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(10)	(8)	(8)
OCI before reclassifications	(10)	(4)	(1)
Amounts reclassified from AOCI	2	4	1
Total other comprehensive income (loss)	(8)	0	0
AOCI, ending balance	(18)	(10)	(8)
Pension and other postretirement benefits [Member] | Southern California Gas Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(2)
AOCI, ending balance			(2)
Accumulated other comprehensive income (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(939)	(764)	(626)
OCI before reclassifications	(291)	(177)	(156)
Amounts reclassified from AOCI	730	44	21
Total other comprehensive income (loss)	439	(133)	(135)
AOCI, ending balance	(500)	(939)	(764)
Accumulated other comprehensive income (loss) [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(42)	(3)
AOCI, ending balance			(42)
Accumulated other comprehensive income (loss) [Member] | San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(16)	(10)	(8)
OCI before reclassifications	(4)	(5)	(6)
Amounts reclassified from AOCI	10	1	4
Total other comprehensive income (loss)	6	(4)	(2)
AOCI, ending balance	(10)	(16)	(10)
Accumulated other comprehensive income (loss) [Member] | San Diego Gas and Electric Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		(2)
AOCI, ending balance			(2)
Accumulated other comprehensive income (loss) [Member] | Southern California Gas Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(23)	(20)	(21)
OCI before reclassifications	(10)	(4)	(1)
Amounts reclassified from AOCI	2	5	2
Total other comprehensive income (loss)	(8)	1	1
AOCI, ending balance	$ (31)	(23)	(20)
Accumulated other comprehensive income (loss) [Member] | Southern California Gas Company [Member] | Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance		$ (4)
AOCI, ending balance			$ (4)

SIGNIFICANT ACCOUNTING POLIC_16

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from discontinued operations, net of income tax									$ 1,840	$ 328	$ 156
(Loss) gain on sale of assets									(3)	63	513
Interest expense									(1,081)	(1,077)	(886)
Equity earnings									1,015	580	175
Energy-related businesses									1,345	1,381	1,563
Other (expense) income, net									48	(77)	(58)
Income before income taxes									1,489	1,734	714
Income tax (expense) benefit									(249)	(315)	49
Income from continuing operations, net of income tax									2,255	1,999	938
Earnings attributable to noncontrolling interest									(172)	(164)	(76)
Total reclassifications for the period, net of tax	$ 414	$ 351	$ 2,239	$ 760	$ 447	$ 813	$ 354	$ 441
San Diego Gas and Electric Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense									(413)	(411)	(221)
Other (expense) income, net									(52)	(39)	(56)
Income before income taxes									1,014	945	849
Income tax (expense) benefit									(190)	(171)	(173)
Earnings attributable to noncontrolling interest					$ 0	$ (3)	$ (3)	$ (1)	0	(7)	(7)
Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense									(158)	(141)	(115)
Other (expense) income, net									28	55	(15)
Income before income taxes									601	762	493
Income tax (expense) benefit									(96)	(120)	(92)
Reclassification out of Accumulated Other Comprehensive Income [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications for the period, net of tax									721	40	21
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]
Total reclassifications for the period, net of tax									1	1	4
Reclassification out of Accumulated Other Comprehensive Income [Member] | Southern California Gas Company [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications for the period, net of tax									2	1	2
Reclassification out of Accumulated Other Comprehensive Income [Member] | Foreign currency translation adjustments [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from discontinued operations, net of income tax									645	0	0
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									67	11	13
Income tax (expense) benefit									(19)	(2)	(4)
Income from continuing operations, net of income tax									48	9	9
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									1	0	(1)
Other (expense) income, net									11	(9)	(2)
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]
(Loss) gain on sale of assets									0	10	9
Interest expense									10	3	1
Equity earnings									46	3	9
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									0	3	7
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]
Equity earnings									0	2	(2)
Energy-related businesses									(1)	2	(1)
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)	(1)	(6)
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									0	(3)	(7)
Reclassification out of Accumulated Other Comprehensive Income [Member] | Financial instruments attributable to parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Total reclassifications for the period, net of tax									47	8	3
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]
Total reclassifications for the period, net of tax									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									0	1	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Amortization of actuarial loss [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from discontinued operations, net of income tax									6	1	1
Other (expense) income, net									8	12	11
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 (expense) income, net									1	0	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 (expense) income, net									1	1	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 (expense) income, net									4	3	2
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 (expense) income, net									1	1	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 (expense) income, net									1	0	1
Reclassification out of Accumulated Other Comprehensive Income [Member] | Accumulated Defined Benefit Plans Adjustment, Net Settlements Attributable to Parent [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net									22	28	12
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 (expense) income, net									0	0	4
Reclassification out of Accumulated Other Comprehensive Income [Member] | Pension and other postretirement benefits [Member]
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income (loss) from discontinued operations, net of income tax									(2)	0	0
Income before income taxes									40	44	26
Income tax (expense) benefit									(9)	(12)	(8)
Income from continuing operations, net of income tax									29	32	18
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									2	1	5
Income tax (expense) benefit									(1)	0	(1)
Income from continuing operations, net of income tax									1	1	4
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									2	1	1
Income tax (expense) benefit									0	(1)	0
Income from continuing operations, net of income tax									$ 2	$ 0	$ 1

SIGNIFICANT ACCOUNTING POLIC_17

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS (Details) $ in Millions	Dec. 02, 2020	Mar. 30, 2020USD ($)	Feb. 07, 2019	Jan. 01, 2019USD ($)	Dec. 31, 2020	Feb. 28, 2019USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2020USD ($)shares	Dec. 31, 2019USD ($)shares	Dec. 31, 2018USD ($)
Noncontrolling Interest [Line Items]
Stock repurchased in the period								$ 566	$ 26	$ 21
Equitization of long-term debt for deficit held by NCI								(22)
Sempra Mexico [Member] | IEnova [Member]
Noncontrolling Interest [Line Items]
Stock repurchased in the period							$ 9	$ 231	$ 10
Stock repurchased during the period (in shares) | shares								77,122,780	2,620,000
Sempra Mexico [Member] | IEnova [Member]
Noncontrolling Interest [Line Items]
Acquired percentage interest	100.00%
Common stock exchange ratio	0.0313
IEnova [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)					70.20%			70.20%	66.60%	66.50%
Ownership percentage held by noncontrolling owners					29.80%			29.80%	33.40%
IEnova [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage sold					16.60%
Ownership percentage after sale					41.70%			41.70%
Bay Gas [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)									9.10%
Cash consideration (fair value of total consideration)						$ 20
Bay Gas [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Cash consideration (fair value of total consideration)				$ 20
ICM Ventures Holdings B.V. [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)							82.50%		53.70%
Liberty Gas Storage [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		24.60%			0.00%			0.00%	24.60%
LA Storage [Member] | Liberty Gas Storage, LLC [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		100.00%
Bay Gas [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Sale of interest (as a percent)			100.00%
Liberty Gas Storage, LLC [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Payments to acquire minority interest		$ 7
Equitization of long-term debt for deficit held by NCI		22
Increase from equity of noncontrolling interest		$ 2
Liberty Gas Storage, LLC [Member] | Liberty Gas Storage [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners					100.00%			100.00%

SIGNIFICANT ACCOUNTING POLIC_18

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Mar. 30, 2020	Dec. 31, 2019
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 1,541		$ 1,856
IEnova [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	29.80%		33.40%
Other noncontrolling interests	$ 1,487		$ 1,608
IEnova subsidiaries [Member] | Sempra Mexico [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	17.50%
Other noncontrolling interests	$ 7		$ 15
IEnova subsidiaries [Member] | Sempra Mexico [Member] | Minimum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners			10.00%
IEnova subsidiaries [Member] | Sempra Mexico [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners			46.30%
Liberty Gas Storage [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.00%	24.60%	24.60%
Other noncontrolling interests	$ 0		$ (13)
ECA LNG JV [Member] | Sempra LNG [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	29.00%		16.70%
Other noncontrolling interests	$ 46		$ 12
PXISE Energy Solutions LLC [Member] | Corporate and Other [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	20.00%		20.00%
Other noncontrolling interests	$ 1		$ 1
Chilquinta Energia subsidiaries [Member] | Discontinued Operations, Held-for-sale [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.00%
Other noncontrolling interests	$ 0		$ 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%
Chilquinta Energia subsidiaries [Member] | Discontinued Operations, Held-for-sale [Member] | Maximum [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners			43.40%
Luz Del Sur [Member] | Discontinued Operations, Held-for-sale [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.00%		16.40%
Other noncontrolling interests	$ 0		$ 205
Tecsur [Member] | Discontinued Operations, Held-for-sale [Member]
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.00%		9.80%
Other noncontrolling interests	$ 0		$ 5

SIGNIFICANT ACCOUNTING POLIC_19

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Foreign currency transaction losses (gains), net	$ (25)	$ 21	$ (6)

SIGNIFICANT ACCOUNTING POLIC_20

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details)	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2020MXN ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 20,000,000	$ 32,000,000
Due from unconsolidated affiliates - noncurrent	780,000,000	742,000,000
Due to unconsolidated affiliates, noncurrent	(234,000,000)	(195,000,000)
Due to unconsolidated affiliates - current	$ (45,000,000)	(5,000,000)
TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Related party transaction rate	3.16%
Due to/from Various Affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ (4,000,000)	(5,000,000)
LIBOR [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Variable percentage rate	1.96%
Related party transaction rate	2.11%
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	$ (234,000,000)	(195,000,000)
Sempra Mexico [Member] | ESJ joint venture [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	85,000,000	0
Accrued interest receivable	1,000,000
Sempra Mexico [Member] | IMG [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	695,000,000	742,000,000
Due from affiliates, allowance for credit loss	3,000,000
Total facility	712,000,000		$ 14,200,000,000
Accrued interest receivable	2,000,000
Sempra Mexico [Member] | Due From Sempra Mexico [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	780,000,000	742,000,000
Sempra Mexico [Member] | TAG Pipeline Norte [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ 0	(39,000,000)
Stated percentage rate	5.50%		5.50%
Sempra Mexico [Member] | TAG Pipeline Norte [Member] | Other Long term Debt Currently Through December 2021 [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (41,000,000)	0
Sempra Mexico [Member] | TAG Pipeline Norte [Member] | Other Long term Debt Currently Through January 2024 [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	(68,000,000)	0
Sempra Mexico [Member] | TAG JV Notes [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (166,000,000)	(156,000,000)
Stated percentage rate	5.74%		5.74%
Sempra Mexico [Member] | Interbank Equilibrium Rate [Member] | IMG [Member]
Related Party Transaction [Line Items]
Variable percentage rate	2.20%
Related party transaction rate	6.66%
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ (64,000,000)	(53,000,000)
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	(38,000,000)	(37,000,000)
Income taxes due (from) Sempra Energy	0	130,000,000
San Diego Gas and Electric Company [Member] | Due to/from SoCalGas [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(21,000,000)	(10,000,000)
San Diego Gas and Electric Company [Member] | Due to/from Various Affiliates [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(5,000,000)	(6,000,000)
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	22,000,000	11,000,000
Due to unconsolidated affiliates - current	(31,000,000)	(47,000,000)
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	(31,000,000)	(45,000,000)
Income taxes due (from) Sempra Energy	(37,000,000)	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	21,000,000	10,000,000
Southern California Gas Company [Member] | Other related parties [Member]
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	$ 0	$ (2,000,000)

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, 2020USD ($)MW	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Related Party Transaction [Line Items]
Related party revenue	$ 37	$ 52	$ 64
Related party cost of sales	45	50	46
Interest Income, Related Party	56	74	62
Interest Expense, Related Party	14	2	2
San Diego Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Related party revenue	6	6	5
Related party cost of sales	79	74	73
Southern California Gas Company [Member]
Related Party Transaction [Line Items]
Related party revenue	88	69	64
Related party cost of sales	$ 0	$ 8	$ 0
Minimum [Member] | Federal Funds Rate [Member] | California Utilities [Member]
Related Party Transaction [Line Items]
Variable percentage rate	13.00%
Maximum [Member] | Federal Funds Rate [Member] | California Utilities [Member]
Related Party Transaction [Line Items]
Variable percentage rate	20.00%
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) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)
Significant Restrictions of Subsidiaries [Line Items]
Undistributed earnings from equity method investments	$ 1,100	$ 634
Sempra Texas Utilities [Member] | Oncor Electric Delivery Holdings Company LLC [Member]
Significant Restrictions of Subsidiaries [Line Items]
Plan percentage of capital structure allocated to equity	42.50%
Plan percentage of capital structure allocated to debt	57.50%
Maximum ratio of indebtedness to total capitalization	0.65
Ownership percentage in equity method investee	100.00%
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	$ 185
Sempra Mexico [Member] | IEnova Pipelines [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	12
Sempra Mexico [Member] | Ventika [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	9
Sempra Mexico [Member] | Energia Sierra Juarez Wind Project [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 7
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	$ 73
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	$ 452
Consolidated Entities [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	12,200
Unconsolidated Entities [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	12,600
San Diego Gas and Electric Company [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	7,000
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 717
Plan percentage of capital structure allocated to equity	52.00%
Southern California Gas Company [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 5,000
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 148
Plan percentage of capital structure allocated to 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	$ 114
Plan percentage of capital structure allocated to debt	55.00%
Maximum ratio of indebtedness to total capitalization	0.70
Ownership percentage in equity method investee	100.00%
Oncor Electric Delivery Company LLC [Member]
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 11,900

SIGNIFICANT ACCOUNTING POLIC_23

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER (EXPENSE) INCOME, NET (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jan. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Other Income [Line Items]
Allowance for equity funds used during construction		$ 128	$ 94	$ 98
Investment gains (losses)		41	61	(6)
(Losses) gains on interest rate and foreign exchange instruments, net		(67)	34	7
Foreign currency transaction losses (gains), net		(25)	21	(6)
Non-service component of net periodic benefit cost		(102)	(132)	(35)
Fine related to Energy Efficiency Program Inquiry		(6)	0	0
Penalties related to billing practices OII		0	(8)	0
Interest on regulatory balancing accounts, net		14	14	2
Sundry, net		(31)	(7)	(2)
Total		(48)	77	58
San Diego Gas and Electric Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		79	56	61
Non-service component of net periodic benefit cost		(20)	(20)	(6)
Fine related to Energy Efficiency Program Inquiry		(6)	0	0
Interest on regulatory balancing accounts, net		9	13	4
Sundry, net		(10)	(10)	(3)
Total		52	39	56
Southern California Gas Company [Member]
Other Income [Line Items]
Allowance for equity funds used during construction		41	34	36
Non-service component of net periodic benefit cost		(54)	(72)	(10)
Penalties related to billing practices OII	$ (8)	0	(8)	0
Interest on regulatory balancing accounts, net		5	1	(2)
Sundry, net		(20)	(10)	(9)
Total		(28)	(55)	15
Sempra Mexico [Member] | IMG [Member]
Other Income [Line Items]
Foreign currency transaction losses (gains), net		$ (42)	$ 30	$ (3)

NEW ACCOUNTING STANDARDS (Detai

NEW ACCOUNTING STANDARDS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Deferred income taxes	$ 136	$ 155
Other current liabilities	1,016	866
Deferred credits and other	2,119	2,062
Retained earnings	13,673	11,130
Other noncontrolling interests	$ 1,541	1,856
Accounting Standards Update 2016-13 [Member] | Cumulative Effect, Period of Adoption, Adjustment
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Accounts receivable – trade, net		(1)
Due from unconsolidated affiliates – noncurrent		(6)
Deferred income taxes		4
Other current liabilities		4
Deferred credits and other		2
Retained earnings		(7)
Other noncontrolling interests		$ (2)

REVENUES - DISAGGREGATION OF RE

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ 10,310	$ 10,141	$ 9,447
Utilities regulatory revenues									570	264	165
Other revenues									490	424	490
Total revenues	$ 3,171	$ 2,644	$ 2,526	$ 3,029	$ 2,943	$ 2,758	$ 2,230	$ 2,898	11,370	10,829	10,102
Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									9,455	9,184	8,374
Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									855	957	1,073
Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									5,796	5,596	4,800
Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,514	4,545	4,647
Operating Segments [Member] | San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,920	4,819	4,788
Utilities regulatory revenues									393	106	(220)
Other revenues									0	0	0
Total revenues									5,313	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									4,920	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	0
Operating Segments [Member] | San Diego Gas and Electric Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									692	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									4,228	4,232	4,297
Operating Segments [Member] | Southern California Gas Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,571	4,367	3,577
Utilities regulatory revenues									177	158	385
Other revenues									0	0	0
Total revenues									4,748	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									4,571	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	0
Operating Segments [Member] | Southern California Gas Company [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									4,571	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	0
Operating Segments [Member] | Sempra Mexico [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									892	992	1,019
Utilities regulatory revenues									0	0	0
Other revenues									364	383	357
Total revenues									1,256	1,375	1,376
Operating Segments [Member] | Sempra Mexico [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									58	73	78
Operating Segments [Member] | Sempra Mexico [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									834	919	941
Operating Segments [Member] | Sempra Mexico [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									603	680	711
Operating Segments [Member] | Sempra Mexico [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									289	312	308
Operating Segments [Member] | Sempra LNG [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									92	176	232
Utilities regulatory revenues									0	0	0
Other revenues									282	234	240
Total revenues									374	410	472
Operating Segments [Member] | Sempra LNG [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0	0
Operating Segments [Member] | Sempra LNG [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									92	176	232
Operating Segments [Member] | Sempra LNG [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									86	170	224
Operating Segments [Member] | Sempra LNG [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									6	6	8
Operating Segments [Member] | Sempra Renewables [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	5	46
Utilities regulatory revenues									0	0	0
Other revenues									0	5	78
Total revenues									0	10	124
Operating Segments [Member] | Sempra Renewables [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	5	46
Operating Segments [Member] | Sempra Renewables [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	0	0
Operating Segments [Member] | Sempra Renewables [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									0	5	46
Consolidation, Eliminations [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(165)	(218)	(215)
Utilities regulatory revenues									0	0	0
Other revenues									(156)	(198)	(185)
Total revenues									(321)	(416)	(400)
Consolidation, Eliminations [Member] | Utilities service line [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(94)	(75)	(69)
Consolidation, Eliminations [Member] | Energy-Related Businesses [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(71)	(143)	(146)
Consolidation, Eliminations [Member] | Gas market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									(156)	(208)	(203)
Consolidation, Eliminations [Member] | Electric market [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers									$ (9)	$ (10)	$ (12)

REVENUES - PERFORMANCE OBLIGATI

REVENUES - PERFORMANCE OBLIGATIONS (Details) $ in Millions	Dec. 31, 2020USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 6,260
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	$ 387
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	$ 407
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	$ 348
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	$ 351
Revenues to be recognized, period of recognition	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 4,361
Revenues to be recognized, period of recognition
San Diego Gas and Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 87
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	$ 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]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenues to be recognized	$ 67
Revenues to be recognized, period of recognition

REVENUES - CONTRACT LIABILITIES

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Contract with Customer, Liability [Roll Forward]
Beginning balance	$ (163)	$ (70)	$ 0
Revenue from performance obligations satisfied during reporting period	4	2	7
Payments received in advance	(48)	(95)	(16)
Ending balance	(207)	(163)	(70)
Cumulative Effect, Period of Adoption, Adjustment
Contract with Customer, Liability [Roll Forward]
Beginning balance	0	0	(61)
Ending balance		0	0
Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	(4)
Ending balance	(52)	(4)
Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	(159)
Ending balance	(155)	(159)
San Diego Gas and Electric Company [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	(91)	0
Revenue from performance obligations satisfied during reporting period	4	1
Payments received in advance	0	(92)
Ending balance	(87)	(91)	$ 0
San Diego Gas and Electric Company [Member] | Other Current Liabilities [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	(4)
Ending balance	(4)	(4)
San Diego Gas and Electric Company [Member] | Deferred Credits and Other [Member]
Contract with Customer, Liability [Roll Forward]
Beginning balance	(87)
Ending balance	$ (83)	$ (87)

REVENUES - RECEIVABLES FROM REV

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,462	$ 1,184
Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,447	1,163
Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	12	16
Due from unconsolidated affiliates – current [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	3	5
San Diego Gas and Electric Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	583	405
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	573	398
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	8	5
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	2
Southern California Gas Company [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	790	721
Southern California Gas Company [Member] | Accounts receivable – trade, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	786	710
Southern California Gas Company [Member] | Accounts receivable – other, net [Member]
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 4	$ 11

REGULATORY MATTERS - REGULATORY

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Amortization of Regulatory Asset	$ 9	$ 7	$ 5
Net Regulatory Assets (Liabilities) Sempra Energy Consolidated [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,500)	(1,908)
San Diego Gas and Electric Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	139	108
Amortization of Regulatory Asset	4	3	2
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)	(53)	8
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)	22	(108)
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)	50	103
San Diego Gas and Electric Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(2,121)	(2,056)
San Diego Gas and Electric Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	56	45
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	121
Regulatory Asset, Amortization Period	49 years
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)	$ 72	102
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)	35	22
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)	67	77
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)	(158)	(124)
San Diego Gas and Electric Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	56	111
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)	233	106
San Diego Gas and Electric Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	72	(153)
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)	(1,548)	(1,746)
Southern California Gas Company [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	218	500
Amortization of Regulatory Asset	5	4	$ 3
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)	(82)	(203)
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)	417	400
Southern California Gas Company [Member] | Employee benefit costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	37	44
Southern California Gas Company [Member] | Removal obligations [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(685)	(728)
Southern California Gas Company [Member] | Environmental costs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	36	40
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Safety and reliability [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	335	295
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Public purpose programs [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(253)	(273)
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Commodity - gas including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(56)	(118)
Southern California Gas Company [Member] | GRC retroactive impacts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	202	400
Southern California Gas Company [Member] | Regulatory Balancing Accounts, Other balancing accounts [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(58)	(7)
Southern California Gas Company [Member] | Other regulatory (liabilities) assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	75	(101)
Southern California Gas Company [Member] | Net Regulatory Assets (Liabilities) SoCalGas [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(32)	(251)
Sempra Mexico [Member] | Deferred income taxes (refundable) recoverable in rates [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	80	83
Sempra Mexico [Member] | Other Regulatory Assets [Member]
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 0	$ 6

REGULATORY MATTERS - SCHEDULE O

REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE AUTHORIZED REVENUE INCREASES (Details) - USD ($) $ in Millions	Sep. 26, 2019	Apr. 30, 2020
San Diego Gas and Electric Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability		$ 86
Southern California Gas Company [Member] | General Rate Case [Member]
General Rate Case [Line Items]
Tracked income tax expense liability		89
2019 GRC FD [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC revenue requirement	$ 1,990
2019 GRC FD [Member] | San Diego Gas and Electric Company [Member] | Electricity [Member]
General Rate Case [Line Items]
GRC revenue requirement	1,590
2019 GRC FD [Member] | San Diego Gas and Electric Company [Member] | Natural Gas, Gathering, Transportation, Marketing and Processing [Member]
General Rate Case [Line Items]
GRC revenue requirement	400
2019 GRC FD [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC revenue requirement	2,770
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%
2019 GRC FD - 2022 Requirement [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC revenue requirement		91
2019 GRC FD - 2022 Requirement [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC revenue requirement		150
2019 GRC FD - 2023 Requirement [Member] | San Diego Gas and Electric Company [Member]
General Rate Case [Line Items]
GRC revenue requirement		104
2019 GRC FD - 2023 Requirement [Member] | Southern California Gas Company [Member]
General Rate Case [Line Items]
GRC revenue requirement		$ 131

REGULATORY MATTERS - COST OF CA

REGULATORY MATTERS - COST OF CAPITAL & FERC RATES (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended		36 Months Ended
	Jan. 31, 2020	Oct. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2022
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Minimum common equity ratio (as a percent)		10.60%
FERC requirement to maintain common equity ratio at or above, base (as a percent)		10.10%
FERC requirement, additional basis spread		0.50%
FERC, revenue requirement			$ 12
San Diego Gas and Electric Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate (as a percent)			4.498%
San Diego Gas and Electric Company [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
FERC requirement, additional basis spread		0.50%
FERC, revenue requirement			$ 17
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%
San Diego Gas and Electric Company [Member] | Capital Structure, Common Equity [Member] | Federal Energy Regulatory Commission [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				10.05%
Southern California Gas Company [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate (as a percent)			4.029%
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] | authorized weighting | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Debt Capital Structure, Percentage					45.25%
Forecast [Member] | San Diego Gas and Electric Company [Member] | authorized weighting | California Public Utilities Commission [Member] | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					2.75%
Forecast [Member] | San Diego Gas and Electric Company [Member] | authorized weighting | California Public Utilities Commission [Member] | Capital Structure, Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					52.00%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Return on Rate Base | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Debt Capital Structure, Percentage					4.59%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Return on Rate Base | California Public Utilities Commission [Member] | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					6.22%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Return on Rate Base | California Public Utilities Commission [Member] | Capital Structure, Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					10.20%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Debt Capital Structure, Percentage					2.08%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission [Member] | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					0.17%
Forecast [Member] | San Diego Gas and Electric Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission [Member] | Capital Structure, Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Return on Equity, Percentage					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] | authorized weighting | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Debt Capital Structure, Percentage					45.60%
Forecast [Member] | Southern California Gas Company [Member] | authorized weighting | California Public Utilities Commission [Member] | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)					2.40%
Forecast [Member] | Southern California Gas Company [Member] | authorized weighting | California Public Utilities Commission [Member] | Capital Structure, Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)					52.00%
Forecast [Member] | Southern California Gas Company [Member] | Return on Rate Base | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Debt Capital Structure, Percentage					4.23%
Forecast [Member] | Southern California Gas Company [Member] | Return on Rate Base | California Public Utilities Commission [Member] | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)					6.00%
Forecast [Member] | Southern California Gas Company [Member] | Return on Rate Base | California Public Utilities Commission [Member] | Capital Structure, Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)					10.05%
Forecast [Member] | Southern California Gas Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Public Utilities, Approved Debt Capital Structure, Percentage					1.93%
Forecast [Member] | Southern California Gas Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission [Member] | Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)					0.14%
Forecast [Member] | Southern California Gas Company [Member] | Weighted Return on Rate Base | California Public Utilities Commission [Member] | Capital Structure, Common Equity [Member]
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)					5.23%

REGULATORY MATTERS - BILLING PR

REGULATORY MATTERS - BILLING PRACTICES (Details) - USD ($)	1 Months Ended	12 Months Ended
	Jan. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Public Utilities, General Disclosures [Line Items]
Litigation fines		$ 6,000,000	$ 0	$ 0
Penalties related to billing practices		0	8,000,000	0
Energy Efficiency Program Inquiry [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue		51,000,000
Litigation fines		6,000,000
Litigation fines, after tax		44,000,000
Southern California Gas Company [Member]
Public Utilities, General Disclosures [Line Items]
Energy efficiency codes and standards advocacy, amount				9,000
Penalties related to billing practices	$ 8,000,000	0	8,000,000	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
San Diego Gas and Electric Company [Member]
Public Utilities, General Disclosures [Line Items]
Litigation fines		6,000,000	$ 0	$ 0
San Diego Gas and Electric Company [Member] | Energy Efficiency Program Inquiry [Member] | California Public Utilities Commission [Member]
Public Utilities, General Disclosures [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue		51,000,000
Litigation fines		6,000,000
Litigation fines, after tax		$ 44,000,000

ACQUISTIONS, DIVESTITURES AND_3

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Acquisitions (Details) $ / shares in Units, $ in Millions	May 16, 2019USD ($)$ / shares	Dec. 18, 2018USD ($)	Mar. 09, 2018USD ($)	Feb. 28, 2021USD ($)MW	Feb. 29, 2020USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2020USD ($)	Sep. 30, 2020	Dec. 31, 2019USD ($)	May 31, 2019
Business Acquisition [Line Items]
Investment in Oncor Holdings							$ 12,440		$ 11,519
Goodwill							$ 1,602		1,602
Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Acquired percentage interest			80.25%
Ownership percentage held by noncontrolling owners					80.45%
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
Identifiable assets acquired			9,670
Liabilities assumed			102
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] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)			$ 26
Sempra Texas Intermediate Holding Company LLC [Member] | TTHC [Member]
Business Acquisition [Line Items]
Ownership percentage held by noncontrolling owners					99.00%
Sempra Texas Intermediate Holding Company LLC [Member] | Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity			100.00%
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%				100.00%
Sempra Texas Intermediate Holding Company LLC [Member] | TTHC [Member]
Business Acquisition [Line Items]
Additional interest acquired (as a percent)					1.00%			1.00%
Sempra Texas Intermediate Holding Company LLC [Member] | Oncor Electric Delivery Company LLC Additional Acquisition [Member]
Business Acquisition [Line Items]
Acquired percentage interest							80.25%
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			0.22%		0.1975%
Notes receivable acquired					$ 6
Cash consideration (fair value of total consideration)					23
Fair value of notes receivable					$ 7
Sempra Texas Intermediate Holding Company LLC [Member] | Sharyland Holdings, LP [Member]
Business Acquisition [Line Items]
Acquired percentage interest										50.00%
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
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) | $ / shares	$ 21
Management agreement termination fee	$ 40
Oncor Electric Delivery Holdings Company LLC [Member] | InfraREIT Partners [Member]
Business Acquisition [Line Items]
Acquired percentage interest	100.00%
Oncor Electric Delivery Holdings Company LLC [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)			9,450
Additional consideration transferred			$ 31
Sharyland Holdings, LP [Member] | Sharyland Holdings, LP [Member] | Sharyland Utilities [Member]
Business Acquisition [Line Items]
Acquired percentage interest	100.00%
TTHC [Member] | TTI [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity					100.00%
Investment in Oncor Holdings					$ 16
TTHC [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity					19.75%
TTHC [Member] | Sempra Texas Holdings Corp [Member] | Oncor Electric Delivery Company LLC [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity					19.75%
Compania Transmisora del Norte Grande S.A. [Member]
Business Acquisition [Line Items]
Cash consideration (fair value of total consideration)		$ 208
Cash acquired						$ 18
Total purchase price paid		226
Identifiable assets acquired		231
Liabilities assumed		43
Goodwill		$ 38
Compania Transmisora del Norte Grande S.A. [Member] | Compania Transmisora del Norte Grande S.A. [Member] | Sempra South American Utilities [Member]
Business Acquisition [Line Items]
Acquired percentage interest		100.00%
IEnova [Member] | ESJ [Member] | Sempra Mexico [Member]
Business Acquisition [Line Items]
Ownership percentage in consolidated entity							100.00%
Ownership percentage before acquisition							50.00%
Oncor Electric Delivery Holdings Company LLC [Member]
Business Acquisition [Line Items]
Capital contributions to investees	$ 1,330
Oncor Electric Delivery Holdings Company LLC [Member] | Sempra Texas Intermediate Holding Company LLC [Member]
Business Acquisition [Line Items]
Investment in Oncor Holdings							$ 12,440		11,519
Goodwill							$ 2,868		$ 2,868
Subsequent Event [Member] | IEnova [Member] | ESJ [Member] | Sempra Mexico [Member]
Business Acquisition [Line Items]
Acquired percentage interest				50.00%
Additional interest acquired (as a percent)				100.00%
Total purchase price paid				$ 83
Net operating capacity (in MW) | MW				108
Subsequent Event [Member] | IEnova [Member] | ESJ [Member] | San Diego Gas and Electric Company [Member]
Business Acquisition [Line Items]
Net operating capacity (in MW) | MW				155

ACQUISTIONS, DIVESTITURES AND_4

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Schedule of Purchase Price Allocation (Details) - Oncor Electric Delivery Holdings Company LLC [Member] $ in Millions	Mar. 09, 2018USD ($)
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

ACQUISTIONS, DIVESTITURES AND_5

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, 2020	Dec. 31, 2019	Dec. 31, 2018	Feb. 07, 2019	Jan. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Gain (loss) on deconsolidation		$ 367
Current liabilities						$ 0	$ 444
(Loss) gain on sale of assets						$ (3)	$ 63	$ 513
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, after 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]
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 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, after 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
(Loss) gain on sale of assets	61		$ 61
Gain on sale of assets, after tax	$ 45		$ 45
Sempra Renewables [Member] | 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
Sempra Renewables [Member] | Disposal Group Disposed of by Sale [Member] | Certain Subsidiaries Of Sempra Renewables [Member] | Broken Bow 2 Wind [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage held by noncontrolling owners				50.00%				50.00%
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, after taxes and noncontrolling interests				$ (126)	$ 755			$ 629
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
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_6

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Discontinued Operations (Details) - USD ($) $ in Millions	1 Months Ended		3 Months Ended								12 Months Ended
	Jun. 30, 2020	Apr. 30, 2020	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Apr. 24, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from discontinued operations, net of income tax			$ 0	$ (7)	$ 1,777	$ 80	$ 71	$ 256	$ 78	$ (42)	$ 1,850	$ 363	$ 188
Earnings attributable to noncontrolling interests											(10)	(35)	(32)
Income (loss) from discontinued operations, net of income tax											1,840	328	156
Restricted cash			0				75				0	75
Assets held for sale in discontinued operations			0				445				0	445
Noncurrent assets			0				3,513				0	3,513
Liabilities held for sale in discontinued operations			0				444				0	444
Noncurrent liabilities			0				1,052				0	1,052
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]
After tax gain on sale											2,899	0	0
Revenues											570	1,614	1,585
Cost of sales											(364)	(1,012)	(1,041)
Operating expenses											(66)	(159)	(206)
Interest and other											(3)	(11)	(6)
Income before income taxes and equity earnings											3,036	432	332
Income tax expense											(1,186)	(72)	(145)
Equity earnings											0	3	1
Income from discontinued operations, net of income tax											1,850	363	188
Income (loss) from discontinued operations, net of income tax											1,840	328	$ 156
Cash and cash equivalents			4,600				74				4,600	74
Restricted cash							1					1
Accounts receivable, net							303					303
Due from unconsolidated affiliates							2					2
Inventories							36					36
Other current assets							29					29
Assets held for sale in discontinued operations							445					445
Due from unconsolidated affiliates							54					54
Goodwill and other intangible assets							801					801
Property, plant and equipment, net							2,618					2,618
Other noncurrent assets							40					40
Noncurrent assets							3,513					3,513
Short-term debt							52					52
Accounts payable							201					201
Current portion of long-term debt and finance leases							85					85
Other current liabilities							106					106
Liabilities held for sale in discontinued operations							444					444
Long-term debt and finance leases							702					702
Deferred income taxes							284					284
Other noncurrent liabilities							66					66
Noncurrent liabilities							$ 1,052					$ 1,052
Cumulative foreign currency translation adjustments			$ 645								$ 645
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member] | Luz Del Sur [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale		$ 3,549												$ 3,549
Pretax gain on sale		2,271
After tax gain on sale		$ 1,499
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member] | Chilquinta Energia [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 2,216				$ 2,216
Pretax gain on sale	628
After tax gain on sale	$ 248
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 (as a percent)			100.00%								100.00%
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 (as a percent)			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 (as a percent)	50.00%				50.00%

INVESTMENTS IN UNCONSOLIDATED_3

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 12,440	$ 11,519
Other investments	1,388	2,103
Goodwill	1,602	1,602
Equity earnings, before income tax	294	30	$ (236)
Equity earnings (losses), net of tax	721	550	411
Total equity earnings	1,015	580	175
Distributions from investments	1,462	256	212
Return of investment	761	9	10
Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Other investments	1,387	2,097
Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Other investments	1	6
R B S Sempra Commodities [Member]
Schedule of Equity Method Investments [Line Items]
Total equity earnings	(100)
Sempra Texas Intermediate Holding Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	$ 286	$ 246	149
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	$ 12,440	$ 11,519
Difference between carrying amount of equity method investment and underlying equity	2,833	2,823
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	104	114
Equity earnings (losses), net of tax	$ 577	$ 526	371
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%	50.00%
Equity method investment	$ 102	$ 100
Difference between carrying amount of equity method investment and underlying equity	42
Equity earnings, before income tax	3	2	0
Sempra Mexico [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	$ 8	$ 2	0
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	$ 34	$ 39
Difference between carrying amount of equity method investment and underlying equity	12
Equity earnings (losses), net of tax	$ 5	$ 2	2
Sempra Mexico [Member] | IMG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	40.00%	40.00%
Other investments	$ 440	$ 337
Difference between carrying amount of equity method investment and underlying equity	5
Equity earnings (losses), net of tax	$ 103	$ 9	29
Sempra Mexico [Member] | TAG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%
Other investments	$ 378	$ 365
Difference between carrying amount of equity method investment and underlying equity	130
Equity earnings (losses), net of tax	36	13	9
Sempra Renewables [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	0	1	63
Sempra Renewables [Member] | Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	2	(3)
Sempra Renewables [Member] | Auwahi Wind [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	3
Sempra Renewables [Member] | Broken Bow 2 Wind [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	(2)
Sempra Renewables [Member] | Cedar Creek 2 Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	(1)
Sempra Renewables [Member] | Flat Ridge 2 Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	(3)	(178)
Sempra Renewables [Member] | Fowler Ridge 2 Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	5	3
Sempra Renewables [Member] | Mehoopany Wind Farm [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	1	(30)
Sempra Renewables [Member] | California Solar Partnership [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	8
Sempra Renewables [Member] | Copper Mountain Solar 2 [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	5
Sempra Renewables [Member] | Copper Mountain Solar 3 [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	8
Sempra Renewables [Member] | Mesquite Solar 1 [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	0	18
Sempra LNG [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	$ 1,168	$ 0	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	$ 433	$ 1,256
Difference between carrying amount of equity method investment and underlying equity	259	263
Sempra LNG [Member] | Cameron LNG Holdings [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	391	24	0
Sempra Energy and Other [Member]
Schedule of Equity Method Investments [Line Items]
Distributions from investments	0	7	0
Sempra Energy and Other [Member] | Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	0	(1)	0
Sempra Energy and Other [Member] | R B S Sempra Commodities [Member]
Schedule of Equity Method Investments [Line Items]
Equity earnings, before income tax	$ (100)	$ 0	$ (67)

INVESTMENTS IN UNCONSOLIDATED_4

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details)

May 16, 2019USD ($)

Mar. 09, 2018

Feb. 28, 2021USD ($)

Jul. 31, 2020USD ($)

Dec. 31, 2019USD ($)

Sep. 30, 2018USD ($)

Dec. 31, 2020USD ($)MTBcf

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)

Feb. 29, 2020

May 31, 2019

Jun. 30, 2015USD ($)

Nov. 30, 2014USD ($)

Oct. 31, 2014USD ($)

Schedule of Equity Method Investments [Line Items]

Undistributed earnings from equity method investments

$ 634,000,000

$ 1,100,000,000

$ 634,000,000

Undistributed earnings, equity method investments, over 50 percent owned

792,000,000

Interest costs capitalized

202,000,000

183,000,000

$ 193,000,000

Debt instrument converted

22,000,000

0

0

Return of investment

761,000,000

9,000,000

10,000,000

Equity earnings

1,015,000,000

580,000,000

175,000,000

Oncor Electric Delivery Holdings Company LLC [Member]

Schedule of Equity Method Investments [Line Items]

Cash contributed to fund the acquisition

1,067,000,000

1,067,000,000

R B S Sempra Commodities [Member]

Schedule of Equity Method Investments [Line Items]

Other than temporary impairment

$ 65,000,000

Equity earnings

(100,000,000)

R B S Sempra Commodities [Member] | Current liabilities: Other [Member]

Schedule of Equity Method Investments [Line Items]

Equity earnings

25,000,000

R B S Sempra Commodities [Member] | Deferred Credits and Other [Member]

Schedule of Equity Method Investments [Line Items]

Equity earnings

$ 75,000,000

Cameron LNG [Member]

Schedule of Equity Method Investments [Line Items]

Ownership percentage in equity method investee

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%

Indirect economic and beneficial and ownership interest after financial completion

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%

Debt instrument, maximum borrowing amount

$ 4,000,000,000

$ 82,000,000

Maximum exposure, remaining percentage

49.80%

Current guarantor obligations

$ 3,000,000

$ 1,000,000

$ 3,000,000

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

80,000,000

Ownership percentage in equity method investee

40.00%

Transportation service contract term

35 years

Sempra Renewables [Member]

Schedule of Equity Method Investments [Line Items]

Payments to acquire equity method investments

5,000,000

Other than temporary impairment

200,000,000

Sempra LNG [Member]

Schedule of Equity Method Investments [Line Items]

Debt instrument, maximum borrowing amount

$ 4,000,000,000

Sempra LNG [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Schedule of Equity Method Investments [Line Items]

Debt instrument, maximum borrowing amount

979,000,000

Current guarantor obligations

3,000,000

Sempra LNG [Member] | Deferred Credits and Other [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Schedule of Equity Method Investments [Line Items]

Current guarantor obligations

4,000,000

Sempra LNG [Member] | Current assets: Other [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Schedule of Equity Method Investments [Line Items]

Current guarantor obligations

7,000,000

Sempra LNG [Member] | Cameron LNG [Member]

Schedule of Equity Method Investments [Line Items]

Payments to acquire equity method investments

$ 54,000,000

$ 77,000,000

228,000,000

Project capacity | MT

13.9

Proved undeveloped reserve | MT

12

Proved undeveloped reserve per day | Bcf

1.7

Interest costs capitalized

$ 33,000,000

47,000,000

Debt amount

$ 7,400,000,000

Debt instrument converted

$ 3,000,000,000

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%

Notional amount of derivatives

$ 1,500,000,000

$ 3,700,000,000

Derivative amount terminated

$ 790,000,000

Effective fixed rate (as a percent)

3.26%

Weighted-average all-in cost of loans outstanding (as a percent)

3.72%

Sempra LNG [Member] | Cameron LNG [Member] | Corporate Joint Venture [Member]

Schedule of Equity Method Investments [Line Items]

Proceeds from related parties

$ 1,500,000,000

Debt covenant, liability cap (as a percent)

130.00%

Debt covenant, liability cap amount

$ 979,000,000

Sempra LNG [Member] | Cameron LNG [Member] | Corporate Joint Venture [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]

Schedule of Equity Method Investments [Line Items]

Proceeds from related parties

$ 753,000,000

Return of investment

$ 753,000,000

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%

Weighted average rate after project completion

1.22%

Sharyland Holdings, LP [Member]

Schedule of Equity Method Investments [Line Items]

Acquired percentage interest

50.00%

Payments to acquire equity method investments

$ 95,000,000

$ 3,000,000

Post-closing adjustments

7,000,000

Total purchase price paid

$ 95,000,000

Sharyland Holdings, LP [Member] | Sempra Texas Intermediate Holding Company LLC [Member]

Schedule of Equity Method Investments [Line Items]

Acquired percentage interest

50.00%

ESJ [Member] | Sempra Mexico [Member] | IEnova [Member]

Schedule of Equity Method Investments [Line Items]

Ownership percentage in consolidated entity

100.00%

ESJ [Member] | Sempra Mexico [Member] | IEnova [Member] | Subsequent Event [Member]

Schedule of Equity Method Investments [Line Items]

Acquired percentage interest

50.00%

Total purchase price paid

$ 83,000,000

Oncor Electric Delivery Holdings Company LLC [Member]

Schedule of Equity Method Investments [Line Items]

Payments to acquire equity method investments

$ 632,000,000

$ 1,587,000,000

$ 230,000,000

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%

100.00%

Oncor Electric Delivery Company LLC [Member]

Schedule of Equity Method Investments [Line Items]

Acquired percentage interest

80.25%

Ownership percentage held by noncontrolling owners

80.45%

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 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%

Cameron LNG [Member] | Sempra LNG [Member]

Schedule of Equity Method Investments [Line Items]

Ownership percentage in consolidated entity

50.20%

ESJ [Member] | ESJ [Member] | Sempra Mexico [Member] | IEnova [Member]

Schedule of Equity Method Investments [Line Items]

Ownership percentage held by noncontrolling owners

50.00%

INVESTMENTS IN UNCONSOLIDATED_5

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	Dec. 13, 2018	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule of Equity Method Investments [Line Items]
Operating revenues											$ 10,025	$ 9,448	$ 8,539
Net income		$ 432	$ 421	$ 2,305	$ 947	$ 500	$ 909	$ 435	$ 518		4,105	2,362	1,126
Current assets		4,511				3,339					4,511	3,339
Current liabilities		6,839				9,150					6,839	9,150
Other Equity Method Investments [Member]
Schedule of Equity Method Investments [Line Items]
Operating revenues											2,341	798	706
Operating expense											(706)	(372)	(609)
Income from operations											1,635	426	97
Interest expense											(514)	(401)	(322)
Net income											1,132	85	$ (36)
Current assets		1,035				1,124					1,035	1,124
Noncurrent assets		15,304				15,039					15,304	15,039
Current liabilities		1,342				1,232					1,342	1,232
Noncurrent liabilities		12,863				11,438					12,863	11,438
Sempra Renewables [Member] | Broken Bow 2 Wind [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity	50.00%
Oncor Electric Delivery Holdings Company LLC [Member] | Equity Method Investment, Nonconsolidated Investee or Group of Investees [Member]
Schedule of Equity Method Investments [Line Items]
Operating revenues										$ 3,347	4,511	4,347
Operating expense										(2,434)	(3,224)	(3,135)
Income from operations										913	1,287	1,212
Interest expense										(285)	(405)	(375)
Income tax expense										(119)	(146)	(131)
Net income										455	703	643
Noncontrolling interest held by TTI										(94)	(141)	(129)
Earnings attributable to Sempra Energy										$ 360	562	514
Current assets		1,045				913					1,045	913
Noncurrent assets		28,022				26,012					28,022	26,012
Current liabilities		1,120				1,626					1,120	1,626
Noncurrent liabilities		15,611				14,125					15,611	14,125
Noncontrolling interest held by TTI		$ 2,737				$ 2,473					$ 2,737	$ 2,473

DEBT AND CREDIT FACILITIES - SU

DEBT AND CREDIT FACILITIES - SUMMARY OF LINES OF CREDIT (Details)	1 Months Ended	12 Months Ended
	Oct. 31, 2020USD ($)	Dec. 31, 2020USD ($)lendercustomer
Line of Credit Facility [Line Items]
Number of lenders | lender		23
Lenders, percent of facility		6.00%
Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding		$ (113,000,000)
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		3,185,000,000
Sempra Global [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding		0
San Diego Gas and Electric Company [Member]
Line of Credit Facility [Line Items]
Total facility		1,500,000,000
Available unused credit		1,500,000,000
San Diego Gas and Electric Company [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding		0
Southern California Gas Company [Member]
Line of Credit Facility [Line Items]
Total facility		750,000,000
Available unused credit		637,000,000
Committed lines of credit, capacity for issuance of letters of credit		100,000,000
Line of credit, increase limit		250,000,000
Southern California Gas Company [Member] | Commercial paper [Member]
Line of Credit Facility [Line Items]
Line of credit outstanding		(113,000,000)
Sempra U.S. Businesses [Member]
Line of Credit Facility [Line Items]
Total facility		6,685,000,000
Available unused credit		$ 6,572,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)		65.00%
Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility		$ 1,780,000,000
Line of credit outstanding		(672,000,000)
Available unused credit		$ 1,108,000,000
U.S. Committed Lines of Credit [Member]
Line of Credit Facility [Line Items]
Term of contract		5 years
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		(392,000,000)
Available unused credit		$ 1,108,000,000
Term of contract		5 years
Number of Lenders | customer		10
Foreign Committed Lines of Credit, Due February 2024 [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Variable percentage rate		0.80%
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
Term of contract		2 years
Foreign Committed Lines of Credit, Due September 2021 [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Variable percentage rate		0.54%
Uncommitted Revolving Credit Facility with Scotiabank Inverlat S.A. [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	$ 20,000,000
Term of contract	3 years
Uncommitted Revolving Credit Facility with Bank of Nova Scotia [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Total facility	$ 100,000,000
Term of contract	3 years
Foreign Uncommitted Revolving Credit Facility Due April 2022 [Member] | Sempra Mexico [Member] | Foreign Line of Credit [Member]
Line of Credit Facility [Line Items]
Available unused credit		$ 20,000,000

DEBT AND CREDIT FACILITIES - NA

DEBT AND CREDIT FACILITIES - NARRATIVE (Details)	Mar. 30, 2020USD ($)	Dec. 31, 2020USD ($)MMBbls	Oct. 31, 2020USD ($)	Sep. 30, 2020USD ($)	Jun. 30, 2020USD ($)	Apr. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Jan. 31, 2020USD ($)	Apr. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding		$ 508,000,000									$ 508,000,000
Unsecured debt		$ 11,200,000,000									11,200,000,000
Redemptions prior to maturity											5,864,000,000	$ 3,667,000,000	$ 3,342,000,000
Equitization of long-term debt for deficit held by NCI											$ (22,000,000)
Sempra Energy Consolidated [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding		0.83%									0.83%	2.31%
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding		0.00%									0.00%	1.97%
First mortgage bonds available for future issuance		$ 6,500,000,000									$ 6,500,000,000
Redemptions prior to maturity											510,000,000	$ 274,000,000	492,000,000
Total facility		$ 1,500,000,000									$ 1,500,000,000
San Diego Gas and Electric Company [Member] | Term Loan [Member]
Debt Instrument [Line Items]
Proceeds from debt							$ 200,000,000
Basis spread on variable percentage rate	0.80%										0.95%
San Diego Gas and Electric Company [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Repayments of Long-term Lines of Credit										$ 200,000,000
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Weighted average interest rate on total short-term debt outstanding		0.14%									0.14%	1.86%
Unsecured debt		$ 309,000,000									$ 309,000,000
First mortgage bonds available for future issuance		1,200,000,000									1,200,000,000
Redemptions prior to maturity											12,000,000	$ 6,000,000	$ 500,000,000
Total facility		$ 750,000,000									$ 750,000,000
Southern California Gas Company [Member] | First Mortgage Bonds, Due February 2030
Debt Instrument [Line Items]
Stated percentage rate		2.55%						2.55%			2.55%
Sempra Energy [Member]
Debt Instrument [Line Items]
Total facility		$ 1,250,000,000									$ 1,250,000,000
Sempra Energy [Member] | Term Loan [Member]
Debt Instrument [Line Items]
Proceeds from debt									$ 1,599,000,000
Debt issuance costs						$ 1,000,000			1,000,000
Sempra Mexico [Member] | IEnova Loan Agreement [Member] | Japan International Cooperation Agency [Member]
Debt Instrument [Line Items]
Proceeds from debt						98,000,000
Debt issuance costs						2,000,000			$ 2,000,000
Proceeds from issuance of debt						$ 100,000,000
Fixed interest rate (as a percent)						2.38%			2.38%
Sempra Mexico [Member] | IEnova Loan Agreement [Member] | U.S. International Development Finance Corporation [Member]
Debt Instrument [Line Items]
Proceeds from debt					$ 236,000,000
Debt issuance costs					5,000,000
Proceeds from issuance of debt					$ 241,000,000
Fixed interest rate (as a percent)					2.90%
Sempra Mexico [Member] | IEnova Loan Agreement [Member] | LIBOR [Member] | Japan International Cooperation Agency [Member]
Debt Instrument [Line Items]
Basis spread on variable percentage rate						1.50%
Sempra LNG [Member] | Liberty Gas Storage, LLC [Member]
Debt Instrument [Line Items]
Equitization of long-term debt for deficit held by NCI	$ 22,000,000
Sempra LNG [Member] | ECA LNG JV [Member]
Debt Instrument [Line Items]
Ownership percentage in consolidated entity		41.70%
Sempra LNG [Member] | Loan Agreement To Finance Natural Gas Liquefaction Export Facility [Member]
Debt Instrument [Line Items]
Stated percentage rate		2.70%									2.70%
Term of contract		5 years
Total facility		$ 1,600,000,000									$ 1,600,000,000
Long-term debt outstanding		$ 17,000,000									$ 17,000,000
Name plate capacity (in Mtpa) | MMBbls		3.25
Initial offtake capacity (in Mtpa) | MMBbls		2.5
Subsidiary of TOTAL SE [Member] | ECA LNG JV [Member]
Debt Instrument [Line Items]
Ownership percentage in consolidated entity		16.60%
IEnova [Member] | ECA LNG JV [Member]
Debt Instrument [Line Items]
Ownership percentage in consolidated entity		41.70%
Bonds [Member] | San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due June 2049 [Member]
Debt Instrument [Line Items]
Proceeds from debt				$ 792,000,000
Debt issuance costs				8,000,000
Debt amount				$ 800,000,000
Stated percentage rate				1.70%
Bonds [Member] | San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Proceeds from debt						$ 395,000,000
Debt issuance costs						5,000,000			$ 5,000,000
Debt amount						$ 400,000,000			$ 400,000,000
Stated percentage rate						3.32%			3.32%
Repayments of lines of credit						$ 200,000,000
Bonds [Member] | Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2050 [Member]
Debt Instrument [Line Items]
Proceeds from debt				$ 298,000,000
Debt issuance costs				2,000,000
Debt amount				300,000,000
Bonds [Member] | Southern California Gas Company [Member] | First Mortgage Bonds, Due February 2030
Debt Instrument [Line Items]
Proceeds from debt								$ 643,000,000
Debt issuance costs								7,000,000
Debt amount								$ 650,000,000
Bonds [Member] | Prior To Maturity In 2034 [Member] | San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Redemptions prior to maturity		$ 176,000,000
Bonds [Member] | Prior To Maturity In 2039 [Member] | San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Redemptions prior to maturity		$ 75,000,000
Junior Subordinated Debt [Member] | Sempra Mexico [Member] | Junior Subordinated Notes Due 2079 [Member]
Debt Instrument [Line Items]
Debt amount				$ 800,000,000
Stated percentage rate				4.75%
Unsecured Debt [Member] | Southern California Gas Company [Member] | Senior Unsecured Notes Maturing 2023 [Member]
Debt Instrument [Line Items]
Debt instrument, redemption price (as a percent)				100.00%
Unsecured Debt [Member] | Southern California Gas Company [Member] | Senior Unsecured Notes Maturing 2023 [Member] | LIBOR [Member]
Debt Instrument [Line Items]
Basis spread on variable percentage rate				0.35%
Unsecured Debt [Member] | Sempra Mexico [Member] | Four Point Seven Five Percent Senior Unsecured Notes Maturing 2051 [Member]
Debt Instrument [Line Items]
Proceeds from debt				$ 770,000,000
Debt issuance costs				$ 30,000,000
Sempra Energy Consolidated [Member] | Prior to maturity in 2021
Debt Instrument [Line Items]
Redemptions prior to maturity			$ 700,000,000

DEBT AND CREDIT FACILITIES - SC

DEBT AND CREDIT FACILITIES - SCHEDULE OF LONG-TERM DEBT INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Jan. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Long-term lease liabilities	$ 1,294		$ 1,263
Finance lease obligations	1,330		1,289
Current portion of long-term debt	(1,540)		(1,526)
Long-term debt and finance leases	21,781		20,785
San Diego Gas and Electric Company [Member]
Debt Instrument [Line Items]
Gross long-term debt	6,053		5,140
Long-term lease liabilities	1,250		1,250
Long term debt and lease obligations, including current maturities	7,529		6,410
Finance lease obligations	1,276		1,270
Current portion of long-term debt	(611)		(56)
Unamortized discount on long-term debt	(13)		(12)
Unamortized debt issuance costs	(39)		(36)
Total debt and lease obligations	6,866		6,306
Long-term debt and finance leases	$ 6,866		6,306
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due August 2021 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.00%
Gross long-term debt	$ 350		350
San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due February 2022 [Member]
Debt Instrument [Line Items]
Stated percentage rate	1.914%
Gross long-term debt	$ 53		89
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due September 2023 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.60%
Gross long-term debt	$ 450		450
San Diego Gas and Electric Company [Member] | First Mortgage Bonds Due May 2026 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.50%
Gross long-term debt	$ 500		500
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2026 [Member]
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 250		250
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due October 2030
Debt Instrument [Line Items]
Stated percentage rate	1.70%
Gross long-term debt	$ 800		0
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due January And February 2034 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.875%
Gross long-term debt	$ 0		176
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2035 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250		250
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due September 2037 [Member]
Debt Instrument [Line Items]
Stated percentage rate	6.125%
Gross long-term debt	$ 250		250
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2039 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.00%
Gross long-term debt	$ 0		75
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2039 [Member]
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 300		300
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2040 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250		250
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due August 2040 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.50%
Gross long-term debt	$ 500		500
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due November 2041 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 250		250
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due April 2042 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 250		250
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 2047 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 400		400
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due May 2048 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.15%
Gross long-term debt	$ 400		400
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due June 15 2049 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.10%
Gross long-term debt	$ 400		400
San Diego Gas and Electric Company [Member] | First Mortgage Bonds, Due April 2050
Debt Instrument [Line Items]
Stated percentage rate	3.32%
Gross long-term debt	$ 400		0
San Diego Gas and Electric Company [Member] | Other Long Term Debt, Variable Rate Notes Due March 2021 [Member]
Debt Instrument [Line Items]
Stated percentage rate	0.95%
Gross long-term debt	$ 200		0
San Diego Gas and Electric Company [Member] | Finance Lease Obligations, Purchased Power Contracts [Member]
Debt Instrument [Line Items]
Long-term lease liabilities	1,237		1,255
San Diego Gas and Electric Company [Member] | Finance Lease Obligations, Other [Member]
Debt Instrument [Line Items]
Long-term lease liabilities	39		15
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	1,476		1,270
Southern California Gas Company [Member]
Debt Instrument [Line Items]
Gross long-term debt	4,450		3,800
Long-term lease liabilities	44		13
Long term debt and lease obligations, including current maturities	4,813		3,828
Finance lease obligations	54		19
Finance lease obligations and other long term debt	363		28
Current portion of long-term debt	(10)		(6)
Unamortized discount on long-term debt	(8)		(7)
Unamortized debt issuance costs	(32)		(27)
Total debt and lease obligations	4,763		3,788
Long-term debt and finance leases	$ 4,763		3,788
Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2026 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.60%
Gross long-term debt	$ 500		500
Southern California Gas Company [Member] | First Mortgage Bonds, Due September 2024 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.15%
Gross long-term debt	$ 500		500
Southern California Gas Company [Member] | First Mortgage Bonds Due June 2025 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.20%
Gross long-term debt	$ 350		350
Southern California Gas Company [Member] | First Mortgage Bonds, Due February 2030
Debt Instrument [Line Items]
Stated percentage rate	2.55%	2.55%
Gross long-term debt	$ 650		0
Southern California Gas Company [Member] | First Mortgage Bonds, Due November 2035 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 250		250
Southern California Gas Company [Member] | First Mortgage Bonds, Due November 2040 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.125%
Gross long-term debt	$ 300		300
Southern California Gas Company [Member] | First Mortgage Bonds, Due September 2042 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 350		350
Southern California Gas Company [Member] | First Mortgage Bonds, Due March 2044 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.45%
Gross long-term debt	$ 250		250
Southern California Gas Company [Member] | First Mortgage Bonds, Due June 2048 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.125%
Gross long-term debt	$ 400		400
Southern California Gas Company [Member] | First Mortgage Bonds, Due January 2049 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 550		550
Southern California Gas Company [Member] | First Mortgage Bonds, Due February 2050 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 350		350
Southern California Gas Company [Member] | Other Long-term Debt, Due September 2023
Debt Instrument [Line Items]
Stated percentage rate	0.57%
Gross long-term debt	$ 300		0
Southern California Gas Company [Member] | Other Long-term Debt, Due May 2026 [Member]
Debt Instrument [Line Items]
Stated percentage rate	1.875%
Gross long-term debt	$ 4		4
Southern California Gas Company [Member] | Other Long-term Debt, Due January 2028 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.67%
Gross long-term debt	$ 5		5
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 February 2020 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.40%
Gross long-term debt	$ 0		500
Sempra Energy [Member] | Other Long Term Debt Due March 2020 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.40%
Gross long-term debt	$ 0		500
Sempra Energy [Member] | Other Long Term Debt, Due November 2020 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.85%
Gross long-term debt	$ 0		400
Sempra Energy [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 0		700
Sempra Energy [Member] | Other Long Term Debt, Due October 2022 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.875%
Gross long-term debt	$ 500		500
Sempra Energy [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.90%
Gross long-term debt	$ 500		500
Sempra Energy [Member] | Other Long-term Debt, Due December 2023 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.05%
Gross long-term debt	$ 500		500
Sempra Energy [Member] | Other Long-term Debt, Due June 2024 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.55%
Gross long-term debt	$ 500		500
Sempra Energy [Member] | Other Long Term Debt Due November 2025 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 350		350
Sempra Energy [Member] | Other Long Term Debt Due June 2027 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.25%
Gross long-term debt	$ 750		750
Sempra Energy [Member] | Other Long Term Debt Due February 2028 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.40%
Gross long-term debt	$ 1,000		1,000
Sempra Energy [Member] | Other Long Term Debt Due February 2038 [Member]
Debt Instrument [Line Items]
Stated percentage rate	3.80%
Gross long-term debt	$ 1,000		1,000
Sempra Energy [Member] | Other Long-term Debt, Due October 2039 [Member]
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 750		750
Sempra Energy [Member] | Other Long Term Debt Due February 2048 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.00%
Gross long-term debt	$ 800		800
Sempra Energy [Member] | Other Long-term Debt, Junior Subordinated Notes, Due July 2079 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 758		758
Sempra Mexico [Member] | Other Long-term Debt, 6.3% Notes Due February 2023
Debt Instrument [Line Items]
Stated percentage rate	6.30%
Gross long-term debt	$ 197		207
Fixed interest rate after floating to fixed interest rate swaps	4.124%
Sempra Mexico [Member] | Other Long-Term Debt, Due 2016 Through December 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 196		237
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]
Stated percentage rate	3.75%
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	$ 398		423
Sempra Mexico [Member] | Other Long-Term Debt, Payable 2016 Through March 2032 [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Stated percentage rate	6.87%
Gross long-term debt	$ 234
Sempra Mexico [Member] | Other Long-term Debt, Currently Through January 2048 [Member]
Debt Instrument [Line Items]
Stated percentage rate	4.875%
Gross long-term debt	$ 540		540
Sempra Mexico [Member] | Other Long-term Debt, Currently Through July 2028 [Member]
Debt Instrument [Line Items]
Gross long-term debt	0		11
Sempra Mexico [Member] | Other Long-term Debt, Variable Rate Payable Through November 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 200		200
Fixed interest rate after floating to fixed interest rate swaps	4.0275%
Sempra Mexico [Member] | Other Long-term Debt, 4.75% Notes Due September 2051
Debt Instrument [Line Items]
Stated percentage rate	4.75%
Gross long-term debt	$ 800		0
Sempra Mexico [Member] | Other Long-term Debt, Variable Rate Loan Due November 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 100		0
Fixed interest rate after floating to fixed interest rate swaps	2.38%
Sempra Mexico [Member] | Other Long-Term Debt, Payable 2022 Through November 2034 [Member]
Debt Instrument [Line Items]
Stated percentage rate	2.90%
Gross long-term debt	$ 241		0
Sempra LNG [Member] | Other Long-term Debt, Currently Through October 2026 [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 0		22
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%
Sempra LNG [Member] | Other Long-Term Debt, Variable Rate Loan Due December 2025
Debt Instrument [Line Items]
Stated percentage rate	2.82%
Gross long-term debt	$ 17		0
Other Sempra Energy [Member]
Debt Instrument [Line Items]
Gross long-term debt	11,247		12,298
Current portion of long-term debt	(919)		(1,464)
Unamortized discount on long-term debt	(55)		(35)
Unamortized debt issuance costs	(121)		(108)
Long-term debt and finance leases	$ 10,152		$ 10,691
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	3.45%
Gross long-term debt	$ 34
LIBOR [Member] | Sempra Mexico [Member] | Other Long-Term Debt, Payable 2016 Through March 2032 [Member] | Weighted Average [Member]
Debt Instrument [Line Items]
Gross long-term debt	$ 130
Fixed interest rate after floating to fixed interest rate swaps	6.54%
LIBOR [Member] | Sempra Mexico [Member] | Other Long-term Debt, Currently Through July 2028 [Member]
Debt Instrument [Line Items]
Stated percentage rate	5.75%

DEBT AND CREDIT FACILITIES - MA

DEBT AND CREDIT FACILITIES - MATURITIES OF LONG-TERM DEBT (5 YEAR SCHEDULE) (Details) $ in Millions	Dec. 31, 2020USD ($)
Schedule Of Long Term Debt Maturities [Line Items]
2021	$ 1,504
2022	601
2023	2,031
2024	1,064
2025	811
Thereafter	16,248
Total	22,259
San Diego Gas and Electric Company [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2021	585
2022	18
2023	450
2024	0
2025	0
Thereafter	5,200
Total	6,253
Southern California Gas Company [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2021	0
2022	0
2023	300
2024	500
2025	350
Thereafter	3,609
Total	4,759
Other Sempra Energy [Member]
Schedule Of Long Term Debt Maturities [Line Items]
2021	919
2022	583
2023	1,281
2024	564
2025	461
Thereafter	7,439
Total	$ 11,247

DEBT AND CREDIT FACILITIES - CA

DEBT AND CREDIT FACILITIES - CALLABLE LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2020USD ($)
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	$ 1,803
Callable long-term debt, subject to make-whole provisions	19,006
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	200
Callable long-term debt, subject to make-whole provisions	6,053
Southern California Gas Company [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	304
Callable long-term debt, subject to make-whole provisions	4,450
Other Sempra Energy [Member]
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	1,299
Callable long-term debt, subject to make-whole provisions	$ 8,503

INCOME TAXES - RECONCILIATION T

INCOME TAXES - RECONCILIATION TO EFFECTIVE TAX RATE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 249	$ 315	$ (49)
Income from continuing operations before income taxes and equity earnings	1,489	1,734	714
Equity earnings, before income tax	294	30	(236)
Pretax income	$ 1,783	$ 1,764	$ 478
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Depreciation	3.00%	3.00%	12.00%
Non-U.S. earnings taxed at lower statutory income tax rates	2.00%	3.00%	10.00%
State income taxes, net of federal income tax benefit	1.00%	2.00%	(8.00%)
Impairment losses	1.00%	0.00%	(32.00%)
Effects of the TCJA	0	0	0.09
Unrecognized income tax benefits	0.00%	0.00%	4.00%
Noncontrolling interests in tax equity arrangements	0.00%	0.00%	3.00%
Resolution of prior years’ income tax items	0.00%	0.00%	(1.00%)
Excess deferred income taxes outside of ratemaking	0.00%	(4.00%)	0.00%
Compensation-related items	(1.00%)	0.00%	3.00%
Valuation allowances	(1.00%)	0.00%	0.00%
Amortization of excess deferred income taxes	(1.00%)	(1.00%)	(4.00%)
Allowance for equity funds used during construction	(1.00%)	(1.00%)	(4.00%)
Tax credits	(1.00%)	(2.00%)	(10.00%)
Foreign exchange and inflation effects	(3.00%)	4.00%	6.00%
Utility self-developed software expenditures	(3.00%)	(2.00%)	(7.00%)
Utility repairs expenditures	(4.00%)	(3.00%)	(13.00%)
Other, net	1.00%	(2.00%)	1.00%
Effective income tax rate	14.00%	18.00%	(10.00%)
San Diego Gas and Electric Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 190	$ 171	$ 173
Income from continuing operations before income taxes and equity earnings	1,014	945	849
Pretax income	$ 1,014	$ 945	$ 849
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Depreciation	3.00%	3.00%	3.00%
State income taxes, net of federal income tax benefit	5.00%	6.00%	5.00%
Excess deferred income taxes outside of ratemaking	0.00%	(3.00%)	0.00%
Amortization of excess deferred income taxes	(1.00%)	(1.00%)	(1.00%)
Allowance for equity funds used during construction	(2.00%)	(1.00%)	(2.00%)
Utility self-developed software expenditures	(4.00%)	(3.00%)	(2.00%)
Utility repairs expenditures	(3.00%)	(3.00%)	(3.00%)
Other, net	0.00%	(1.00%)	(1.00%)
Effective income tax rate	19.00%	18.00%	20.00%
Southern California Gas Company [Member]
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ 96	$ 120	$ 92
Income from continuing operations before income taxes and equity earnings	601	762	493
Pretax income	$ 601	$ 762	$ 493
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Depreciation	5.00%	4.00%	7.00%
State income taxes, net of federal income tax benefit	2.00%	4.00%	2.00%
Nondeductible expenditures	2.00%	0.00%	0.00%
Unrecognized income tax benefits	0.00%	0.00%	4.00%
Resolution of prior years’ income tax items	0.00%	0.00%	(1.00%)
Excess deferred income taxes outside of ratemaking	0.00%	(5.00%)	0.00%
Compensation-related items	0.00%	0.00%	1.00%
Amortization of excess deferred income taxes	(1.00%)	(1.00%)	(2.00%)
Allowance for equity funds used during construction	(1.00%)	(1.00%)	(2.00%)
Utility self-developed software expenditures	(4.00%)	(2.00%)	(3.00%)
Utility repairs expenditures	(7.00%)	(4.00%)	(7.00%)
Other, net	(1.00%)	0.00%	(1.00%)
Effective income tax rate	16.00%	16.00%	19.00%

INCOME TAXES - ADDITIONAL INFOR

INCOME TAXES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Millions	11 Months Ended	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax benefit related to outside differences on plans to sell businesses			$ (89)
Income tax expense related to increase in outside basis differences	$ 51	$ (7)
Foreign undistributed earnings		1,300
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested		58
Foreign earnings repatriated		4,700	254	$ 338
San Diego Gas and Electric Company [Member]
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense recognized in current period, related to remeasurement of deferred income tax assets and liabilities			31
Southern California Gas Company [Member]
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Income tax expense recognized in current period, related to remeasurement of deferred income tax assets and liabilities			$ 38
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		$ 1,100

INCOME TAXES - COMPONENTS OF IN

INCOME TAXES - COMPONENTS OF INCOME TAX EXPENSE (BENEFIT) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S.	$ 1,461	$ 1,191	$ (102)
Non-U.S.	322	573	580
Pretax income	1,783	1,764	478
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	0	0	(1)
U.S. state	(22)	(14)	67
Non-U.S.	112	140	127
Total	90	126	193
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	157	87	(121)
U.S. state	36	21	(183)
Non-U.S.	(34)	84	66
Total	159	192	(238)
Deferred investment tax credits	0	(3)	(4)
Total income tax expense (benefit)	249	315	(49)
San Diego Gas and Electric Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	1,014	945	849
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	121	35	104
U.S. state	34	31	30
Total	155	66	134
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	11	75	17
U.S. state	25	32	24
Total	36	107	41
Deferred investment tax credits	(1)	(2)	(2)
Total income tax expense (benefit)	190	171	173
Southern California Gas Company [Member]
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Pretax income	601	762	493
Current Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	163	8	4
U.S. state	45	24	10
Total	208	32	14
Deferred Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S. federal	(85)	79	78
U.S. state	(28)	10	2
Total	(113)	89	80
Deferred investment tax credits	1	(1)	(2)
Total income tax expense (benefit)	$ 96	$ 120	$ 92

INCOME TAXES - DEFERRED INCOME

INCOME TAXES - DEFERRED INCOME TAXES (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Deferred income tax assets:
Less: valuation allowances	$ 174	$ 144
Deferred income taxes assets, noncurrent	136	155
Deferred income tax liabilities, noncurrent	2,871	2,577
Sempra Energy Consolidated [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	4,891	4,052
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	46	153
Regulatory balancing accounts	587	468
Right-of-use assets – operating leases	144	131
Property taxes	51	44
Other deferred income tax liabilities	40	93
Total deferred income tax liabilities	5,759	4,941
Deferred income tax assets:
Tax credits	1,161	1,136
Net operating losses	1,299	911
Postretirement benefits	162	200
Compensation-related items	169	161
Operating lease liabilities	125	131
Other deferred income tax assets	152	72
Accrued expenses not yet deductible	130	52
Deferred income tax assets before valuation allowances	3,198	2,663
Less: valuation allowances	174	144
Total deferred income tax assets	3,024	2,519
Net deferred income tax liability	2,735	2,422
Deferred income taxes assets, noncurrent	136	155
Deferred income tax liabilities, noncurrent	2,871	2,577
San Diego Gas and Electric Company [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	1,833	1,735
Regulatory balancing accounts	224	141
Right-of-use assets – operating leases	28	32
Property taxes	34	30
Other deferred income tax liabilities	2	14
Total deferred income tax liabilities	2,121	1,952
Deferred income tax assets:
Tax credits	5	6
Postretirement benefits	14	37
Compensation-related items	12	6
Operating lease liabilities	28	32
Bad debt allowance	18	3
Other deferred income tax assets	3	4
State income taxes	8	7
Accrued expenses not yet deductible	14	9
Total deferred income tax assets	102	104
Net deferred income tax liability	2,019	1,848
Deferred income tax liabilities, noncurrent	2,019	1,848
Southern California Gas Company [Member]
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	1,322	1,246
Regulatory balancing accounts	362	327
Right-of-use assets – operating leases	21	22
Property taxes	17	14
Other deferred income tax liabilities	1	1
Total deferred income tax liabilities	1,723	1,610
Deferred income tax assets:
Tax credits	3	3
Postretirement benefits	123	120
Compensation-related items	36	25
Operating lease liabilities	21	22
Bad debt allowance	15	1
Other deferred income tax assets	15	13
State income taxes	11	8
Accrued expenses not yet deductible	93	15
Total deferred income tax assets	317	207
Net deferred income tax liability	1,406	1,403
Deferred income tax liabilities, noncurrent	$ 1,406	$ 1,403

INCOME TAXES - NET OPERATING LO

INCOME TAXES - NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Valuation allowances	$ 174	$ 144
U.S. Federal [Member]
Operating Loss Carryforwards [Line Items]
NOLs	5,284
Valuation allowances	118	90
U.S. Federal [Member] | General business tax credits [Member]
Operating Loss Carryforwards [Line Items]
Tax credits	428
U.S. Federal [Member] | Foreign tax credits [Member]
Operating Loss Carryforwards [Line Items]
Tax credits	694
U.S. state [Member]
Operating Loss Carryforwards [Line Items]
NOLs	3,047
Valuation allowances	32	33
U.S. state [Member] | General business tax credits [Member]
Operating Loss Carryforwards [Line Items]
Tax credits	39
Non-U.S. [Member]
Operating Loss Carryforwards [Line Items]
NOLs	126
Valuation allowances	$ 24	$ 21

INCOME TAXES - UNRECOGNIZED TAX

INCOME TAXES - UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of Unrecognized Tax Benefits
Beginning balance	$ 93	$ 119	$ 89
Increase in prior period tax positions	3	5	7
Decrease in prior period tax positions	(1)	0	(1)
Increase in current period tax positions	4	2	24
Settlements with taxing authorities	0	(32)	0
Expiration of statutes of limitations	0	(1)	0
Ending balance	99	93	119
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(87)	(81)	(107)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	31	27	24
San Diego Gas and Electric Company [Member]
Reconciliation of Unrecognized Tax Benefits
Beginning balance	12	11	10
Increase in prior period tax positions	1	1	1
Ending balance	13	12	11
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(10)	(9)	(9)
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]
Reconciliation of Unrecognized Tax Benefits
Beginning balance	64	61	35
Increase in prior period tax positions	1	1	2
Increase in current period tax positions	3	2	24
Ending balance	68	64	61
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(59)	(55)	(51)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	$ 30	$ 26	$ 23

INCOME TAXES - CHANGES IN UNREC

INCOME TAXES - CHANGES IN UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2020	Dec. 31, 2019
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ (41)	$ (8)	$ (8)
Accrual for interest and penalties			1
Interest and penalties expense	1
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	(1)	0	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	(40)	(8)	(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	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Dedicated assets in support of certain benefit plans	$ 512,000	$ 488,000
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	5,000
Settlement charges	22,000	28,000	$ 12,000
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0
Settlement charges	0	0	0
Increase in liability due to special termination benefits			5,000
San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	3,000
Settlement charges	0	0	4,000
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0
Settlement charges	0	0	0
Increase in liability due to special termination benefits			3,000
Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	2,000
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0
Increase in liability due to special termination benefits			2,000
Nonqualified Plan [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement	22,000	24,000	12,000
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
Qualified Plan [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement			54,000
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
Qualified Plan [Member] | Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Benefit obligation payment for settlement			32,000
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	$ 11,000	$ 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, 2020	Dec. 31, 2019	Dec. 31, 2018
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (1,059)	$ (1,067)
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Expected return on plan assets	6.75%
Pension Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 3,768	3,339
Service cost	129	110	$ 124
Interest cost	129	139	140
Contributions from plan participants	0	0
Actuarial loss	351	445
Plan amendments	0	5
Benefit payments	(93)	(93)
Settlements	(207)	(177)
Net obligation at December 31	4,077	3,768	3,339
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	2,662	2,160
Actual return on plan assets	350	496
Employer contributions	290	276
Contributions from plan participants	0	0
Benefit payments	(93)	(93)
Settlements	(207)	(177)
Net recorded (liability) asset at December 31	3,002	2,662	2,160
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(1,075)	(1,106)
Net recorded (liability) asset at December 31	(1,075)	(1,106)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0
Current liabilities	(35)	(59)
Noncurrent liabilities	(1,040)	(1,047)
Net recorded (liability) asset	(1,075)	(1,106)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(102)	(113)
Prior service cost	(11)	(14)
Total	(113)	(127)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	129	110	124
Interest cost	129	139	140
Expected return on assets	(169)	(144)	(157)
Amortization of prior service cost (credit)	12	12	11
Amortization of actuarial loss (gain)	35	36	22
Settlement charges	22	28	66
Special termination benefits	0	0	0
Net periodic benefit cost	158	181	206
Regulatory adjustment	91	77	(30)
Total expense recognized	249	258	176
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	28	17	56
Prior service cost	0	5	12
Amortization of actuarial loss	(14)	(13)	(12)
Amortization of prior service cost	(4)	(3)	(2)
Settlements	(22)	(28)	(12)
Total recognized in OCI	(12)	(22)	42
Total recognized in net periodic benefit cost and OCI	$ 237	$ 236	$ 218
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	2.78%	3.49%
Interest crediting rate	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	3.49%	4.29%	3.64%
Expected return on plan assets	7.00%	7.00%	7.00%
Interest crediting rate	2.28%	3.36%	2.80%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 246
EXPECTED BENEFIT PAYMENTS
2021	389
2022	268
2023	255
2024	246
2025	239
2026-2030	$ 1,130
Pension Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.00%	2.00%
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%
Other Postretirement Benefits Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 913	$ 868
Service cost	18	17	$ 21
Interest cost	33	36	36
Contributions from plan participants	22	21
Actuarial loss	79	45
Plan amendments	0	0
Benefit payments	(74)	(72)
Settlements	(2)	(2)
Net obligation at December 31	989	913	868
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,281	1,108
Actual return on plan assets	164	218
Employer contributions	8	8
Contributions from plan participants	22	21
Benefit payments	(74)	(72)
Settlements	(2)	(2)
Net recorded (liability) asset at December 31	1,399	1,281	1,108
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	410	368
Net recorded (liability) asset at December 31	410	368
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	430	391
Current liabilities	(1)	(3)
Noncurrent liabilities	(19)	(20)
Net recorded (liability) asset	410	368
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	8	10
Prior service cost	0	0
Total	8	10
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	18	17	21
Interest cost	33	36	36
Expected return on assets	(55)	(71)	(70)
Amortization of prior service cost (credit)	(2)	0	1
Amortization of actuarial loss (gain)	(10)	(10)	(6)
Settlement charges	0	0	0
Special termination benefits	0	0	5
Net periodic benefit cost	(16)	(28)	(13)
Regulatory adjustment	16	29	17
Total expense recognized	0	1	4
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	1	(3)	(4)
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	1	(3)	(4)
Total recognized in net periodic benefit cost and OCI	$ 1	$ (2)	$ 0
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	2.88%	3.54%
Interest crediting rate	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	3.54%	4.29%	3.68%
Expected return on plan assets	4.64%	6.48%	6.49%
Interest crediting rate	2.28%	3.36%	2.80%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 5
EXPECTED BENEFIT PAYMENTS
2021	47
2022	47
2023	48
2024	48
2025	47
2026-2030	$ 235
Other Postretirement Benefits Plan [Member] | Pre-65Retiree [Member]
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	6.00%	6.25%	6.50%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
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%	4.75%
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] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.00%	2.00%
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]
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (92)	$ (153)
San Diego Gas and Electric Company [Member] | Pension Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	895	814
Service cost	31	30	$ 30
Interest cost	30	34	35
Contributions from plan participants	0	0
Actuarial loss	37	61
Plan amendments	0	3
Benefit payments	(18)	(18)
Settlements	(52)	(39)
Transfer of liability from other plans	(10)	10
Net obligation at December 31	913	895	814
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	739	600
Actual return on plan assets	94	135
Employer contributions	52	52
Contributions from plan participants	0	0
Benefit payments	(18)	(18)
Settlements	(52)	(39)
Transfer of assets from other plans	4	9
Net recorded (liability) asset at December 31	819	739	600
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(94)	(156)
Net recorded (liability) asset at December 31	(94)	(156)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0
Current liabilities	(2)	(3)
Noncurrent liabilities	(92)	(153)
Net recorded (liability) asset	(94)	(156)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(8)	(9)
Prior service cost	(2)	(7)
Total	(10)	(16)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	31	30	30
Interest cost	30	34	35
Expected return on assets	(49)	(38)	(47)
Amortization of prior service cost (credit)	2	3	2
Amortization of actuarial loss (gain)	3	11	1
Settlement charges	0	0	26
Special termination benefits	0	0	0
Net periodic benefit cost	17	40	47
Regulatory adjustment	38	14	(8)
Total expense recognized	55	54	39
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	6	5	(1)
Prior service cost	0	2	8
Transfer of actuarial loss	(7)	0	0
Transfer of prior service cost	(5)	0	0
Amortization of actuarial loss	(1)	0	(1)
Amortization of prior service cost	(1)	(1)	0
Settlements	0	0	(4)
Total recognized in OCI	(8)	6	2
Total recognized in net periodic benefit cost and OCI	$ 47	$ 60	$ 41
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	2.73%	3.44%
Interest crediting rate	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	3.44%	4.29%	3.64%
Expected return on plan assets	7.00%	7.00%	7.00%
Interest crediting rate	2.28%	3.36%	2.80%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 53
EXPECTED BENEFIT PAYMENTS
2021	112
2022	68
2023	65
2024	61
2025	60
2026-2030	$ 263
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%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.00%	2.00%
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] | Other Postretirement Benefits Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 177	$ 170
Service cost	4	4	$ 5
Interest cost	6	7	7
Contributions from plan participants	8	7
Actuarial loss	17	7
Plan amendments	0	0
Benefit payments	(20)	(18)
Settlements	0	0
Transfer of liability from other plans	1	0
Net obligation at December 31	193	177	170
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	197	172
Actual return on plan assets	26	36
Employer contributions	1	0
Contributions from plan participants	8	7
Benefit payments	(20)	(18)
Settlements	0	0
Transfer of assets from other plans	1	0
Net recorded (liability) asset at December 31	213	197	172
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	20	20
Net recorded (liability) asset at December 31	20	20
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	20	20
Current liabilities	0	0
Noncurrent liabilities	0	0
Net recorded (liability) asset	20	20
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	4	4	5
Interest cost	6	7	7
Expected return on assets	(10)	(11)	(13)
Amortization of prior service cost (credit)	0	2	3
Amortization of actuarial loss (gain)	(3)	(2)	(3)
Settlement charges	0	0	0
Special termination benefits	0	0	3
Net periodic benefit cost	(3)	0	2
Regulatory adjustment	3	0	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
Settlements	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	2.85%	3.55%
Interest crediting rate	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	3.55%	4.30%	3.65%
Expected return on plan assets	5.51%	6.92%	6.94%
Interest crediting rate	2.28%	3.36%	2.80%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2021	10
2022	10
2023	10
2024	10
2025	10
2026-2030	$ 47
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%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.00%	2.00%
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%
Southern California Gas Company [Member] | Pension Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 2,526	$ 2,148
Service cost	86	68	$ 81
Interest cost	88	91	92
Contributions from plan participants	0	0
Actuarial loss	282	345
Plan amendments	0	2
Benefit payments	(60)	(59)
Settlements	(105)	(65)
Transfer of liability from other plans	12	(4)
Net obligation at December 31	2,829	2,526	2,148
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,737	1,385
Actual return on plan assets	243	320
Employer contributions	152	152
Contributions from plan participants	0	0
Benefit payments	(60)	(59)
Settlements	(105)	(65)
Transfer of assets from other plans	2	4
Net recorded (liability) asset at December 31	1,969	1,737	1,385
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(860)	(789)
Net recorded (liability) asset at December 31	(860)	(789)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0
Current liabilities	(7)	(4)
Noncurrent liabilities	(853)	(785)
Net recorded (liability) asset	(860)	(789)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(14)	(7)
Prior service cost	(4)	(3)
Total	(18)	(10)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	86	68	81
Interest cost	88	91	92
Expected return on assets	(107)	(94)	(98)
Amortization of prior service cost (credit)	8	8	8
Amortization of actuarial loss (gain)	26	16	13
Settlement charges	0	0	32
Special termination benefits	0	0	0
Net periodic benefit cost	101	89	128
Regulatory adjustment	53	63	(22)
Total expense recognized	154	152	106
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	6	2	1
Prior service cost	0	3	0
Transfer of actuarial loss	5	(4)	0
Transfer of prior service cost	3	(1)	0
Amortization of actuarial loss	(1)	(1)	0
Amortization of prior service cost	(1)	0	(1)
Total recognized in OCI	12	(1)	0
Total recognized in net periodic benefit cost and OCI	$ 166	$ 151	$ 106
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	2.79%	3.50%
Interest crediting rate	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	3.50%	4.30%	3.65%
Expected return on plan assets	7.00%	7.00%	7.00%
Interest crediting rate	2.28%	3.36%	2.80%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 157
EXPECTED BENEFIT PAYMENTS
2021	226
2022	172
2023	166
2024	159
2025	157
2026-2030	$ 752
Southern California Gas Company [Member] | Pension Plan [Member] | Minimum [Member]
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.00%	2.00%
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] | Other Postretirement Benefits Plan [Member]
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 688	$ 646
Service cost	14	12	$ 15
Interest cost	25	27	27
Contributions from plan participants	14	13
Actuarial loss	57	39
Plan amendments	0	0
Benefit payments	(49)	(49)
Settlements	0	0
Transfer of liability from other plans	0	0
Net obligation at December 31	749	688	646
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,059	916
Actual return on plan assets	134	178
Employer contributions	1	1
Contributions from plan participants	14	13
Benefit payments	(49)	(49)
Settlements	0	0
Transfer of assets from other plans	0	0
Net recorded (liability) asset at December 31	1,159	1,059	916
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	410	371
Net recorded (liability) asset at December 31	410	371
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	410	371
Current liabilities	0	0
Noncurrent liabilities	0	0
Net recorded (liability) asset	410	371
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	14	12	15
Interest cost	25	27	27
Expected return on assets	(43)	(58)	(56)
Amortization of prior service cost (credit)	(2)	(2)	(3)
Amortization of actuarial loss (gain)	(7)	(8)	(2)
Settlement charges	0	0	0
Special termination benefits	0	0	2
Net periodic benefit cost	(13)	(29)	(17)
Regulatory adjustment	13	29	17
Total expense recognized	0	0	0
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	$ 0
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	2.90%	3.55%
Interest crediting rate	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	3.55%	4.30%	3.70%
Expected return on plan assets	4.41%	6.38%	6.38%
Interest crediting rate	2.28%	3.36%	2.80%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2021	34
2022	34
2023	35
2024	35
2025	35
2026-2030	$ 172
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%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.00%	2.00%
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%
Funded Plan [Member] | Pension Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	$ 3,679	$ 3,578
Accumulated benefit obligation	3,265	3,229
Fair value of plan assets	2,788	2,662
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	33	32
Fair value of plan assets	27	25
Funded 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	887	861
Accumulated benefit obligation	834	818
Fair value of plan assets	819	739
Funded 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	2,792	2,505
Accumulated benefit obligation	2,431	2,208
Fair value of plan assets	1,969	1,737
Unfunded Plan [Member] | Pension Plan [Member]
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	184	190
Accumulated benefit obligation	146	158
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	14	16
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	26	34
Accumulated benefit obligation	22	27
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	37	21
Accumulated benefit obligation	$ 31	$ 17

EMPLOYEE BENEFIT PLANS - PLAN A

EMPLOYEE BENEFIT PLANS - PLAN ASSETS (Details)	12 Months Ended
	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.75%
Ultra-long duration government securities [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%
Other Diversifying Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	2.00%
Domestic Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	33.00%
International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	22.00%
Long Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	21.00%
Diversified Real Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	10.00%
Return Seeking Credit [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	7.00%
Minimum [Member] | Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
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	12.00%
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	30.00%
Asset allocations	38.00%
Southern California Gas Company [Member] | Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	70.00%
Asset allocations	62.00%

EMPLOYEE BENEFIT PLANS - FAIR V

EMPLOYEE BENEFIT PLANS - FAIR VALUE OF PLAN ASSETS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 3,002	$ 2,662	$ 2,160
Pension Plan [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	7	17
Pension Plan [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	931	923
Pension Plan [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	563	556
Pension Plan [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	183	96
Pension Plan [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	272	267
Pension Plan [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	13	9
Pension Plan [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	418	346
Pension Plan [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	61	62
Pension Plan [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	37	2
Pension Plan [Member] | Defined Benefit Plan, Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Pension Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 493	$ 417
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Pension Plan [Member] | Private Equity Funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 10	$ 5
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Pension Plan [Member] | Defined Benefit Plan, Accounts Receivable (Payable), Net
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 13	$ (38)
Pension Plan [Member] | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2,486	2,278
Pension Plan [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,924	1,819
Pension Plan [Member] | Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	7	17
Pension Plan [Member] | Level 1 [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	931	923
Pension Plan [Member] | Level 1 [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	563	555
Pension Plan [Member] | Level 1 [Member] | Equity Securities, Registered Investment Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	183	96
Pension Plan [Member] | Level 1 [Member] | Domestic Government Bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	238	228
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] | Defined Benefit Plan, Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	2
Pension Plan [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	562	459
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	0	1
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	34	39
Pension Plan [Member] | Level 2 [Member] | International government bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	13	9
Pension Plan [Member] | Level 2 [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	418	346
Pension Plan [Member] | Level 2 [Member] | International corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	61	62
Pension Plan [Member] | Level 2 [Member] | Registered investment companies [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	37	2
Pension Plan [Member] | Level 2 [Member] | Defined Benefit Plan, Other
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	(1)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,399	1,281	1,108
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	624	602
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	533	478
San Diego Gas and Electric Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	819	739	600
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	213	197	172
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	17	21
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	11	13
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	80	68
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	40	33
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	8
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	1
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	7	8
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 51	$ 47
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan, Accounts Receivable (Payable), Net
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ (2)	$ (2)
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	164	152
San Diego Gas and Electric Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	146	134
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	17	21
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	11	13
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	80	68
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	38	32
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 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	18	18
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	2	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	8
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	1
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	7	8
Southern California Gas Company [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,969	1,737	1,385
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1,159	1,059	$ 916
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	1	3
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	76	78
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	46	48
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	61	52
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	298	288
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	15	11
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	349	309
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	42	40
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	81	75
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	1	3
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 188	$ 157
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan, Venture Capital Funds and Real Estate Funds
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 1
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Defined Benefit Plan, Accounts Receivable (Payable), Net
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets		$ (5)
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 970	907
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	459	452
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	1	3
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	76	78
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	46	48
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	61	52
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	273	267
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	1	3
Southern California Gas Company [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	511	455
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	25	21
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	14	10
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	349	309
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	42	40
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	81	75
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
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	27	25
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	10	9
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6	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	2	4
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Domestic corporate bonds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	3
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	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] | Common/collective trusts [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 4	$ 4
Defined Benefit Plan, Plan Assets, Fair Value by Hierarchy and NAV [Extensible List]	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember	us-gaap:FairValueMeasuredAtNetAssetValuePerShareMember
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Equity Securities, Registered Investment Companies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Fair Value, Inputs, Level 1, 2 and 3
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	23	$ 21
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19	16
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	10	9
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	6	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	2	3
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	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] | Equity Securities, Registered Investment Companies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	1
Other Sempra Energy [Member] | Other Postretirement Benefits Plan [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	4	5
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	0	1
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	4	3
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	$ 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] | Equity Securities, Registered Investment Companies
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 0

EMPLOYEE BENEFIT PLANS - SAVING

EMPLOYEE BENEFIT PLANS - SAVINGS PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 47	$ 44	$ 43
Market value of employer stock held by plan	1,100	1,300
San Diego Gas and Electric Company [Member]
Savings Plan [Line Items]
Employer contributions to defined benefit plan	16	15	15
Southern California Gas Company [Member]
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 25	$ 24	$ 23

SHARE-BASED COMPENSATION - SHAR

SHARE-BASED COMPENSATION - SHARE-BASED COMPENSATION EXPENSE/ OPTIONS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Number of shares available for future grants (in shares)	6,927,284
Number of shares authorized for issuance (in shares)	6,927,284
Share-based compensation expense, before income taxes	$ 62	$ 66	$ 76
Income tax benefit	(17)	(18)	(21)
Share-based Payment Arrangement, Expense, after Tax	45	48	55
Capitalized share-based compensation cost	11	11	10
Excess income tax deficiency	$ 19	$ 4	$ 15
Stock option exercise period (in years)	3 years
Weighted-average fair value for options granted (in dollars per share)	$ 19.76	$ 13.20
Stock price volatility (as a percent)	18.78%	18.63%
Expected term (in years)	5 years 4 months 2 days	5 years 4 months 2 days
Risk-free rate of return (as a percent)	1.68%	2.49%
Annual dividend yield (as a percent)	2.60%	3.35%
Common shares under options
Beginning balance (in shares)	247,577
Options grants in period (in shares)	154,860	261,075	0
Exercised (in shares)	(4,400)	(52,540)	(138,861)
Forfeited/canceled (in shares)	(32,642)
Ending balance (in shares)	365,395	247,577
Vested at period end (in shares)	349,596
Exercisable at period end (in shares)	81,061
Weighted- average exercise price
Beginning balance (in dollars per share)	$ 105.86
Granted (in dollars per share)	149.12
Exercised (in dollars per share)	55.90
Forfeited/canceled (in dollars per share)	149.12
Ending balance (in dollars per share)	120.93	$ 105.86
Vested at period end, Weighted- average exercise price (in dollars per share)	120.28
Exercisable at period end, Weighted- average exercise price (in dollars per share)	$ 106.76
Outstanding at period end, Weighted- average remaining contractual term	8 years 4 months 2 days
Vested at period end, Weighted- average remaining contractual term	8 years 3 months 25 days
Exercisable at period end, Weighted- average remaining contractual term	8 years
Outstanding at period end, Aggregate intrinsic value	$ 2
Vested at period end, Aggregate intrinsic value	2
Exercisable at period end, Aggregate intrinsic value	2
Aggregate intrinsic value of options exercised	$ 0.4	$ 4	$ 9
Weighted average period over which unrecognized compensation cost will be recognized	1 year 3 months 18 days
Weighted-average per share fair value for nonqualified stock options granted (in dollars per share)		$ 106.76
Cash received from exercise of options	$ 0.2	$ 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	11	10	12
Income tax benefit	(3)	(3)	(3)
Share-based Payment Arrangement, Expense, after Tax	8	7	9
Capitalized share-based compensation cost	7	6	6
Excess income tax deficiency	3	1	3
Southern California Gas Company [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Share-based compensation expense, before income taxes	14	15	16
Income tax benefit	(4)	(4)	(5)
Share-based Payment Arrangement, Expense, after Tax	10	11	11
Capitalized share-based compensation cost	4	5	4
Excess income tax deficiency	$ 3	$ 1	$ 2
Share-based Payment Arrangement, Option [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Expiration period	10 years
Awards Granted In 2020 and 2019 [Member] | Share-based Payment Arrangement, Option [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awards Granted In 2010 and Prior [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 2015 [Member] | Performance Shares [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting 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 Granted Prior to 2015 [Member] | Performance Shares [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	4 years
Awards Granted Prior to 2015 [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	4 years
Awarded During Or After 2014 [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting rights maximum additional award	100.00%
Awards Granted in 2019 [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awards Granted During 2015 Through 2018 [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Minimum [Member] | Restricted Stock Units (RSUs), Service-based [Member]
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Maximum [Member] | Restricted Stock Units (RSUs), Service-based [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, 2020	Dec. 31, 2019	Dec. 31, 2018
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free rate of return (as a percent)	1.68%	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	1 year 3 months 18 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	16.35%	17.74%	17.46%
Risk-free rate of return (as a percent)	1.55%	2.46%	2.00%
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)	1,086,981
Granted (in shares)	265,236
Vested (in shares)	(403,302)
Forfeited (in shares)	(54,954)
Nonvested, end of period (in shares)	893,961	1,086,981
Expected to vest (in shares)	882,903
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 109.85
Weighted average grant date fair value, granted (in dollars per share)	155.62	$ 113.54	$ 105.03
Weighted average grant date fair value, vested (in dollars per share)	110.45
Weighted average grant date fair value, forfeited (in dollars per share)	134.90
Weighted average grant date fair value, end of period (in dollars per share)	121.61	$ 109.85
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 121.45
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)	415,787
Granted (in shares)	165,847
Vested (in shares)	(230,612)
Forfeited (in shares)	(7,445)
Nonvested, end of period (in shares)	343,577	415,787
Expected to vest (in shares)	339,025
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 119.96
Weighted average grant date fair value, granted (in dollars per share)	138.91	$ 112.50	$ 107.60
Weighted average grant date fair value, vested (in dollars per share)	112.11
Weighted average grant date fair value, forfeited (in dollars per share)	140.18
Weighted average grant date fair value, end of period (in dollars per share)	121.59	$ 119.96
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 121.46
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	$ 70	$ 36	$ 32
Nonvested awards, compensation cost not yet recognized	$ 28
Weighted average period over which unrecognized compensation cost will be recognized	1 year 8 months 12 days

DERIVATIVE FINANCIAL INSTRUME_3

DERIVATIVE FINANCIAL INSTRUMENTS - COMMODITY VOLUMES (Details)	12 Months Ended
	Dec. 31, 2020MWhMMBTU	Dec. 31, 2019MMBTUMWh
Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	5	32
Electric Energy Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	1	2
Congestion Revenue Rights Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	43	48
SDG&E [Member] | Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	16	37
SDG&E [Member] | Electric Energy Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	1	2
SDG&E [Member] | Congestion Revenue Rights Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	43	48
SoCalGas [Member] | Natural Gas Derivative [Member]
Derivatives, Fair Value [Line Items]
Notional amount, energy measure | MMBTU	1	2

DERIVATIVE FINANCIAL INSTRUME_4

DERIVATIVE FINANCIAL INSTRUMENTS - NOTIONALS AMOUNTS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
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	1,764	1,796
Cash Flow Hedging [Member] | Interest rate instruments [Member]
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 1,486	$ 1,445

DERIVATIVE FINANCIAL INSTRUME_5

DERIVATIVE FINANCIAL INSTRUMENTS - BALANCE SHEET (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Current assets: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	$ 57,000,000	$ 58,000,000
Additional margin posted for commodity contracts not subject to rate recovery	21,000,000	43,000,000
Additional margin posted for commodity contracts subject to rate recovery	30,000,000	25,000,000
Total	108,000,000	126,000,000
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	100,000,000	85,000,000
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	100,000,000	85,000,000
Current liabilities: Other [Member]
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(72,000,000)	(53,000,000)
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	(72,000,000)	(53,000,000)
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	(188,000,000)	(192,000,000)
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	(188,000,000)	(192,000,000)
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	0
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	1,000,000	3,000,000
Designated as Hedging Instrument [Member] | Current liabilities: Other [Member]
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate and foreign exchange instruments	(26,000,000)	(17,000,000)
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	(160,000,000)	(140,000,000)
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	24,000,000	41,000,000
Associated offsetting foreign exchange instruments		(20,000,000)
Commodity contracts not subject to rate recovery	82,000,000	34,000,000
Associated offsetting commodity contracts not subject to rate recovery	(82,000,000)	(32,000,000)
Commodity contracts subject to rate recovery	35,000,000	41,000,000
Associated offsetting commodity contracts subject to rate recovery	(2,000,000)	(6,000,000)
Associated cash collateral commodity contracts subject to rate recovery		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	0
Associated offsetting foreign exchange instruments		0
Commodity contracts not subject to rate recovery	17,000,000	11,000,000
Associated offsetting commodity contracts not subject to rate recovery	(13,000,000)	(2,000,000)
Commodity contracts subject to rate recovery	95,000,000	76,000,000
Associated offsetting commodity contracts subject to rate recovery	0	(3,000,000)
Associated cash collateral commodity contracts subject to rate recovery		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	0	(20,000,000)
Associated offsetting foreign exchange instruments		20,000,000
Commodity contracts not subject to rate recovery	(95,000,000)	(41,000,000)
Associated offsetting commodity contracts not subject to rate recovery	82,000,000	32,000,000
Commodity contracts subject to rate recovery	(35,000,000)	(47,000,000)
Associated offsetting commodity contracts subject to rate recovery	2,000,000	6,000,000
Associated cash collateral commodity contracts subject to rate recovery		14,000,000
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	0
Associated offsetting foreign exchange instruments		0
Commodity contracts not subject to rate recovery	(16,000,000)	(10,000,000)
Associated offsetting commodity contracts not subject to rate recovery	13,000,000	2,000,000
Commodity contracts subject to rate recovery	(25,000,000)	(47,000,000)
Associated offsetting commodity contracts subject to rate recovery	0	3,000,000
Associated cash collateral commodity contracts subject to rate recovery		0
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	31,000,000	26,000,000
Additional margin posted for commodity contracts subject to rate recovery	24,000,000	16,000,000
Total	55,000,000	42,000,000
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	95,000,000	73,000,000
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	95,000,000	73,000,000
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	(27,000,000)	(23,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(27,000,000)	(23,000,000)
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	(25,000,000)	(44,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(25,000,000)	(44,000,000)
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	32,000,000	30,000,000
Associated offsetting commodity contracts subject to rate recovery	(1,000,000)	(4,000,000)
Associated cash collateral commodity contracts subject to rate recovery		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	95,000,000	76,000,000
Associated offsetting commodity contracts subject to rate recovery	0	(3,000,000)
Associated cash collateral commodity contracts subject to rate recovery		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	(28,000,000)	(41,000,000)
Associated offsetting commodity contracts subject to rate recovery	1,000,000	4,000,000
Associated cash collateral commodity contracts subject to rate recovery		14,000,000
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	(25,000,000)	(47,000,000)
Associated offsetting commodity contracts subject to rate recovery	0	3,000,000
Associated cash collateral commodity contracts subject to rate recovery		0
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	2,000,000	9,000,000
Additional margin posted for commodity contracts subject to rate recovery	6,000,000	9,000,000
Total	8,000,000	18,000,000
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	(6,000,000)	(4,000,000)
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	(6,000,000)	(4,000,000)
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	3,000,000	11,000,000
Associated offsetting commodity contracts subject to rate recovery	(1,000,000)	(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	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	(7,000,000)	(6,000,000)
Associated offsetting commodity contracts subject to rate recovery	1,000,000	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	$ 0

DERIVATIVE FINANCIAL INSTRUME_6

DERIVATIVE FINANCIAL INSTRUMENTS - INCOME STATEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	$ (232)	$ (187)	$ 68
Pretax (loss) gain reclassified from AOCI into earnings	(67)	(11)	(13)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | (Loss) Gain on Sale of Assets [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	0	(10)	(9)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Interest Expense [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(34)	(24)	17
Pretax (loss) gain reclassified from AOCI into earnings	(10)	(3)	(1)
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 (loss) gain recognized in OCI	(6)	19	14
Pretax (loss) gain reclassified from AOCI into earnings	(1)	0	1
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Equity Earnings [Member] | Interest rate instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(185)	(164)	44
Pretax (loss) gain reclassified from AOCI into earnings	(46)	(3)	(9)
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Equity Earnings [Member] | Foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain recognized in OCI	(3)	(10)	(3)
Pretax (loss) gain reclassified from AOCI into earnings	0	(2)	2
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 (loss) gain recognized in OCI	(4)	(8)	(4)
Pretax (loss) gain reclassified from AOCI into earnings	1	(2)	1
Designated as Hedging Instrument [Member] | Cash Flow Hedging [Member] | Other (Expense) Income, Net [Member] | Interest rate and foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain reclassified from AOCI into earnings	(11)	9	2
Not Designated as Hedging Instrument [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	42	(100)	313
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	17	12	26
Not Designated as Hedging Instrument [Member] | Other (Expense) Income, Net [Member] | Foreign exchange instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(56)	25	3
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	88	(140)	279
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	(7)	3	5
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 (loss) gain recognized in OCI	0	(1)	1
Pretax (loss) gain reclassified from AOCI into earnings	0	(3)	(7)
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	88	(140)	279
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 (loss) gain recognized in OCI	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	0	(1)	(1)
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	$ (7)	$ 3	$ 5

DERIVATIVE FINANCIAL INSTRUME_7

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES ADDITIONAL INFORMATION (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (87)
Maximum length of time hedged in cash flow hedge	14 years
Equity Method Investee [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Maximum length of time hedged in cash flow hedge	19 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, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	$ 16	$ 21
Aggregate fair value of additional collateral	16
Southern California Gas Company [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	6	$ 4
Aggregate fair value of additional collateral	$ 6

FAIR VALUE MEASUREMENTS - RECUR

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
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
Fair Value, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	$ 1,025	1,074
Support Agreement, net of related guarantee fees	7
Assets fair value disclosure, total	1,240	1,285
Support Agreement, net of related guarantee fees	4
Liabilities fair value disclosure, total	264	245
Fair Value, Recurring [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	364	509
Fair Value, Recurring [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	65	57
Fair Value, Recurring [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	326	282
Fair Value, Recurring [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	270	226
Fair Value, Recurring [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	661	565
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	25	24
Derivative liability	186	157
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	4	11
Effect of netting and allocation of collateral	21	43
Derivative liability	16	17
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	128	108
Effect of netting and allocation of collateral	30	25
Derivative liability	58	85
Effect of netting and allocation of collateral		(14)
Fair Value, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	399	549
Support Agreement, net of related guarantee fees	0
Assets fair value disclosure, total	445	608
Support Agreement, net of related guarantee fees	0
Liabilities fair value disclosure, total	0	0
Fair Value, Recurring [Member] | Level 1 [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	358	503
Fair Value, Recurring [Member] | Level 1 [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	41	46
Fair Value, Recurring [Member] | Level 1 [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Fair Value, Recurring [Member] | Level 1 [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Fair Value, Recurring [Member] | Level 1 [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	41	46
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	21	43
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	6	5
Effect of netting and allocation of collateral	19	11
Derivative liability	0	14
Effect of netting and allocation of collateral		(14)
Fair Value, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	626	525
Support Agreement, net of related guarantee fees	0
Assets fair value disclosure, total	661	576
Support Agreement, net of related guarantee fees	0
Liabilities fair value disclosure, total	208	178
Fair Value, Recurring [Member] | Level 2 [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	6	6
Fair Value, Recurring [Member] | Level 2 [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	24	11
Fair Value, Recurring [Member] | Level 2 [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	326	282
Fair Value, Recurring [Member] | Level 2 [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	270	226
Fair Value, Recurring [Member] | Level 2 [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	620	519
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	25	24
Derivative liability	186	157
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	4	11
Effect of netting and allocation of collateral	0	0
Derivative liability	16	17
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	1	8
Effect of netting and allocation of collateral	5	8
Derivative liability	6	4
Effect of netting and allocation of collateral		0
Fair Value, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Support Agreement, net of related guarantee fees	7
Assets fair value disclosure, total	134	101
Support Agreement, net of related guarantee fees	4
Liabilities fair value disclosure, total	56	67
Fair Value, Recurring [Member] | Level 3 [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Fair Value, Recurring [Member] | Level 3 [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Fair Value, Recurring [Member] | Level 3 [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Fair Value, Recurring [Member] | Level 3 [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
Fair Value, Recurring [Member] | Level 3 [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
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	121	95
Effect of netting and allocation of collateral	6	6
Derivative liability	52	67
Effect of netting and allocation of collateral		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]
Total nuclear decommissioning trusts	1,025	1,074
Assets fair value disclosure, total	1,175	1,189
Liabilities fair value disclosure, total	52	67
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	364	509
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	65	57
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	326	282
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	270	226
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	661	565
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	126	99
Effect of netting and allocation of collateral	24	16
Derivative liability	52	81
Effect of netting and allocation of collateral		(14)
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]
Total nuclear decommissioning trusts	399	549
Assets fair value disclosure, total	422	560
Liabilities fair value disclosure, total	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	358	503
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	41	46
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 1 [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	41	46
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	5	1
Effect of netting and allocation of collateral	18	10
Derivative liability	0	14
Effect of netting and allocation of collateral		(14)
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]
Total nuclear decommissioning trusts	626	525
Assets fair value disclosure, total	626	528
Liabilities fair value disclosure, total	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	6	6
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	24	11
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	326	282
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	270	226
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 2 [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	620	519
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	0	3
Effect of netting and allocation of collateral	0	0
Derivative liability	0	0
Effect of netting and allocation of collateral		0
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]
Total nuclear decommissioning trusts	0	0
Assets fair value disclosure, total	127	101
Liabilities fair value disclosure, total	52	67
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member] | Equity Funds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member] | US Government Debt Securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member] | Municipal Bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member] | Other securities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
San Diego Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Level 3 [Member] | Debt
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0
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	121	95
Effect of netting and allocation of collateral	6	6
Derivative liability	52	67
Effect of netting and allocation of collateral		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	8	18
Liabilities fair value disclosure, total	6	4
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	2	9
Effect of netting and allocation of collateral	6	9
Derivative liability	6	4
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	2	5
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	1	4
Effect of netting and allocation of collateral	1	1
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	6	13
Liabilities fair value disclosure, total	6	4
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	1	5
Effect of netting and allocation of collateral	5	8
Derivative liability	6	4
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, 2020	Dec. 31, 2019	Dec. 31, 2018
Sempra LNG [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 0
Realized and unrealized gains	6,000,000
Settlements	(3,000,000)
Ending balance	3,000,000	$ 0
Change in unrealized gains (losses) relating to instruments still held at the end of the period	3,000,000
San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights, 2019 (price per MWh)			$ (8.57)
Congestion revenue rights, 2020 (price per MWh)		(3.77)
Congestion revenue rights, 2021 (price per MWh)	(1.81)
San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights, 2019 (price per MWh)			35.21
Congestion revenue rights, 2020 (price per MWh)		6.03
Congestion revenue rights, 2021 (price per MWh)	14.11
San Diego Gas and Electric Company [Member] | Median [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights, 2019 (price per MWh)			(2.94)
Congestion revenue rights, 2020 (price per MWh)		(1.58)
Congestion revenue rights, 2021 (price per MWh)	(0.12)
Level 3 [Member] | San Diego Gas and Electric Company [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at beginning of period	28,000,000	179,000,000	(28,000,000)
Realized and unrealized gains (losses)	19,000,000	(184,000,000)	209,000,000
Allocated transmission instruments	6,000,000	6,000,000	10,000,000
Settlements	16,000,000	27,000,000	(12,000,000)
Balance at end of period	69,000,000	28,000,000	179,000,000
Change in unrealized gains (losses) relating to derivative instruments still held at the end of the period	34,000,000	(139,000,000)	$ 183,000,000
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Minimum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs (price per MWh)	19.60	21
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Maximum [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs (price per MWh)	78.10	61.15
Level 3 [Member] | San Diego Gas and Electric Company [Member] | Weighted Average [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs (price per MWh)	39.71	$ 37.92
Level 3 [Member] | Sempra LNG [Member] | Current assets: Other [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	7,000,000
Level 3 [Member] | Sempra LNG [Member] | Deferred Credits and Other [Member]
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Ending balance	$ 4,000,000

FAIR VALUE MEASUREMENTS - FINAN

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	$ 268	$ 225
Finance lease obligations	1,330	1,289
Long term amounts due from unconsolidated affiliates, allowance for credit losses	3
Accrued interest receivable	3
Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	786	742
Long-term amounts due to unconsolidated affiliates	275	195
Total long-term debt	22,259	21,247
Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term amounts due from unconsolidated affiliates	817	759
Long-term amounts due to unconsolidated affiliates	266	184
Total long-term debt	25,478	22,664
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	817	759
Long-term amounts due to unconsolidated affiliates	266	184
Total long-term debt	25,478	22,638
Fair Value [Member] | Level 3 [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	26
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	52	48
Finance lease obligations	1,276	1,270
San Diego Gas and Electric Company [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	6,253	5,140
San Diego Gas and Electric Company [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	7,384	5,662
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	7,384	5,662
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	0
Southern California Gas Company [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Unamortized discount (net of premium) and debt issuance costs	40	34
Finance lease obligations	54	19
Southern California Gas Company [Member] | Carrying Amount [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	4,759	3,809
Southern California Gas Company [Member] | Fair Value [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Total long-term debt	5,655	4,189
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	5,655	4,189
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) - USD ($) $ in Millions	Jan. 01, 2019	Dec. 31, 2018	Jun. 25, 2018	Jun. 30, 2018	Dec. 31, 2018	Apr. 22, 2019
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 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 Renewables [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				$ (1,500)
Asset impairment charges, net of taxes and noncontrolling interests				(900)
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		$ 183	$ (1,300)		(1,100)
Asset impairment charges, net of taxes and noncontrolling interests		126			(629)
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			(1,300)
Asset impairment charges, net of taxes and noncontrolling interests			(755)
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				(200)
Asset impairment charges, net of taxes and noncontrolling interests				$ (145)
Assets, fair value disclosure			145
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
Other than temporary impairment, after tax					145
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
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	$ 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, 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			(0.10)
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, Discount Rate [Member] | 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%
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%
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 (as a percent)			90.90%
Bay Gas [Member] | Sempra LNG [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Ownership interest (as a percent)	9.10%
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 (as a percent)			75.40%

PREFERRED STOCK (Details)

PREFERRED STOCK (Details)	Jun. 19, 2020USD ($)$ / sharesshares	Jul. 13, 2018shares	Jul. 31, 2018USD ($)$ / sharesshares	Jan. 31, 2018USD ($)$ / sharesshares	Dec. 31, 2020USD ($)directorday$ / sharesshares	Dec. 31, 2019USD ($)shares	Dec. 31, 2018shares	Jan. 15, 2021shares
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)					50,000,000	50,000,000
Shares issued (in shares)					0	16,906,185	21,175,473
Increase (decrease) in number of directors | director					2
Sempra Energy [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)					50,000,000
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
Preferred stock, shares issued (in shares)					0	0
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]
Shares issued (in shares)				17,250,000
Stated percentage rate				6.00%
Conversion price per share (in dollars per share) | $ / shares				$ 100
Conversion price per share net of underwriting discount (in dollars per share) | $ / shares				$ 98.20
Value of shares issued | $				$ 1,690,000,000
Underwriting discount | $				$ 32,000,000
Liquidation preference (in dollars per share) | $ / shares				$ 100
Series A Preferred Stock [Member] | Subsequent Event [Member]
Preferred Stock [Line Items]
Shares converted								17,250,000
Series B Preferred Stock [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
Conversion price per share net of underwriting discount (in dollars per share) | $ / shares			$ 98.35
Value of shares issued | $			$ 565,000,000
Underwriting discount | $			$ 10,000,000
Liquidation preference (in dollars per share) | $ / shares			$ 100
Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Conversion price per share (in dollars per share) | $ / shares					$ 100
Threshold appreciation price (in dollars per share) | $ / shares					$ 136.50
Number of shares issuable		4,200,000
Share dividends issued, percentage of weighted average share price		97.00%
Consecutive trading days | day					5
Convertible Preferred Stock Series A [Member]
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)					17,250,000	17,250,000
Convertible Preferred Stock Series A [Member] | Subsequent Event [Member]
Preferred Stock [Line Items]
Shares converted								13,781,025
Preferred stock conversion ratio								0.7989
Series C Preferred Stock [Member]
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)					900,000
Stated percentage rate	4.875%
Preferred stock, shares issued (in shares)	900,000
Preferred stock redemption price (in dollars per share) | $ / shares	$ 1,000
Preferred stock, discount on shares | $	$ 11,000,000
Proceeds from issuance of preferred stock | $	889,000,000
Preferred stock, liquidation preference | $	$ 1,000
Series C Preferred Stock [Member] | Debt Instrument, Redemption, Period Three [Member]
Preferred Stock [Line Items]
Preferred stock redemption price (in dollars per share) | $ / shares	$ 1,020
Liquidation preference per share (as a percent)	102.00%
Series C Preferred Stock [Member] | Debt Instrument, Redemption, Period One [Member]
Preferred Stock [Line Items]
Liquidation preference (in dollars per share) | $ / shares	$ 1,000
Preferred stock, percent	4.875%
Series C Preferred Stock [Member] | Debt Instrument, Redemption, Period Two [Member]
Preferred Stock [Line Items]
Liquidation preference (in dollars per share) | $ / shares	$ 1,000
Preferred stock, percent	4.55%
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 | $					$ 22,000,000	$ 22,000,000
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 | $					$ 3,000,000	3,000,000
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
Preferred stock outstanding | $					$ 19,000,000	19,000,000
So Cal Gas Preferred Stock Owned By Pacific Enterprises [Member]
Preferred Stock [Line Items]
Preferred stock outstanding held by parent | $					$ (2,000,000)	(2,000,000)
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 | $					$ 20,000,000	$ 20,000,000
Minimum [Member] | Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Threshold appreciation price (in dollars per share) | $ / shares					$ 113.75
Shares issuable for each instrument					0.7326
Maximum [Member] | Series B Preferred Stock [Member] | Sempra Energy [Member]
Preferred Stock [Line Items]
Threshold appreciation price (in dollars per share) | $ / shares					$ 136.50
Shares issuable for each instrument					0.8791

SEMPRA ENERGY - SHAREHOLDERS'_3

SEMPRA ENERGY - SHAREHOLDERS' EQUITY AND EARNINGS PER SHARE - COMMON STOCK OFFERINGS (Details) - USD ($)	Aug. 04, 2020	Jul. 01, 2020	Jul. 31, 2018	Jan. 31, 2018	Dec. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2019	Sep. 30, 2019	Jul. 06, 2020	Sep. 11, 2007
Shares issued (in shares)										0	16,906,185	21,175,473
Issuances of common stock, net										$ 11,000,000	$ 1,830,000,000	$ 2,272,000,000
Common Stock [Member]
Stock repurchase program, authorized amount															$ 2,000,000,000	$ 2,000,000,000
Number of shares authorized to be repurchased (in shares)															25,000,000	40,000,000
ASR program, amount prepaid		$ 500,000,000
Common shares repurchased	4,089,375
Common shares repurchased, average price (in dollars per share)	$ 122.27
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													$ 1,200,000,000	$ 2,800,000,000
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							$ 164,000,000		$ 367,000,000
Payments of stock issuance costs							$ 3,000,000		$ 8,000,000
Settlement of Forward Sale Contracts [Member] | Common Stock [Member]
Shares issued (in shares)					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					$ 1,066,000,000	$ 728,000,000		$ 800,000,000	$ 900,000,000
Payments of stock issuance costs					$ 18,000,000	$ 13,000,000		$ 14,000,000	$ 16,000,000
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, shares in Thousands, $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Earnings Per Share [Abstract]
Income from continuing operations, net of income tax									$ 2,255	$ 1,999	$ 938
Earnings attributable to noncontrolling interests									(162)	(129)	(44)
Preferred dividends									(168)	(142)	(125)
Preferred dividends of subsidiary									(1)	(1)	(1)
Earnings from continuing operations attributable to common shares									1,924	1,727	768
Income from discontinued operations, net of income tax	$ 0	$ (7)	$ 1,777	$ 80	$ 71	$ 256	$ 78	$ (42)	1,850	363	188
Earnings attributable to noncontrolling interests									(10)	(35)	(32)
Earnings (losses) from discontinued operations attributable to common shares									1,840	328	156
Earnings attributable to common shares									3,764	2,055	924
Earnings attributable to common shares, diluted									$ 3,764	$ 2,055	$ 924
Weighted-average common shares outstanding for basic EPS (in shares)	289,000	289,500	293,100	292,800	284,600	277,400	275,000	274,700	291,077	277,904	268,072
Dilutive effect of stock options and RSUs (in shares)									1,175	1,585	919
Dilutive effect of common shares sold forward (in shares)									0	2,544	861
Weighted-average number of shares outstanding, diluted (in shares)	290,200	290,600	294,200	313,900	288,800	295,800	279,600	277,200	292,252	282,033	269,852
Earnings from continuing operations attributable to common shares	$ 1.43	$ 1.23	$ 1.58	$ 2.35	$ 1.36	$ 2.04	$ 1.03	$ 1.79	$ 6.61	$ 6.22	$ 2.86
Earnings (losses) from discontinued operations attributable to common shares	0	(0.02)	6.06	0.25	0.21	0.89	0.26	(0.19)	6.32	1.18	0.59
Basic earnings per common share (in shares)									12.93	7.40	3.45
Earnings from continuing operations (in dollars per share)	1.43	1.23	1.58	2.30	1.34	2	1.01	1.78	6.58	6.13	2.84
Earnings (losses) from discontinued operations (in dollars per share)	$ 0	$ (0.02)	$ 6.03	$ 0.23	$ 0.21	$ 0.84	$ 0.25	$ (0.19)	6.30	1.16	0.58
Diluted earnings per common share (in dollars per share)									$ 12.88	$ 7.29	$ 3.42
Fully vested RSUs included in the computation of EPS									537	617	641

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, 2020	Dec. 31, 2019	Dec. 31, 2018
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	187,028	80,281	20,814
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	17,889,365	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, 2020	Dec. 31, 2019	Dec. 31, 2018
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	291,712,925	273,769,513	251,358,977
Shares issued under forward sale agreements	0	16,906,185	21,175,473
RSUs vesting	896,839	463,012	509,042
Stock options exercised	4,400	52,540	138,861
Savings plan issuance	201,431	475,774	553,036
Common stock investment plan	42,955	199,253	231,242
Issuance of RSUs held in our Deferred Compensation Plan	103,552	59,470	3,357
Shares repurchased	(4,491,858)	(212,822)	(200,475)
Common shares outstanding, December 31	288,470,244	291,712,925	273,769,513

SAN ONOFRE NUCLEAR GENERATING_3

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Jointly Owned Utility Plant Interests [Line Items]
Regulatory asset, current	$ 190	$ 222
Regulatory asset, noncurrent	1,822	1,930
San Diego Gas and Electric Company [Member]
Jointly Owned Utility Plant Interests [Line Items]
Regulatory asset, current	174	209
Regulatory asset, noncurrent	$ 534	$ 440
Period of environmental exit	10 years
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]
Receivable for nuclear plant closure	$ 49
Regulatory asset, current	37
Regulatory asset, noncurrent	$ 12
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 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	$ 89

SAN ONOFRE NUCLEAR GENERATING_4

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Debt Securities, Available-for-sale [Line Items]
Cost	$ 731	$ 729
Gross unrealized gains	290	360
Gross unrealized losses	(2)	(7)
Estimated fair value	1,019	1,082
Proceeds from sales	1,439	914	$ 890
Gross realized gains	156	24	42
Gross realized losses	(17)	(5)	$ (10)
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	64	57
Gross unrealized gains	1	0
Gross unrealized losses	0	0
Estimated fair value	65	57
Municipal bonds [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	308	270
Gross unrealized gains	18	12
Gross unrealized losses	0	0
Estimated fair value	326	282
Other securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	253	218
Gross unrealized gains	17	9
Gross unrealized losses	0	(1)
Estimated fair value	270	226
Debt Securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	625	545
Gross unrealized gains	36	21
Gross unrealized losses	0	(1)
Estimated fair value	661	565
Equity securities [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	112	176
Gross unrealized gains	254	339
Gross unrealized losses	(2)	(6)
Estimated fair value	364	509
Cash and cash equivalents [Member]
Debt Securities, Available-for-sale [Line Items]
Cost	3	16
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Estimated fair value	3	16
Accounts Payable
Debt Securities, Available-for-sale [Line Items]
Cost	(9)	(8)
Gross unrealized gains	0	0
Gross unrealized losses	0	0
Estimated fair value	$ (9)	$ (8)

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, 2020USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Decommissioning liability	$ 579
Cost study estimate decommissioning escalated	860
2021	110
2022	83
2023	63
2024	45
2025	44
Thereafter	$ 697

SAN ONOFRE NUCLEAR GENERATING_6

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) - San Diego Gas and Electric Company [Member] $ in Millions	Dec. 31, 2020USD ($)
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	130
Federal nuclear property damage insurance, minimum required	50
Maximum premium assessment under nuclear property damage insurance	3.5
Maximum nuclear property insurance terrorism coverage	$ 3,240

COMMITMENTS AND CONTINGENCIES -

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) £ in Millions

Feb. 22, 2021lawsuitplaintiff

Nov. 30, 2019customer

Feb. 28, 2019USD ($)

Oct. 31, 2018plaintiff

Jan. 31, 2017lawsuit

Sep. 30, 2016USD ($)

Dec. 31, 2020USD ($)lawsuitclaim

Dec. 31, 2020GBP (£)

Dec. 31, 2019USD ($)

Dec. 31, 2018USD ($)claimant

Aug. 31, 2017lawsuit

Oct. 31, 2014USD ($)

Oct. 31, 2014GBP (£)

Loss Contingencies [Line Items]

Loss contingency accrual

$ 616,000,000

Number of alleged violations | customer

330

Reserve for Aliso Canyon costs

141,000,000

$ (144,000,000)

$ 56,000,000

Reserve for Aliso Canyon costs

150,000,000

9,000,000

Equity earnings, before income tax

294,000,000

30,000,000

(236,000,000)

Gas Transmission [Member]

Loss Contingencies [Line Items]

Net book value of pipeline

447,000,000

Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

471,000,000

Recoverable costs through insurance settlement

1,279,000,000

Reserve for Aliso Canyon costs

141,000,000

(144,000,000)

$ 56,000,000

Reserve for Aliso Canyon costs

$ 150,000,000

$ 9,000,000

Energy Future Holdings Corp. [Member]

Loss Contingencies [Line Items]

Proof of claims | claim

28,000

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

Loss Contingencies [Line Items]

Loss contingency accrual

$ 484,000,000

Net book value Of Aliso Canyon Natural Gas Storage Facility

821,000,000

Recorded estimated costs

1,627,000,000

Reserve for Aliso Canyon costs

451,000,000

Insurance receivable for Aliso Canyon costs

445,000,000

Proceeds from insurance settlement

834,000,000

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

Loss Contingencies [Line Items]

Loss contingency accrual

$ 445,000,000

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

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

4

3

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

Reimbursement costs

246,673

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]

Damage awarded

$ 61,000,000

£ 45

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

Loss Contingencies [Line Items]

VAT tax claim paid upon appeal | £

£ 86

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

Loss Contingencies [Line Items]

VAT tax claim, penalty percentage

100.00%

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

R B S Sempra Commodities [Member]

Loss Contingencies [Line Items]

Equity earnings, before income tax

$ 100,000,000

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

209

Number of lawsuits | lawsuit

77

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

395

Number of plaintiffs | plaintiff

36,000

Sempra Mexico [Member] | ECA LNG Regasification facility [Member]

Loss Contingencies [Line Items]

Number of pending claims | lawsuit

4

Number of plaintiffs | claimant

2

Insurance Receivable for Aliso Canyon Costs [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

$ 177,000,000

Aliso Canyon Litigation and Regulatory Matters [Member] | Aliso Canyon Natural Gas Storage Facility Gas Leak [Member] | Southern California Gas Company [Member]

Loss Contingencies [Line Items]

Loss contingency accrual

307,000,000

Loss accrual, net of tax

$ 233,000,000

COMMITMENTS AND CONTINGENCIES_2

COMMITMENTS AND CONTINGENCIES - LEASES BALANCE SHEET INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Right-of-use assets	$ 543	$ 591
Finance leases, property plant and equipment	1,429	1,353
Finance leases, accumulated depreciation	(99)	(64)
Finance leases, property plant and equipment, net	1,330	1,289
Total right-of-use assets	$ 1,873	$ 1,880
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesCurrent	us-gaap:OtherLiabilitiesCurrent
Operating lease, other current liabilities	$ 52	$ 52
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:DeferredCreditsAndOtherLiabilities	us-gaap:DeferredCreditsAndOtherLiabilities
Operating lease, deferred credits and other	$ 407	$ 445
Total lease liabilities	459	497
Finance lease, current portion of long-term debt and finance leases	36	26
Long-term lease liabilities	1,294	1,263
Total finance leases	1,330	1,289
Lease liabilities	$ 1,789	$ 1,786
Operating lease, weighted-average remaining lease term	13 years	13 years
Finance lease, weighted-average remaining lease term	18 years	19 years
Operating lease, weighted-average discount rate (as a percent)	5.81%	6.01%
Finance lease, weighted-average discount rate (as a percent)	14.45%	14.76%
SDG&E [Member]
Lessee, Lease, Description [Line Items]
Variable payments, due in 2021	$ 297
Variable payments, due in 2022	297
Variable payments, due in 2023	296
Variable payments, due in 2024	297
Variable payments, due in 2025	296
Variable payments, due thereafter	3,069
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets	102	$ 130
Finance leases, property plant and equipment	1,356	1,326
Finance leases, accumulated depreciation	(80)	(57)
Finance leases, property plant and equipment, net	1,276	1,269
Total right-of-use assets	1,378	1,399
Operating lease, other current liabilities	27	27
Operating lease, deferred credits and other	73	102
Total lease liabilities	100	129
Finance lease, current portion of long-term debt and finance leases	26	20
Long-term lease liabilities	1,250	1,250
Total finance leases	1,276	1,270
Lease liabilities	$ 1,376	$ 1,399
Operating lease, weighted-average remaining lease term	6 years	6 years
Finance lease, weighted-average remaining lease term	19 years	20 years
Operating lease, weighted-average discount rate (as a percent)	3.62%	3.55%
Finance lease, weighted-average discount rate (as a percent)	14.65%	14.83%
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Right-of-use assets	$ 74	$ 94
Finance leases, property plant and equipment	73	27
Finance leases, accumulated depreciation	(19)	(7)
Finance leases, property plant and equipment, net	54	20
Total right-of-use assets	128	114
Operating lease, other current liabilities	18	18
Operating lease, deferred credits and other	56	75
Total lease liabilities	74	93
Finance lease, current portion of long-term debt and finance leases	10	6
Long-term lease liabilities	44	13
Total finance leases	54	19
Lease liabilities	$ 128	$ 112
Operating lease, weighted-average remaining lease term	5 years	6 years
Finance lease, weighted-average remaining lease term	7 years	6 years
Operating lease, weighted-average discount rate (as a percent)	2.03%	3.73%
Finance lease, weighted-average discount rate (as a percent)	2.83%	3.23%
Maximum [Member]
Lessee, Lease, Description [Line Items]
Operating lease renewal period	20 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) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 92	$ 96
Amortization of ROU assets	35	24
Interest on lease liabilities	188	173
Total finance lease costs	223	197
Short-term lease costs	7	6
Variable lease costs	477	482
Total lease costs	799	781
Depreciation and Amortization Expense [Member]
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	18	15
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	31	33
Amortization of ROU assets	23	18
Interest on lease liabilities	186	173
Total finance lease costs	209	191
Short-term lease costs	3	2
Variable lease costs	467	471
Total lease costs	710	697
San Diego Gas and Electric Company [Member] | Depreciation and Amortization Expense [Member]
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	18	15
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Operating lease costs	24	27
Amortization of ROU assets	12	6
Interest on lease liabilities	2	0
Total finance lease costs	14	6
Short-term lease costs	0	0
Variable lease costs	10	10
Total lease costs	$ 48	$ 43

COMMITMENTS AND CONTINGENCIES_4

COMMITMENTS AND CONTINGENCIES - LEASES CASH FLOW INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	$ 79	$ 101
Cash paid for finance leases	173	173
Cash paid for finance leases	35	24
Increase (decrease) in operating lease obligations for right-of-use assets	20	585
Increase in finance lease obligations for investment in property, plant and equipment	77	38	$ 556
San Diego Gas and Electric Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	31	33
Cash paid for finance leases	171	173
Cash paid for finance leases	23	18
Increase (decrease) in operating lease obligations for right-of-use assets	(1)	158
Increase in finance lease obligations for investment in property, plant and equipment	30	16	550
Southern California Gas Company [Member]
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	24	27
Cash paid for finance leases	2	0
Cash paid for finance leases	12	6
Increase (decrease) in operating lease obligations for right-of-use assets	1	118
Increase in finance lease obligations for investment in property, plant and equipment	$ 47	$ 22	$ 6

COMMITMENTS AND CONTINGENCIES_5

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY ANALYSIS OF LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Operating leases
2021	$ 73
2022	64
2023	55
2024	51
2025	40
Thereafter	415
Total undiscounted lease payments	698
Less: imputed interest	(239)
Total lease liabilities	459	$ 497
Less: current lease liabilities	(52)	(52)
Long-term lease liabilities	407	445
Finance leases
2021	206
2022	203
2023	203
2024	198
2025	193
Thereafter	2,465
Total undiscounted lease payments	3,468
Less: imputed interest	(2,138)
Total finance leases	1,330	1,289
Less: current lease liabilities	(36)	(26)
Long-term lease liabilities	1,294	1,263
San Diego Gas and Electric Company [Member]
Operating leases
2021	30
2022	22
2023	17
2024	15
2025	5
Thereafter	22
Total undiscounted lease payments	111
Less: imputed interest	(11)
Total lease liabilities	100	129
Less: current lease liabilities	(27)	(27)
Long-term lease liabilities	73	102
Finance leases
2021	194
2022	194
2023	194
2024	189
2025	185
Thereafter	2,453
Total undiscounted lease payments	3,409
Less: imputed interest	(2,133)
Total finance leases	1,276	1,270
Less: current lease liabilities	(26)	(20)
Long-term lease liabilities	1,250	1,250
Southern California Gas Company [Member]
Operating leases
2021	19
2022	17
2023	13
2024	11
2025	9
Thereafter	8
Total undiscounted lease payments	77
Less: imputed interest	(3)
Total lease liabilities	74	93
Less: current lease liabilities	(18)	(18)
Long-term lease liabilities	56	75
Finance leases
2021	12
2022	9
2023	9
2024	9
2025	8
Thereafter	12
Total undiscounted lease payments	59
Less: imputed interest	(5)
Total finance leases	54	19
Less: current lease liabilities	(10)	(6)
Long-term lease liabilities	$ 44	$ 13

COMMITMENTS AND CONTINGENCIES_6

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

COMMITMENTS AND CONTINGENCIES_7

COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Lessor, Lease, Description [Line Items]
Property, plant and equipment	$ 53,928	$ 49,329
Accumulated depreciation	(13,925)	(12,877)
Property, plant and equipment, net	40,003	36,452
2021	207
2022	202
2023	202
2024	202
2025	202
Thereafter	2,344
Total undiscounted cash flows	3,359
Fixed lease payments	195	200	$ 194
Variable lease payments	1	6	72
Total revenues from operating leases	196	206	266
Depreciation expense	1,646	1,551	1,470
Assets Leased to Others [Member]
Lessor, Lease, Description [Line Items]
Property, plant and equipment	1,092	1,038
Accumulated depreciation	(228)	(179)
Property, plant and equipment, net	864	859
Depreciation expense	$ 39	$ 38	$ 72

COMMITMENTS AND CONTINGENCIES_8

COMMITMENTS AND CONTINGENCIES - CONTRACTUAL COMMITMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Variable payments, due in 2021	$ 297
Variable payments, due in 2022	297
Variable payments, due in 2023	296
Variable payments, due in 2024	297
Variable payments, due in 2025	296
Variable payments, due thereafter	3,069
Natural Gas Storage and Transportation Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	216
2022	203
2023	189
2024	166
2025	131
Thereafter	1,014
Total minimum payments	1,919
Natural Gas Supply Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	61
2022	13
2023	12
2024	12
2025	6
Thereafter	0
Total minimum payments	104
Natural Gas Supply Contracts [Member] | SoCalGas [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	41
2022	0
2023	0
2024	0
2025	0
Thereafter	0
Total minimum payments	41
Natural Gas Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	277
2022	216
2023	201
2024	178
2025	137
Thereafter	1,014
Total minimum payments	2,023
Payments	989	$ 1,326	$ 1,345
Natural Gas Contracts [Member] | SoCalGas [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	175
2022	126
2023	123
2024	103
2025	68
Thereafter	359
Total minimum payments	954
Payments	935	1,181	1,169
Natural Gas Transportation Contracts [Member] | SoCalGas [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	134
2022	126
2023	123
2024	103
2025	68
Thereafter	359
Total minimum payments	913
Liquefied Natural Gas Contracts [Member] | Sempra LNG [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	320
2022	422
2023	389
2024	386
2025	390
Thereafter	1,452
Total minimum payments	$ 3,359
Long-term Contracts [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	28.00%
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	27.00%
Other Owned Generation [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	43.00%
Spot Market Purchases [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Purchase commitment component percentage	29.00%
Purchased-Power Contracts [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2022	$ 208
2023	173
2024	145
2025	88
Thereafter	794
Total minimum payments	1,630
Purchased-Power Contracts [Member] | SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	222
2022	208
2023	173
2024	145
2025	88
Thereafter	794
Total minimum payments	1,630
Variable payments, due in 2021	66
Variable payments, due in 2022	66
Variable payments, due in 2023	67
Variable payments, due in 2024	65
Variable payments, due in 2025	66
Variable payments, due thereafter	541
Payments	534	$ 744	$ 712
Infrastructure Construction And Improvements [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	525
2022	22
2023	19
2024	16
2025	16
Thereafter	98
Total minimum payments	696
Infrastructure Construction And Improvements [Member] | SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	2
2022	1
2023	1
2024	1
2025	1
Thereafter	19
Construction projects, payable	25
Infrastructure Improvements For Natural Gas And Electric Transmission And Distribution [Member] | SDG&E [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	1
Nuclear Plant Maintenance [Member] | San Diego Gas and Electric Company [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Construction projects, payable	24
Pipelines [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	466
2022	19
2023	16
2024	15
2025	15
Thereafter	79
Total minimum payments	610
Liquid Fuels Terminals [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments	349
Natural Gas Pipelines and Ongoing Maintenance Services [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments	249
Renewables Projects [Member] | Sempra Mexico [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
Total minimum payments	12
Sempra LNG & Midstream Construction [Member] | Sempra LNG [Member]
Unrecorded Unconditional Purchase Obligation, Rolling Maturity [Abstract]
2021	57
2022	2
2023	2
Total minimum payments	$ 61

COMMITMENTS AND CONTINGENCIES_9

COMMITMENTS AND CONTINGENCIES - OTHER COMMITMENTS (Details)	12 Months Ended
	Dec. 31, 2020USD ($)	Dec. 31, 2011USD ($)MMcf
Sunrise Powerlink Construction [Member] | SDG&E [Member]
Loss Contingencies [Line Items]
Expected payment	$ 4,000,000
Expected payment, thereafter	$ 279,000,000
Estimated annual escalation	2.00%
Purchase commitment period	49 years
Present value of future payments	$ 121,000,000
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
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_10

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020USD ($)site	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)
Environmental Issues [Line Items]
Capital expendistures for environmental issues	$ 76	$ 80	$ 100
Accrued liability for environmental matters, discount	$ 9
Accrued liability for environmental matters, discount rate (as a percent)	1.50%
Accrual for environmental loss contingencies	$ 60
Expected future payments for accruals, 2021	12
Expected future payments for accruals, 2022	16
Expected future payments for accruals, 2023	3
Expected future payments for accruals, 2024	6
Expected future payments for accruals, 2025	3
Expected future payments for accruals, thereafter	58
Minimum [Member]
Environmental Issues [Line Items]
Potential monetary sanctions threshold	1
Sempra Energy [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies, current	11
Accrual for environmental loss contingencies, noncurrent	49
Potential monetary sanctions threshold, actual amount	45
San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Capital expendistures for environmental issues	39	39	38
Accrual for environmental loss contingencies	19
Accrual for environmental loss contingencies, current	1
Accrual for environmental loss contingencies, noncurrent	18
Potential monetary sanctions threshold, actual amount	16
Southern California Gas Company [Member]
Environmental Issues [Line Items]
Capital expendistures for environmental issues	37	$ 41	$ 62
Accrual for environmental loss contingencies	40
Accrual for environmental loss contingencies, current	10
Accrual for environmental loss contingencies, noncurrent	30
Potential monetary sanctions threshold, actual amount	15
Other Sempra Energy [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
Manufactured Gas Sites [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	$ 36
Manufactured Gas Sites [Member] | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Number of sites complete | site	3
Number of sites in process | site	0
Accrual for environmental loss contingencies	$ 0
Manufactured Gas Sites [Member] | Southern California Gas Company [Member]
Environmental Issues [Line Items]
Number of sites complete | site	39
Number of sites in process | site	3
Accrual for environmental loss contingencies	$ 36
Manufactured Gas Sites [Member] | Other Sempra Energy [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	0
Waste Disposal Sites [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	$ 10
Waste Disposal Sites [Member] | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Number of sites complete | site	2
Number of sites in process | site	1
Accrual for environmental loss contingencies	$ 6
Waste Disposal Sites [Member] | Southern California Gas Company [Member]
Environmental Issues [Line Items]
Number of sites complete | site	5
Number of sites in process | site	2
Accrual for environmental loss contingencies	$ 3
Waste Disposal Sites [Member] | Other Sempra Energy [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
Other Hazardous Waste Sites [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	14
Other Hazardous Waste Sites [Member] | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	13
Other Hazardous Waste Sites [Member] | Southern California Gas Company [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	1
Other Hazardous Waste Sites [Member] | Other Sempra Energy [Member]
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	0
SONGS Sites [Member] | San Diego Gas and Electric Company [Member]
Environmental Issues [Line Items]
Estimated SONGS mitigation costs, recoverable in rates	84
SONGS mitigation costs incurred	47
SONGS mitigation costs remaining	$ 37

SEGMENT INFORMATION (Details)

SEGMENT INFORMATION (Details) $ in Millions	3 Months Ended	12 Months Ended			21 Months Ended
	Mar. 31, 2019segment	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2020USD ($)segment	May 16, 2019	Mar. 09, 2018
Segment Reporting Information [Line Items]
Number of reportable segments | segment	6				5
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		$ 11,370	$ 10,829	$ 10,102
INTEREST EXPENSE		1,081	1,077	886
INTEREST INCOME		96	87	85
DEPRECIATION AND AMORTIZATION		1,666	1,569	1,491
INCOME TAX EXPENSE (BENEFIT)		249	315	(49)
Earnings attributable to common shares		3,764	2,055	924
Income (loss) from discontinued operations, net of income tax		1,840	328	156
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		4,676	3,708	3,544
ASSETS		66,623	65,665	60,638	$ 66,623
Long-lived assets		53,831	50,074	46,411	53,831
Entity-Wide Disclosure On Geographic Areas, United States [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		10,205	9,574	8,840
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets		46,902	43,719	40,611	46,902
Entity-Wide Disclosure On Geographic Areas Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		1,165	1,255	1,262
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets		6,929	6,355	5,800	6,929
Operating Segments [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		5,313	4,925	4,568
INTEREST EXPENSE		413	411	221
INTEREST INCOME		2	4	4
DEPRECIATION AND AMORTIZATION		801	760	688
INCOME TAX EXPENSE (BENEFIT)		190	171	173
Earnings attributable to common shares		824	767	669
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		1,942	1,522	1,542
ASSETS		22,311	20,560	19,225	22,311
Operating Segments [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		4,748	4,525	3,962
INTEREST EXPENSE		158	141	115
INTEREST INCOME		2	2	2
DEPRECIATION AND AMORTIZATION		654	602	556
INCOME TAX EXPENSE (BENEFIT)		96	120	92
Earnings attributable to common shares		504	641	400
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		1,843	1,439	1,538
ASSETS		18,460	17,077	15,389	18,460
Operating Segments [Member] | Sempra Texas Utilities [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
INCOME TAX EXPENSE (BENEFIT)		1	0	0
Earnings attributable to common shares		579	528	371
Segment Reporting Information, Additional Information [Abstract]
ASSETS		12,542	11,619	9,652	12,542
Operating Segments [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		1,256	1,375	1,376
INTEREST EXPENSE		132	119	120
INTEREST INCOME		60	78	65
DEPRECIATION AND AMORTIZATION		189	183	175
INCOME TAX EXPENSE (BENEFIT)		57	227	185
Earnings attributable to common shares		259	253	237
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		611	624	368
ASSETS		10,752	9,938	9,165	10,752
Operating Segments [Member] | Sempra Renewables [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		0	10	124
INTEREST EXPENSE		0	3	19
INTEREST INCOME		0	11	12
DEPRECIATION AND AMORTIZATION		0	0	27
INCOME TAX EXPENSE (BENEFIT)		0	4	71
Earnings attributable to common shares		0	59	328
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		0	2	51
ASSETS		0	0	2,549	0
Operating Segments [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		374	410	472
INTEREST EXPENSE		43	35	21
INTEREST INCOME		81	61	49
DEPRECIATION AND AMORTIZATION		9	10	26
INCOME TAX EXPENSE (BENEFIT)		92	(5)	(435)
Earnings attributable to common shares		320	(6)	(617)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		268	112	31
ASSETS		2,205	3,901	4,060	2,205
Adjustment and Elimination [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		(3)	(3)	(3)
Income (loss) from discontinued operations, net of income tax		1,840	328	156
Segment Reporting Information, Additional Information [Abstract]
Assets, discontinued operations		0	3,958	3,718	0
Intersegment Eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		(320)	(416)	(397)
INTEREST EXPENSE		(54)	(82)	(106)
INTEREST INCOME		(56)	(73)	(61)
Segment Reporting Information, Additional Information [Abstract]
ASSETS		(856)	(2,137)	(4,190)	(856)
Intersegment Eliminations [Member] | SDG&E [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		5	5	4
Intersegment Eliminations [Member] | SoCalGas [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		88	69	64
Intersegment Eliminations [Member] | Sempra Mexico [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		91	120	114
Intersegment Eliminations [Member] | Sempra LNG [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		136	222	215
All Other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES		2	3	0
INTEREST EXPENSE		389	450	496
INTEREST INCOME		7	4	14
DEPRECIATION AND AMORTIZATION		13	14	19
INCOME TAX EXPENSE (BENEFIT)		(187)	(202)	(135)
Earnings attributable to common shares		(562)	(515)	(620)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT		12	9	14
ASSETS		$ 1,209	$ 749	$ 1,070	$ 1,209
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 (as a percent)		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, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Selected Quarterly Financial Information [Line Items]
Revenues	$ 3,171	$ 2,644	$ 2,526	$ 3,029	$ 2,943	$ 2,758	$ 2,230	$ 2,898	$ 11,370	$ 10,829	$ 10,102
Expenses and other income	2,743	2,443	2,063	2,632	2,444	2,310	1,944	2,397
Income from continuing operations, net of income tax	432	428	528	867	429	653	357	560
Income from discontinued operations, net of income tax	0	(7)	1,777	80	71	256	78	(42)	1,850	363	188
Operating revenues									10,025	9,448	8,539
Net income/Earnings attributable to common shares	432	421	2,305	947	500	909	435	518	4,105	2,362	1,126
Earnings attributable to noncontrolling interest									(172)	(164)	(76)
Earnings attributable to common shares									$ 3,764	$ 2,055	$ 924
Total reclassifications for the period, net of tax	$ 414	$ 351	$ 2,239	$ 760	$ 447	$ 813	$ 354	$ 441
Earnings from continuing operations - Basic EPS (in dollars per share)	$ 1.43	$ 1.23	$ 1.58	$ 2.35	$ 1.36	$ 2.04	$ 1.03	$ 1.79	$ 6.61	$ 6.22	$ 2.86
Basic earnings per common share attributable to Sempra Energy (in dollars per share)	$ 1.43	$ 1.21	$ 7.64	$ 2.60	$ 1.57	$ 2.93	$ 1.29	$ 1.60
Weighted-average number of shares outstanding, basic (in shares)	289,000	289,500	293,100	292,800	284,600	277,400	275,000	274,700	291,077	277,904	268,072
Earnings from continuing operations - Diluted EPS (in dollars per share)	$ 1.43	$ 1.23	$ 1.58	$ 2.30	$ 1.34	$ 2	$ 1.01	$ 1.78	$ 6.58	$ 6.13	$ 2.84
Earnings (losses) from discontinued operations (in dollars per share)	0	(0.02)	6.03	0.23	0.21	0.84	0.25	(0.19)	$ 6.30	$ 1.16	$ 0.58
Diluted earnings per common share attributable to Sempra Energy (in dollars per share)	$ 1.43	$ 1.21	$ 7.61	$ 2.53	$ 1.55	$ 2.84	$ 1.26	$ 1.59
Weighted-average number of shares outstanding, diluted (in shares)	290,200	290,600	294,200	313,900	288,800	295,800	279,600	277,200	292,252	282,033	269,852
Dividends on preferred stock									$ (168)	$ (142)	$ (125)
Earnings (losses) from discontinued operations attributable to common shares	$ 0	$ (0.02)	$ 6.06	$ 0.25	$ 0.21	$ 0.89	$ 0.26	$ (0.19)	$ 6.32	$ 1.18	$ 0.59
San Diego Gas and Electric Company [Member]
Selected Quarterly Financial Information [Line Items]
Operating revenues	$ 1,337	$ 1,472	$ 1,235	$ 1,269	$ 1,259	$ 1,427	$ 1,094	$ 1,145	$ 5,313	$ 4,925	$ 4,568
Operating expenses	1,016	1,157	887	880	894	1,004	831	883	3,940	3,612	3,558
Operating income	321	315	348	389	365	423	263	262	1,373	1,313	1,010
Net income/Earnings attributable to common shares					185	266	146	177	824	774	676
Earnings attributable to noncontrolling interest					0	(3)	(3)	(1)	0	(7)	(7)
Earnings attributable to common shares	191	178	193	262	185	263	143	176	824	767	669
Southern California Gas Company [Member]
Selected Quarterly Financial Information [Line Items]
Operating revenues	1,501	842	1,010	1,395	1,383	975	806	1,361	4,748	4,525	3,962
Operating expenses	1,333	826	773	1,031	1,000	762	747	1,060	3,963	3,569	3,371
Operating income	168	16	237	364	383	213	59	301	785	956	591
Net income/Earnings attributable to common shares	79	(24)	147	303	204	143	31	264	505	642	401
Earnings attributable to common shares	79	(24)	146	303	204	143	30	264	504	641	400
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	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Apr. 30, 2020	Mar. 31, 2020	Apr. 30, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Apr. 24, 2020
Significant Items Affecting Quarterly Results [Line Items]
(Loss) gain on sale of assets								$ (3)	$ 63	$ 513
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member]
Significant Items Affecting Quarterly Results [Line Items]
After tax gain on sale								$ 2,899	$ 0	$ 0
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member] | Luz Del Sur [Member]
Significant Items Affecting Quarterly Results [Line Items]
Proceeds from sale					$ 3,549						$ 3,549
Pretax gain on sale					2,271
After tax gain on sale					$ 1,499
Discontinued Operations, Held-for-sale [Member] | Sempra South American Utilities [Member] | Chilquinta Energia [Member]
Significant Items Affecting Quarterly Results [Line Items]
Proceeds from sale				$ 2,216
Pretax gain on sale				628
After tax gain on sale				$ 248
Disposal Group Held-for-sale [Member] | Wind Generation Projects [Member] | Sempra Renewables [Member]
Significant Items Affecting Quarterly Results [Line Items]
Proceeds from sale	$ 569
(Loss) gain on sale of assets	61						$ 61
Gain on sale of assets, after tax	$ 45						$ 45
Aliso Canyon Litigation and Regulatory Matters [Member] | Southern California Gas Company [Member]
Significant Items Affecting Quarterly Results [Line Items]
Charge for settlement		$ 180	$ 27			$ 100
Litigation fines, after tax		$ 139	$ 22			$ 72

SCHEDULE I - CONDENSED FINANC_3

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, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Condensed Income Statements, Captions [Line Items]
Interest income									$ 96	$ 87	$ 85
Interest expense									(1,081)	(1,077)	(886)
Other (expense) income, net									(48)	77	58
Income tax benefit									(249)	(315)	49
Net of income tax									2,255	1,999	938
Net income	$ 432	$ 421	$ 2,305	$ 947	$ 500	$ 909	$ 435	$ 518	$ 4,105	$ 2,362	$ 1,126
Earnings attributable to common shares	$ 414	$ 351	$ 2,239	$ 760	$ 447	$ 813	$ 354	$ 441
Basic earnings per common share (in shares)									$ 12.93	$ 7.40	$ 3.45
Weighted-average number of shares outstanding, basic (in shares)	289,000	289,500	293,100	292,800	284,600	277,400	275,000	274,700	291,077	277,904	268,072
Diluted earnings per common share (in dollars per share)									$ 12.88	$ 7.29	$ 3.42
Weighted-average number of shares outstanding, diluted (in shares)	290,200	290,600	294,200	313,900	288,800	295,800	279,600	277,200	292,252	282,033	269,852
Parent Company [Member]
Condensed Income Statements, Captions [Line Items]
Interest income									$ 4	$ 3	$ 14
Interest expense									(495)	(521)	(495)
Operating expenses									(86)	(124)	(82)
Other (expense) income, net									(38)	59	(16)
Income tax benefit									176	163	154
Net of income tax									(439)	(420)	(425)
Equity in earnings of subsidiaries, net of income taxes									4,371	2,617	1,474
Net income									3,932	2,197	1,049
Preferred dividends									(168)	(142)	(125)
Earnings attributable to common shares									$ 3,764	$ 2,055	$ 924
Basic earnings per common share (in shares)									$ 12.93	$ 7.40	$ 3.45
Weighted-average number of shares outstanding, basic (in shares)									291,077	277,904	268,072
Diluted earnings per common share (in dollars per share)									$ 12.88	$ 7.29	$ 3.42
Weighted-average number of shares outstanding, diluted (in shares)									292,252	282,033	269,852

SCHEDULE I - CONDENSED FINANC_4

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	3 Months Ended								12 Months Ended
	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Condensed Statement of Income Captions [Line Items]
Net income	$ 432	$ 421	$ 2,305	$ 947	$ 500	$ 909	$ 435	$ 518	$ 4,105	$ 2,362	$ 1,126
Total other comprehensive (loss) income									422	(140)	(133)
Pretax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									5,368	2,585	1,146
Foreign currency translation adjustments									547	(43)	(144)
Financial instruments									(146)	(161)	64
Pension and other postretirement benefits									11	25	(38)
Total other comprehensive (loss) income									412	(179)	(118)
Total comprehensive income, after preferred dividends of subsidiaries									5,779	2,405	1,027
Income tax benefit [Member]
Condensed Statement of Income Captions [Line Items]
Net income									(1,435)	(387)	(96)
Foreign currency translation adjustments									0	0	0
Financial instruments									33	53	(21)
Pension and other postretirement benefits									1	(7)	4
Total other comprehensive (loss) income									34	46	(17)
Total comprehensive income, after preferred dividends of subsidiaries									(1,401)	(341)	(113)
Net-of-tax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									3,933	2,198	1,050
Foreign currency translation adjustments									547	(43)	(144)
Financial instruments									(113)	(108)	43
Pension and other postretirement benefits									12	18	(34)
Total other comprehensive (loss) income									446	(133)	(135)
Total comprehensive income, after preferred dividends of subsidiaries									4,378	2,064	914
Parent Company [Member]
Condensed Statement of Income Captions [Line Items]
Net income									3,932	2,197	1,049
Parent Company [Member] | Pretax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									3,756	2,034	895
Foreign currency translation adjustments									547	(43)	(144)
Financial instruments									(146)	(161)	64
Pension and other postretirement benefits									11	25	(38)
Total other comprehensive (loss) income									412	(179)	(118)
Total comprehensive income, after preferred dividends of subsidiaries									4,168	1,855	777
Parent Company [Member] | Income tax benefit [Member]
Condensed Statement of Income Captions [Line Items]
Net income									176	163	154
Foreign currency translation adjustments									0	0	0
Financial instruments									33	53	(21)
Pension and other postretirement benefits									1	(7)	4
Total other comprehensive (loss) income									34	46	(17)
Total comprehensive income, after preferred dividends of subsidiaries									210	209	137
Parent Company [Member] | Net-of-tax amount [Member]
Condensed Statement of Income Captions [Line Items]
Net income									3,932	2,197	1,049
Foreign currency translation adjustments									547	(43)	(144)
Financial instruments									(113)	(108)	43
Pension and other postretirement benefits									12	18	(34)
Total other comprehensive (loss) income									446	(133)	(135)
Total comprehensive income, after preferred dividends of subsidiaries									$ 4,378	$ 2,064	$ 914

SCHEDULE I - CONDENSED FINANC_5

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
ASSETS
Cash and cash equivalents	$ 960	$ 108
Due from affiliates	20	32
Income taxes receivable	113	112
Other current assets	364	324
Total current assets	4,511	3,339
Due from affiliates	780	742
Deferred income taxes	136	155
Other long-term assets	753	732
Total assets	66,623	65,665	$ 60,638
Liabilities and shareholders’ equity:
Current portion of long-term debt	1,540	1,526
Due to affiliates	45	5
Other current liabilities	1,016	866
Total current liabilities	6,839	9,150
Long-term debt	21,781	20,785
Due to affiliates	234	195
Commitments and contingencies (Note 4)
Total shareholders’ equity	23,373	19,929
Total liabilities and shareholders’ equity	66,623	65,665
Parent Company [Member]
ASSETS
Cash and cash equivalents	366	6	$ 14	$ 104
Due from affiliates	58	98
Income taxes receivable	42	0
Other current assets	26	34
Total current assets	492	138
Investments in subsidiaries	33,898	32,604
Due from affiliates	1	3
Deferred income taxes	2,187	1,766
Other long-term assets	717	682
Total assets	37,295	35,193
Liabilities and shareholders’ equity:
Current portion of long-term debt	850	1,399
Due to affiliates	224	369
Income taxes payable, net	0	274
Other current liabilities	536	561
Total current liabilities	1,610	2,603
Long-term debt	7,317	8,856
Due to affiliates	4,375	3,138
Other long-term liabilities	620	667
Commitments and contingencies (Note 4)
Total shareholders’ equity	23,373	19,929
Total liabilities and shareholders’ equity	$ 37,295	$ 35,193

SCHEDULE I - CONDENSED FINANC_6

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	$ 2,591	$ 3,088	$ 3,516
Expenditures for property, plant and equipment	(4,676)	(3,708)	(3,544)
Expenditures for acquisition	0	0	(9,568)
Distributions from investments	651	247	202
Other	15	21	31
Net cash provided by (used in) investing activities	553	(4,593)	(12,470)
Common stock dividends paid	(1,174)	(993)	(877)
Preferred dividends paid	(157)	(142)	(89)
Proceeds from Issuance of Preferred Stock and Preference Stock	891	0	2,258
Issuances of common stock, net	11	1,830	2,272
Repurchases of common stock	(566)	(26)	(21)
Issuances of long-term debt	6,051	4,296	8,927
Payments on long-term debt	(5,864)	(3,667)	(3,342)
Increase in loans from affiliates, net	7	3	3
Net cash (used in) provided by financing activities	(2,373)	1,475	8,850
Cash and cash equivalents, January 1	108
Cash and cash equivalents, December 31	960	108
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Common dividends issued in stock	22	55	54
Parent Company [Member]
Condensed Cash Flow Statements, Captions [Line Items]
Net cash (used in) provided by operating activities	(978)	294	213
Expenditures for property, plant and equipment	(9)	(8)	(11)
Expenditures for acquisition	0	0	(329)
Capital contributions to investees	(364)	(1,528)	(9,457)
Distributions from investments	3,616	0	0
Decrease (increase) in loans to affiliates, net	2	0	(1)
Other	0	4	0
Net cash provided by (used in) investing activities	3,245	(1,532)	(9,798)
Common stock dividends paid	(1,174)	(993)	(877)
Preferred dividends paid	(157)	(142)	(89)
Proceeds from Issuance of Preferred Stock and Preference Stock	891	0	2,258
Issuances of common stock, net	11	1,830	2,272
Repurchases of common stock	(566)	(26)	(21)
Issuances of long-term debt	1,599	758	4,969
Payments on long-term debt	(3,700)	(1,500)	(500)
Increase in loans from affiliates, net	1,194	1,328	1,520
Equity transaction costs with third parties	(4)	0	0
Debt issuance costs	(1)	(25)	(37)
Net cash (used in) provided by financing activities	(1,907)	1,230	9,495
Increase (decrease) in cash and cash equivalents	360	(8)	(90)
Cash and cash equivalents, January 1	6	14	104
Cash and cash equivalents, December 31	366	6	14
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Preferred dividends declared but not paid	47	36	36
Common dividends issued in stock	22	55	54
Common dividends declared but not paid	$ 301	$ 283	$ 245

SCHEDULE I - CONDENSED FINANC_7

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - FOOTNOTES (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Basis of Presentation
Investment gains (losses) on Rabbi Trust		$ 41	$ 61	$ (6)
Debt Instruments [Abstract]
Current portion of long-term debt		(1,540)	(1,526)
Long-term debt		21,781	20,785
Long-term Debt, Fiscal Year Maturity [Abstract]
2021		1,504
2022		601
2023		2,031
2024		1,064
2025		811
Thereafter		16,248
Operating leases
Total operating lease commitments		698
2021		73
2022		64
2023		55
2024		51
2025		40
Thereafter		415
Parent Company [Member]
Basis of Presentation
Investment gains (losses) on Rabbi Trust		41	61	(6)
Debt Instruments [Abstract]
Gross long-term debt		8,258	10,358
Current portion of long-term debt		(850)	(1,399)
Unamortized discount on long-term debt		(32)	(35)
Unamortized debt issuance costs		(59)	(68)
Long-term debt		7,317	8,856
Long-term Debt, Fiscal Year Maturity [Abstract]
2021		850
2022		500
2023		1,000
2024		500
2025		350
Thereafter		5,100
Operating leases
Total operating lease commitments		257
2021		10
2022		11
2023		12
2024		12
2025		12
Thereafter		$ 200
Parent Company [Member] | Other Long Term Debt Due February 2020 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.40%
Gross long-term debt		$ 0	500
Parent Company [Member] | Other Long Term Debt Due March 2020 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.40%
Gross long-term debt		$ 0	500
Parent Company [Member] | Other Long Term Debt, Due November 2020 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.85%
Gross long-term debt		$ 0	400
Parent Company [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 0	700
Proceeds from issuance of debt	$ 700
Parent Company [Member] | Other Long Term Debt, Due March 2021 [Member]
Debt Instruments [Abstract]
Fixed interest rate after floating to fixed interest rate swaps		3.069%
Gross long-term debt		$ 850	850
Parent Company [Member] | Other Long-term Debt, Due October 2022 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.875%
Gross long-term debt		$ 500	500
Parent Company [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.90%
Gross long-term debt		$ 500	500
Parent Company [Member] | Other Long-term Debt, Due December 2023 [Member]
Debt Instruments [Abstract]
Stated percentage rate		4.05%
Gross long-term debt		$ 500	500
Parent Company [Member] | Other Long Term Debt Due June 2024 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.55%
Gross long-term debt		$ 500	500
Parent Company [Member] | Other Long-term Debt, Due November 2025 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.75%
Gross long-term debt		$ 350	350
Parent Company [Member] | Other Long Term Debt Due June 2027 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.25%
Gross long-term debt		$ 750	750
Parent Company [Member] | Other Long Term Debt Due February 2028 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.40%
Gross long-term debt		$ 1,000	1,000
Parent Company [Member] | Other Long Term Debt Due February 2038 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.80%
Gross long-term debt		$ 1,000	1,000
Parent Company [Member] | Other Long-term Debt, Due October 2039 [Member]
Debt Instruments [Abstract]
Stated percentage rate		6.00%
Gross long-term debt		$ 750	750
Parent Company [Member] | Other Long Term Debt Due February 2048 [Member]
Debt Instruments [Abstract]
Stated percentage rate		4.00%
Gross long-term debt		$ 800	800
Parent Company [Member] | Other Long-term Debt, Junior Subordinated Notes, Due July 2079 [Member]
Debt Instruments [Abstract]
Stated percentage rate		5.75%
Gross long-term debt		$ 758	758
Parent Company [Member] | Foreign exchange instruments [Member]
Basis of Presentation
Gain (loss) on settlement				(3)
PERU | Parent Company [Member] | Foreign exchange instruments [Member]
Basis of Presentation
Gain (loss) on settlement		$ 3	15
Sempra Energy [Member] | Other Long Term Debt Due February 2020 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.40%
Gross long-term debt		$ 0	500
Sempra Energy [Member] | Other Long Term Debt Due March 2020 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.40%
Gross long-term debt		$ 0	500
Sempra Energy [Member] | Other Long Term Debt, Due November 2020 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.85%
Gross long-term debt		$ 0	400
Sempra Energy [Member] | Other Long-term Debt, Due January 2021 [Member]
Debt Instruments [Abstract]
Gross long-term debt		$ 0	700
Sempra Energy [Member] | Other Long Term Debt, Due March 2021 [Member]
Debt Instruments [Abstract]
Fixed interest rate after floating to fixed interest rate swaps		3.069%
Gross long-term debt		$ 850	850
Sempra Energy [Member] | Other Long-term Debt, Due October 2022 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.875%
Gross long-term debt		$ 500	500
Sempra Energy [Member] | Other Long-term Debt, Due February 2023 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.90%
Gross long-term debt		$ 500	500
Sempra Energy [Member] | Other Long-term Debt, Due December 2023 [Member]
Debt Instruments [Abstract]
Stated percentage rate		4.05%
Gross long-term debt		$ 500	500
Sempra Energy [Member] | Other Long Term Debt Due June 2024 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.55%
Gross long-term debt		$ 500	500
Sempra Energy [Member] | Other Long-term Debt, Due November 2025 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.75%
Gross long-term debt		$ 350	350
Sempra Energy [Member] | Other Long Term Debt Due June 2027 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.25%
Gross long-term debt		$ 750	750
Sempra Energy [Member] | Other Long Term Debt Due February 2028 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.40%
Gross long-term debt		$ 1,000	1,000
Sempra Energy [Member] | Other Long Term Debt Due February 2038 [Member]
Debt Instruments [Abstract]
Stated percentage rate		3.80%
Gross long-term debt		$ 1,000	1,000
Sempra Energy [Member] | Other Long-term Debt, Due October 2039 [Member]
Debt Instruments [Abstract]
Stated percentage rate		6.00%
Gross long-term debt		$ 750	750
Sempra Energy [Member] | Other Long Term Debt Due February 2048 [Member]
Debt Instruments [Abstract]
Stated percentage rate		4.00%
Gross long-term debt		$ 800	800
Sempra Energy [Member] | Other Long-term Debt, Junior Subordinated Notes, Due July 2079 [Member]
Debt Instruments [Abstract]
Stated percentage rate		5.75%
Gross long-term debt		$ 758	758
Sempra Energy [Member] | Parent Company [Member]
Basis of Presentation
Cash dividends received		$ 300	$ 150	$ 300
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 January 2021 [Member]
Debt Instruments [Abstract]
Stated percentage rate		2.50%

Uncategorized Items - sre-20201

Label	Element	Value
Accounting Standards Update [Extensible List]	us-gaap_AccountingStandardsUpdateExtensibleList	us-gaap:AccountingStandardsUpdate201712Member