0001032208-22-000007 | 10-K | XBRL Viewer

Share-based Payment Arrangement, Noncash Expense [Abstract]

REGULATORY MATTERS

REGULATORY ASSETS AND LIABILITIES

We show the details of regulatory assets and liabilities in the following table and discuss them below. With the exception of regulatory balancing accounts, we generally do not earn a return on our regulatory assets until such time as a related cash expenditure has been made. Upon the occurrence of a cash expenditure associated with a regulatory asset, the related amounts are recoverable through a regulatory account mechanism for which we earn a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate. The periods during which we recognize a regulatory asset while we do not earn a return vary by regulatory asset.


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	December 31,
	2021		2020		2019
SDG&E:
Fixed-price contracts and other derivatives	$	(50)	$	(53)	$	8
Deferred income taxes recoverable (refundable) in rates	125		22		(108)
Pension and other postretirement benefit plan obligations	(7)		50		103
Removal obligations	(2,251)		(2,121)		(2,056)
Environmental costs	62		56		45
Sunrise Powerlink fire mitigation	122		121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	77		72		102
Gas transportation	49		35		22
Safety and reliability	67		67		77
Public purpose programs	(107)		(158)		(124)
2019 GRC retroactive impacts	—		56		111
Wildfire mitigation plan	178		93		12
Liability insurance premium	110		79		24
Other balancing accounts	207		61		70
Other regulatory assets (liabilities), net(2)	119		72		(153)
Total SDG&E	(1,299)		(1,548)		(1,746)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	44		(82)		(203)
Pension and other postretirement benefit plan obligations	51		417		400
Employee benefit costs	31		37		44
Removal obligations	(627)		(685)		(728)
Environmental costs	34		36		40
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(146)		(56)		(118)
Safety and reliability	339		335		295
Public purpose programs	(183)		(253)		(273)
2019 GRC retroactive impacts	—		202		400
Liability insurance premium	16		7		4
Other balancing accounts	42		(65)		(11)
Other regulatory assets (liabilities), net(2)	142		75		(101)
Total SoCalGas	(257)		(32)		(251)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		80		83
Other regulatory assets	—		—		6
Total Sempra	$	(1,479)	$	(1,500)	$	(1,908)

(1) At December 31, 2021, 2020 and 2019, the noncurrent portion of regulatory balancing accounts – net undercollected for SDG&E was $358, $139 and $108, respectively, and for SoCalGas was $410, $218 and $500, respectively.

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

Regulatory Assets Not Earning a Return

▪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. The related amounts are recovered in rates once these contracts are settled, generally within two years.

▪Deferred income taxes recoverable/refundable in rates are based on current regulatory ratemaking and income tax laws. SDG&E, SoCalGas and Sempra Infrastructure expect to recover/refund net regulatory assets/liabilities related to deferred income taxes over the lives of the assets, ranging from 5 to 69 years, 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. The assets are 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 48-year period.

Regulatory Assets Earning a Return

▪Over- and undercollected regulatory balancing accounts reflect the difference between customer billings and recorded or CPUC-authorized amounts. 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 were recovered in rates over a 24-month period that began in January 2020.

Amortization expense on certain regulatory assets for the years ended December 31, 2021, 2020 and 2019 was $10 million, $9 million and $7 million, respectively, at Sempra, $5 million, $4 million and $3 million, respectively, at SDG&E, and $5 million, $5 million and $4 million, respectively, at SoCalGas.

SEMPRA CALIFORNIA

COVID-19 Pandemic Protections

In connection with the COVID-19 pandemic and at the direction of the CPUC, SDG&E and SoCalGas implemented certain measures to assist customers, including suspending service disconnections due to nonpayment for all customers (except for SoCalGas’ noncore customers), waiving late payment fees, and offering flexible payment plans. At the CPUC’s direction, SDG&E and SoCalGas are automatically enrolling residential and small business customers with past-due balances in long-term repayment plans.

In 2021, SDG&E and SoCalGas applied, on behalf of their customers, for financial assistance from the California Department of Community Services and Development under the California Arrearage Payment Program, which provided funds of $63 million and $79 million for SDG&E and SoCalGas, respectively. In the first quarter of 2022, SDG&E and SoCalGas received and will apply the amounts directly to eligible customer accounts to reduce past due balances.

SDG&E and SoCalGas have been authorized to track and request recovery of incremental costs associated with complying with 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 customers’ failure to pay. SDG&E and SoCalGas expect to pursue recovery of small and medium-large commercial and industrial customers’ tracked costs in rates in future CPUC proceedings, which recovery is not assured. Uncollectible expenses related to residential customers are recorded in a two-way balancing account as we discuss below.

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. As permitted by the decision, SDG&E and SoCalGas have each established 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 GRC

The CPUC uses GRCs to set rates designed to allow SDG&E and SoCalGas to recover their reasonable operating costs and to provide the opportunity to realize their authorized rates of return on their investments.

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. SDG&E and SoCalGas 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). In May 2021, the CPUC issued a final decision approving SDG&E’s and SoCalGas’ request to continue their authorized post-test year mechanisms for 2022 and 2023. For SDG&E, the decision authorizes revenue requirement increases of $87 million (3.92%) for 2022 and $86 million (3.70%) for 2023. For SoCalGas, the decision authorizes revenue requirement increases of $142 million (4.53%) for 2022 and $130 million (3.97%) for 2023.

The 2019 GRC FD approved SDG&E’s and SoCalGas’ 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 SDG&E and SoCalGas 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 SDG&E and SoCalGas released these regulatory liability balances to revenues and regulatory interest.

CPUC Cost of Capital

A CPUC cost of capital proceeding determines a utility’s authorized capital structure and authorized return on rate base. 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, subject to the CCM.


CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
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 applies in the interim years between required cost of capital applications and considers changes in the cost of capital based on changes in interest rates based on the applicable utility bond index published by Moody’s (the CCM benchmark rate) for each 12-month period ending September 30 (the measurement period). The CCM benchmark rate is the basis of comparison to

determine if the CCM is triggered, which occurs if the change in the applicable Moody’s utility bond index relative to the CCM benchmark rate is larger than plus or minus 1.000% at the end of the measurement period. The index applicable to SDG&E and SoCalGas is based on each utility’s credit rating. 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. Alternatively, under the CCM, SDG&E and SoCalGas are permitted to file a cost of capital application in an interim year in which an extraordinary or catastrophic event materially impacts its cost of capital and affects utilities differently than the market as a whole.

For the measurement period ended September 30, 2021, the CCM would trigger for SDG&E because the average Moody’s Baa- utility bond index between October 1, 2020 and September 30, 2021 was 1.17% below SDG&E’s CCM benchmark rate of 4.498%. In August 2021, SDG&E filed an application with the CPUC to update its cost of capital effective January 1, 2022 due to the ongoing effects of the COVID-19 pandemic rather than have the CCM apply. In this application, SDG&E proposed to adjust its authorized capital structure by increasing its common equity ratio from 52% to 54%. SDG&E also proposed to increase its authorized ROE from 10.20% to 10.55% and decrease its authorized cost of debt from 4.59% to 3.84%. As a result, SDG&E’s proposed return on rate base would decrease from 7.55% to 7.46% if such application is approved by the CPUC as filed. SDG&E filed a joint motion with PG&E and Edison to consolidate all three utilities’ cost of capital applications given the overlapping issues of law and fact, which joint motion was granted in October 2021. In December 2021, the CPUC established a proceeding to determine if SDG&E’s cost of capital was impacted by an extraordinary event. If the CPUC finds that there was not an extraordinary event, the CCM would be effective retroactive to January 1, 2022 and would automatically adjust SDG&E’s authorized ROE from 10.20% to 9.62% and adjust its authorized cost of debt to reflect the then current embedded cost and projected interest rate. If the CPUC finds that there was an extraordinary event, it will then determine whether to suspend the CCM for 2022 and preserve SDG&E’s current authorized cost of capital or hold a second phase of the proceeding to set a new cost of capital for 2022. SDG&E expects a final decision in the second half of 2022. In December 2021, the CPUC granted SDG&E the establishment of memorandum accounts effective January 1, 2022 to track any differences in revenue requirement resulting from the interim cost of capital decision expected in 2022.

For the measurement period ended September 30, 2021, the CCM was not triggered for SoCalGas. SDG&E and SoCalGas are required to file their next cost of capital applications in April 2022 for a January 1, 2023 effective date.

SDG&E

FERC Rate Matters

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 (the California ISO adder). If the FERC issues an order ruling that California IOUs are no longer eligible for the California ISO adder, SDG&E would refund the California ISO adder as of the refund effective date (June 1, 2019) if such a refund is determined to be required by the terms of the TO5 settlement. The TO5 term is effective June 1, 2019 and shall remain in effect each calendar quarter until terminated by a notice at least six months before the end of the calendar year. 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 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, SDG&E concluded that some concessions were appropriate, which include refunding certain costs to customers and reducing certain performance-based incentives. 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 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. In September 2021, the CPUC approved the settlement agreement.

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 relating to energy efficiency (EE) codes and standards advocacy activities, undertaken by SoCalGas following a CPUC decision disallowing SoCalGas’ future engagement in advocacy around such EE codes and standards. On February 3, 2022, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 1) that found that SoCalGas did undertake prohibited EE codes and standards advocacy activities using ratepayer funds. POD 1 imposes on SoCalGas a financial penalty of $10 million; customer refunds for certain ratepayer expenditures and shareholder incentives that SoCalGas estimates will be negligible; and a prohibition from recovering from ratepayers costs of proposed codes and standards activities until SoCalGas demonstrates policies, practices and procedures that adhere to the CPUC’s intent for codes and standards advocacy. POD 1 can be appealed within 30 days or be reviewed by any of the CPUC commissioners. If there are no appeals or commissioner requests for review, POD 1 automatically becomes the final decision of the CPUC. SoCalGas does not intend to appeal POD 1.

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 (later expanded to include 2014 and 2015), whether its shareholders should bear the costs of those advocacy activities, and to address whether any other remedies are appropriate. In April 2021, the assigned Administrative Law Judge issued a Presiding Officer’s Decision (POD 2) on this second OSC. POD 2 finds no violations and assesses no fines or penalties but finds that SoCalGas spent ratepayer funds on activities that were not aligned with the CPUC’s intent for EE codes and standards advocacy, and orders customer refunds that SoCalGas estimates will be negligible. Additionally, POD 2 precludes SoCalGas from seeking cost recovery associated with EE codes and standards advocacy programs until lifted by the CPUC, and orders certain nonfinancial remedies. POD 2 was appealed by intervenors and in February 2022, the assigned Administrative Law Judge issued a modified POD 2 that substantially retains the original conclusions, including no fines or penalties. Also, in February 2022, a CPUC commissioner issued an alternative decision that imposes a financial penalty of $150,000. SoCalGas expects that both the modified POD 2 and the CPUC commissioner’s alternative decision will be heard at a CPUC meeting in March 2022.

If the CPUC were to assess fines, penalties or other restrictions on SoCalGas that are different from what has been ordered in POD 1 and the modified POD 2, they could be material to SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

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’s and SDG&E’s Consolidated Statements of Operations.

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. Major decommissioning work began in 2020. We expect the majority of the decommissioning work to take approximately 10 years. 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 cost.

The Samuel Lawrence Foundation filed a writ petition under the California Coastal Act in LA Superior Court in December 2019 seeking to invalidate the coastal development permit and to obtain injunctive relief to stop decommissioning work. The petition was denied in September 2021. In December 2021, the foundation filed a notice of appeal. In September 2020, the 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. In December 2021, the foundation filed a request for dismissal. To date, decommissioning work has not been interrupted as a result of these writ petitions.

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. Amounts that were 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 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 2021, SDG&E received authorization from the CPUC to access NDT funds of up to $78 million for forecasted 2022 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 on the Sempra and SDG&E Consolidated Balance Sheets. We provide additional fair value disclosures for the NDT in Note 12.


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
At December 31, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	56	$	—	$	—	$	56
Municipal bonds(2)	309		13		(1)		321
Other securities(3)	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Short-term investments, primarily 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
Short-term investments, primarily cash equivalents	16		—		—		16
Receivables (payables), net	(8)		—		—		(8)
Total	$	729	$	360	$	(7)	$	1,082

(1) Maturity dates are 2022-2052.

(2) Maturity dates are 2022-2056.

(3) Maturity dates are 2022-2072.

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 NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Proceeds from sales	$	961	$	1,439	$	914
Gross realized gains	67		156		24
Gross realized losses	(5)		(17)		(5)

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’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

The present value of SDG&E’s ARO related to decommissioning costs for all three SONGS units was $568 million at December 31, 2021 and is based on a cost study prepared in 2020, which will be submitted to the CPUC in the first half of 2022. 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. We expect SDG&E’s undiscounted SONGS decommissioning payments to be $79 million in 2022, $66 million in 2023, $77 million in 2024, $46 million in 2025, $52 million in 2026, and $718 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. 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, which is pending DOE approval. It is unclear when Edison will pursue litigation claims for spent fuel management costs incurred on or after August 1, 2018. SDG&E will continue to support Edison in its pursuit of claims on behalf of the SONGS co-owners against the DOE for its failure to timely accept the spent nuclear fuel.

NUCLEAR INSURANCE

SDG&E and the other owners of SONGS have insurance to cover claims from nuclear liability incidents arising at SONGS. Currently, this insurance provides $450 million in coverage limits, the maximum amount available, including coverage for acts of terrorism. In addition, the Price-Anderson Act provides an additional $110 million of coverage. If a nuclear liability loss occurs at SONGS and exceeds the $450 million insurance limit, this additional coverage would be available to provide a total of $560 million in coverage limits per incident.

The SONGS owners 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 $4.3 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.

SHARE-BASED COMPENSATION (Tables)

12 Months Ended

Dec. 31, 2021

Schedule Of Share-based Compensation Expense

Total share-based compensation expense for all of Sempra’s share-based awards was comprised as follows:


SHARE-BASED COMPENSATION EXPENSE
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Share-based compensation expense, before income taxes(1)	$	58	$	62	$	66
Income tax benefit(1)	(16)		(17)		(18)
	$	42	$	45	$	48

Capitalized share-based compensation cost	$	9	$	11	$	11
Excess income tax (benefit) deficiency	$	(9)	$	(19)	$	4
SDG&E:
Share-based compensation expense, before income taxes	$	10	$	11	$	10
Income tax benefit	(3)		(3)		(3)
	$	7	$	8	$	7

Capitalized share-based compensation cost	$	5	$	7	$	6
Excess income tax (benefit) deficiency	$	(1)	$	(3)	$	1
SoCalGas:
Share-based compensation expense, before income taxes	$	14	$	14	$	15
Income tax benefit	(4)		(4)		(4)
	$	10	$	10	$	11

Capitalized share-based compensation cost	$	4	$	4	$	5
Excess income tax (benefit) deficiency	$	(1)	$	(3)	$	1

(1) Includes activity of awards issued from the IEnova 2013 LTIP, which settled in cash upon vesting based on the price of IEnova’s common stock.

Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions

To calculate this fair value, we used the Black-Scholes model with the following weighted-average assumptions:


KEY ASSUMPTIONS FOR STOCK OPTIONS GRANTED

	Years ended December 31,
	2021		2020		2019
Sempra:
Stock price volatility	26.57	%	18.78	%	18.63	%
Expected term	5.36 years		5.34 years		5.34 years
Risk-free rate of return	0.41	%	1.68	%	2.49	%
Annual dividend yield	3.38	%	2.60	%	3.35	%

Schedule Of Non-qualified Stock Options

The following table shows a summary of nonqualified stock options at December 31, 2021 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)
Sempra:
Outstanding at January 1, 2021	365,395	$	120.93
Granted	222,620	$	123.80
Exercised	(50,671)	$	106.76

Outstanding at December 31, 2021	537,344	$	123.45	8.06	$	5

Vested or expected to vest at December 31, 2021	537,344	$	123.45	8.06	$	5
Exercisable at December 31, 2021	152,189	$	118.10	7.27	$	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,
	2021		2020		2019
Sempra:
Stock price volatility	33.39	%	16.35	%	17.74	%
Risk-free rate of return	0.16	%	1.55	%	2.46	%

Schedule Of Restricted Stock Units

The following table shows a summary of RSUs at December 31, 2021 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
Sempra:
Nonvested at January 1, 2021	893,961	$	121.61	343,577	$	121.59
Granted	323,889	$	133.03	143,980	$	124.84
Vested	(317,128)	$	105.03	(202,352)	$	116.28
Forfeited	(29,945)	$	131.55	(7,905)	$	161.49
Nonvested at December 31, 2021(1)	870,777	$	131.64	277,300	$	127.54
Expected to vest at December 31, 2021	854,697	$	131.47	271,197	$	127.47

(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 exceeds target performance conditions.

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER INTANGIBLE ASSETS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Finite-Lived Intangible Assets [Line Items]
Goodwill	$ 1,602	$ 1,602	$ 1,602
Total intangible assets, gross	440	250	250
Accumulated amortization	(70)	(48)	(37)
Other intangible assets	370	202	213
Intangible assets amortization expense	22	11	11
Amortization recorded against revenues	10
Expected amortization, year one	26
Expected amortization, year two	26
Expected amortization, year three	26
Expected amortization, year four	26
Expected amortization, year five	26
Expected amortization expense recorded against revenue, next five years	13
Renewable energy transmission and consumption permits
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	169	169	169
Accumulated amortization	$ (40)	(32)	(24)
Renewable energy transmission and consumption permits \| Minimum
Finite-Lived Intangible Assets [Line Items]
Amortization period	15 years
Renewable energy transmission and consumption permits \| Maximum
Finite-Lived Intangible Assets [Line Items]
Amortization period	19 years
O&M agreement
Finite-Lived Intangible Assets [Line Items]
Amortization period	23 years
Intangible assets, gross	$ 66	66	66
Accumulated amortization	$ (12)	(9)	(6)
ESJ PPA
Finite-Lived Intangible Assets [Line Items]
Amortization period	14 years
Intangible assets, gross	$ 190	0	0
Accumulated amortization	(10)	0	0
Other
Finite-Lived Intangible Assets [Line Items]
Intangible assets, gross	15	15	15
Accumulated amortization	$ (8)	$ (7)	$ (7)
Other \| Minimum
Finite-Lived Intangible Assets [Line Items]
Amortization period	10 years

DEBT AND CREDIT FACILITIES - SCHEDULE OF CALLABLE LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2021 USD ($)
Schedule Of Callable Long-term Debt [Line Items]
Callable long-term debt, not subject to make-whole provisions	$ 2,603
Callable long-term debt, subject to make-whole provisions	$ 17,337

DEBT AND CREDIT FACILITIES - SHORT TERM DEBT DETAILS (Details)	1 Months Ended		12 Months Ended
	Nov. 30, 2021 USD ($) lender	Jun. 30, 2021 USD ($)	Dec. 31, 2021 USD ($) lender	Sep. 30, 2021 USD ($)
Line of Credit Facility [Line Items]
Total facility	$ 1,000,000,000		$ 9,535,000,000
Number of lenders \| lender	12		23
Lenders, percent of facility	8.33%		6.00%
Committed lines of credit, capacity for issuance of letters of credit	$ 200,000,000		$ 100,000,000
Line of credit, increase limit			$ 250,000,000
Maximum ratio of indebtedness to total capitalization (as a percent)			65.00%
Term of contract	3 years
Line of credit			$ 749,000,000
Maximum adjustment EBITDA allowed	5.25
Letters of credit outstanding			682,000,000
Sempra Energy Line Of Credit Due May 2024
Line of Credit Facility [Line Items]
Total facility			1,250,000,000
Line of credit			0
Term Loan Due 2022 \| Secured Debt [Member]
Line of Credit Facility [Line Items]
Variable percentage rate		0.625%
Debt amount		$ 375,000,000	375,000,000
Swingline Sub-Limit
Line of Credit Facility [Line Items]
Line of credit	$ 100,000,000
Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility			470,000,000
Line of credit			321,000,000
Foreign Line of Credit \| Foreign Committed Lines of Credit, Due September 2021
Line of Credit Facility [Line Items]
Total facility			$ 350,000,000	$ 280,000,000
Foreign Line of Credit \| Foreign Committed Lines of Credit, Due September 2021 \| LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate			0.54%
Foreign Line of Credit \| Foreign Committed Lines of Credit, Due February 2024
Line of Credit Facility [Line Items]
Total facility			$ 1,500,000,000
Number of lenders \| lender			10
Foreign Line of Credit \| Foreign Committed Lines of Credit, Due February 2024 \| LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate			0.80%
Foreign Unsecured Line of Credit
Line of Credit Facility [Line Items]
Total facility			$ 470,000,000

REVENUES - DISAGGREGATION OF REVENUE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ 11,676	$ 10,310	$ 10,141
Utilities regulatory revenues	451	570	264
Other revenues	730	490	424
Total revenues	12,857	11,370	10,829
Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	10,540	9,455	9,184
Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,136	855	957
Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	6,969	5,796	5,596
Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,707	4,514	4,545
Operating Segments \| San Diego Gas and Electric Company [Member]
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,144	4,920	4,819
Utilities regulatory revenues	360	393	106
Other revenues	0	0	0
Total revenues	5,504	5,313	4,925
Operating Segments \| San Diego Gas and Electric Company [Member] \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,144	4,920	4,819
Operating Segments \| San Diego Gas and Electric Company [Member] \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments \| San Diego Gas and Electric Company [Member] \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	790	692	587
Operating Segments \| San Diego Gas and Electric Company [Member] \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	4,354	4,228	4,232
Operating Segments \| SoCalGas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,424	4,571	4,367
Utilities regulatory revenues	91	177	158
Other revenues	0	0	0
Total revenues	5,515	4,748	4,525
Operating Segments \| SoCalGas \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,424	4,571	4,367
Operating Segments \| SoCalGas \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments \| SoCalGas \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	5,424	4,571	4,367
Operating Segments \| SoCalGas \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments \| Sempra Infrastructure
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,246	912	1,024
Utilities regulatory revenues	0	0	0
Other revenues	751	488	430
Total revenues	1,997	1,400	1,454
Operating Segments \| Sempra Infrastructure \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	81	58	73
Operating Segments \| Sempra Infrastructure \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	1,165	854	951
Operating Segments \| Sempra Infrastructure \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	856	623	711
Operating Segments \| Sempra Infrastructure \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	390	289	313
Operating Segments \| Sempra Renewables
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	5
Utilities regulatory revenues	0	0	0
Other revenues	0	0	5
Total revenues	0	0	10
Operating Segments \| Sempra Renewables \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments \| Sempra Renewables \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	5
Operating Segments \| Sempra Renewables \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	0
Operating Segments \| Sempra Renewables \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	0	0	5
Consolidating adjustments and Parent and other
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(138)	(93)	(74)
Utilities regulatory revenues	0	0	0
Other revenues	(21)	2	(11)
Total revenues	(159)	(91)	(85)
Consolidating adjustments and Parent and other \| Utilities
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(109)	(94)	(75)
Consolidating adjustments and Parent and other \| Energy-related businesses
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(29)	1	1
Consolidating adjustments and Parent and other \| Gas
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	(101)	(90)	(69)
Consolidating adjustments and Parent and other \| Electric
Disaggregation of Revenue [Line Items]
Revenues from contracts with customers	$ (37)	$ (3)	$ (5)

COMMITMENTS AND CONTINGENCIES - LEASES CASH FLOW INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Cash paid for operating leases	$ 20	$ 24	$ 27
Cash paid for finance leases	2	2	0
Cash paid for finance leases	12	12	6
Increase (decrease) in operating lease obligations for ROU assets	1	1	118
Increase in finance lease obligations for investment in PP&E	$ 19	$ 47	$ 22

DEBT AND CREDIT FACILITIES

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Debt and Credit Facilities

DEBT AND CREDIT FACILITIES

SHORT-TERM DEBT

Committed Lines of Credit

At December 31, 2021, Sempra had an aggregate capacity of $9.5 billion under seven primary committed lines of credit, which provide liquidity and support our commercial paper programs. Because our commercial paper programs are supported by these lines of credit, we reflect the amount of commercial paper outstanding, before reductions of any unamortized discounts, and any letters of credit outstanding as a reduction to the available unused credit capacity.


COMMITTED LINES OF CREDIT
(Dollars in millions)
		At December 31, 2021
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	May 2024	$	3,185	$	(1,240)	$	—	1,945
Sempra	May 2024	1,250		—		—		1,250
SDG&E	May 2024	1,500		(401)		—		1,099
SoCalGas	May 2024	750		(385)		—		365
SI Partners	November 2024	1,000		—		—		1,000
IEnova	September 2023	350		—		(350)		—
IEnova	February 2024	1,500		—		(399)		1,101
Total		$	9,535	$	(2,026)	$	(749)	$	6,760

The principal terms of the Sempra, SDG&E and SoCalGas primary committed lines of credit reflected in the table above include the following:

▪Each facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in any facility.

▪Sempra’s $1.3 billion facility and SDG&E’s and SoCalGas’ facilities provide for the issuance of $200 million, $100 million and $100 million, respectively, of letters of credit. Subject to obtaining commitments from existing or new lenders and satisfaction of other specified conditions, Sempra, SDG&E and SoCalGas each have the right to increase its letter of credit commitment up to $500 million, $250 million and $250 million, respectively.

▪Borrowings bear interest at a benchmark rate plus a margin that varies with the borrower’s credit rating.

▪Each borrower 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, 2021, each entity was in compliance with this ratio under its respective credit facility.

In November 2021, SI Partners entered into a three-year $1.0 billion credit facility. The principal terms of the SI Partners’ line of credit reflected in the table above include the following:

▪A syndication of 12 lenders each having an 8.33% share in the facility.

▪The facility provides for issuance of $200 million of letters of credit.

▪The facility includes a $100 million swingline loan sub-limit, whereby any outstanding amounts would reduce available unused credit. No swingline loan borrowings were outstanding at December 31, 2021.

▪Borrowings are issued in U.S. dollars and letters of credit can be issued in U.S. dollars or Mexican pesos.

▪Borrowings bear interest at a benchmark rate plus a margin that varies with SI Partners’ credit rating.

▪SI Partners must maintain a ratio of consolidated adjusted net indebtedness to consolidated earnings before interest, taxes, depreciation and amortization (as defined in its credit facility) of no more than 5.25 to 1.00 as of the end of each quarter. At December 31, 2021, SI Partners was in compliance with this ratio.

IEnova has two revolving credit facilities. The principal terms of IEnova’s lines of credit reflected in the table above include the following:

▪The $350 million revolving credit facility, which was amended in September 2021 to increase the amount available under the facility from $280 million to $350 million and extend the expiration date from September 2021 to September 2023, has a single lender and borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 54 bps.

▪The $1.5 billion revolving credit facility has a syndicate of 10 lenders and borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 80 bps.

▪Borrowings can be issued in U.S. dollars only.

Uncommitted Lines of Credit

In addition to our committed lines of credit, Sempra Infrastructure’s foreign operations in Mexico have uncommitted lines of credit with an aggregate capacity of $470 million at December 31, 2021, which are generally used for working capital requirements. We reflect amounts outstanding before reductions of any unamortized discounts.


FOREIGN UNCOMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
			December 31, 2021
Borrower	Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
IEnova(1)	September 2022	U.S. dollars	$	250	$	(250)	$	—
ECA LNG Phase 1(2)	August 2023	U.S. dollars or Mexican pesos	100		(63)		37
IEnova(3)	October 2023	U.S. dollars	100		(8)		92
IEnova(4)	October 2023	U.S. dollars or Mexican pesos	20		—		20
	Total		$	470	$	(321)	$	149

(1) Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps.

(2) Outstanding amounts were borrowed in Mexican pesos and bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus 105 bps. Borrowings made in U.S. dollars bear interest at a variable rate based on the 1-month or 3-month LIBOR plus 105 bps.

(3) Borrowings bear interest at a per annum rate equal to between 1-month and 6-month LIBOR plus 52 bps.

(4) Borrowings made in Mexican pesos bear interest at a variable rate based on the 28-day Interbank Equilibrium Interest Rate plus an applicable margin. Borrowings made in U.S. dollars bear interest at a variable rate based on 1-month LIBOR plus an applicable margin. The applicable margin is determined on the date of borrowing.

Uncommitted Letters of Credit

Outside of our domestic and foreign 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, 2021, there was approximately $682 million in standby letters of credit outstanding under these agreements.


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		December 31, 2021
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2022 to May 2022	$	15
SoCalGas	March 2022 to November 2022	15
Sempra Infrastructure	March 2022 to October 2043	473
Parent and other	April 2022 to May 2023	179
Total		$	682

Term Loan

In June 2021, SDG&E entered into a $375 million, 364-day term loan with a maturity date of June 27, 2022. At December 31, 2021, $375 million, net of negligible issuance costs, was outstanding under the term loan. The borrowing bears interest at benchmark rates plus 62.5 bps. The term loan provides SDG&E with additional liquidity outside of its line of credit.

Weighted-Average Interest Rates

The weighted-average interest rates on the total short-term debt at December 31 were as follows:


WEIGHTED-AVERAGE INTEREST RATES

	December 31,
	2021		2020		2019
Sempra	0.60	%	0.83	%	2.31	%
SDG&E	0.65		—		1.97
SoCalGas	0.21		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,
	2021		2020		2019
SDG&E:
First mortgage bonds (collateralized by plant assets):
3% August 15, 2021	$	—	$	350	$	350
1.914% payable 2015 through February 2022	17		53		89
3.6% September 1, 2023	450		450		450
2.5% May 15, 2026	500		500		500
6% June 1, 2026	250		250		250
1.7% October 1, 2030	800		800		—
5.875% January and February 2034(1)	—		—		176
5.35% May 15, 2035	250		250		250
6.125% September 15, 2037	250		250		250
4% May 1, 2039(1)	—		—		75
6% June 1, 2039	300		300		300
5.35% May 15, 2040	250		250		250
4.5% August 15, 2040	500		500		500
3.95% November 15, 2041	250		250		250
4.3% April 1, 2042	250		250		250
3.75% June 1, 2047	400		400		400
4.15% May 15, 2048	400		400		400
4.1% June 15, 2049	400		400		400
3.32% April 15, 2050	400		400		—
2.95% August 15, 2051	750		—		—
	6,417		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	1,217		1,237		1,255
Other	57		39		15
	1,274		1,476		1,270
	7,691		7,529		6,410
Current portion of long-term debt	(49)		(611)		(56)
Unamortized discount on long-term debt	(17)		(13)		(12)
Unamortized debt issuance costs	(44)		(39)		(36)
Total SDG&E	7,581		6,866		6,306

SoCalGas:
First mortgage bonds (collateralized by plant assets):
3.15% September 15, 2024	$	500	$	500	$	500
3.2% June 15, 2025	350		350		350
2.6% June 15, 2026	500		500		500
2.55% February 1, 2030	650		650		—
5.75% November 15, 2035	250		250		250
5.125% November 15, 2040	300		300		300
3.75% September 15, 2042	350		350		350
4.45% March 15, 2044	250		250		250
4.125% June 1, 2048	400		400		400
4.3% January 15, 2049	550		550		550
3.95% February 15, 2050	350		350		350

	4,450		4,450		3,800
Other long-term debt (uncollateralized):
Notes at variable rates (0.55% at December 31, 2021) September 14, 2023(1)	300		300		—
1.875% Notes May 14, 2026(1)	4		4		4
5.67% Notes January 18, 2028(2)	5		5		5
Finance lease obligations	61		54		19
	370		363		28
	4,820		4,813		3,828
Current portion of long-term debt	(11)		(10)		(6)
Unamortized discount on long-term debt	(7)		(8)		(7)
Unamortized debt issuance costs	(29)		(32)		(27)
Total SoCalGas	4,773		4,763		3,788


LONG-TERM DEBT AND FINANCE LEASES (CONTINUED)
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
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		750
3.4% Notes February 1, 2028	1,000		1,000		1,000
3.8% Notes February 1, 2038	1,000		1,000		1,000
6% Notes October 15, 2039	750		750		750
4% Notes February 1, 2048	800		800		800
4.125% Junior Subordinated Notes April 1, 2052(1)	1,000		—		—
5.75% Junior Subordinated Notes July 1, 2079(1)	758		758		758


Sempra Infrastructure:
Other long-term debt (uncollateralized unless otherwise noted):
6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013)	189		197		207
Loan at variable rates (2.93% at December 31, 2021) December 9, 2025	341		17		—
Notes at 2.87% to 3.51% October 1, 2026(1)	—		—		22
Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets(2)	154		196		237
3.75% Notes January 14, 2028	300		300		300
Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)	—		—		11
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
Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034(1)	200		200		200
2.9% Loan November 15, 2034(1)	241		241		—
Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034(1)	100		100		—
4.875% Notes January 14, 2048	540		540		540
4.75% Notes January 15, 2051	800		800		—
	8,923		11,247		12,298
Current portion of long-term debt	(46)		(919)		(1,464)
Unamortized discount on long-term debt	(65)		(55)		(35)

Unamortized debt issuance costs	(98)		(121)		(108)
Total other Sempra	8,714		10,152		10,691
Total Sempra	$	21,068	$	21,781	$	20,785

(1) Callable long-term debt not subject to make-whole provisions.

(2) Debt is not callable.


MATURITIES OF LONG-TERM DEBT(1)
(Dollars in millions)
	SDG&E		SoCalGas		Other Sempra		Total Sempra
2022	$	17	$	—	$	46	$	63
2023	450		300		257		1,007
2024	—		500		48		548
2025	—		350		410		760
2026	750		500		74		1,324
Thereafter	5,200		3,109		8,088		16,397
Total	$	6,417	$	4,759	$	8,923	$	20,099

(1) Excludes finance lease obligations, discounts, and debt issuance costs.

Various long-term obligations totaling $9.1 billion at Sempra at December 31, 2021 are unsecured. This includes unsecured long-term obligations totaling $309 million at SoCalGas. SDG&E does not have unsecured long-term obligations at December 31, 2021.

Callable Long-Term Debt

At the option of Sempra, SDG&E and SoCalGas, certain debt at December 31, 2021 is callable subject to premiums:


CALLABLE LONG-TERM DEBT
(Dollars in millions)
	SDG&E		SoCalGas		Other Sempra		Total Sempra
Not subject to make-whole provisions	$	—	$	304	$	2,299	$	2,603
Subject to make-whole provisions	6,417		4,450		6,470		17,337

First Mortgage Bonds

SDG&E and SoCalGas issue first mortgage bonds secured by liens on their respective utility plant assets. SDG&E and SoCalGas 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 $7.3 billion at SDG&E and $1.9 billion at SoCalGas at December 31, 2021.

SDG&E

In August 2021, SDG&E issued $750 million of 2.95% green first mortgage bonds maturing in 2051 and received proceeds of $737 million, net of debt discount, underwriting discounts and debt issuance costs of $13 million. SDG&E intends to use the net proceeds to finance or refinance eligible projects that fall into one or more of the following categories: climate change adaptation, clean energy solutions and clean transportation.

Other Long-Term Debt

Sempra

In December 2021, Sempra redeemed, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon the early redemptions, we recognized $126 million ($92 million after tax) in charges associated with the make-whole premiums and a write-off of unamortized discount and debt issuance costs.

In November 2021, we issued $1.0 billion of 4.125% fixed-to-fixed reset rate junior subordinated notes maturing on April 1, 2052. Interest on the notes accrues from and including November 19, 2021 and is payable semi-annually in arrears on April 1 and October 1 of each year, beginning on April 1, 2022. The notes will bear interest (i) from and including November 19, 2021 to, but excluding, April 1, 2027 at the rate of 4.125% per annum and (ii) from and including April 1, 2027, during each subsequent five-year period beginning on April 1 of every fifth year, at a rate per annum equal to the Five-year U.S. Treasury Rate (as defined in the notes) as of the day falling two business days before the first day of such five-year period plus a spread of 2.868%, to be reset on April 1 of every fifth year beginning in 2027. We received proceeds of $988 million (net of underwriting discounts and debt issuance costs of $12 million). We used the proceeds from the offering to repay a portion of the aggregate principal amount of the $2.35 billion of senior unsecured notes that we discuss above. We may redeem some or all of the notes before their maturity, as follows:

▪in whole or from time to time in part, on any day during any period from and including the January 1 immediately preceding an interest rate reset date through and including such reset date at a redemption price in cash equal to 100% of the principal amount of the notes to be redeemed, plus accrued and unpaid interest on the notes to be redeemed to, but excluding, the redemption date;

▪in whole but not in part, at any time following the occurrence and during the continuance of a tax event (as defined in the notes) at a redemption price in cash equal to 100% of the principal amount of the notes, plus accrued and unpaid interest on the notes to, but excluding, the redemption date; and

▪in whole but not in part, at any time following the occurrence and during the continuance of a rating agency event (as defined in the notes) at a redemption price in cash equal to 102% of the principal amount of the notes, plus accrued and unpaid interest on the notes to, but excluding, the redemption date.

The notes are unsecured obligations and rank junior and subordinate in right of payment to our existing and future senior indebtedness. The notes rank equally in right of payment with our existing 5.75% junior subordinated notes due 2079 and with any future unsecured indebtedness that we may incur if the terms of such indebtedness provide that it ranks equally with the notes in right of payment. The notes are effectively subordinated in right of payment to any secured indebtedness we have incurred or may incur and to all existing and future indebtedness and other liabilities of our subsidiaries.

SDG&E

On February 18, 2022, SDG&E entered into a $400 million, two-year term loan with a maturity date of February 18, 2024. SDG&E may request up to three borrowings for an aggregate amount of $400 million through May 18, 2022. On February 18, 2022, SDG&E borrowed $200 million. The borrowing bears interest at benchmark rates plus 62.5 bps. The margin is based on SDG&E’s long-term senior unsecured credit rating.

Sempra Infrastructure

SI Partners. On January 11, 2022, SI Partners completed a private offering of $400 million in aggregate principal of 3.25% senior notes due January 15, 2032 to “qualified institutional buyers” as defined in Rule 144A under the Securities Act of 1933, as amended (the Securities Act), and non-U.S. persons outside the U.S. under Regulation S under the Securities Act. The notes were issued at 98.903% of the principal amount and require semi-annual interest payments in January and July, commencing July 15, 2022. The notes are senior unsecured obligations that rank equally with all of SI Partners’ existing and future outstanding unsecured senior indebtedness. Sempra Infrastructure received proceeds of $390 million (net of debt discount, underwriting discounts and debt issuance costs of $10 million). Sempra Infrastructure intends to use the net proceeds for general corporate purposes, which may include the repayment of certain indebtedness of its subsidiaries.

At any time prior to October 15, 2031, SI Partners may redeem some or all of the notes by paying the greater of (i) 100% of the principal amount of the notes to be redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest thereon (exclusive of interest accrued to, but excluding, the date of redemption) as if redeemed on October 15, 2031 discounted to the redemption date on a semi-annual basis at the U.S. Treasury rate plus 25 bps and, in each case, accrued and unpaid interest to, but excluding, the date of redemption. At any time beginning on October 15, 2031, SI Partners may redeem some or all of the notes by paying 100% of the principal amount of the notes to be redeemed, plus, in each case, accrued and unpaid interest to, but excluding, the date of redemption. Upon the occurrence of specific kinds of change of control events that result in a downgrade of SI Partners’ credit ratings, holders of the notes would have the right to require SI Partners to offer to purchase some or all of the notes at 101% of the then outstanding principal amount thereof, plus, in each case, accrued and unpaid interest to, but excluding, the date of redemption.

ECA LNG Phase 1. 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. 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 and TotalEnergies 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 83.4% 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 TotalEnergies SE as a guarantor. At December 31, 2021 and 2020, $341 million and $17 million, respectively, was outstanding under the loan agreement, with a weighted-average interest rate of 2.93% and 2.82%, respectively.

ESJ. As we discuss in Note 5, through its acquisition of the remaining 50% of ESJ, Sempra Infrastructure assumed a $177 million (net of $6 million in unamortized debt issuance costs) variable rate loan payable to a syndicate of five lenders that matures in June 2033. To moderate exposure to interest rate and associated cash flow variability, ESJ entered into floating-to-fixed rate swaps for 90% of the principal balance, resulting in a fixed rate of 6.13%. The remaining 10% of the principal balance bore interest at 6-month LIBOR plus a margin of 2.63% with an increase of 25 bps every four years. On October 8, 2021, Sempra Infrastructure used proceeds from borrowings against IEnova’s committed and uncommitted lines of credit to fully repay the $175 million of outstanding principal plus accrued and unpaid interest on the ESJ loan prior to its scheduled maturity in 2033, and recognized $18 million ($10 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

Ventika. On October 13, 2021, Sempra Infrastructure used proceeds from borrowings against IEnova’s committed and uncommitted lines of credit to fully repay $375 million of outstanding principal plus accrued and unpaid interest on the Ventika fixed- and variable-rate loans prior to scheduled maturity dates through 2032, and recognized $36 million ($20 million after tax and NCI) in charges associated with hedge termination costs and a write-off of unamortized debt issuance costs.

The entire disclosure for information about short-term and long-term debt arrangements, which includes amounts of borrowings under each line of credit, note payable, commercial paper issue, bonds indenture, debenture issue, own-share lending arrangements and any other contractual agreement to repay funds, and about the underlying arrangements, rationale for a classification as long-term, including repayment terms, interest rates, collateral provided, restrictions on use of assets and activities, whether or not in compliance with debt covenants, and other matters important to users of the financial statements, such as the effects of refinancing and noncompliance with debt covenants.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-URI http://asc.fasb.org/topic&trid=2208564

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (h)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1I
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495371-112611

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1I
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495371-112611

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(c))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (g)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1C
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495334-112611

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1E
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495348-112611

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1I
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495371-112611

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 20
-Section 50
-Paragraph 1B
-Subparagraph (i)
-URI http://asc.fasb.org/extlink&oid=123466505&loc=SL123495323-112611

Condensed Financial Information Disclosure [Abstract]

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT

12 Months Ended

Dec. 31, 2021

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,
	2021		2020		2019
Interest income	$	11	$	4	$	3
Interest expense	(576)		(495)		(521)
Operating expenses	(92)		(86)		(124)
Other income (expense), net	20		(38)		59
Income tax benefit	190		176		163
Loss before equity in earnings of subsidiaries	(447)		(439)		(420)
Equity in earnings of subsidiaries, net of income taxes	1,764		4,371		2,617
Net income	1,317		3,932		2,197
Preferred dividends	(63)		(168)		(142)
Earnings	$	1,254	$	3,764	$	2,055

Basic EPS:
Earnings	$	4.03	$	12.93	$	7.40
Weighted-average common shares outstanding	311,755		291,077		277,904

Diluted EPS:
Earnings	$	4.01	$	12.88	$	7.29
Weighted-average common shares outstanding	313,036		292,252		282,033

See Notes to Condensed Financial Information of Parent.


SEMPRA ENERGY
CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
	Years ended December 31, 2021, 2020 and 2019
	Pretax amount		Income tax benefit (expense)		Net-of-tax amount
2021:
Net income	$	1,127	$	190	$	1,317
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)		—		(6)
Financial instruments	191		(47)		144
Pension and other postretirement benefits	28		(6)		22
Total other comprehensive income	213		(53)		160
Comprehensive income	$	1,340	$	137	$	1,477
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

See Notes to Condensed Financial Information of Parent.


SEMPRA ENERGY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	December 31,
	2021		2020		2019
Assets:
Cash and cash equivalents	$	186	$	366	$	6
Restricted cash	2		—		—
Due from affiliates	446		58		98
Income taxes receivable, net	—		42		—
Other current assets	31		26		34
Total current assets	665		492		138

Investments in subsidiaries	33,308		33,898		32,604
Due from affiliates	21		1		3
Deferred income taxes	626		2,187		1,766
Other long-term assets	1,090		717		682
Total assets	$	35,710	$	37,295	$	35,193

Liabilities and shareholders’ equity:
Short-term debt	$	1,240	$	—	$	—
Current portion of long-term debt	—		850		1,399
Due to affiliates	185		224		369
Income taxes payable, net	4		—		274
Other current liabilities	531		536		561
Total current liabilities	1,960		1,610		2,603

Long-term debt	5,969		7,317		8,856
Due to affiliates	1,151		4,375		3,138
Other long-term liabilities	649		620		667

Commitments and contingencies (Note 4)

Shareholders’ equity	25,981		23,373		19,929
Total liabilities and shareholders’ equity	$	35,710	$	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,
	2021		2020		2019
Net cash (used in) provided by operating activities	$	(255)	$	(978)	$	294

Expenditures for property, plant and equipment	(8)		(9)		(8)
Capital contributions to investees	(1,005)		(364)		(1,528)
Disbursement for note receivable	(305)		—		—
Distribution from investments	1,552		3,616		—
(Increase) decrease in loans to affiliates, net	(20)		2		—
Other	—		—		4
Net cash provided by (used in) investing activities	214		3,245		(1,532)

Common stock dividends paid	(1,331)		(1,174)		(993)
Preferred dividends paid	(99)		(157)		(142)
Issuances of preferred stock, net	—		891		—
Issuances of common stock, net	5		11		1,830
Repurchases of common stock	(339)		(566)		(26)
Issuances of long-term debt	990		1,599		758
Payments on long-term debt	(3,200)		(3,700)		(1,500)
Increase in short-term debt	1,240		—		—
Increase in loans from affiliates, net	1,092		1,194		1,328
Purchases of noncontrolling interest	(217)		—		—
Proceeds from sale of noncontrolling interest	1,846		—		—
Equity transaction costs with third parties	—		(4)		—
Debt issuance costs	—		(1)		(25)
Make-whole premiums related to early redemptions of debt	(121)		—		—
Other financing	(2)		—		—
Net cash (used in) provided by financing activities	(136)		(1,907)		1,230

Effect of exchange rate changes on cash and cash equivalents	(1)		—		—

(Decrease) increase in cash and cash equivalents	(178)		360		(8)
Cash and cash equivalents, January 1	366		6		14
Cash, cash equivalents and restricted cash, December 31	$	188	$	366	$	6

SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Issuance of common stock in exchange for NCI and related AOCI	$	1,373	$	—	$	—
Common dividends issued in stock	—		22		55
Common dividends declared but not paid	349		301		283
Conversion of mandatory convertible preferred stock	2,258		—		—
Preferred dividends declared but not paid	11		47		36
Equitization of amounts due from affiliates	4,351		—		—

See Notes to Condensed Financial Information of Parent.

BASIS OF PRESENTATION

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, except that Sempra Energy accounts for the earnings of its subsidiaries under the equity method in this unconsolidated financial information.

Sempra Energy received cash dividends from its consolidated subsidiaries totaling $375 million, $300 million and $150 million in 2021, 2020 and 2019, respectively.

NEW ACCOUNTING STANDARDS

We describe below and in Note 2 of the Notes to Consolidated Financial Statements recent pronouncements that have had or may have a significant effect on Sempra Energy’s results of operations, financial condition, cash flows or disclosures.

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 and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. 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 will adopt the standard on January 1, 2022 using a modified retrospective approach and do not expect the adoption will materially impact our financial statements or per-share amounts.

SHORT-TERM DEBT

Committed Line of Credit

At December 31, 2021, Sempra Energy had an aggregate capacity of $4.4 billion under two primary committed lines of credit and available unused credit of $3.1 billion, which provide liquidity and support its commercial paper program. The amount of commercial paper outstanding, before reduction of any unamortized discount, and any letters of credit outstanding is reflected as a reduction to the available unused credit.

The principal terms of Sempra Energy’s committed lines of credit include the following:

▪Each facility has a syndicate of 23 lenders. No single lender has greater than a 6% share in the facility.

▪One facility provides for the issuance of $200 million of 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 its letter of credit commitment to $500 million. No letters of credit were outstanding at December 31, 2021.

▪Borrowings bear interest at a benchmark rate plus a margin that varies with Sempra Energy’s credit rating.

▪Sempra Energy must maintain a ratio of indebtedness to total capitalization (as defined in its credit facility) of no more than 65% at the end of each quarter. At December 31, 2021, Sempra Energy was in compliance with this ratio under credit facility.

LONG-TERM DEBT

The following table shows the detail and maturities of long-term debt outstanding:


LONG-TERM DEBT
(Dollars in millions)
	December 31,
	2021		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		750
3.4% Notes February 1, 2028	1,000		1,000		1,000
3.8% Notes February 1, 2038	1,000		1,000		1,000
6% Notes October 15, 2039	750		750		750
4% Notes February 1, 2048	800		800		800
4.125% Junior Subordinated Notes April 1, 2052(1)	1,000		—		—
5.75% Junior Subordinated Notes July 1, 2079(1)	758		758		758
	6,058		8,258		10,358
Current portion of long-term debt	—		(850)		(1,399)
Unamortized discount on long-term debt	(37)		(32)		(35)
Unamortized debt issuance costs	(52)		(59)		(68)
Total long-term debt	$	5,969	$	7,317	$	8,856

(1) Callable long-term debt not subject to make-whole provisions.

In December 2021, Sempra Energy redeemed, at respective make-whole redemption prices, an aggregate principal amount of $2.35 billion of senior unsecured notes prior to scheduled maturities in 2022 through 2025. Upon the early redemptions, we recognized $126 million ($92 million after tax) in charges associated with the make-whole premiums and a write-off of unamortized discount and debt issuance costs.

At December 31, 2021, long-term debt maturities totaling $6.1 billion commence after 2026.

Additional information on Sempra Energy’s long-term debt is provided in Note 7 of the Notes to Consolidated Financial Statements.

COMMITMENTS AND CONTINGENCIES

Sempra Energy has an operating lease commitment related to its corporate headquarters building of approximately $279 million. Sempra Energy expects payments for its operating lease to be $11 million in 2022, $12 million in each of 2023 through 2026 and $220 million thereafter.

For other contingencies and guarantees related to Sempra Energy, refer to Notes 6 and 16 of the Notes to Consolidated Financial Statements.

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - WILDFIRE FUND (Details) - USD ($)	1 Months Ended	12 Months Ended
	Jul. 31, 2019	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Sep. 30, 2019
Loss Contingencies [Line Items]
Fire risk mitigation capital improvements	$ 215,000,000
Wildfire fund, threshold amount to seek payment	$ 1,000,000,000
Wildfire fund, threshold percentage of equity portion of electric transmission	20.00%
Initial liability cap		$ 1,100,000,000
Liquidity fund, maximum borrowing capacity		10,500,000,000
Initial shareholder contributions		7,500,000,000			$ 322,500,000
Additional annual contributions, aggregate value		$ 129,000,000
Period of annual contributions		10 years
Wildfire fund asset				$ 451,500,000
Annual contributions		$ 12,900,000
Amortization of wildfire fund asset		15 years
Current portion of Wildfire fund		$ 29,000,000	$ 29,000,000	29,000,000
Noncurrent portion of the Wildfire Fund asset		331,000,000	363,000,000	392,000,000
Wildfire fund obligations in current liabilities		13,000,000	13,000,000	13,000,000
Noncurrent Wildfire Fund obligation		64,000,000	75,000,000	86,000,000
Amortization of Wildfire Fund asset		29,000,000	29,000,000	12,000,000
Wildfire Fund asset, impairment losses		3,000,000	0	0
Accretion of Wildfire Fund obligation		$ 2,000,000	$ 2,000,000	$ 1,000,000

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - FOREIGN CURRENCY TRANSLATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Foreign currency transaction (losses) gains, net	$ (18)	$ (25)	$ 21

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Discontinued Operations (Details) - USD ($) $ in Millions	1 Months Ended		12 Months Ended
	Jun. 30, 2020	Apr. 30, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Income from discontinued operations, net of income tax			$ 0	$ 1,850	$ 363
Earnings attributable to noncontrolling interests			0	(10)	(35)
Earnings from discontinued operations attributable to common shares			0	1,840	328
Restricted cash			0	0	75
Assets held for sale in discontinued operations			0	0	445
Noncurrent assets			0	0	3,513
Liabilities held for sale in discontinued operations			0	0	444
Noncurrent liabilities			$ 0	0	1,052
Discontinued Operations, Held-for-sale \| Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Proceeds from sale	$ 2,216	$ 3,549
Pretax gain on sale	628	2,271
After tax gain on sale	$ 248	$ 1,499		2,899	0
Revenues				570	1,614
Cost of sales				(364)	(1,012)
Operating expenses				(66)	(159)
Interest and other				(3)	(11)
Income before income taxes and equity earnings				3,036	432
Income tax expense				(1,186)	(72)
Equity earnings				0	3
Income from discontinued operations, net of income tax				1,850	363
Earnings from discontinued operations attributable to common shares				1,840	328
Cash and cash equivalents				4,600	74
Restricted cash					1
Accounts receivable, net					303
Due from unconsolidated affiliates					2
Inventories					36
Other current assets					29
Assets held for sale in discontinued operations					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
Liabilities held for sale in discontinued operations					444
Long-term debt and finance leases					702
Deferred income taxes					284
Other noncurrent liabilities					66
Noncurrent liabilities					$ 1,052
Cumulative foreign currency translation adjustments				$ 645
Luz Del Sur \| Discontinued Operations, Held-for-sale \| Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)			83.60%
Eletrans \| Discontinued Operations, Held-for-sale \| Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)	50.00%
Chilquinta Energia \| Discontinued Operations, Held-for-sale \| Sempra South American Utilities
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)			100.00%
PXISE Energy Solutions LLC
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership interest (as a percent)			80.00%

NEW ACCOUNTING STANDARDS	12 Months Ended
NEW ACCOUNTING STANDARDS	Dec. 31, 2021
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 results of operations, financial condition, cash flows or disclosures. 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 and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. 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 will adopt the standard on January 1, 2022 using a modified retrospective approach and do not expect the adoption will materially impact our financial statements or per-share amounts.

The entire disclosure for change in accounting principle. Includes, but is not limited to, nature, reason, and method of adopting amendment to accounting standards or other change in accounting principle.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 65
-Paragraph 1
-Subparagraph (g)(2)
-URI http://asc.fasb.org/extlink&oid=123338486&loc=SL49131195-203048

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-URI http://asc.fasb.org/topic&trid=2122394

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 65
-Paragraph 1
-Subparagraph (i)
-URI http://asc.fasb.org/extlink&oid=123338486&loc=SL49131195-203048

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (e)(2)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section S99
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=122038215&loc=SL108384541-122693

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (d)(1)
-URI http://asc.fasb.org/extlink&oid=124402435&loc=SL124402458-218513

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (e)(2)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 65
-Paragraph 1
-Subparagraph (i)(2)
-URI http://asc.fasb.org/extlink&oid=123338486&loc=SL49131195-203048

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (e)(1)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(iii)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(4)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(ii)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(i)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 15: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (e)(1)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (g)(1)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 17: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (e)(1)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 18: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (d)(2)
-URI http://asc.fasb.org/extlink&oid=124402435&loc=SL124402458-218513

Reference 19: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 65
-Paragraph 1
-Subparagraph (j)
-URI http://asc.fasb.org/extlink&oid=123338486&loc=SL49131195-203048

Reference 20: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(iv)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 21: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 926
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (f)(1)
-URI http://asc.fasb.org/extlink&oid=120154821&loc=SL120154904-197079

Reference 22: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section S99
-Paragraph 5
-Subparagraph (SAB Topic 11.M.Q2)
-URI http://asc.fasb.org/extlink&oid=122038215&loc=d3e31137-122693

Reference 23: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 926
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (f)(2)
-URI http://asc.fasb.org/extlink&oid=120154821&loc=SL120154904-197079

Reference 24: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 25: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 926
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (f)(3)
-URI http://asc.fasb.org/extlink&oid=120154821&loc=SL120154904-197079

Reference 26: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (e)(3)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 27: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (e)(1)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 28: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (c)(1)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 29: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (h)(2)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 30: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (e)(2)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 31: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(1)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 32: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 848
-SubTopic 10
-Section 65
-Paragraph 1
-Subparagraph (e)(1)
-URI http://asc.fasb.org/extlink&oid=122150657&loc=SL122150809-237846

Reference 33: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (e)(3)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 34: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (c)

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

12 Months Ended

Dec. 31, 2021

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, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of losses in excess of any amounts accrued.

At December 31, 2021, loss contingency accruals for legal matters, including associated legal fees and regulatory matters related to the Leak, that are probable and estimable were $2,086 million for Sempra, including $4 million for SDG&E and $2,006 million for SoCalGas. Amounts for Sempra and SoCalGas include $1,980 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, 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 Litigation – Litigation Subject to Agreements to Resolve. As of February 18, 2022, approximately 390 lawsuits, including approximately 36,000 plaintiffs (the Individual Plaintiffs) were pending against SoCalGas and Sempra related to the Leak. All these cases are coordinated before a single court in the LA Superior Court for pretrial management.

In November 2017, in the coordinated proceeding, a Third Amended Consolidated Master Case Complaint for Individual Actions was filed on behalf of the Individual Plaintiffs, through which their separate lawsuits are 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 (excluding the Proposition 65 claims, the Individual Plaintiff Litigation). 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, 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 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 attorneys’ fees. These complaints are included in the coordinated proceeding and the Individual Plaintiff Litigation.

On September 26, 2021, SoCalGas and Sempra entered into an agreement with counsel representing over 80% of the plaintiffs in the Individual Plaintiff Litigation to resolve the claims of all Individual Plaintiffs for a payment of up to $1.8 billion. The agreement is subject to acceptance by no fewer than roughly 97% of all plaintiffs in the Individual Plaintiff Litigation by June 1, 2022, although SoCalGas and Sempra have the right to waive such condition. The agreement, which requires each plaintiff who accepts a settlement to release all such plaintiff’s claims against SoCalGas, Sempra and their respective affiliates related to the Individual Plaintiff Litigation and the Leak, provides that the settlement amount will be reduced based on the number of plaintiffs who do not accept. The LA Superior Court has approved the process to allocate payments among the plaintiffs. The plaintiffs who do not agree to participate in the settlement will be able to continue to pursue their claims. Pursuant to the agreement, the Individual Plaintiff Litigation has been stayed.

In January 2017, two consolidated class action complaints were filed against SoCalGas and Sempra, 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.

On September 26, 2021, SoCalGas and Sempra entered into an agreement to settle the Property Class Action for a total amount of $40 million. If, following a fairness hearing at which any objections to the settlement will be heard, the LA Superior Court gives final approval of the settlement, the agreement provides for a release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak by all property class members who do not opt out of the class. Members of the property class who opt out of the settlement will have the right to pursue their claims on an individual basis.

On September 27, 2021, SoCalGas and Sempra entered into an agreement to settle the individual claims of the named plaintiffs in the Business Class Action for a total amount of $100,000 in exchange for a dismissal and release of SoCalGas, Sempra and their respective affiliates from all claims related to the Leak. The complaint was dismissed in January 2022.

The Third Amended Consolidated Master Case Complaint for Individual Actions includes claims for violation of Proposition 65 seeking penalties for alleged violation of requirements to warn about certain chemical exposures as a result of the Leak. On November 4, 2021, SoCalGas entered into an agreement to settle these claims for a payment of approximately $2 million; in addition, SoCalGas agreed to implement certain measures to reduce emissions at the Aliso Canyon natural gas storage facility and to provide warnings to residents if benzene measured at the facility’s fence line exceeds certain levels. In January 2022, the LA Superior Court entered a consent judgment resolving the Proposition 65 claims.

In October 2018 and October 2020, five property developers (the Developer Plaintiffs) filed complaints against SoCalGas and Sempra alleging causes of action for strict liability, negligence per se, negligence, negligent interference, continuing nuisance, permanent nuisance, inverse condemnation and violation of the California Unfair Competition Law and California Public Utilities Code section 2106, 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 2021, the claims against the individual SoCalGas directors were dismissed. In January 2022, SoCalGas and Sempra entered into an agreement to settle the claims of one of the Developer Plaintiffs, and its complaint was dismissed.

An adverse ruling in any of the lawsuits in the Individual Plaintiff Litigation filed by plaintiffs who do not agree to settle, any lawsuits filed by property class members who opt out of the Property Class Action settlement or by members of the putative Business Class Action could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects. In addition, there can be no assurance that the conditions to resolve the Individual Plaintiff Litigation will be satisfied or that the LA Superior Court will approve the settlement for the Property Class Action.

In addition, a federal securities class action alleging violation of the federal securities laws was filed against Sempra 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, and in February 2021, the U.S. Court of Appeals for the Ninth Circuit affirmed the dismissal. The time for appeal has passed and, as a result, this represents the final judgment in this proceeding.

Civil Litigation – Unresolved Litigation. The claims of four of the Developer Plaintiffs remain pending, and the LA Superior Court has scheduled a trial in October 2022. SoCalGas has engaged in settlement discussions with the Developer Plaintiffs.

Four shareholder derivative actions were filed alleging breach of fiduciary duties against certain officers and certain directors of Sempra 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 plaintiffs have appealed the dismissal. The remaining action was also dismissed but plaintiffs were given leave to amend their complaint.

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.

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 of the CPUC and Blade during the pre-formal investigation, and whether any of the mitigation measures proposed by Blade should be implemented to the extent not already done. The SED, based largely on the Blade report, has alleged a total of 324 violations in the first phase, 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 began in March 2021. The second phase will consider whether SoCalGas should be sanctioned for the Leak and what damages, fines or other penalties, if any, should be imposed for any violations, unreasonable or imprudent practices, or failure to cooperate sufficiently 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 the 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 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 is evaluating 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 who is analyzing alternative means for meeting or avoiding the demand for the facility’s services if it were eliminated in either the 2027 or 2035 timeframe. In July 2021, the CPUC combined Phase 2 and Phase 3 and modified the scope of Phase 3 to also address potential implementation of alternatives to the Aliso Canyon natural gas storage facility if the CPUC determines that the Aliso Canyon natural gas storage facility should be permanently closed. The CPUC also added all California IOUs as parties to the proceeding and encouraged all load serving entities in the Los Angeles Basin to join the proceeding.

In November 2020, the CPUC issued a decision on the interim range of gas inventory levels at the Aliso Canyon natural gas storage facility, setting the interim range between 0 Bcf and 34 Bcf. In November 2021, the CPUC issued a decision approving a new interim range of gas inventory levels of up to 41.16 Bcf. The CPUC may issue future changes to this interim range of authorized gas inventory levels before issuing a final inventory determination within the SB 380 OII proceeding.

At December 31, 2021, the Aliso Canyon natural gas storage facility had a net book value of $883 million. 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, we may record an impairment of the facility, incur higher than expected operating costs and/or be required to make additional capital expenditures (any or all of which may not be recoverable in rates), and natural gas reliability and electric generation could be jeopardized. Any such outcome could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

Cost Estimate, Accounting Impact and Insurance. SoCalGas has incurred significant costs related to the Leak, primarily 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, 2021, SoCalGas estimates these costs related to the Leak are $3,221 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 portion of the cost estimate has been paid, and $1,983 million is accrued as Reserve for Aliso Canyon Costs at December 31, 2021 on SoCalGas’ and Sempra’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. Of this amount, $177 million was recorded in Insurance Receivable for Aliso Canyon Costs on the SoCalGas and Sempra Consolidated Balance Sheets and $307 million ($233 million after tax) was recorded in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Consolidated Statements of Operations.

As a result of entering into the agreements described under “Civil Litigation – Litigation Subject to Agreements to Resolve” above, and other continuing settlement negotiations, SoCalGas recorded total charges of $1.59 billion ($1.15 billion after tax) in 2021 in Aliso Canyon Litigation and Regulatory Matters on the SoCalGas and Sempra Consolidated Statements of Operations. Sempra elected to make an $800 million equity contribution to SoCalGas in September 2021 and may elect to make additional equity contributions in the future that are intended to maintain SoCalGas’ approved capital structure in connection with these accruals.

Except for the amounts paid or estimated to settle certain legal and regulatory matters as described above, the cost estimate does not include (i) any amounts necessary to resolve claims of Individual Plaintiffs who do not agree to participate in the settlement of the Individual Actions or members of the Property Class Action who opt out of that settlement or (ii) the matters that we describe above in “Civil Litigation – Unresolved Litigation” and “Regulatory Proceedings” to the extent it is not possible to predict at this time the outcome of these actions or reasonably estimate the possible costs or a range of possible costs for damages, restitution, civil or administrative fines or penalties, defense, settlement or other costs or remedies that may be imposed or incurred. The cost estimate also does not include certain other costs incurred by Sempra associated with defending against shareholder derivative

lawsuits and other potential costs that we currently do not anticipate incurring or that we cannot reasonably estimate. Further, we are not able to reasonably estimate the possible loss or a range of possible losses in excess of the amounts accrued. These costs or losses not included in the cost estimate could be significant and could have a material adverse effect on SoCalGas’ and Sempra’s results of operations, financial condition, cash flows and/or prospects.

We have received insurance payments for many of the categories of 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. At December 31, 2021, we recorded the expected recovery of the cost estimate related to the Leak of $360 million as Insurance Receivable for Aliso Canyon Costs on SoCalGas’ and Sempra’s Consolidated Balance Sheets. This amount is exclusive of insurance retentions and $919 million of insurance proceeds we received through December 31, 2021. 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’s results of operations, financial condition, cash flows and/or prospects.

Sempra Infrastructure

Energía Costa Azul

We describe below certain land and customer disputes and permit challenges affecting our ECA Regas Facility and our proposed ECA LNG liquefaction projects. One or more unfavorable final decisions on these disputes or challenges could materially adversely affect our existing natural gas regasification operations and proposed natural gas liquefaction projects at the site of the ECA Regas Facility and have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Land Disputes. Sempra Infrastructure 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), as follows:

▪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 to the claimant and cause it to be registered. Both SEDATU and Sempra Infrastructure 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, which is pending resolution.

▪In a separate proceeding, the claimant filed suit to reinitiate an administrative procedure at SEDATU to obtain the property title that was previously dismissed. In April 2021, the Agrarian Court ordered that the administrative procedure be restarted.

In addition, four 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, as follows:

▪The first disputed area is subject to a claim in the federal Agrarian Court that has been ongoing since 2006, in which the plaintiff seeks 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 proceeding, which seeks an order that SEDATU annul the ECA Regas Facility’s competing property title, was initiated in 2006 and, in July 2021, a decision was issued in favor of the ECA Regas Facility. The plaintiff appealed, and in February 2022, the appellate court confirmed the ruling in favor the ECA Regas Facility and dismissed the appeal.

▪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 federal Agrarian Court and two claims in Mexican civil courts. The ECA Regas Facility first bought the property from the federal government in 2003; however, to resolve an ownership controversy, in 2008, the ECA Regas Facility reached a financial settlement with the plaintiff to eliminate an adverse claim to our title. Nevertheless, the plaintiff sued in 2013 for the nullity of both titles. The Agrarian Court ruled in favor of the plaintiff in May 2021, nullifying the first property title. Sempra Infrastructure appealed the ruling in July 2021, which is pending resolution. The ECA Regas Facility continues to hold the second property title to the land. The two civil court proceedings, which seek to invalidate the contract by which the ECA Regas Facility purchased for the second time 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 civil case, initiated in 2013, the court ruled in favor of the ECA Regas Facility, and the final decision was affirmed on a federal appeal. The descendants of the same plaintiff filed the second civil case in 2019, which was dismissed by the court. However, the dismissal has been appealed, which is pending the appellate court’s ruling.

Certain of these land disputes involve land on which portions of the ECA LNG liquefaction facilities, including ECA LNG Phase 1 currently under construction, 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.

Environmental and Social Impact Permits. 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 and 2021, three 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 ASEA and SENER to ECA LNG authorizing natural gas liquefaction activities at the ECA Regas Facility, as follows:

▪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 permits that were issued by ASEA and SENER. This injunction has uncertain application absent clarification by the court. The claimants petitioned the court to rule that construction of natural gas liquefaction facilities violated the injunction, and in February 2022, the court ruled in favor of the ECA Regas Facility, meaning that the natural gas liquefaction activities have not been affected. The claimants may appeal this ruling.

▪In the third case, a group of residents filed a complaint in June 2021 against various federal and state authorities alleging deficiencies in the public consultation process for the issuance of the permits. The request for an initial injunction was denied and the claimants have appealed, which is pending the appellate court’s ruling.

Customer Dispute. 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 Sempra Infrastructure 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. Sempra Infrastructure has rejected the customers’ assertions and has drawn 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 since replenished the amounts drawn on its letter of credit and has resumed making regular monthly payments under its LNG storage and regasification agreement. As a consequence, Sempra Infrastructure is not currently drawing on Gazprom’s letter of credit but expects to continue to draw on Shell Mexico’s letter of credit. Sempra Infrastructure 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 and an additional constitutional claim against the issuance of the liquefaction permit. Shell Mexico’s request to stay the CRE’s approval of the general terms and conditions was denied and upheld on appeal. The claim regarding the liquefaction permit issuance was denied and is currently on appeal. A hearing on the merits of the arbitration case was held in October 2021.

Sonora Pipeline

Guaymas-El Oro Segment. Sempra Infrastructure’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, Sempra Infrastructure 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, Sempra Infrastructure 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, Sempra Infrastructure 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 Sempra Infrastructure from making repairs to put the pipeline back in service. In July 2019, a federal district court ruled in favor of Sempra Infrastructure 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 Sempra Infrastructure 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. In December 2021, the court of appeals referred the matter to Mexico’s Supreme Court.

Sempra Infrastructure 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 Sempra Infrastructure 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, Sempra Infrastructure and the CFE agreed to extend the service start date multiple times, most recently to March 14, 2022. 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, 2022, and the parties do not agree on a new service start date, Sempra Infrastructure retains the right to terminate the contract and seek to recover its reasonable and documented costs and lost profits. Discussions with the CFE regarding the future of the pipeline, including the potential re-routing of a portion of the pipeline, are underway in accordance with a non-binding MOU announced in January 2022 that, among other matters, addresses efforts to restart service on the pipeline. Sempra Infrastructure intends to enter into a definitive agreement with respect to the pipeline in the first quarter of 2022.

At December 31, 2021, Sempra Infrastructure had $432 million in PP&E, net, related to the Guaymas-El Oro segment of the Sonora pipeline, which could be subject to impairment if Sempra Infrastructure is unable to make such repairs (which have not commenced) or re-route a portion of the pipeline (which has not been agreed to by the parties, but is subject to negotiation pursuant to a non-binding MOU, as described above) and resume operations in the Guaymas-El Oro segment of the Sonora pipeline or if Sempra Infrastructure terminates the contract and is unable to obtain recovery, which in each case could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Sasabe-Puerto Libertad-Guaymas Segment. In June 2014, Sempra Infrastructure and a landowner agreed to enter into a voluntary right-of-way easement agreement for the construction and operation of a seven-mile section of the 314-mile Sasabe-Puerto Libertad-Guaymas segment of the Sonora natural gas pipeline on the landowner’s property. However, in 2015, the landowner filed a complaint demanding the easement agreement be nullified. In September 2021, a definitive and non-appealable judgment was issued declaring the easement agreement nullified and ordering the removal of the pipeline from the landowner’s property. The execution of the judgment is suspended as a result of an amparo lawsuit filed by the CFE as an interested third party that did not participate in the litigation. Sempra Infrastructure filed a special judicial action asking the civil court to acknowledge the existence of the easement and to determine the consideration the landowner should receive in exchange for the easement. The failure to stay this judgment pending the resolution of Sempra Infrastructure’s planned special judicial action or prevail in preserving the easement in the special judicial action could require us to modify the route of the pipeline and could require a temporary shutdown of this portion of the pipeline, which could have a material adverse effect on Sempra’s business, results of operations, financial condition, cash flows and/or prospects.

Regulatory and Other Actions by the Mexican Government

We describe below certain actions by the Mexican government that could have a material impact on the energy sector in Mexico. Sempra Infrastructure and other parties affected by these resolutions, orders, decrees, regulations and proposed amendments to Mexican law have challenged them by filing amparo and other claims, some of which have been granted injunctive relief. The court-ordered injunctions or suspensions provide temporary relief until Mexico’s federal district court or Supreme Court ultimately resolves the amparo and other claims. If passed in its current form, the proposed constitutional reform described below introduces significant changes to the legal and economic principles underlying the country’s energy reform of 2013, generating imminent risks for private investments in this sector. An unfavorable decision on one or more of these amparo or other challenges, the potential for extended disputes, or if passed in its current form, the proposed constitutional reform may impact our ability to operate our facilities at existing levels or at all, may result in increased costs for Sempra Infrastructure and its customers, may adversely affect our ability to develop new projects, and may negatively impact our ability to recover the carrying values of our investments in Mexico, any of which may have a material adverse effect on our business, results of operations, financial condition, cash flows and/or prospects.

Transmission Rates for Legacy Generation Facilities. In May 2020, the CRE approved an update to the transmission rates included in legacy renewable 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 Sempra Infrastructure’s renewable energy facilities (Don Diego Solar, Border Solar and Ventika) are currently holders of contracts with such legacy rates, and under the terms of these contracts any increases in the transmission rates would be passed through directly to their customers. These renewable energy facilities have obtained injunctive relief but are required to guarantee the difference in tariffs, which could be material, until the claims are definitively resolved by the courts. The three facilities obtained favorable resolutions from a lower court and the CRE has appealed one of these decisions.

Offtakers of Legacy Generation Permits. 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, Border Solar and Ventika are holders of self-supply permits and are impacted by the Offtaker Resolution. In January 2022, Don Diego Solar and Border Solar obtained a favorable resolution from a Mexican federal district court that we expect the CRE will appeal. If Sempra Infrastructure is not able to obtain legal protection for these impacted facilities, Sempra Infrastructure 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 lower than the fixed prices in the PPAs that were entered into through self-supply permits. At December 31, 2021, Sempra Infrastructure had $14 million in other intangible assets, net, related to these self-supply permits previously granted by the CRE and impacted by the Offtaker Resolution that could be subject to impairment if Sempra Infrastructure is unable to obtain adequate legal protection. Sempra Infrastructure has filed lawsuits against the Offtaker Resolution and received injunctive relief pending final resolution.Amendments to Mexico’s Electricity Industry Law. In March 2021, the Mexican government published a decree with amendments to Mexico’s Electricity Industry Law that include some public policy changes, including establishing priority of dispatch for CFE plants over privately owned plants. According to the decree, these amendments were to become effective on March 10, 2021, and SENER, the CRE and CENACE were to have 180 calendar days to modify, as necessary, all resolutions, policies, criteria, manuals and other regulations applicable to the power industry to conform with this decree. However, a Mexican court issued a suspension of the amendments on March 19, 2021, and it is expected that Mexico’s Supreme Court will ultimately settle the matter. If the proposed amendments are affirmed by the Supreme Court, the CRE may be required to revoke self-supply permits granted under the former electricity law, which were grandfathered when the new Electricity Industry Law was enacted, under a legal standard that is ambiguous and not well defined under the law.Amendments to Mexico’s Hydrocarbons Law. In May 2021, amendments to Mexico’s Hydrocarbons Law were published and became effective. The amendments grant SENER and the CRE additional powers to suspend and revoke permits related to the midstream and downstream sectors. Suspension of permits will be determined by SENER or the CRE when a danger to national security, energy security, or to the national economy is foreseen. Likewise, new grounds for the revocation of permits are in place if the permit holder (i) carries out its activity with illegally imported products; (ii) fails, on more than one occasion, to comply with the provisions applicable to quantity, quality and measurement of the products; or (iii) modifies the technical conditions of its infrastructure without authorization. Additionally, in the case of existing permits, authorities will revoke those permits that fail to comply with the minimum storage requirements established by SENER or fail to comply with requirements or violate provisions established by the amended Hydrocarbons Law. All of Sempra Infrastructure’s facilities participating in the hydrocarbons sector filed lawsuits against the initiative to reform the Hydrocarbons Law and received injunctive relief pending a final resolution by the courts. In May 2021, a Mexican district court ordered the suspension of several of the provisions of the amendments with general application across the sector. In 2021, district courts issued judgments that the amendments do not affect the interests of the companies at this time and, as a result, dismissed the amparo lawsuits filed by several companies in the market, including three of the five lawsuits filed by Sempra Infrastructure. These judgments have been appealed and the granted suspensions will remain valid until the lawsuits are definitively resolved.Amendments to Mexico’s General Foreign Trade Rules. In June 2021, amendments to Mexico’s General Foreign Trade Rules went into effect, which establish that only state-owned companies may import and export hydrocarbons, refined products, petrochemicals, and biofuels through channels other than those authorized (LDA authorization). These amendments prevent non-state-owned companies from (i) obtaining LDA authorizations, which affect new projects that have not obtained such approval, and (ii) renewing existing LDA authorizations, which affect operational projects and those under construction. The ECA Regas Facility and the Veracruz terminal have LDA authorizations that are valid through 2023 and, as a preventive measure, have filed amparo claims to challenge the newly introduced barrier to renewing their existing LDA authorizations. In order to start operations at terminals currently under construction or in development in the vicinity of Topolobampo, Manzanillo and Ensenada, including the proposed ECA LNG liquefaction projects, Sempra Infrastructure filed amparo claims to challenge such amendments that prevent them from obtaining LDA authorizations in the future. In October and November of 2021, the Mexican government published new General Foreign Trade Rules in which private companies are allowed to obtain LDA authorizations and, as a consequence, the amparo claims filed by the ECA Regas Facility and the Veracruz terminal have been dismissed by the courts, while the appropriate court is being determined to hear the amparo claim for future LDA authorizations. There can be no assurance that new or renewed LDA authorizations will be obtained in a timely manner or at all.

Proposed Constitutional Reform in Mexico. In September 2021, the President of Mexico presented a constitutional reform initiative with the stated goal of preserving energy security and self-sufficiency, and a continuous supply of electricity to the country’s population, as a condition for guaranteeing national security and the human right to a decent life. The CRE and the National Commission of Hydrocarbons would be dissolved, and their functions would be carried out by SENER. CENACE would be reinstated to the CFE, and the CFE would be responsible for generating, conducting, transforming, distributing and supplying electricity, and would be the only entity allowed to commercialize electric energy in Mexico. Electricity generation permits and contracts for the sale of electricity and RECs to the CFE, including permits at all of Sempra Infrastructure’s operational power generation facilities, would be canceled. The public electricity supply service would be provided exclusively by the CFE, which may acquire up to 46% of required energy from the private sector. Only certain private power plants would be permitted to continue generating electricity and compete to offer the CFE the lowest production costs.

The initiative must first be submitted to a vote and approved in the respective plenary sessions of the Chamber of Deputies and the Chamber of Senators in Mexico. Additionally, the initiative must be approved by a two-thirds vote of Mexico’s Federal Congress and by the majority of the legislatures of the Mexican States and published in the Federal Official Gazette to be in force. Sempra Infrastructure is following this legislative procedure while assessing alternatives for its project companies. If passed in its current form, the initiative could have a material adverse effect on our business, results of operations, financial condition, cash flows and/or prospects, our ability to recover the carrying values of our investments in Mexico, and our ability to operate existing facilities and develop new energy projects in the country.

Other Litigation

RBS Sempra Commodities

Sempra holds an equity method investment in RBS Sempra Commodities, a limited liability partnership in the process of being liquidated. RBS, now NatWest Markets plc, our partner in the JV, paid an assessment of £86 million (approximately $138 million in U.S. dollars) in October 2014 to HMRC for denied VAT refund claims filed in connection with the purchase of carbon credit allowances by RBS SEE, a subsidiary of RBS Sempra Commodities. RBS SEE was subsequently sold to J.P. Morgan Chase & Co. and later to Mercuria Energy Group, Ltd. HMRC asserted that RBS was not entitled to reduce its VAT liability by VAT paid on certain carbon credit purchases during 2009 because RBS knew or should have known that certain vendors in the trading chain did not remit their own VAT to HMRC. In July 2021, RBS entered into a settlement with HMRC that resolved this matter.

In 2015, liquidators filed a claim in the High Court of Justice against RBS and Mercuria Energy Europe Trading Limited (the Defendants) on behalf of 10 companies (the Liquidating Companies) that engaged in carbon credit trading via chains that included a company that traded directly with RBS SEE. The claim alleges that the Defendants’ participation in the purchase and sale of carbon credits resulted in the Liquidating Companies’ carbon credit trading transactions creating a VAT liability they were unable to pay, and that the Defendants are liable to provide for equitable compensation due to dishonest assistance and for compensation under the U.K. Insolvency Act of 1986. Trial on the matter was held in June and July of 2018. In March 2020, the High Court of Justice rendered its judgment mostly in favor of the Liquidating Companies and awarded damages of approximately £45 million

(approximately $61 million in U.S. dollars at December 31, 2021), plus costs and interest. In October 2020, the High Court of Justice issued assessed costs and interest to be approximately £21 million (approximately $28 million in U.S. dollars at December 31, 2021) as of that date, with interest continuing to accrue. The Defendants appealed and, in May 2021, the Court of Appeal set aside the High Court of Justice’s decision and ordered a retrial. The Liquidating Companies in the High Court of Justice case have applied to the Supreme Court for permission to appeal the Court of Appeal’s decision. J.P. Morgan Chase & Co. has notified us that Mercuria Energy Group, Ltd. has sought indemnity for the claim, and J.P. Morgan Chase & Co. has in turn sought indemnity from Sempra and RBS.

We recorded $100 million in equity losses from our investment in RBS Sempra Commodities in Equity Earnings on Sempra’s Consolidated Statement of Operations in 2020, which represented an estimate of our obligations to settle pending VAT matters and related legal costs. In 2021, we reduced this estimate by $50 million based on the settlement with HMRC on the First-Tier Tribunal case and revised assumptions on the High Court of Justice case. The final outcome of the High Court of Justice case remains uncertain.

Asbestos Claims Against EFH Subsidiaries

Certain EFH subsidiaries that we acquired as part of the merger of EFH with an indirect subsidiary of Sempra were defendants in personal injury lawsuits brought in state courts throughout the U.S. These cases alleged illness or death as a result of exposure to asbestos in power plants designed and/or built by companies whose assets were purchased by predecessor entities to the EFH subsidiaries, and generally assert claims for product defects, negligence, strict liability and wrongful death. They sought compensatory and punitive damages. As of February 18, 2022, no lawsuits are pending. Additionally, in connection with the EFH bankruptcy proceeding, approximately 28,000 proofs of claim were filed on behalf of persons who allege exposure to asbestos under similar circumstances and assert the right to file such lawsuits in the future. None of these claims or lawsuits were discharged in the EFH bankruptcy proceeding. The costs to defend or resolve these lawsuits and the amount of damages that may be imposed or incurred could have a material adverse effect on Sempra’s results of operations, financial condition, cash flows and/or prospects.

Ordinary Course Litigation

We are also defendants in ordinary routine litigation incidental to our businesses, including personal injury, employment litigation, product liability, property damage and other claims. Juries have demonstrated an increasing willingness to grant large awards, including punitive damages, in these types of cases.

LEASES

A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. We determine if an arrangement is or contains a lease at inception of the contract.

Some of our lease agreements contain nonlease components, which represent activities that transfer a separate good or service to the lessee. As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate, power generating facilities and liquid fuels terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately.

Lessee Accounting

We have operating and finance leases for real and personal property (including office space, land, fleet vehicles, machinery and equipment, warehouses and other operational facilities) and PPAs with renewable energy, energy storage and peaker plant facilities.

Some of our leases include options to extend the lease terms for up to 20 years, or to terminate the lease within one year. Our lease liabilities and ROU assets are based on lease terms that may include such options when it is reasonably certain that we will exercise the option.

Certain of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. We do not recognize a lease liability or ROU asset arising from short-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.

Certain of our leases contain escalation clauses requiring annual increases in rent ranging from 2% to 5% or based on the Consumer Price Index. The rentals payable under these leases may increase by a fixed amount each year or by a percentage of a base year. Variable lease payments that are based on an index or rate are included in the initial measurement of our lease liability and ROU asset based on the index or rate at lease commencement and are not remeasured because of changes to the index or rate. Rather, changes to the index or rate are treated as variable lease payments and recognized in the period in which the obligation for those payments is incurred.

Similarly, PPAs for the purchase of renewable energy at SDG&E require lease payments based on a stated rate per MWh produced by the facilities, and we are required to purchase substantially all the output from the facilities. SDG&E is required to pay additional amounts for capacity charges and actual purchases of energy that exceed the minimum energy commitments. Under these contracts, we do not recognize a lease liability or ROU asset for leases for which there are no fixed lease payments. Rather, these variable lease payments are recognized separately as variable lease costs. SDG&E estimates these variable lease payments to be $297 million in 2022, $296 million in 2023, $297 million in 2024, $296 million in 2025, $290 million in 2026 and $2,779 million thereafter.

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. SDG&E and SoCalGas 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. SDG&E and SoCalGas 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.

Our leases do not contain any material residual value guarantees, restrictions or covenants.

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									SDG&E									SoCalGas
	December 31,
	2021			2020			2019			2021			2020			2019			2021			2020			2019
ROU assets:
Operating leases:
ROU assets	$	594		$	543		$	591		$	185		$	102		$	130		$	57		$	74		$	94

Finance leases:
PP&E	1,473			1,429			1,353			1,381			1,356			1,326			92			73			27
Accumulated depreciation	(138)			(99)			(64)			(107)			(80)			(57)			(31)			(19)			(7)
PP&E, net	1,335			1,330			1,289			1,274			1,276			1,269			61			54			20
Total ROU assets	$	1,929		$	1,873		$	1,880		$	1,459		$	1,378		$	1,399		$	118		$	128		$	114

Lease liabilities:
Operating leases:
Other current liabilities	$	49		$	52		$	52		$	26		$	27		$	27		$	15		$	18		$	18
Deferred credits and other	470			407			445			159			73			102			41			56			75
	519			459			497			185			100			129			56			74			93
Finance leases:
Current portion of long-term debt and finance leases	43			36			26			32			26			20			11			10			6
Long-term debt and finance leases	1,292			1,294			1,263			1,242			1,250			1,250			50			44			13
	1,335			1,330			1,289			1,274			1,276			1,270			61			54			19
Total lease liabilities	$	1,854		$	1,789		$	1,786		$	1,459		$	1,376		$	1,399		$	117		$	128		$	112

Weighted-average remaining lease term (in years):
Operating leases	14			13			13			11			6			6			4			5			6
Finance leases	17			18			19			17			19			20			7			7			6
Weighted-average discount rate:
Operating leases	5.45		%	5.81		%	6.01		%	3.22		%	3.62		%	3.55		%	1.98		%	2.03		%	3.73		%
Finance leases	14.25		%	14.45		%	14.76		%	14.48		%	14.65		%	14.83		%	2.91		%	2.83		%	3.23		%

The components of lease costs were as follows:


LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS(1)
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	Years ended December 31,
	2021		2020		2019		2021		2020		2019		2021		2020		2019

Operating lease costs	$	89	$	92	$	96	$	32	$	31	$	33	$	20	$	24	$	27

Finance lease costs:
Amortization of ROU assets(2)	39		35		24		27		23		18		12		12		6
Interest on lease liabilities	186		188		173		184		186		173		2		2		—
Total finance lease costs	225		223		197		211		209		191		14		14		6

Short-term lease costs(3)	7		7		6		1		3		2		—		—		—
Variable lease costs(3)	432		477		482		422		467		471		10		10		10
Total lease costs	$	753	$	799	$	781	$	666	$	710	$	697	$	44	$	48	$	43

(1) Includes costs capitalized in PP&E.

(2) Included in O&M, except for $22 at Sempra, $21 at SDG&E and $1 at SoCalGas in 2021, $18 at Sempra and SDG&E in 2020, and $15 at Sempra and SDG&E in 2019, which is included in Depreciation and Amortization Expense.

(3) Short-term leases with variable lease costs are recorded and presented as variable lease costs.

Cash paid for amounts included in the measurement of lease liabilities and supplemental noncash information were as follows:


LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	Years ended December 31
	2021		2020		2019		2021		2020		2019		2021		2020		2019
Operating activities:
Cash paid for operating leases	$	78	$	79	$	101	$	32	$	31	$	33	$	20	$	24	$	27
Cash paid for finance leases	171		173		173		169		171		173		2		2		—
Financing activities:
Cash paid for finance leases	39		35		24		27		23		18		12		12		6
Increase (decrease) in operating lease obligations for ROU assets	116		20		585		112		(1)		158		1		1		118
Increase in finance lease obligations for investment in PP&E	43		77		38		24		30		16		19		47		22

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, 2021
	Sempra				SDG&E				SoCalGas
	Operating leases(1)		Finance leases(2)		Operating leases(1)		Finance leases(2)		Operating leases		Finance leases
2022	$	73	$	209	$	30	$	197	$	17	$	12
2023	66		208		27		197		13		11
2024	62		203		25		192		11		11
2025	50		199		16		188		10		11
2026	48		196		15		188		8		8
Thereafter	493		2,292		105		2,279		—		13
Total undiscounted lease payments	792		3,307		218		3,241		59		66
Less: imputed interest	(273)		(1,972)		(33)		(1,967)		(3)		(5)
Total lease liabilities	519		1,335		185		1,274		56		61
Less: current lease liabilities	(49)		(43)		(26)		(32)		(15)		(11)
Long-term lease liabilities	$	470	$	1,292	$	159	$	1,242	$	41	$	50

(1) Includes $9 in each of 2022 through 2026 and $87 thereafter related to purchased-power contracts.

(2) Substantially all amounts are related to purchased-power contracts.

Leases That Have Not Yet Commenced

SDG&E has entered into three energy storage tolling agreements, of which SDG&E expects two will commence in the third quarter of 2022 and one will commence in the second quarter of 2023. SDG&E expects to account for these agreements as operating leases upon commencement and expects the future minimum lease payments to be $8 million in 2022, $17 million in 2023, $18 million in each of 2024 through 2026 and $101 million thereafter until expiration at various dates from 2032 through 2033.

SoCalGas has entered into a fleet vehicle agreement, which SoCalGas expects will commence in May 2022. SoCalGas expects to account for the agreement as a finance lease upon commencement and expects the future minimum lease payments to be $1 million in 2022 and $2 million in each of 2023 through 2026 and $6 million thereafter until expiration in 2029.

Lessor Accounting

Sempra Infrastructure is a lessor for certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and liquid fuels terminals, which we account for as operating or sales-type leases. These leases expire at various dates from 2022 through 2041.

Over the lease term, we monitor the underlying assets in operating leases for impairment, and we evaluate the net investment in sales-type leases for expected credit losses. Sempra Infrastructure expects to continue to derive value from the underlying assets associated with its pipelines following the end of their respective lease terms based on the expected remaining useful life, expected market conditions and plans to re-market and re-contract the underlying assets.

Generally, we recognize operating lease income on a straight-line basis over the lease term, and sales-type lease income based on the effective interest method over the lease term. 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.

In July 2021, a rail facility agreement commenced, which Sempra Infrastructure is accounting for as a sales-type lease. The rail facility is being used by the lessee to transport liquid fuels out of the Veracruz terminal. The lessee has the right to direct the use of the rail facility and will obtain substantially all of the economic benefits of the rail facility. At lease commencement, Sempra Infrastructure derecognized the $44 million carrying value of the rail facility from PP&E and recognized a net investment in sales-type lease asset of $62 million and a selling profit of $18 million. The agreement expires in 2041 and will automatically renew for successive five-year terms unless written notice is provided by Sempra Infrastructure or the lessee. Fixed lease payments are payable in the first five years of the agreement, which the lessee is required to pay even in the event of lease termination.


LESSOR INFORMATION – SEMPRA
(Dollars in millions)
	December 31,
	2021		2020		2019
Assets subject to operating leases:
Property, plant and equipment(1)	$	1,499	$	1,092	$	1,038
Accumulated depreciation	(276)		(228)		(179)
Property, plant and equipment, net	$	1,223	$	864	$	859

			December 31, 2021
Maturity analysis of lease payments:			Operating leases		Sales-type leases
2022			$	272	$	16
2023			272		16
2024			273		17
2025			272		17
2026			272		9
Thereafter			3,031		—
Total undiscounted cash flows			$	4,392	75
Present value of lease payments (recognized as lease receivable)(2)					55
Difference between undiscounted cash flows and discounted cash flows					$	20

(1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.

(2) Includes $9 in Other Current Assets and $46 in Other Long-Term Assets on the Consolidated Balance Sheet.


LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sales-type leases:
Income recognized at lease commencement	$	18	$	1	$	—
Interest income	4		1		—
Total revenues from sales-type leases(1)	$	22	$	2	—

Operating leases:
Fixed lease payments	$	256	$	195	$	200
Variable lease payments	10		1		6
Total revenues from operating leases(1)	$	266	$	196	$	206

Depreciation expense	$	48	$	39	$	38

(1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.

CONTRACTUAL COMMITMENTS

Natural Gas Contracts

SoCalGas has responsibility for procuring natural gas for both SDG&E’s and SoCalGas’ core customers in a combined portfolio. SoCalGas buys natural gas under short-term and long-term contracts for this portfolio from various producing regions in the southwestern U.S., U.S. Rockies and Canada. At December 31, 2021, SoCalGas’ natural gas purchase commitments under long-term contracts are negligible.

SoCalGas transports natural gas primarily under long-term firm interstate pipeline capacity agreements that provide for annual reservation charges, which are recovered in rates. SoCalGas has commitments with interstate pipeline companies for firm pipeline capacity under contracts that expire at various dates through 2032.

Sempra Infrastructure has various capacity agreements for natural gas storage and transportation that expire at various dates through 2059. Transportation costs on these agreements vary based on pipeline capacity.

Payments on our natural gas contracts could exceed the minimum commitment based on portfolio needs. At December 31, 2021, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts are as follows:


FUTURE MINIMUM PAYMENTS
(Dollars in millions)
	Sempra						SoCalGas
	Storage and transportation		Natural gas(1)		Total(1)		Transportation
2022	$	214	$	20	$	234	$	134
2023	204		39		243		132
2024	181		15		196		114
2025	141		7		148		77
2026	137		—		137		75
Thereafter	903		—		903		310
Total minimum payments	$	1,780	$	81	$	1,861	$	842

(1) Excludes amounts related to the LNG purchase agreement discussed below.

Total payments under natural gas contracts and natural gas storage and transportation contracts as well as payments to meet additional portfolio needs at Sempra and SoCalGas were as follows:


PAYMENTS UNDER NATURAL GAS CONTRACTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra	$	1,691	$	989	$	1,326
SoCalGas	1,590		935		1,181

LNG Purchase Agreement

Sempra Infrastructure has a sale and purchase agreement for the supply of LNG to the ECA Regas Facility. The commitment amount is calculated using a predetermined formula based on estimated forward prices of the index applicable from 2022 to 2029. Although this agreement specifies a number of cargoes to be delivered, under its terms, the customer may divert certain cargoes, which would reduce amounts paid under the agreement by Sempra Infrastructure.

At December 31, 2021, the following LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted, under the agreement are delivered:


LNG COMMITMENT AMOUNTS
(Dollars in millions)
Sempra:
2022	$	435
2023	553
2024	516
2025	518
2026	519
Thereafter	1,381
Total	$	3,922

Actual LNG purchases were approximately $27 million in 2021, $16 million in 2020 and $17 million in 2019 due to the customer electing to divert cargoes as allowed by the agreement.

Purchased-Power Contracts

For 2022, SDG&E expects to meet its customer power requirements from the following resource types:

▪Long-term contracts: 60% (of which 57% is provided by renewable energy contracts expiring on various dates through 2042)

▪Other SDG&E-owned generation and tolling contracts expiring on various dates through 2039: 46%

▪Spot market sales: (6)%

Payments on our purchased-power contracts could exceed the minimum commitments based on energy needs. At December 31, 2021, the future minimum payments under long-term purchased-power contracts for Sempra and SDG&E are as follows:


FUTURE MINIMUM PAYMENTS – PURCHASED-POWER CONTRACTS
(Dollars in millions)
2022	$	218
2023	188
2024	162
2025	105
2026	100
Thereafter	817
Total minimum payments(1)	$	1,590

(1) Excludes purchase agreements accounted for as operating leases and finance leases.

Payments on these contracts represent capacity charges and minimum energy and transmission purchases that exceed the minimum commitment. SDG&E is required to pay additional amounts for actual purchases of energy that exceed the minimum energy commitments. SDG&E estimates these variable payments to be $63 million in each of 2022 through 2026 and $430 million thereafter. Total payments under purchased-power contracts for Sempra and SDG&E were $495 million in 2021, $534 million in 2020 and $744 million in 2019.

Construction and Development Projects

Sempra has various capital projects in progress in the U.S. and Mexico. Our total contractual commitments at December 31, 2021 under these projects are approximately $389 million, requiring future payments of $223 million in 2022, $22 million in 2023, $18 million in each of 2024 and 2025, $5 million in 2026 and $103 million thereafter. The following is a summary by segment of contractual commitments and contingencies related to such projects.

SDG&E

At December 31, 2021, SDG&E has commitments to make future payments of $27 million for construction projects that include:

▪$4 million for infrastructure improvements for electric and natural gas transmission and distribution systems; and

▪$23 million related to spent fuel management at SONGS.

SDG&E expects future payments under these contractual commitments to be $3 million in each of 2022 and 2023, $1 million in each of 2024 through 2026 and $18 million thereafter.

Sempra Infrastructure

At December 31, 2021, Sempra Infrastructure has commitments to make future payments of $362 million for construction and development projects that include:

▪$43 million for liquid fuels terminals;

▪$296 million for natural gas pipelines and ongoing maintenance services; and

▪$23 million for renewables projects.

Sempra Infrastructure expects future payments under these contractual commitments to be $220 million in 2022, $19 million in 2023, $17 million in each of 2024 and 2025, $4 million in 2026 and $85 million thereafter.

OTHER COMMITMENTS

SDG&E

We discuss nuclear insurance and nuclear fuel disposal related to SONGS in Note 15.

Fire Mitigation Fund

In connection with the completion of the Sunrise Powerlink project in 2012, the CPUC required that SDG&E establish a fire mitigation fund to minimize the risk of fire as well as reduce the potential wildfire impact on residences and structures near the Sunrise Powerlink. The future payments for these contractual commitments, for which a liability has been recorded, are expected

to be $4 million per year in 2022 through 2026 and $275 million thereafter, subject to escalation of 2% per year, for a remaining 48-year period. At December 31, 2021, the present value of these future payments of $122 million has been recorded as a regulatory asset as the amounts represent a cost that we expect will be recovered from customers in the future.

Franchise Agreements

In December 2020, the City of San Diego and SDG&E agreed to extend SDG&E’s natural gas and electric franchises for the city to June 1, 2021. After completing a competitive bid process, on June 8, 2021, the City of San Diego approved ordinances granting to SDG&E the natural gas and electric franchises for the city. These franchise agreements provide SDG&E the opportunity to serve the City of San Diego for the next 20 years, consisting of 10-year agreements that will automatically renew for an additional 10 years unless the City Council voids the automatic renewal with a supermajority vote. The agreements went into effect in July 2021. Over the 20-year term of the agreements, SDG&E will make principal payments of $110 million and interest payments of $13 million as consideration for the natural gas and electric franchise agreements. The consideration paid will not be recovered from customers and will be amortized over 20 years. SDG&E paid $11 million to the City of San Diego in 2021. At December 31, 2021, SDG&E has commitments to make future payments of $14 million per year in 2022 through 2024, $15 million in 2025, $4 million in 2026 and $51 million thereafter.

Two lawsuits have been filed in the California Superior Court challenging the City’s process for its award of the natural gas and electric franchises and seeking to declare the franchise agreements null and void.

Sempra Infrastructure

Additional consideration for a 2006 comprehensive legal settlement with the State of California to resolve the Continental Forge litigation included an agreement that, for a period of 18 years beginning in 2011, Sempra Infrastructure would sell to SDG&E and SoCalGas, subject to annual CPUC approval, up to 500 MMcf per day of regasified LNG from Sempra Infrastructure’s ECA Regas Facility that is not delivered or sold in Mexico at the price indexed to the California border minus $0.02 per MMBtu. There are no specified minimums required, and to date, Sempra Infrastructure has not been required to deliver any natural gas pursuant to this agreement.

ENVIRONMENTAL ISSUES

Our operations are subject to federal, state and local environmental laws. We also are subject to regulations related to hazardous wastes, air and water quality, land use, solid waste disposal and the protection of wildlife. These laws and regulations require that we investigate and correct the effects of the release or disposal of materials at sites associated with our past and our present operations. These sites include those at which we have been identified as a PRP under the federal Superfund laws and similar state laws.

In addition, we are required to obtain numerous governmental permits, licenses and other approvals to construct facilities and operate our businesses. The related costs of environmental monitoring, pollution control equipment, cleanup costs, and emissions fees are significant. Increasing national and international concerns regarding global warming and mercury, carbon dioxide, nitrogen oxide and sulfur dioxide emissions could result in requirements for additional pollution control equipment or significant emissions fees or taxes that could adversely affect Sempra Infrastructure. SDG&E’s and SoCalGas’ costs to operate their facilities in compliance with these laws and regulations generally have been recovered in customer rates.

We disclose any proceeding under environmental laws to which a government authority is a party when the potential monetary sanctions, exclusive of interest and costs, exceed the lesser of $1 million or 1% of current assets, which was $44 million for Sempra, $14 million for SDG&E and $16 million for SoCalGas at December 31, 2021.

We discuss environmental matters related to the natural gas leak at SoCalGas’ Aliso Canyon natural gas storage facility above in “Legal Proceedings – SoCalGas – Aliso Canyon Natural Gas Storage Facility Gas Leak.”

Other Environmental Issues

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:


CAPITAL EXPENDITURES FOR ENVIRONMENTAL ISSUES
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra	$	95	$	76	$	80
SDG&E	32		39		39
SoCalGas	63		37		41

We have not identified any significant environmental issues outside the U.S.

At SDG&E and SoCalGas, 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 Leak as we discuss above or resolved during the last three years, include (1) investigation and remediation of SDG&E’s and SoCalGas’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by SDG&E and SoCalGas 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.

The table below shows the status at December 31, 2021 of SDG&E’s and SoCalGas’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP:


STATUS OF ENVIRONMENTAL SITES

	# Sites complete(1)	# Sites in process
SDG&E:
Manufactured-gas sites	3	—
Third-party waste-disposal sites	2	1
SoCalGas:
Manufactured-gas sites	39	3
Third-party waste-disposal sites	5	2

(1) There may be ongoing compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.

We record environmental liabilities when our liability is probable and the costs can be reasonably estimated. In many cases, however, investigations are not yet at a stage where we can determine whether we are liable or, if the liability is probable, to reasonably estimate the amount or range of amounts of the costs. Estimates of our liability are further subject to uncertainties such as the nature and extent of site contamination, evolving cleanup standards and imprecise engineering evaluations. We review our accruals periodically and, as investigations and cleanups proceed, we make adjustments as necessary.

The following table shows our accrued liabilities for environmental matters at December 31, 2021. 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- gas sites		Waste disposal sites (PRP)(1)		Other hazardous waste sites		Total(2)
SDG&E(3)	$	—	$	6	$	12	$	18
SoCalGas(4)	34		3		1		38
Other	—		1		—		1
Total Sempra	$	34	$	10	$	13	$	57

(1) Sites for which we have been identified as a PRP.

(2) Includes $5, $2 and $3 classified as current liabilities, and $52, $16 and $35 classified as noncurrent liabilities on Sempra’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.”

In connection with the issuance of operating permits, SDG&E and the other owners of SONGS previously reached an agreement with the CCC to mitigate the damage to the marine environment caused by the cooling-water discharge from SONGS during its operation. SONGS’ early retirement, described in Note 15, does not reduce SDG&E’s mitigation obligation. SDG&E’s share of the estimated mitigation costs is $97 million, of which $53 million has been incurred through December 31, 2021 and $44 million is accrued for remaining costs through 2053, which is recoverable in rates and included in noncurrent Regulatory Assets on Sempra’s and SDG&E’s Consolidated Balance Sheets.

We expect future payments related to our environmental liabilities on an undiscounted basis to be $6 million in 2022, $13 million in 2023, $9 million in 2024, $4 million in 2025, $17 million in 2026 and $53 million thereafter.

PREFERRED STOCK

12 Months Ended

Dec. 31, 2021

Equity [Abstract]

Preferred Stock

PREFERRED STOCKSempra and SDG&E are authorized to issue up to 50 million and 45 million shares of preferred stock, respectively. At December 31, 2021, 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 MANDATORY CONVERTIBLE 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.

As of July 15, 2021, we had converted, pursuant to either early conversions at the election of the holder or the mandatory conversion of all outstanding shares, all 5,750,000 shares of series B preferred stock into an aggregate of 4,256,720 shares of our common stock and a nominal amount of cash in lieu of fractional share interests, based on a conversion rate of 0.7403 shares of our common stock for each issued and outstanding share of series B preferred stock. As a consequence, no shares of series B preferred stock were outstanding after July 15, 2021 and the 5,750,000 shares that were formerly series B preferred stock have returned to the status of authorized and unissued shares of preferred stock.

SEMPRA 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

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 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,
	2021		2020		2019
$25 par value, authorized 1,000,000 shares:
6% Series, 79,011 shares outstanding	$	3	$	3	$	3
6% Series A, 783,032 shares outstanding	19		19		19
SoCalGas - Total preferred stock	22		22		22
Less: 50,970 shares of the 6% Series outstanding owned by PE	(2)		(2)		(2)
Sempra - Total preferred stock of subsidiary	$	20	$	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.

DEBT AND CREDIT FACILITIES - SCHEDULE OF WEIGHTED-AVERAGE INTEREST RATES (Details)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Line of Credit Facility [Line Items]
Weighted average interest rate on total short-term debt outstanding (as a percent)	0.21%	0.14%	1.86%

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RESTRICTED NET ASSETS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 12,600
Undistributed earnings from equity method investments	1,500	$ 1,100	$ 634
Amount available for dividend distribution and loans without prior approval from regulatory agency	$ 445
Plan percentage of capital structure allocated to equity	52.00%
Maximum ratio of indebtedness to total capitalization	0.65
Sharyland Holdings, LP
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	50.00%
Sharyland Utilities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 103
Maximum ratio of indebtedness to total capitalization	0.70
Ownership percentage in equity method investee	100.00%
Plan percentage of capital structure allocated to debt	60.00%
Sempra Texas Utilities \| Oncor Holdings
Significant Restrictions of Subsidiaries [Line Items]
Plan percentage of capital structure allocated to equity	42.50%
Maximum ratio of indebtedness to total capitalization	0.65
Ownership percentage in equity method investee	100.00%
Plan percentage of capital structure allocated to debt	57.50%
Sempra Texas Utilities \| Oncor Electric Delivery Company LLC
Significant Restrictions of Subsidiaries [Line Items]
Ownership percentage in equity method investee	80.25%
Sempra Infrastructure \| Mexican Subsidiaries
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 193
Sempra Infrastructure \| IEnova Pipelines
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	20
Sempra Infrastructure \| SI Partners
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	6,800
Sempra Infrastructure \| Cameron LNG JV
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	395
Sempra Infrastructure \| TAG JV
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 66
Ownership percentage in equity method investee	50.00%
Consolidated Entities
Significant Restrictions of Subsidiaries [Line Items]
Restricted net assets of consolidated or unconsolidated subsidiaries	$ 19,300

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income	$ (426)	$ 505	$ 642
Other comprehensive income (loss):
Total other comprehensive (loss) income	171	(8)	1
Pretax amount
Net income	(736)	601	762
Other comprehensive income (loss):
Financial instruments	191	(146)	1
Pension and other postretirement benefits	28	(12)	1
Total other comprehensive (loss) income	213	(12)	2
Total comprehensive income, after preferred dividends of subsidiaries	1,020	1,022	932
Income tax (expense) benefit
Net income	310	(96)	(120)
Other comprehensive income (loss):
Financial instruments	(47)	33	0
Pension and other postretirement benefits	(6)	4	(1)
Total other comprehensive (loss) income	(53)	4	(1)
Total comprehensive income, after preferred dividends of subsidiaries	(201)	(192)	(169)
Net-of-tax amount
Net income	(426)	505	642
Other comprehensive income (loss):
Financial instruments	144	(113)	1
Pension and other postretirement benefits	22	(8)	0
Total other comprehensive (loss) income	160	(8)	1
Total comprehensive income, after preferred dividends of subsidiaries	819	830	763
Noncontrolling interests (after tax)
Net income	0	0	7
Other comprehensive income (loss):
Financial instruments	14	(12)	2
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	11	0	2
Total comprehensive income, after preferred dividends of subsidiaries	0	0	9
Total
Net income	819	824	774
Other comprehensive income (loss):
Financial instruments	158	(125)	2
Pension and other postretirement benefits	22	6	(4)
Total other comprehensive (loss) income	171	6	(2)
Total comprehensive income, after preferred dividends of subsidiaries	$ 819	$ 830	$ 772

REGULATORY MATTERS - SCHEDULE OF GENERAL RATE CASE AUTHORIZED REVENUE INCREASES (Details) - USD ($) $ in Millions		1 Months Ended
	Sep. 26, 2019	May 31, 2021	Apr. 30, 2020
General Rate Case
General Rate Case [Line Items]
Tracked income tax expense liability			$ 89
2019 GRC FD
General Rate Case [Line Items]
GRC revenue requirement	$ 2,770
2019 GRC FD \| Electricity
General Rate Case [Line Items]
GRC revenue requirement	1,590
2019 GRC FD \| Gas
General Rate Case [Line Items]
GRC revenue requirement	400
2020 GRC FD
General Rate Case [Line Items]
Revenue increase	$ 220
Percent increase (as a percent)	7.92%
2020 GRC FD \| O&M
General Rate Case [Line Items]
Revenue increase	$ 36
Percent increase (as a percent)	2.64%
2020 GRC FD \| Capital-related costs
General Rate Case [Line Items]
Revenue increase	$ 184
Percent increase (as a percent)	14.36%
2021 GRC FD
General Rate Case [Line Items]
Revenue increase	$ 150
Percent increase (as a percent)	5.00%
2021 GRC FD \| O&M
General Rate Case [Line Items]
Revenue increase	$ 34
Percent increase (as a percent)	2.40%
2021 GRC FD \| Capital-related costs
General Rate Case [Line Items]
Revenue increase	$ 116
Percent increase (as a percent)	7.93%
2019 GRC FD - 2022 Requirement \| General Rate Case
General Rate Case [Line Items]
Revenue increase		$ 142
Percent increase (as a percent)		4.53%
2019 GRC FD - 2023 Requirement \| General Rate Case
General Rate Case [Line Items]
Revenue increase		$ 130
Percent increase (as a percent)		3.97%

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARIZED FINANCIAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 19, 2021	Mar. 18, 2021
Schedule of Equity Method Investments [Line Items]
Operating revenue	$ 5,515	$ 4,748	$ 4,525
Operating Income	(566)	785	956
Net income	(426)	505	642
Current assets	1,599	1,482	1,218
Current liabilities	4,312	$ 2,082	2,182
ESJ
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners		50.00%		50.00%	50.00%	50.00%
Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Operating revenue	4,764	$ 4,511	4,347
Operating expense	(3,397)	(3,224)	(3,135)
Operating Income	1,367	1,287	1,212
Interest expense	(413)	(405)	(375)
Income tax expense	(163)	(146)	(131)
Net income	760	703	643
Noncontrolling interest held by TTI	(152)	(141)	(129)
Equity Method Investment, Summarized Financial Information, Net Income (Loss), Attributable To Controlling Interest	608	562	514
Current assets	1,039	1,045	913
Noncurrent assets	29,481	28,022	26,012
Current liabilities	2,220	1,120	1,626
Noncurrent liabilities	15,281	15,611	14,125
Noncontrolling interest held by TTI	2,916	2,737	2,473
Other
Schedule of Equity Method Investments [Line Items]
Operating revenue	2,721	2,341	798
Operating expense	(719)	(706)	(372)
Operating Income	2,002	1,635	426
Interest expense	(548)	(514)	(401)
Net income	1,388	1,132	85
Current assets	788	1,035	1,124
Noncurrent assets	14,686	15,304	15,039
Current liabilities	1,230	1,342	1,232
Noncurrent liabilities	$ 11,807	$ 12,863	$ 11,438

COMMITMENTS AND CONTINGENCIES - LEASES BALANCE SHEET INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Right-of-use assets – operating leases	$ 57	$ 74	$ 94
Finance leases, property plant and equipment	92	73	27
Finance leases, accumulated depreciation	$ (31)	$ (19)	$ (7)
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, plant and equipment, net	Property, plant and equipment, net	Property, plant and equipment, net
Finance leases, property plant and equipment, net	$ 61	$ 54	$ 20
Lease, Right-of-Use Asset	$ 118	$ 128	$ 114
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other current liabilities	Other current liabilities	Other current liabilities
Operating lease, other current liabilities	$ 15	$ 18	$ 18
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Deferred credits and other	Deferred credits and other	Deferred credits and other
Operating lease, deferred credits and other	$ 41	$ 56	$ 75
Total lease liabilities	$ 56	$ 74	$ 93
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Current portion of long-term debt and finance leases	Current portion of long-term debt and finance leases	Current portion of long-term debt and finance leases
Finance lease, current portion of long-term debt and finance leases	$ 11	$ 10	$ 6
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Long-term debt	Long-term debt	Long-term debt
Long-term lease liabilities	$ 50	$ 44	$ 13
Total finance leases	1,274	1,276	1,270
Lease liabilities	$ 117	$ 128	$ 112
Operating lease, weighted-average remaining lease term	4 years	5 years	6 years
Finance lease, weighted-average remaining lease term	7 years	7 years	6 years
Operating lease, weighted-average discount rate (as a percent)	1.98%	2.03%	3.73%
Finance lease, weighted-average discount rate (as a percent)	2.91%	2.83%	3.23%
SDG&E
Lessee, Lease, Description [Line Items]
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 in 2026	290
Variable payments, due thereafter	$ 2,779
Maximum
Lessee, Lease, Description [Line Items]
Operating lease renewal period	20 years
Annual increase in rent, percent	5.00%
Minimum
Lessee, Lease, Description [Line Items]
Operating lease termination period	1 year
Annual increase in rent, percent	2.00%

DEBT AND CREDIT FACILITIES (Tables)

12 Months Ended

Dec. 31, 2021

Debt Disclosure [Abstract]

Schedule of Line of Credit Facilities


COMMITTED LINES OF CREDIT
(Dollars in millions)
		At December 31, 2021
Borrower	Expiration date of facility	Total facility		Commercial paper outstanding		Amounts outstanding		Available unused credit
Sempra	May 2024	$	3,185	$	(1,240)	$	—	1,945
Sempra	May 2024	1,250		—		—		1,250
SDG&E	May 2024	1,500		(401)		—		1,099
SoCalGas	May 2024	750		(385)		—		365
SI Partners	November 2024	1,000		—		—		1,000
IEnova	September 2023	350		—		(350)		—
IEnova	February 2024	1,500		—		(399)		1,101
Total		$	9,535	$	(2,026)	$	(749)	$	6,760


FOREIGN UNCOMMITTED LINES OF CREDIT
(U.S. dollar equivalent in millions)
			December 31, 2021
Borrower	Expiration date of facility	Borrowing denomination	Total facility		Amounts outstanding		Available unused credit
IEnova(1)	September 2022	U.S. dollars	$	250	$	(250)	$	—
ECA LNG Phase 1(2)	August 2023	U.S. dollars or Mexican pesos	100		(63)		37
IEnova(3)	October 2023	U.S. dollars	100		(8)		92
IEnova(4)	October 2023	U.S. dollars or Mexican pesos	20		—		20
	Total		$	470	$	(321)	$	149

(1) Borrowings bear interest at a per annum rate equal to 3-month LIBOR plus 10 bps.

(3) Borrowings bear interest at a per annum rate equal to between 1-month and 6-month LIBOR plus 52 bps.


UNCOMMITTED LETTERS OF CREDIT
(Dollars in millions)
		December 31, 2021
	Expiration date range	Uncommitted letters of credit outstanding
SDG&E	January 2022 to May 2022	$	15
SoCalGas	March 2022 to November 2022	15
Sempra Infrastructure	March 2022 to October 2043	473
Parent and other	April 2022 to May 2023	179
Total		$	682

The weighted-average interest rates on the total short-term debt at December 31 were as follows:


WEIGHTED-AVERAGE INTEREST RATES

	December 31,
	2021		2020		2019
Sempra	0.60	%	0.83	%	2.31	%
SDG&E	0.65		—		1.97
SoCalGas	0.21		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,
	2021		2020		2019
SDG&E:
First mortgage bonds (collateralized by plant assets):
3% August 15, 2021	$	—	$	350	$	350
1.914% payable 2015 through February 2022	17		53		89
3.6% September 1, 2023	450		450		450
2.5% May 15, 2026	500		500		500
6% June 1, 2026	250		250		250
1.7% October 1, 2030	800		800		—
5.875% January and February 2034(1)	—		—		176
5.35% May 15, 2035	250		250		250
6.125% September 15, 2037	250		250		250
4% May 1, 2039(1)	—		—		75
6% June 1, 2039	300		300		300
5.35% May 15, 2040	250		250		250
4.5% August 15, 2040	500		500		500
3.95% November 15, 2041	250		250		250
4.3% April 1, 2042	250		250		250
3.75% June 1, 2047	400		400		400
4.15% May 15, 2048	400		400		400
4.1% June 15, 2049	400		400		400
3.32% April 15, 2050	400		400		—
2.95% August 15, 2051	750		—		—
	6,417		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	1,217		1,237		1,255
Other	57		39		15
	1,274		1,476		1,270
	7,691		7,529		6,410
Current portion of long-term debt	(49)		(611)		(56)
Unamortized discount on long-term debt	(17)		(13)		(12)
Unamortized debt issuance costs	(44)		(39)		(36)
Total SDG&E	7,581		6,866		6,306

SoCalGas:
First mortgage bonds (collateralized by plant assets):
3.15% September 15, 2024	$	500	$	500	$	500
3.2% June 15, 2025	350		350		350
2.6% June 15, 2026	500		500		500
2.55% February 1, 2030	650		650		—
5.75% November 15, 2035	250		250		250
5.125% November 15, 2040	300		300		300
3.75% September 15, 2042	350		350		350
4.45% March 15, 2044	250		250		250
4.125% June 1, 2048	400		400		400
4.3% January 15, 2049	550		550		550
3.95% February 15, 2050	350		350		350

	4,450		4,450		3,800
Other long-term debt (uncollateralized):
Notes at variable rates (0.55% at December 31, 2021) September 14, 2023(1)	300		300		—
1.875% Notes May 14, 2026(1)	4		4		4
5.67% Notes January 18, 2028(2)	5		5		5
Finance lease obligations	61		54		19
	370		363		28
	4,820		4,813		3,828
Current portion of long-term debt	(11)		(10)		(6)
Unamortized discount on long-term debt	(7)		(8)		(7)
Unamortized debt issuance costs	(29)		(32)		(27)
Total SoCalGas	4,773		4,763		3,788


LONG-TERM DEBT AND FINANCE LEASES (CONTINUED)
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
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		750
3.4% Notes February 1, 2028	1,000		1,000		1,000
3.8% Notes February 1, 2038	1,000		1,000		1,000
6% Notes October 15, 2039	750		750		750
4% Notes February 1, 2048	800		800		800
4.125% Junior Subordinated Notes April 1, 2052(1)	1,000		—		—
5.75% Junior Subordinated Notes July 1, 2079(1)	758		758		758


Sempra Infrastructure:
Other long-term debt (uncollateralized unless otherwise noted):
6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013)	189		197		207
Loan at variable rates (2.93% at December 31, 2021) December 9, 2025	341		17		—
Notes at 2.87% to 3.51% October 1, 2026(1)	—		—		22
Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets(2)	154		196		237
3.75% Notes January 14, 2028	300		300		300
Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)	—		—		11
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
Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034(1)	200		200		200
2.9% Loan November 15, 2034(1)	241		241		—
Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034(1)	100		100		—
4.875% Notes January 14, 2048	540		540		540
4.75% Notes January 15, 2051	800		800		—
	8,923		11,247		12,298
Current portion of long-term debt	(46)		(919)		(1,464)
Unamortized discount on long-term debt	(65)		(55)		(35)

Unamortized debt issuance costs	(98)		(121)		(108)
Total other Sempra	8,714		10,152		10,691
Total Sempra	$	21,068	$	21,781	$	20,785

(1) Callable long-term debt not subject to make-whole provisions.

(2) Debt is not callable.

The following table shows the detail and maturities of long-term debt outstanding:


LONG-TERM DEBT
(Dollars in millions)
	December 31,
	2021		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		750
3.4% Notes February 1, 2028	1,000		1,000		1,000
3.8% Notes February 1, 2038	1,000		1,000		1,000
6% Notes October 15, 2039	750		750		750
4% Notes February 1, 2048	800		800		800
4.125% Junior Subordinated Notes April 1, 2052(1)	1,000		—		—
5.75% Junior Subordinated Notes July 1, 2079(1)	758		758		758
	6,058		8,258		10,358
Current portion of long-term debt	—		(850)		(1,399)
Unamortized discount on long-term debt	(37)		(32)		(35)
Unamortized debt issuance costs	(52)		(59)		(68)
Total long-term debt	$	5,969	$	7,317	$	8,856

(1) Callable long-term debt not subject to make-whole provisions.

Schedule of Maturities of Long-term Debt


MATURITIES OF LONG-TERM DEBT(1)
(Dollars in millions)
	SDG&E		SoCalGas		Other Sempra		Total Sempra
2022	$	17	$	—	$	46	$	63
2023	450		300		257		1,007
2024	—		500		48		548
2025	—		350		410		760
2026	750		500		74		1,324
Thereafter	5,200		3,109		8,088		16,397
Total	$	6,417	$	4,759	$	8,923	$	20,099

(1) Excludes finance lease obligations, discounts, and debt issuance costs.

Schedule Of Callable Long Term Debt

At the option of Sempra, SDG&E and SoCalGas, certain debt at December 31, 2021 is callable subject to premiums:


CALLABLE LONG-TERM DEBT
(Dollars in millions)
	SDG&E		SoCalGas		Other Sempra		Total Sempra
Not subject to make-whole provisions	$	—	$	304	$	2,299	$	2,603
Subject to make-whole provisions	6,417		4,450		6,470		17,337

COMMITMENTS AND CONTINGENCIES - ENVIRONMENTAL ISSUES (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($) site	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Environmental Issues [Line Items]
Potential monetary sanctions threshold, actual amount	$ 16
Capital expendistures for environmental issues	63	$ 37	$ 41
Accrued liability for environmental matters, discount	$ 9
Accrued liability for environmental matters, discount rate (as a percent)	1.50%
Accrual for environmental loss contingencies	$ 57
Accrual for environmental loss contingencies, current	3
Accrual for environmental loss contingencies, noncurrent	35
Expected future payments for accruals, 2022	6
Expected future payments for accruals, 2023	13
Expected future payments for accruals, 2024	9
Expected future payments for accruals, 2025	4
Expected future payments for accruals, 2026	17
Expected future payments for accruals, thereafter	53
Minimum
Environmental Issues [Line Items]
Potential monetary sanctions threshold	$ 1
Manufactured-gas sites
Environmental Issues [Line Items]
Number of sites complete \| site	39
Number of sites in process \| site	3
Accrual for environmental loss contingencies	$ 34
Waste Disposal Sites
Environmental Issues [Line Items]
Number of sites complete \| site	5
Number of sites in process \| site	2
Accrual for environmental loss contingencies	$ 10
Other hazardous waste sites
Environmental Issues [Line Items]
Accrual for environmental loss contingencies	13
SONGS Sites
Environmental Issues [Line Items]
Estimated SONGS mitigation costs, recoverable in rates	97
SONGS mitigation costs incurred	53
SONGS mitigation costs remaining	$ 44

REGULATORY MATTERS - REGULATORY ACCOUNTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Regulatory balancing accounts - net undercollected, Noncurrent	$ 410	$ 218	$ 500
Amortization of regulatory asset	5	5	4
Fixed-price contracts and other derivatives
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(50)	(53)	8
Deferred income taxes recoverable (refundable) in rates
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	77	80	83
Pension and other postretirement benefit plan obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	51	417	400
Employee benefit costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	31	37	44
Removal obligations
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(627)	(685)	(728)
Environmental costs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	34	36	40
Sunrise Powerlink fire mitigation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 122	121	121
Amortization period	48 years
Commodity – electric
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ 77	72	102
Gas transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	49	35	22
Safety and reliability
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	339	335	295
Public purpose programs
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(183)	(253)	(273)
Commodity – gas, including transportation
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(146)	(56)	(118)
2019 GRC retroactive impacts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	202	400
Wildfire mitigation plan
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	178	93	12
Liability insurance premium
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	16	7	4
Other balancing accounts
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	42	(65)	(11)
Other regulatory (liabilities) assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	142	75	(101)
Total SDG&E
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(1,299)	(1,548)	(1,746)
Total SoCalGas
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	(257)	(32)	(251)
Other regulatory assets
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	0	0	6
Total Sempra
Schedule Of Net Regulatory Assets (Liabilities) [Line Items]
Net regulatory assets (liabilities)	$ (1,479)	$ (1,500)	$ (1,908)

DERIVATIVE FINANCIAL INSTRUMENTS - COMMODITY VOLUMES (Details)	12 Months Ended
	Dec. 31, 2021 MMBTU MWh	Dec. 31, 2020 MMBTU MWh	Dec. 31, 2019 MMBTU MWh
Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure \| MMBTU	184	189	231
Electricity
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	1	1	2
Congestion revenue rights
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	45	43	48
SDG&E \| Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure \| MMBTU	7	16	37
SDG&E \| Electricity
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	1	1	2
SDG&E \| Congestion revenue rights
Derivatives, Fair Value [Line Items]
Notional amount, energy measure	45	43	48
SoCalGas \| Natural gas
Derivatives, Fair Value [Line Items]
Notional amount, energy measure \| MMBTU	201	185	201

CONSOLIDATED BALANCE SHEETS (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	0	0	1,000,000
Common stock, shares authorized (in shares)	750,000,000	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	316,919,782	288,470,244	291,712,925	273,769,513
Convertible Preferred Stock Series A
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)		17,250,000	17,250,000
Convertible Preferred Stock Series B
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)		5,750,000	5,750,000
Series C Preferred Stock
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares outstanding (in shares)	900,000	900,000

FAIR VALUE MEASUREMENTS

12 Months Ended

Dec. 31, 2021

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, 2021, 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 accounts receivable and accounts payable. 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 short-term investments that consist of money market and mutual funds 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).

▪As we discuss in Note 6, in July 2020, Sempra 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 Infrastructure.”


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Short-term investments held in Rabbi Trust	81		—		—		81
Interest rate instruments	—		6		—		6
Foreign exchange instruments	—		2		—		2

Commodity contracts not subject to rate recovery	—		46		—		46
Effect of netting and allocation of collateral(2)	58		—		—		58
Commodity contracts subject to rate recovery	12		1		69		82
Effect of netting and allocation of collateral(2)	31		9		6		46
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	601	$	649	$	82	$	1,332
Liabilities:
Interest rate instruments	$	—	$	8	$	—	$	8
Foreign exchange instruments	—		1		—		1
Interest rate and foreign exchange instruments	—		131		—		131
Commodity contracts not subject to rate recovery	—		31		—		31
Commodity contracts subject to rate recovery	—		35		15		50


Total	$	—	$	206	$	15	$	221

(1) Excludes 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 – SEMPRA
(Dollars in millions)
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	9	$	(6)	$	—	$	3
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)	408		620		—		1,028
Short-term investments held in Rabbi Trust	61		—		—		61
Interest rate instruments	—		1		—		1
Foreign exchange instruments	—		24		—		24
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	$	515	$	655	$	134	$	1,304
Liabilities:
Interest rate instruments	$	—	$	47	$	—	$	47
Foreign exchange instruments	—		11		—		11
Interest rate and foreign exchange instruments	—		128		—		128
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

(1) Excludes 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 – SEMPRA
(Dollars in millions)
	Fair value at December 31, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	14	$	2	$	—	$	16
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)	563		527		—		1,090
Short-term investments held in Rabbi Trust	66		—		—		66
Interest rate instruments	—		3		—		3
Foreign exchange instruments	—		21		—		21
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	$	688	$	578	$	101	$	1,367
Liabilities:
Interest rate instruments	$	—	$	28	$	—	$	28
Foreign exchange instruments	—		7		—		7
Interest rate and foreign exchange instruments	—		122		—		122
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 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, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Commodity contracts subject to rate recovery	12		—		69		81
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	453	$	585	$	75	$	1,113
Liabilities:


Commodity contracts subject to rate recovery	$	—	$	—	$	15	$	15

Total	$	—	$	—	$	15	$	15

	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	9	$	(6)	$	—	$	3
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)	408		620		—		1,028
Commodity contracts subject to rate recovery	5		—		121		126
Effect of netting and allocation of collateral(2)	18		—		6		24
Total	$	431	$	620	$	127	$	1,178
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	52	$	52
Total	$	—	$	—	$	52	$	52

(1) Excludes 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, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	14	$	2	$	—	$	16
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)	563		527		—		1,090
Commodity contracts subject to rate recovery	1		3		95		99
Effect of netting and allocation of collateral(2)	10		—		6		16
Total	$	574	$	530	$	101	$	1,205
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 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, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	9		9		—		18
Total	$	9	$	10	$	—	$	19

Liabilities:

Commodity contracts subject to rate recovery	$	—	$	35	$	—	$	35
Total	$	—	$	35	$	—	$	35

	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 and SDG&E.


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Balance at January 1	$	69	$	28	$	179
Realized and unrealized (losses) gains	(50)		19		(184)
Allocated transmission instruments	3		6		6
Settlements	32		16		27
Balance at December 31	$	54	$	69	$	28
Change in unrealized (losses) gains relating to instruments still held at December 31	$	(16)	$	34	$	(139)

(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
2022	$	(3.67)	to	$	6.96	$	(0.70)
2021		(1.81)	to		14.11		(0.12)
2020		(3.77)	to		6.03		(1.58)

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
2021	$	24.10	to	$	105.00	$	53.57
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 Infrastructure

The table below sets forth reconciliations of changes in the fair value of Sempra’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra.


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Years ended December 31,
	2021		2020
Balance at January 1	$	3	$	—
Realized and unrealized gains(1)	11		6
Settlements	(7)		(3)
Balance at December 31(2)	$	7	$	3
Change in unrealized gains relating to instruments still held at December 31	$	11	$	3

(1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Consolidated Statements of Operations.

(2) Balances at December 31, 2021 and 2020 include $7 and $7, respectively, in Other Current Assets, offset by a negligible amount and $4, respectively, in Deferred Credits and Other on Sempra’s Consolidated Balance Sheets.

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 could 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 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)
	Carrying		Fair value
	amount		Level 1		Level 2		Level 3		Total
	December 31, 2021
Sempra:
Long-term note receivable(1)	$	300	$	—	$	—	$	327	$	327
Long-term amounts due from unconsolidated affiliates(2)	640		—		642		—		642
Long-term amounts due to unconsolidated affiliates	287		—		295		—		295
Total long-term debt(3)	20,099		—		22,126		—		22,126
SDG&E:
Total long-term debt(4)	$	6,417	$	—	$	7,236	$	—	$	7,236
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,367	$	—	$	5,367

	December 31, 2020
Sempra:
Long-term amounts due from unconsolidated affiliates(2)	$	786	$	—	$	817	$	—	$	817
Long-term amounts due to unconsolidated affiliates	275		—		266		—		266
Total long-term debt(3)	22,259		—		25,478		—		25,478
SDG&E:
Total long-term debt(4)	$	6,253	$	—	$	7,384	$	—	$	7,384
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,655	$	—	$	5,655

	December 31, 2019
Sempra:
Long-term amounts due from unconsolidated affiliates	$	742	$	—	$	759	$	—	$	759
Long-term amounts due to unconsolidated affiliates	195		—		184		—		184
Total long-term debt(3)	21,247		—		22,638		26		22,664
SDG&E:
Total long-term debt(4)	$	5,140	$	—	$	5,662	$	—	$	5,662
SoCalGas:
Total long-term debt(5)	$	3,809	$	—	$	4,189	$	—	$	4,189

(1) Before allowances for credit losses of $8 and excluding transaction costs of $5 at December 31, 2021.

(2) Before allowances for credit losses of $1 and $3 at December 31, 2021 and 2020, respectively. Includes $2 and $3 of accrued interest receivable at December 31, 2021 and 2020, respectively, in Due From Unconsolidated Affiliate – Current.

(3) Before reductions of unamortized discount and debt issuance costs of $260, $268 and $225 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $1,335, $1,330 and $1,289 at December 31, 2021 and 2020 and 2019, respectively.

(4) Before reductions of unamortized discount and debt issuance costs of $61, $52 and $48 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $1,274, $1,276 and $1,270 at December 31, 2021, 2020 and 2019, respectively.

(5) Before reductions of unamortized discount and debt issuance costs of $36, $40 and $34 at December 31, 2021, 2020 and 2019, respectively, and excluding finance lease obligations of $61, $54 and $19 at December 31, 2021, 2020 and 2019, respectively.

We provide the fair values for the securities held in the NDT related to SONGS in Note 15.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

+ References + Details

SAN ONOFRE NUCLEAR GENERATING STATION (Tables)

12 Months Ended

Dec. 31, 2021

Schedule of Nuclear Decommissioning Trusts


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
At December 31, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	56	$	—	$	—	$	56
Municipal bonds(2)	309		13		(1)		321
Other securities(3)	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Short-term investments, primarily 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
Short-term investments, primarily cash equivalents	16		—		—		16
Receivables (payables), net	(8)		—		—		(8)
Total	$	729	$	360	$	(7)	$	1,082

(1) Maturity dates are 2022-2052.

(2) Maturity dates are 2022-2056.

(3) Maturity dates are 2022-2072.

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 NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Proceeds from sales	$	961	$	1,439	$	914
Gross realized gains	67		156		24
Gross realized losses	(5)		(17)		(5)

FAIR VALUE MEASUREMENTS - FINANCIAL INSTRUMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Notes receivable, allowance for credit losses	$ 8
Notes receivable, transaction costs	5
Long term amounts due from unconsolidated affiliates, allowance for credit losses	1	$ 3
Accrued interest receivable	2	3
Unamortized discount (net of premium) and debt issuance costs	36	40	$ 34
Finance lease obligations	1,274	1,276	1,270
Carrying Amount
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	300
Long-term amounts due from unconsolidated affiliates	640	786	742
Long-term amounts due to unconsolidated affiliates	287	275	195
Total long-term debt	4,759	4,759	3,809
Fair Value
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	327
Long-term amounts due from unconsolidated affiliates	642	817	759
Long-term amounts due to unconsolidated affiliates	295	266	184
Total long-term debt	5,367	5,655	4,189
Fair Value \| Level 1
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	0
Long-term amounts due from unconsolidated affiliates	0	0	0
Long-term amounts due to unconsolidated affiliates	0	0	0
Total long-term debt	0	0	0
Fair Value \| Level 2
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	0
Long-term amounts due from unconsolidated affiliates	642	817	759
Long-term amounts due to unconsolidated affiliates	295	266	184
Total long-term debt	5,367	5,655	4,189
Fair Value \| Level 3
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term note receivable	327
Long-term amounts due from unconsolidated affiliates	0	0	0
Long-term amounts due to unconsolidated affiliates	0	0	0
Total long-term debt	$ 0	$ 0	$ 0

COMMITMENTS AND CONTINGENCIES - OTHER COMMITMENTS (Details)		12 Months Ended
	Jun. 08, 2021 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2012 USD ($) MMcf
Natural Gas and Electric Franchise
Loss Contingencies [Line Items]
Expected payment		$ 14,000,000
Expected payment, due in second year		14,000,000
Expected payment, due in third year		14,000,000
Expected payment, due in fourth year		15,000,000
Expected payment, due in fifth year		4,000,000
Expected payment, thereafter		51,000,000
Other Commitment	$ 110,000,000
Other Commitments, Interest Payments	$ 13,000,000
Other Commitments, Payments		11,000,000
Sunrise Powerlink Construction \| SDG&E
Loss Contingencies [Line Items]
Expected payment		4,000,000
Expected payment, due in second year		4,000,000
Expected payment, due in third year		4,000,000
Expected payment, due in fourth year		4,000,000
Expected payment, due in fifth year		4,000,000
Expected payment, thereafter		$ 275,000,000
Estimated annual escalation		2.00%
Purchase commitment period		48 years
Present value of future payments		$ 122,000,000
Continental Forge \| Sempra Infrastructure
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

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

12 Months Ended

Dec. 31, 2021

Business Combination and Asset Acquisition [Abstract]

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

ACQUISITIONS, DIVESTITURES AND DISCONTINUED OPERATIONS

ACQUISITIONS

Sempra Texas Utilities

Sharyland Holdings

In May 2019, Sempra 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 Infrastructure

ESJ

In March 2021, Sempra Infrastructure completed the acquisition of Saavi Energía’s 50% equity interest in ESJ for a purchase price of $65 million (net of $14 million of acquired cash and cash equivalents) plus the assumption of $277 million in debt (including $94 million owed from ESJ to Sempra Infrastructure that eliminates upon consolidation). Sempra Infrastructure previously accounted for its 50% interest in ESJ as an equity method investment. This acquisition increased Sempra Infrastructure’s ownership interest in ESJ from 50% to 100%. We accounted for this asset acquisition using a cost accumulation model whereby the cost of the acquisition and carrying value of our previously held interest in ESJ ($34 million) were allocated to

assets acquired ($458 million) and liabilities assumed ($345 million) based on their relative fair values. ESJ owns a fully operating wind power generation facility with a nameplate capacity of 155 MW that is fully contracted by SDG&E under a long-term PPA. Sempra Infrastructure recorded a $190 million intangible asset for the relative fair value of the PPA that will be amortized over a period of 14 years against revenues. On January 15, 2022, ESJ completed construction and began commercial operation of a second wind power generation facility with a nameplate capacity of 108 MW that is also fully contracted by SDG&E under a long-term PPA.

DIVESTITURES

Sempra Infrastructure

In February 2019, Sempra Infrastructure 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 Infrastructure completed the sale of other non-utility assets for $5 million.

Sempra Renewables

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 Sempra’s 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.

Parent and Other

PXiSE

In December 2021, Parent and other completed the sale of its 80% interest in PXiSE for total cash proceeds of $38 million, net of transaction costs totaling $4 million, and recorded a $36 million ($26 million after tax) gain, which is included in Gain (Loss) on Sale of Assets on Sempra’s Consolidated Statement of Operations.

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 Sempra’s Consolidated Statements of Operations.

Summarized results from discontinued operations were as follows:


DISCONTINUED OPERATIONS
(Dollars in millions)
	Years ended December 31,
	2020(1)		2019
Revenues	$	570	$	1,614
Cost of sales	(364)		(1,012)
Gain on sale of discontinued operations	2,899		—
Operating expenses	(66)		(159)
Interest and other	(3)		(11)
Income before income taxes and equity earnings	3,036		432
Income tax expense	(1,186)		(72)
Equity earnings	—		3
Income from discontinued operations, net of income tax	1,850		363
Earnings attributable to noncontrolling interests	(10)		(35)
Earnings from discontinued operations attributable to common shares	$	1,840	$	328

(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.

As a result of the sales of our South American businesses, in 2020, we reclassified $645 million of cumulative foreign currency translation losses from AOCI to Gain on Sale of Discontinued Operations, which is included in Income from Discontinued Operations, Net of Income Tax, on Sempra’s Consolidated Statements of Operations.

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA

12 Months Ended

Dec. 31, 2021

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

Sempra’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, a new segment that includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Through an internal reorganization, we consolidated the assets of our LNG business (previously included in our Sempra LNG segment) and our ownership of IEnova (previously included in our Sempra Mexico segment) under Sempra Global (previously included in Parent and other), which was renamed SI Partners. This reorganization simplifies Sempra’s ownership and management of its non-utility, energy infrastructure assets in North America by consolidating them under a single platform. As a result, the Sempra LNG and Sempra Mexico segments no longer exist. Our historical segment disclosures have been restated to conform with the current presentation, so that all discussions of our reportable segments reflect the revised segment information of our four separate reportable segments, 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.

SoCalGas

SoCalGas’ common stock is wholly owned by PE, which is a wholly owned subsidiary of Sempra.

BASIS OF PRESENTATION

This is a combined report of Sempra, 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” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We sometimes refer to SDG&E and SoCalGas collectively as Sempra California. SI Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. 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;

▪the Consolidated Financial Statements and related Notes of SDG&E; 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

We completed the sales of our equity interests in our Peruvian businesses in April 2020 and our Chilean businesses in June 2020. 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 upon our decision to sell them in January 2019. These

businesses are presented as discontinued operations, which we discuss further in Note 5. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.

Subsequent Events

We evaluated events and transactions that occurred after December 31, 2021 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.

REGULATED OPERATIONS

SDG&E’s and SoCalGas’ 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, SDG&E and SoCalGas record regulatory liabilities when the CPUC or, in the case of SDG&E, 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 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 Infrastructure’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.

Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which 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 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 Infrastructure 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, short-term investments, 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 Infrastructure.

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:

▪for Sempra Infrastructure, funds 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

▪for Parent and other, funds held in a delisting trust for the purpose of purchasing the remaining publicly owned IEnova shares

The following table provides a reconciliation of cash, cash equivalents and restricted cash reported on Sempra’s Consolidated Balance Sheets to the sum of such amounts reported on Sempra’s Consolidated Statements of Cash Flows.


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	At December 31,
	2021		2020		2019
Cash and cash equivalents	$	559	$	960	$	108
Restricted cash, current	19		22		31
Restricted cash, noncurrent	3		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	$	581	$	985	$	217

In Sempra’s 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, amounts due from unconsolidated affiliates, our net investment in a sales-type lease and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 6.

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 receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. 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.

As we discuss in Note 4, the CPUC authorized SDG&E and SoCalGas to track and request recovery of incremental costs, including uncollectible expenses, associated with complying with customer protection measures ordered by the CPUC related to the COVID-19 pandemic.

In connection with a separate CPUC decision addressing residential service disconnections, SDG&E and SoCalGas each established 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, as we discuss in Note 4.

We provide below allowances and changes in allowances for credit losses for trade receivables and other receivables. SDG&E and SoCalGas record changes in the allowances for credit losses related to Accounts Receivable – Trade in regulatory accounts.


RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Allowances for credit losses at January 1	$	138	$	29	$	21
Incremental allowance upon adoption of ASU 2016-13	—		1		—
Provisions for expected credit losses	45		124		22
Write-offs	(47)		(16)		(14)
Allowances for credit losses at December 31	$	136	$	138	$	29
SDG&E:
Allowances for credit losses at January 1	$	69	$	14	$	11
Provisions for expected credit losses	23		65		10
Write-offs	(26)		(10)		(7)
Allowances for credit losses at December 31	$	66	$	69	$	14
SoCalGas:
Allowances for credit losses at January 1	$	68	$	15	$	10
Provisions for expected credit losses	22		59		12
Write-offs	(21)		(6)		(7)
Allowances for credit losses at December 31	$	69	$	68	$	15

Allowances for credit losses are included in the Consolidated Balance Sheets as follows:


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
Accounts receivable – trade, net	$	94	$	111	$	7
Accounts receivable – other, net	39		27		22
Other long-term assets	3		—		—
Total allowances for credit losses	$	136	$	138	$	29
SDG&E:
Accounts receivable – trade, net	$	42	$	55	$	4
Accounts receivable – other, net	22		14		10
Other long-term assets	2		—		—
Total allowances for credit losses	$	66	$	69	$	14
SoCalGas:
Accounts receivable – trade, net	$	51	$	55	$	3
Accounts receivable – other, net	17		13		12
Other long-term assets	1		—		—
Total allowances for credit losses	$	69	$	68	$	15

As we discuss below in “Transactions with Affiliates,” we have loans due from unconsolidated affiliates with varying tenors, interest rates and currencies. On a quarterly basis, we evaluate credit losses and record allowances for expected credit losses on amounts due from unconsolidated affiliates, 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. At December 31, 2021 and 2020, $1 million and $3 million, respectively, of expected credit losses are included in noncurrent Due From Unconsolidated Affiliates on Sempra’s Consolidated Balance Sheets.

As we discuss below in “Note Receivable,” Sempra loaned $300 million to KKR in exchange for an interest-bearing promissory note. We evaluate credit losses and record allowances for expected credit losses on this note receivable based on published default rate studies, the maturity date of the instrument and an internally developed credit rating. At December 31, 2021, $8 million of expected credit losses is included in Other Long-Term Assets on Sempra’s Consolidated Balance Sheet.

As we discuss below in Note 6, Sempra provided a guarantee for the benefit of Cameron LNG JV related to amounts withdrawn by Sempra Infrastructure from the SDSRA. At December 31, 2021, expected credit losses of $7 million related to this guarantee are included in Deferred Credits and Other on Sempra’s 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

SDG&E and SoCalGas 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. SDG&E and SoCalGas generally value materials and supplies at the lower of average cost or net realizable value.

Sempra Infrastructure values natural gas inventory and materials and supplies at the lower of average cost or net realizable value, and LNG inventory using the first-in first-out method.

The components of inventories are as follows:


INVENTORY BALANCES AT DECEMBER 31
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	2021		2020		2019		2021		2020		2019		2021		2020		2019
Natural gas	$	164	$	118	$	110	$	—	$	—	$	1	$	114	$	94	$	90
LNG	27		7		9		—		—		—		—		—		—
Materials and supplies	198		183		158		123		104		93		58		59		46
Total	$	389	$	308	$	277	$	123	$	104	$	94	$	172	$	153	$	136

NOTE RECEIVABLE

In connection with the KKR Purchase Agreement, which we define and discuss below in “Noncontrolling Interests,” we entered into an accommodation and support agreement under which KKR issued a $300 million interest bearing promissory note to Sempra in exchange for cash. Loan-related transaction costs incurred by KKR totaled $5 million, which were reimbursed by Sempra per the terms of the agreement. The promissory note is due to be repaid in full no later than October 1, 2029 and bears compound interest at 5% per annum, which may be paid quarterly or added to the outstanding principal at the election of KKR. At December 31, 2021, Other Long-Term Assets includes $297 million of outstanding principal, net of allowance for credit losses, and Other Current Assets includes $3 million of interest receivable on Sempra’s Consolidated Balance Sheet.

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 2021 rate base, the liability cap for SDG&E is approximately $1.1 billion, 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 July 2021, the CPUC approved SDG&E’s 2021 Wildfire Mitigation Plan. In July 2021, the CPUC’s Wildfire Safety Division became the OEIS under the California Natural Resources Agency. As successor to the Wildfire Safety Division, the OEIS maintains the duties and responsibilities of the former Wildfire Safety Division with respect to Wildfire Mitigation Plans. The 2021 Wildfire Mitigation Plan is effective until the OEIS approves a new plan. In December 2021, SDG&E received its 2021 wildfire safety certification from the OEIS, which is valid for 12 months from the issue date.

The Wildfire Fund was 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 was also funded by initial shareholder contributions from the IOUs totaling $7.5 billion. SDG&E’s share was $322.5 million. 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. 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. The district court and, subsequently, the U.S. Court of Appeals for the Ninth Circuit dismissed the complaint.

Wildfire Fund Asset and Obligation

In 2019, SDG&E recorded both a Wildfire Fund asset and a related obligation for its commitment to make shareholder contributions of $451.5 million 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. SDG&E expects to continue 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 recognizes a reduction of its Wildfire Fund asset and records 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, decrease the Wildfire Fund asset and remaining available coverage.

The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations.


WILDFIRE FUND
(Dollars in millions)
		December 31,
	Location	2021		2020		2019
Wildfire Fund asset:
Current	Prepaid Expenses	$	29	$	29	$	29
Noncurrent	Wildfire Fund	331		363		392
Wildfire Fund obligation:
Current	Other Current Liabilities	$	13	$	13	$	13
Noncurrent	Deferred Credits and Other	64		75		86
		Years ended December 31,
		2021		2020		2019
Amortization of Wildfire Fund asset	Operation and Maintenance	$	29	$	29	$	12
Impairment of Wildfire Fund asset	Impairment Losses(1)	3		—		—
Accretion of Wildfire Fund obligation	Operation and Maintenance	2		2		1

(1) Included in O&M 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 SDG&E and SoCalGas over the estimated service lives of the properties as required by the CPUC.

Under the regulatory accounting treatment required for flow-through temporary differences, SDG&E, SoCalGas and Sempra Infrastructure 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 because they 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

SDG&E, SoCalGas and Sempra Infrastructure 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 SDG&E and SoCalGas, 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. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Infrastructure records 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 is recorded at cost and primarily represents the buildings, equipment and other facilities used by SDG&E and SoCalGas to provide natural gas and electric utility services, and by the Sempra Infrastructure 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 for our non-regulated projects includes capitalized interest. Maintenance costs are expensed as incurred. The cost of most retired depreciable utility plant assets less salvage value is charged to accumulated depreciation. We discuss assets collateralized as security for certain indebtedness in Note 7.


PROPERTY, PLANT AND EQUIPMENT BY MAJOR FUNCTIONAL CATEGORY
(Dollars in millions)
	December 31,						Depreciation rates for years ended December 31,
	2021		2020		2019		2021		2020			2019
SDG&E:
Natural gas operations	$	3,200	$	2,805	$	2,534	2.55	%	2.51	%		2.47	%
Electric distribution	9,471		8,592		7,985		3.93		3.90			3.94
Electric transmission(1)	7,577		7,156		6,577		3.02		3.10			2.79
Electric generation	2,446		2,440		2,415		4.74		4.56			4.50
Other electric	2,100		1,743		1,492		7.23		6.92			6.61
Construction work in progress(1)	1,662		1,700		1,501		NA		NA			NA
Total SDG&E	26,456		24,436		22,504
SoCalGas:
Natural gas operations	21,894		19,961		18,370		3.65		3.63			3.60
Other non-utility	50		45		34		2.23		3.80			5.08
Construction work in progress	1,160		1,174		958		NA		NA			NA
Total SoCalGas	23,104		21,180		19,362

Sempra Infrastructure and parent(2):							Estimated useful lives				Weighted-average useful life
Land and land rights	291		283		278		16 to 50 years(3)					36
Machinery and equipment:
Pipelines and storage	3,698		3,482		3,596		5 to 50 years					42
Generating plants	1,659		1,288		1,154		11 to 30 years					27
LNG terminals	1,138		1,138		1,134		43 years					43
Liquid fuels terminals	420		—		—		37 years					37
Other	370		359		180		3 to 50 years					13
Construction work in progress	1,494		1,514		895		NA					NA
Other	310		248		226		4 to 50 years					21
	9,380		8,312		7,463
Total Sempra	$	58,940	$	53,928	$	49,329

(1) At December 31, 2021, includes $542 in electric transmission assets and $5 in construction work in progress related to SDG&E’s 86% 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’s and SDG&E’s Consolidated Statements of Operations.

(2) Includes $211, $191 and $178 at December 31, 2021, 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 is computed using the straight-line method over the asset’s estimated composite useful life, the CPUC-prescribed period for SDG&E and SoCalGas, or the remaining term of the site leases, whichever is shortest.


DEPRECIATION EXPENSE
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra	$	1,833	$	1,646	$	1,551
SDG&E	884		797		757
SoCalGas	711		649		598


ACCUMULATED DEPRECIATION AND AMORTIZATION
(Dollars in millions)
	December 31,
	2021		2020		2019
SDG&E:
Accumulated depreciation:
Natural gas operations	$	919	$	870	$	832
Electric transmission, distribution and generation(1)	5,489		5,145		4,705
Total SDG&E	6,408		6,015		5,537
SoCalGas:
Accumulated depreciation:
Natural gas operations	6,845		6,422		6,023
Other non-utility	16		15		15
Total SoCalGas	6,861		6,437		6,038
Sempra Infrastructure and parent:
Accumulated depreciation – other(2)	1,777		1,473		1,302
Total Sempra	$	15,046	$	13,925	$	12,877

(1) Includes $292 at December 31, 2021 related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities.

(2) Includes $55, $51 and $49 at December 31, 2021, 2020, and 2019, respectively, of accumulated depreciation for utility plant at Ecogas.

SDG&E and SoCalGas finance 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. SDG&E and SoCalGas 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 under construction by Sempra Infrastructure that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC.

We capitalize interest costs incurred to finance capital projects and interest at equity method investments that have not commenced planned principal operations.

The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest.


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra	$	217	$	202	$	183
SDG&E	106		104		75
SoCalGas	64		55		47

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.

For our annual goodwill impairment testing, we have the option to first make a qualitative assessment of whether it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount before applying the quantitative goodwill impairment test. If we elect to perform the qualitative assessment, we evaluate relevant events and circumstances, including but not limited to, macroeconomic conditions, industry and market considerations, cost factors and the overall financial performance of the reporting unit. If, after assessing these qualitative factors, we determine that it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, then we perform the quantitative goodwill impairment test. If, after performing the quantitative goodwill impairment test, we determine that goodwill is impaired, we 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.

Goodwill of $1,602 million at December 31, 2021, 2020, and 2019 relates to the 2016 acquisitions of IEnova Pipelines and the Ventika wind power generation facilities at Sempra Infrastructure.

Other Intangible Assets

Other Intangible Assets included on Sempra’s Consolidated Balance Sheets are as follows:


OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period (years)	December 31,
		2021		2020		2019
Renewable energy transmission and consumption permits	15 to 19	$	169	$	169	$	169
O&M agreement	23	66		66		66
ESJ PPA	14	190		—		—
Other	10 to indefinite	15		15		15
		440		250		250
Less accumulated amortization:
Renewable energy transmission and consumption permits		(40)		(32)		(24)
O&M agreement		(12)		(9)		(6)
ESJ PPA		(10)		—		—
Other		(8)		(7)		(7)
		(70)		(48)		(37)
		$	370	$	202	$	213

Other Intangible Assets at December 31, 2021 primarily include:

▪renewable energy transmission and consumption permits previously granted by the CRE at the Ventika wind power generation facilities, Don Diego Solar and Border Solar;

▪a favorable O&M agreement acquired in connection with the acquisition of DEN; and

▪the relative fair value of the PPA that was acquired in connection with the acquisition of ESJ in March 2021.

Intangible assets subject to amortization are amortized over their estimated useful lives. Amortization expense for intangible assets was $22 million, including $10 million recorded against revenues, in 2021 and $11 million in both 2020 and 2019. We estimate amortization expense for the next five years to be $26 million per year, including $13 million per year recorded against revenues.

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

We consolidate a VIE if we are the primary beneficiary of the VIE. Our determination of whether we are the primary beneficiary is based on qualitative and quantitative analyses, which assess:

▪the purpose and design of the VIE;

▪the nature of the VIE’s risks and the risks we absorb;

▪the power to direct activities that most significantly impact the economic performance of the VIE; and

▪the obligation to absorb losses or the right to receive benefits that could be significant to the VIE.

We will continue to evaluate our VIEs for any changes that may impact our determination of whether an entity is a VIE and if we are the primary beneficiary.

SDG&E

SDG&E’s power procurement is subject to reliability requirements that may require SDG&E to enter into various PPAs that include variable interests. SDG&E evaluates the respective entities to determine if variable interests exist and, based on the qualitative and quantitative analyses described above, if SDG&E, and indirectly Sempra, is the primary beneficiary.

SDG&E has agreements under which it purchases power generated by facilities for which it supplies all of the natural gas to fuel the power plant (i.e., tolling agreements). SDG&E’s obligation to absorb natural gas costs may be a significant variable interest. In addition, SDG&E has the power to direct the dispatch of electricity generated by these facilities. Based on our analysis, the ability to direct the dispatch of electricity may have the most significant impact on the economic performance of the entity owning the generating facility because of the associated exposure to the cost of natural gas, which fuels the plants, and the value of electricity produced. To the extent that SDG&E (1) is obligated to purchase and provide fuel to operate the facility, (2) has the power to direct the dispatch, and (3) purchases all of the output from the facility for a substantial portion of the facility’s useful life, SDG&E may be the primary beneficiary of the entity owning the generating facility. SDG&E determines if it is the primary beneficiary in these cases based on a qualitative approach in which it considers the operational characteristics of the facility, including its expected power generation output relative to its capacity to generate and the financial structure of the entity, among other factors. If SDG&E determines that it is the primary beneficiary, SDG&E and Sempra consolidate the entity that owns the facility as a VIE.

In addition to tolling agreements, other variable interests involve various elements of fuel and power costs, and other components of cash flows expected to be paid to or received by our counterparties. In most of these cases, the expectation of variability is not substantial, and SDG&E generally does not have the power to direct activities, including the operation and maintenance activities of the generating facility, that most significantly impact the economic performance of the other VIEs. If our ongoing evaluation of these VIEs were to conclude that SDG&E becomes the primary beneficiary and consolidation by SDG&E becomes necessary, the effects could be significant to the financial position and liquidity of SDG&E and Sempra.

SDG&E determined that none of its PPAs and tolling agreements resulted in SDG&E being the primary beneficiary of a VIE at December 31, 2021, 2020 and 2019. PPAs and tolling agreements that relate to SDG&E’s involvement with VIEs are primarily accounted for as finance leases. The carrying amounts of the assets and liabilities under these contracts are included in PP&E, net, and finance lease liabilities with balances of $1,217 million, $1,237 million and $1,255 million at December 31, 2021, 2020 and 2019, respectively. SDG&E recovers costs incurred on PPAs, tolling agreements and other variable interests through CPUC-approved long-term power procurement plans. SDG&E has no residual interest in the respective entities and has not provided or guaranteed any debt or equity support, liquidity arrangements, performance guarantees or other commitments associated with these contracts other than the purchase commitments described in Note 16. As a result, SDG&E’s potential exposure to loss from its variable interest in these VIEs is not significant.

Otay Mesa VIE

Through October 3, 2019, SDG&E had a tolling agreement to purchase power generated at OMEC, a 605-MW generating facility owned by OMEC LLC, which is a VIE that we refer to as Otay Mesa VIE. SDG&E determined that it was the primary beneficiary of Otay Mesa VIE, and therefore, SDG&E and Sempra consolidated Otay Mesa VIE. On August 23, 2019, SDG&E and OMEC LLC executed an amended resource adequacy capacity agreement that resulted in SDG&E and Sempra deconsolidating Otay Mesa VIE. No gain or loss was recognized upon deconsolidation.

Sempra Texas Utilities

Our 100% interest in Oncor Holdings is a VIE that owns an 80.25% interest in Oncor. Sempra is not the primary beneficiary of this VIE because of the structural and operational ring-fencing and governance measures in place that prevent us from having the

power to direct the significant activities of Oncor Holdings. As a result, we do not consolidate Oncor Holdings and instead account for our ownership interest as an equity method investment. See Note 6 for additional information about our equity method investment in Oncor Holdings and restrictions on our ability to influence its activities. Our maximum exposure to loss, which fluctuates over time, from our interest in Oncor Holdings does not exceed the carrying value of our investment, which was $12,947 million, $12,440 million and $11,519 million at December 31, 2021, 2020 and 2019, respectively.

Sempra Infrastructure

Cameron LNG JV

Cameron LNG JV is a VIE principally due to contractual provisions that transfer certain risks to customers. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of Cameron LNG JV, including LNG production and operation and maintenance activities at the liquefaction facility. Therefore, we account for our investment in Cameron LNG JV under the equity method. The carrying value of our investment, including amounts recognized in AOCI related to interest-rate cash flow hedges at Cameron LNG JV, was $514 million at December 31, 2021, $433 million at December 31, 2020 and $1,256 million at December 31, 2019. Our maximum exposure to loss, which fluctuates over time, includes the carrying value of our investment and our obligation under the SDSRA, which we discuss in Note 6.

CFIN

As we discuss in Note 6, in July 2020, Sempra entered into a Support Agreement, which was amended in June 2021, for the benefit of CFIN, which is a VIE. Sempra is not the primary beneficiary of this VIE because we do not have the power to direct the most significant activities of CFIN, including modification, prepayment, and refinance decisions related to the financing arrangement with external lenders and Cameron LNG JV’s four project owners as well as the ability to determine and enforce remedies in the event of default. The conditional obligations of the Support Agreement represent a variable interest that we measure at fair value on a recurring basis (see Note 9). Sempra’s maximum exposure to loss under the terms of the Support Agreement is $979 million.

ECA LNG Phase 1

ECA LNG Phase 1 is a VIE because its total equity at risk is not sufficient to finance its activities without additional subordinated financial support. We expect that ECA LNG Phase 1 will require future capital contributions or other financial support to finance the construction of the facility. Sempra is the primary beneficiary of this VIE because we have the power to direct the development activities related to the construction of the liquefaction facility, which we consider to be the most significant activities of ECA LNG Phase 1 during the construction phase of its natural gas liquefaction export project. As a result, we consolidate ECA LNG Phase 1. Sempra Infrastructure consolidated $632 million and $207 million of assets at December 31, 2021 and 2020, respectively, consisting primarily of PP&E, net, and Accounts Receivable – Other attributable to ECA LNG Phase 1 that could be used only to settle obligations of this VIE and that are not available to settle obligations of Sempra, and $455 million and $49 million of liabilities at December 31, 2021 and 2020, respectively, consisting primarily of long-term debt, short-term debt and accounts payable attributable to ECA LNG Phase 1 for which creditors do not have recourse to the general credit of Sempra. Additionally, as we discuss in Note 7, Sempra and TotalEnergies SE have provided guarantees for the loan facility supporting construction of the liquefaction facility based on their respective proportionate ownership interest in ECA LNG Phase 1.

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 using the present value of the obligation at the time the asset is placed into service, and recognize that cost over the life of the related asset by depreciating the asset retirement cost and accreting the obligation until the liability is settled. Our rate-regulated entities 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.

We have recorded AROs related to various assets, including:

SDG&E and SoCalGas

▪fuel and storage tanks

▪natural gas transmission and distribution systems

▪hazardous waste storage facilities

▪asbestos-containing construction materials

SDG&E

▪nuclear power facilities

▪electric transmission and distribution systems

▪energy storage systems

▪power generation plants

SoCalGas

▪underground natural gas storage facilities and wells

Sempra Infrastructure

▪natural gas transportation and distribution systems

▪power generation plants

▪LNG facility

▪LPG terminal

The changes in AROs are as follows:


CHANGES IN ASSET RETIREMENT OBLIGATIONS
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	2021		2020		2019		2021		2020		2019		2021		2020		2019
Balance as of January 1(1)	$	3,289	$	3,083	$	2,972	$	876	$	866	$	874	$	2,368	$	2,177	$	2,063
Accretion expense	133		127		123		38		39		39		92		86		81
Liabilities incurred and acquired	20		2		2		2		—		—		—		—		—
Deconsolidation	—		—		(2)		—		—		(2)		—		—		—
Payments	(63)		(63)		(46)		(60)		(60)		(44)		(3)		(2)		(2)
Revisions(2)	159		140		34		34		31		(1)		125		107		35
Balance at December 31(1)	$	3,538	$	3,289	$	3,083	$	890	$	876	$	866	$	2,582	$	2,368	$	2,177

(1) Current portion of the ARO for Sempra is included in Other Current Liabilities on the Consolidated Balance Sheets.

(2) SDG&E’s increase in ARO in 2021 includes $22 million due to a revised estimate related to the decommissioning of SONGS, which is offset in noncurrent Regulatory Assets.

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 if:

▪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 or a range of possible losses 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 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.

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

The Consolidated Statements of Comprehensive Income (Loss) show the changes in the components of OCI, including the amounts attributable to NCI. The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, excluding amounts attributable to NCI.


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and other postretirement benefits		Total accumulated other comprehensive income (loss)
Sempra(2):
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)(4)	(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)
OCI before reclassifications(4)	(34)		62		8		36
Amounts reclassified from AOCI(5)	19		113		14		146
Net OCI(4)(5)	(15)		175		22		182
Balance as of December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
SDG&E:
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)
OCI before reclassifications					(1)		(1)
Amounts reclassified from AOCI					1		1
Net OCI					—		—
Balance as of December 31, 2021					$	(10)	$	(10)
SoCalGas:

Balance as of December 31, 2018			$	(12)	$	(8)	$	(20)
Adoption of ASU 2018-02			(2)		(2)		(4)
OCI before reclassifications			—		(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(3)			—		2		2
Net OCI			—		(8)		(8)
Balance as of December 31, 2020			(13)		(18)		(31)

OCI before reclassifications			—		(2)		(2)
Amounts reclassified from AOCI			—		2		2
Net OCI			—		—		—
Balance as of December 31, 2021			$	(13)	$	(18)	$	(31)

(1) All amounts are net of income tax, if subject to tax, and exclude NCI.

(2) Includes discontinued operations in 2020 and 2019.

(3) Pension and Other Postretirement Benefits and Total AOCI include $6 in transfers of liabilities from SDG&E to SoCalGas and $3 in transfers of liabilities from SDG&E to Sempra in 2020 and $4 in transfers of liabilities from SoCalGas to Sempra in 2019 related to the nonqualified pension plans.

(4) Total AOCI includes $28 of foreign currency translation adjustments and $16 of financial instruments associated with the IEnova exchange and cash tender offers in 2021. Total AOCI includes $4 of foreign currency translation adjustments and $3 of financial instruments associated with IEnova’s repurchases of NCI in 2020. We discuss these transactions below in “Other Noncontrolling Interests – Sempra Infrastructure.” These transactions do not impact the Consolidated Statements of Comprehensive Income (Loss).

(5) Total AOCI includes $19 of foreign currency translation adjustments and $47 of financial instruments associated with the sale of NCI to KKR in 2021. We discuss this transaction below in “Other Noncontrolling Interests – Sempra Infrastructure.” This transaction does not impact the Consolidated Statements of Comprehensive Income (Loss).


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)						Affected line item on Consolidated Statements of Operations
	Years ended December 31,
	2021		2020		2019
Sempra:
Foreign currency translation adjustments	$	—	$	645	$	—	Income from Discontinued Operations, Net of Income Tax

Financial instruments:
Interest rate instruments	$	—	$	—	$	10	Gain (Loss) on Sale of Assets
Interest rate instruments(1)	11		10		3		Interest Expense
Interest rate instruments	73		46		3		Equity Earnings(2)
Foreign exchange instruments	1		(1)		2		Revenues: Energy-Related Businesses

Foreign exchange instruments	—		—		2		Equity Earnings(2)
Interest rate and foreign exchange instruments	1		1		—		Interest Expense
	6		11		(9)		Other Income (Expense) , Net
Total before income tax	92		67		11
	(24)		(19)		(2)		Income Tax Expense
Net of income tax	68		48		9
	(2)		(1)		(1)		Earnings Attributable to Noncontrolling Interests
	$	66	$	47	$	8
Pension and other postretirement benefits(3):
Amortization of actuarial loss	$	8	$	8	$	12	Other Income (Expense), Net
Amortization of actuarial loss	—		6		1		Income from Discontinued Operations, Net of Income Tax
Amortization of prior service cost	4		4		3		Other Income (Expense), Net
Settlement charges	7		22		28		Other Income (Expense), Net
Total before income tax	19		40		44
	—		(2)		—		Income from Discontinued Operations, Net of Income Tax
	(5)		(9)		(12)		Income Tax Expense
Net of income tax	$	14	$	29	$	32

Total reclassifications for the period, net of tax	$	80	$	721	$	40
SDG&E:
Financial instruments:
Interest rate instruments(1)	$	—	$	—	$	3	Interest Expense
	—		—		(3)		Earnings Attributable to Noncontrolling Interest
	$	—	$	—	$	—
Pension and other postretirement benefits(3):
Amortization of actuarial loss	$	—	$	1	$	—	Other Income, Net
Amortization of prior service cost	1		1		1		Other Income, Net

Total before income tax	1		2		1
	—		(1)		—		Income Tax Expense
Net of income tax	$	1	$	1	$	1

Total reclassifications for the period, net of tax	$	1	$	1	$	1
SoCalGas:
Financial instruments:
Interest rate instruments	$	—	$	—	$	1	Interest Expense


Pension and other postretirement benefits(3):
Amortization of actuarial loss	$	1	$	1	$	1	Other Expense, Net
Amortization of prior service cost	1		1		—		Other Expense, Net
Total before income tax	2		2		1
	—		—		(1)		Income Tax Benefit (Expense)
Net of income tax	$	2	$	2	$	—

Total reclassifications for the period, net of tax	$	2	$	2	$	1

(1) Amounts in 2019 include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

(2) Equity earnings at our foreign equity method investees are recognized after tax.

(3) Amounts are included in the computation of net periodic benefit cost (see “Net Periodic Benefit Cost” in Note 9).

NONCONTROLLING INTERESTS

Ownership interests in a consolidated entity that are held by unconsolidated owners are accounted for and reported as NCI.

SoCalGas Preferred Stock

The preferred stock at SoCalGas is presented at Sempra as NCI. Sempra records charges against income related to NCI for preferred dividends declared by SoCalGas. We provide additional information regarding SoCalGas’ preferred stock in Note 13.

Other Noncontrolling Interests

The following table provides information about NCI held by others in subsidiaries or entities consolidated by us and recorded in Other Noncontrolling Interests in Total Equity on Sempra’s Consolidated Balance Sheets.


OTHER NONCONTROLLING INTERESTS
(Dollars in millions)
	Percent ownership held by noncontrolling interests						Equity held by noncontrolling interests
	December 31,						December 31,
	2021		2020		2019		2021		2020		2019
Sempra Infrastructure:
SI Partners	20.0	%	—	%	—	%	$	1,384	$	—	$	—
SI Partners subsidiaries(1)	0.1 - 16.6		17.5 - 29.8		10.0 - 46.3		34		1,540		1,622
Parent and other:
PXiSE	—		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							$	1,418	$	1,541	$	1,856

(1) SI Partners and Chilquinta Energía have subsidiaries with NCI held by others. Percentage range reflects the highest and lowest ownership percentages among these subsidiaries.

Sempra Infrastructure

Sale of NCI in SI Partners to KKR. On October 1, 2021, Sempra, its wholly owned subsidiary, SI Partners (formerly Sempra Global), and KKR consummated the transactions contemplated under a purchase and contribution agreement dated April 4, 2021 (as amended prior to closing, the KKR Purchase Agreement). Pursuant to the KKR Purchase Agreement, KKR acquired newly designated Class A Units representing a 20% NCI in SI Partners for a purchase price of $3.4 billion, including post-closing adjustments. As a result of this sale, we recorded a $1.3 billion increase in equity held by NCI and an increase in Sempra’s shareholders’ equity of $1.4 billion, net of $173 million in transaction costs and $490 million in tax impacts, including the tax effect of the sale and changes to a deferred income tax liability related to outside basis differences in SI Partners. Transaction costs include $149 million paid to KKR for reimbursement of certain expenses that KKR incurred in connection with closing the transaction.

Prior to the closing of the transactions contemplated under the KKR Purchase Agreement on October 1, 2021, we completed an internal legal reorganization to consolidate the assets of Sempra LNG Holding, LP and our ownership of IEnova under Sempra Global, which was renamed SI Partners. At closing, we owned 99.9% of the outstanding shares of IEnova. To the extent we later acquire additional shares of IEnova after the closing, such additional shares will be acquired by SI Partners and KKR will provide 20% of the funding.

Pursuant to the KKR Purchase Agreement, we have agreed to indemnify SI Partners for, among other things, certain losses arising from liabilities of SI Partners and its subsidiaries to the extent not primarily relating to the undertaking of the business of SI Partners, and we have agreed to indemnify KKR for losses attributable to pre-closing taxes.

At the closing of the sale of NCI in SI Partners to KKR, Sempra and KKR entered into a limited partnership agreement (the LP Agreement), which governs our and their respective rights and obligations in respect of our ownership interests in SI Partners. We maintain control of SI Partners as the 80% owner with KKR having certain minority protections commensurate with the size of its investment.

SI Partners has two authorized classes of units, designated as “Class A Units” (which are common voting units) and “Sole Risk Interests.” If KKR approves our request that a project not be pursued jointly, or if KKR decides not to participate in any proposed

project for which we nevertheless desire to make a positive final investment decision, we may proceed with such project either independently through a different investment vehicle or as a “Sole Risk Project” within SI Partners and receive Sole Risk Interests in respect thereof. Sole Risk Projects are separated from other SI Partners projects and are conducted at our sole cost, expense and liability and we receive, through the acquisition of Sole Risk Interests, any economic and other benefits from such projects. KKR is not entitled to any benefits or rights in respect of any Sole Risk Project. The Guaymas-El Oro segment of the Sonora pipeline currently constitutes a Sole Risk Project. Until a specified date, KKR has certain discretionary rights to cause the Guaymas-El Oro segment of the Sonora pipeline to cease to be a Sole Risk Project and be pursued jointly within SI Partners.

Under the LP Agreement, SI Partners is managed by a board of managers comprised of members designated by us and by KKR. Matters are generally decided by majority vote. The managers designated by us and the managers designated by KKR each, as a group, have voting power equivalent to the ownership percentage of their respective designating member. However, SI Partners and its controlled subsidiaries are prohibited from taking certain actions without the prior written approval of KKR (subject to KKR maintaining certain ownership thresholds in SI Partners).

The LP Agreement contains certain default remedies if we or KKR fails to fund any amounts required to be funded under the LP Agreement. The LP Agreement also requires that SI Partners distribute to us and to KKR at least 85% of distributable cash of SI Partners and its subsidiaries on a quarterly basis, subject to certain exceptions and reserves. Generally, distributions from SI Partners are made to us and KKR on a pro rata basis in accordance with our and their respective ownership interests in SI Partners. However, KKR is entitled to certain priority distributions in the event of material deviations between certain specified projected cash flows and actual cash flows. Additionally, KKR is entitled to certain priority distributions in the event a specified project that reaches a positive final investment decision does not have projected internal rates of return over a specified threshold or in the event we have not made a positive final investment decision by a certain date on specified LNG projects that are currently in development.

In addition, under the LP Agreement, both parties are granted customary registration rights in the event of an initial public offering of SI Partners, which is subject to certain consent rights of KKR.

At the closing of the transactions contemplated under the KKR Purchase Agreement, SI Partners entered into a management agreement with Sempra to engage Sempra for certain staffing and general and administrative services. The management agreement governs the services that Sempra provides to SI Partners and the charges associated with those services.

Pending Sale of NCI in SI Partners to ADIA. On December 21, 2021, Sempra entered into a purchase and sale agreement (the ADIA Purchase Agreement) with ADIA, and, solely for purposes of guaranteeing the obligations of ADIA, Infinity Investments S.A. and Azure Vista C 2020 S.à.r.l., each a wholly owned affiliate of Abu Dhabi Investment Authority, pursuant to which ADIA will acquire from Sempra, for an aggregate purchase price of $1.8 billion, subject to certain adjustments described below, a 10% NCI in SI Partners. Following the closing of the transaction pursuant to the ADIA Purchase Agreement, Sempra, KKR and ADIA will directly or indirectly own 70%, 20%, and 10%, respectively, of the outstanding Class A Units of SI Partners, which excludes the non-voting Sole Risk Interests held only by Sempra. As further described below, after the closing of the transactions under the ADIA Purchase Agreement, ADIA will have certain rights similar to those of KKR but subject to additional limitations and adjustments to take into account ADIA’s relative ownership percentage.

At December 31, 2021, SI Partners indirectly owned 99.9% of the outstanding shares of IEnova. Under the terms of the ADIA Purchase Agreement, there will be a proportional purchase price adjustment at the closing (i) for any remaining shares of IEnova that are not owned by SI Partners at the closing and (ii) that generally takes into account cash distributions made to, or capital contributions made by, the partners of SI Partners, from and after the date of the ADIA Purchase Agreement to the closing.

The closing of the transactions pursuant to the ADIA Purchase Agreement is subject to receipt of certain regulatory approvals, including from the Comisión Federal de Competencia Económica, FERC and DOE; certain other third-party approvals; the absence of a material adverse effect on the assets, businesses, properties, liabilities, financial condition or results of operations of SI Partners taken as a whole, subject to certain exceptions; and other customary closing conditions. Any party may generally terminate the ADIA Purchase Agreement if the closing has not occurred on or before September 30, 2022, subject to an automatic extension through December 21, 2022 if necessary to receive required regulatory approvals. We expect the transaction will close in the summer of 2022.

At the closing, Sempra and KKR and ADIA (the Minority Partners) will enter into a second amended and restated agreement of limited partnership of SI Partners (the Amended LP Agreement), which will govern their respective rights and obligations in respect of their ownership of SI Partners. Under the Amended LP Agreement, ADIA will have the right at the closing to designate one manager to the SI Partners board of managers. Matters are decided generally by majority vote and the managers designated by Sempra and the managers designated by each Minority Partner will each, as a group, have voting power equivalent to the ownership percentage of their respective designating limited partner. Sempra expects to maintain control of SI Partners as its 70%

owner on terms similar to those currently applicable at SI Partners. However, SI Partners and its controlled subsidiaries will be prohibited from taking certain limited actions without the prior written approval of the Minority Partners (subject to each Minority Partner maintaining certain ownership thresholds in SI Partners). The minority protections held by ADIA constitute a sub-set of the minority protections granted to KKR.

The terms of the Amended LP Agreement applicable to ADIA in relation to capital contributions and distributions are generally consistent with those granted to KKR, with adjustments and limitations to take into account ADIA’s relative ownership percentage, including limiting ADIA’s priority distribution rights to the failure of certain proposed projects to receive a positive final investment decision by a certain date or to achieve specified thresholds of projected internal rates of return or leverage. The transfer rights and restrictions and registration rights in the Amended LP Agreement applicable to ADIA are also generally consistent with those granted to KKR, with adjustments and limitations to take into account ADIA’s relative ownership percentage, including a general restriction on ADIA transferring its interests in SI Partners to third parties (other than pursuant to certain specified permitted transfers) for a specified period following its entry into the Amended LP Agreement.

SI Partners Subsidiaries. In May 2021, we acquired 381,015,194 publicly owned shares of IEnova in exchange for 12,306,777 newly issued shares of our common stock upon completion of our exchange offer launched in the U.S. and Mexico, which increased our ownership interest in IEnova from 70.2% to 96.4%. In addition to being traded on the NYSE, Sempra’s common stock is now also listed on the Mexican Stock Exchange under the trading symbol SRE.MX. We acquired the IEnova shares at an exchange ratio of 0.0323 shares of our common stock for each one IEnova share. In connection with the exchange offer, we recorded a $1.4 billion decrease in equity held by NCI and an increase in Sempra’s shareholders’ equity of $1.4 billion, net of $12 million in transactions costs.

In September 2021, we acquired 51,014,545 publicly owned shares of IEnova for 4.0 billion Mexican pesos (approximately $202 million in U.S. dollars) in cash upon completion of our tender offer launched in the U.S. and Mexico in August 2021, which increased our ownership interest in IEnova from 96.4% to 99.9%. We acquired these IEnova shares at a price of 78.97 Mexican pesos per share (approximately $3.95 per share in U.S. dollars). In connection with the cash tender offer, we recorded a $188 million decrease in equity held by NCI and a decrease in Sempra’s shareholders’ equity of $17 million, including $4 million in transaction costs.

As a result of the increase in our ownership interest in IEnova, we recorded an increase in Sempra’s shareholders’ equity of $72 million offset by a deferred income tax asset related to the outside basis difference in IEnova’s shares. Upon completing the sale of a 20% NCI in SI Partners to KKR in October 2021, which we discuss above, we recorded $72 million in net income tax expense related to the utilization of this deferred income tax asset.

Following the cash tender offer, IEnova’s shares were delisted from the Mexican Stock Exchange effective October 15, 2021. In connection with the delisting, we are maintaining a trust for the purpose of purchasing the 1,212,981 IEnova shares that remained publicly owned as of the completion of the cash tender offer for 78.97 Mexican pesos per share, the same price per share that was offered in our cash tender offer. The trust will be in place through the earlier of April 14, 2022 or the date on which we acquire all the remaining publicly owned IEnova shares. As of February 16, 2022, an aggregate of 629,784 of the remaining publicly owned IEnova shares had been acquired by such trust.

In 2020, IEnova repurchased 77,122,780 shares of its outstanding common stock held by NCI for approximately $231 million, resulting in an increase in Sempra’s ownership interest in IEnova from 66.6% to 70.2%.

In 2019, IEnova repurchased 2,620,000 shares of its outstanding common stock held by NCI for approximately $10 million, resulting in an increase in Sempra’s ownership interest in IEnova from 66.5% to 66.6%.

In 2020, Sempra Infrastructure purchased additional shares in ICM Ventures Holdings B.V. for $9 million, increasing its ownership interest from 53.7% to 82.5%. ICM Ventures Holdings B.V. owns certain permits and land where Sempra Infrastructure is building a terminal for the receipt, storage and delivery of liquid fuels. In July 2021, Sempra Infrastructure acquired the remaining 17.5% interest held by NCI in ICM Ventures Holdings B.V. for $7 million.

In 2020, an affiliate of TotalEnergies SE acquired a 16.6% ownership interest in ECA LNG Phase 1.

In 2020, Sempra Infrastructure purchased for $7 million the 24.6% minority interest in Liberty Gas Storage LLC, increasing Sempra Infrastructure’s ownership in Liberty Gas Storage LLC to 100%. Prior to the purchase, the minority partner converted $22 million in notes payable due from Sempra Infrastructure to equity. As a result of the purchase, we recorded an increase in Sempra’s shareholders’ equity of $2 million for the difference between the carrying value and fair value related to the change in ownership.

In 2019, Sempra Infrastructure purchased for $20 million the 9.1% minority interest in Bay Gas immediately prior to the sale of 100% of Bay Gas.

Parent and Other

As we discuss in Note 5, in December 2021, Parent and other sold its equity interest in PXiSE.

Discontinued Operations

As we discuss in Note 5, we completed the sales of our equity interests in our Peruvian and Chilean businesses in 2020. The minority interests in Luz del Sur and Tecsur were deconsolidated upon the sale of our Peruvian businesses in April 2020, and the minority interests in Chilquinta Energía and its subsidiaries were deconsolidated upon the sale of our Chilean businesses in June 2020.

REVENUES

See Note 3 for a description of significant accounting policies for revenues.

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 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 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 Sempra’s Consolidated Statements of Cash Flows.

Foreign currency transaction (losses) gains in a currency other than Sempra Infrastructure’s functional currency were $(18) million, $(25) million and $21 million for the years ended December 31, 2021, 2020 and 2019, respectively, and are included in Other Income (Expense) , Net, on Sempra’s Consolidated Statements of Operations. Foreign currency transaction gains (losses) in a currency other than the functional currencies of our operations in South America are included in discontinued operations.

TRANSACTIONS WITH AFFILIATES

We summarize amounts due from and to unconsolidated affiliates at Sempra, SDG&E and SoCalGas in the following table.


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
Total due from various unconsolidated affiliates – current	$	23	$	20	$	32

Sempra Infrastructure:
ESJ JV – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020(1)	$	—	$	85	$	—
IMG JV – Note due March 15, 2022, net of allowance for credit losses of $1 and $3 at December 31, 2021 and 2020, respectively(2)	637		695		742
Total due from unconsolidated affiliates – noncurrent	$	637	$	780	$	742
Sempra Infrastructure – TAG Pipelines Norte, S. de R.L. de C.V. – Note due December 20, 2021(3)(4)	$	—	$	(41)	$	—
Various affiliates	—		(4)		(5)
Total due to unconsolidated affiliates – current	$	—	$	(45)	$	(5)

Sempra Infrastructure(4):
TAG Pipelines Norte, S. de R.L. de C.V.:
Note due December 20, 2021(3)	$	—	$	—	$	(39)
5.5% Note due January 9, 2024(5)	(69)		(68)		—
5.5% Note due January 14, 2025(5)	(21)		—		—
5.5% Note due July 16, 2025(5)	(20)		—		—
TAG JV – 5.74% Note due December 17, 2029(5)	(177)		(166)		(156)
Total due to unconsolidated affiliates – noncurrent	$	(287)	$	(234)	$	(195)
SDG&E:


Sempra	$	(40)	$	(38)	$	(37)
SoCalGas	(48)		(21)		(10)

Various affiliates	(9)		(5)		(6)
Total due to unconsolidated affiliates – current	$	(97)	$	(64)	$	(53)

Income taxes due from Sempra(6)	$	19	$	—	$	130
SoCalGas:
SDG&E	$	48	$	21	$	10
Various affiliates	1		1		1
Total due from unconsolidated affiliates – current	$	49	$	22	$	11

Sempra	$	(36)	$	(31)	$	(45)

Various affiliates	—		—		(2)
Total due to unconsolidated affiliates – current	$	(36)	$	(31)	$	(47)

Income taxes due from (to) Sempra(6)	$	6	$	(37)	$	152

(1) 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 of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. In March 2021, Sempra Infrastructure acquired the remaining 50% equity interest in ESJ that it did not already own, and ESJ became a wholly owned, consolidated subsidiary, resulting in the elimination of this note receivable.

(2) Mexican peso-denominated revolving line of credit for up to 14.2 billion Mexican pesos or approximately $691 U.S. dollar-equivalent at December 31, 2021, at a variable interest rate based on the 91-day Interbank Equilibrium Interest Rate plus 220 bps (8.06% at December 31, 2021), to finance construction of a natural gas marine pipeline. At both December 31, 2021 and 2020, $2 of accrued interest receivable is included in Due from Unconsolidated Affiliates – Current. At December 31, 2021, we classified this revolving line of credit as noncurrent because we expect to extend the maturity date on a long-term basis prior to its stated maturity date.

(3) U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.16% at December 31, 2020).

(4) Amounts include principal balances plus accumulated interest outstanding.

(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, 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,
	2021		2020		2019
Sempra:
Revenues	$	31	$	37	$	52
Cost of sales	11		45		50
Interest income	50		56		74
Interest expense	15		14		2
SDG&E:
Revenues	$	11	$	6	$	6
Cost of sales	103		79		74
SoCalGas:
Revenues	$	98	$	88	$	69
Cost of sales(1)	1		—		8

(1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates.

Sempra California

Sempra, SDG&E and SoCalGas provide certain services to each other and are charged an allocable share of the cost of such services. Also, from time-to-time, SDG&E and SoCalGas may make short-term advances of surplus cash to Sempra at interest rates based on the federal funds effective rate plus a margin of 13 to 20 bps, depending on the loan balance.

SoCalGas provides natural gas transportation and storage services for SDG&E and charges SDG&E for such services monthly. SoCalGas records revenues and SDG&E records a corresponding amount to cost of sales.

SDG&E and SoCalGas charge one another, as well as other Sempra affiliates, for shared asset depreciation. SoCalGas and SDG&E record revenues and the affiliates record corresponding amounts to O&M.

The natural gas supply for SDG&E’s and SoCalGas’ core natural gas customers is purchased by SoCalGas as a combined procurement portfolio managed by SoCalGas. Core customers are primarily residential and small commercial and industrial customers. This core gas procurement function is considered a shared service; therefore, revenues and costs related to SDG&E are presented net in SoCalGas’ Statements of Operations.

SDG&E has a 20-year contract for up to 155 MW of renewable power supplied from the ESJ wind power generation facility. Prior to March 2021, ESJ was a 50% owned and unconsolidated JV of Sempra Infrastructure. In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% interest in ESJ and ESJ became a wholly owned, consolidated subsidiary of Sempra. A second 20-year contract between SDG&E and ESJ for up to 108 MW of renewable power supplied from the same facility commenced in January 2022.

Sempra Infrastructure

Sempra Infrastructure, through its indirect wholly owned subsidiaries, DEN and IEnova Pipelines, provides operating and maintenance services to TAG Pipelines Norte, S. de. R.L. de C.V., and also provides personnel under an administrative services arrangement to TAG Pipelines Norte, S. de. R.L. de C.V. and TAG JV.

Sempra Infrastructure provides certain business services to Cameron LNG JV. Sempra Infrastructure had an agreement to provide transportation services to Cameron LNG JV for capacity on the Cameron Interstate Pipeline through August 2020, when Cameron LNG JV achieved commercial operations of Train 3 of its Phase 1 project.

Sempra provided guarantees related to Cameron LNG JV’s construction-period debt, which were terminated in March 2021, as well as guarantees related to Cameron LNG JV’s SDSRA and CFIN’s Support Agreement, which remain outstanding. We discuss these guarantees in Note 6.

RESTRICTED NET ASSETS

Sempra

As we discuss below, SDG&E, SoCalGas and certain other Sempra subsidiaries have restrictions on the amount of funds that can be transferred to Sempra by dividend, advance or loan as a result of conditions imposed by various regulators. Additionally,

certain other Sempra subsidiaries are subject to various financial and other covenants and other restrictions contained in debt and credit agreements (described in Note 7) and in other agreements that limit the amount of funds that can be transferred to Sempra. At December 31, 2021, Sempra was in compliance with all covenants related to its debt agreements.

At December 31, 2021, the amount of restricted net assets of consolidated entities of Sempra, including SDG&E and SoCalGas discussed below, that may not be distributed to Sempra in the form of a loan or dividend is $19.3 billion. Additionally, the amount of restricted net assets of our unconsolidated entities is $13.2 billion. Although the restrictions cap the amount of funding that the various operating subsidiaries can provide to Sempra, we do not believe these restrictions will have a significant impact on our ability to access cash to pay dividends and fund operating needs.

As we discuss in Note 6, $1.5 billion of Sempra’s retained earnings represents undistributed earnings of equity method investments at December 31, 2021.

Sempra California

The CPUC’s regulation of SDG&E’s and SoCalGas’ capital structures limits the amounts available for dividends and loans to Sempra. At December 31, 2021, Sempra could have received combined loans and dividends of approximately $798 million from SDG&E and approximately $445 million from SoCalGas.

The payment and amount of future dividends by SDG&E and SoCalGas are at the discretion of their respective boards of directors. The following restrictions limit the amount of retained earnings that may be paid as common stock dividends or loaned to Sempra from either utility:

▪The CPUC requires that SDG&E’s and SoCalGas’ common equity ratios be no lower than one percentage point below the CPUC-authorized percentage of each entity’s authorized capital structure. The authorized percentage at December 31, 2021 is 52% at both SDG&E and SoCalGas.

▪SDG&E and SoCalGas each have a revolving credit line that requires it to maintain a ratio of consolidated indebtedness to consolidated capitalization (as defined in the agreements) of no more than 65%, as we discuss in Note 7.

Based on these restrictions, at December 31, 2021, SDG&E’s restricted net assets were $7.5 billion and SoCalGas’ restricted net assets were $5.0 billion, which could not be transferred to Sempra.

Sempra Texas Utilities

Sempra owns an indirect, 100% interest in Oncor Holdings, which owns an 80.25% interest in Oncor. As we discuss in Note 6, we account for our investment in Oncor Holdings under the equity method. Significant restrictions at Oncor that limit the amount that may be paid as dividends to Sempra include:

▪In connection with ring-fencing measures, governance mechanisms and commitments, Oncor may not pay any dividends or make any other distributions (except for contractual tax payments) if a majority of its independent directors or a minority member director determines that it is in the best interests of Oncor to retain such amounts to meet expected future requirements.

▪Oncor must remain in compliance with its debt-to-equity ratio established by the PUCT for ratemaking purposes and may not pay dividends or other distributions (except for contractual tax payments) if that payment would cause it to exceed its PUCT authorized debt-to-equity ratio. Oncor’s authorized regulatory capital structure is 57.5% debt to 42.5% equity at December 31, 2021.

▪If the credit rating on Oncor’s senior secured debt by any of the three major credit rating agencies falls below BBB (or the equivalent), Oncor will suspend dividends and other distributions (except for contractual tax payments), unless otherwise allowed by the PUCT. At December 31, 2021, all of Oncor’s senior secured ratings were above BBB.

▪Oncor’s revolving credit line and certain of its other debt agreements require it to maintain a consolidated senior debt-to-capitalization ratio of no more than 65% and observe certain affirmative covenants. At December 31, 2021, Oncor was in compliance with these covenants.

Based on these restrictions, at December 31, 2021, Oncor’s restricted net assets were $12.6 billion, which could not be transferred to Sempra.

Sempra owns an indirect, 50% interest in Sharyland Holdings, which owns a 100% interest in Sharyland Utilities. Significant restrictions related to this equity method investment include:

▪Sharyland Utilities may not pay dividends or make other distributions (except for contractual payments) without the consent of the JV partner.

▪Sharyland Utilities must remain in compliance with the capital structure established by the PUCT for ratemaking purposes and may not pay dividends or other distributions (except for contractual tax payments) if that payment would cause its debt to exceed 60% of its capital structure.

▪Sharyland Utilities has a revolving credit line and a term loan credit agreement that require it to maintain a consolidated debt-to-capitalization ratio of no more than 70% and observe certain customary reporting requirements and other affirmative covenants. At December 31, 2021, Sharyland Utilities was in compliance with these and all other covenants.

Based on these restrictions, at December 31, 2021, Sharyland Utilities’ restricted net assets were $103 million, which could not be transferred to its owners.

Sempra Infrastructure

Significant restrictions at Sempra Infrastructure include:

▪Partnerships and JVs at Sempra Infrastructure may not pay dividends or make other distributions (except for contractual payments) without the consent of the partners.

▪The ADIA Purchase Agreement has certain covenants that require SI Partners to operate its business in ordinary course, including limitations on the ability to liquidate all or substantially all of the company’s assets or to sell or dispose of certain assets, from December 21, 2021 through closing or termination of the ADIA Purchase Agreement. Under these restrictions, net assets of SI Partners totaling $6.8 billion, including the $193 million minimum legal reserves and $20 million restricted cash that we describe below, are restricted at December 31, 2021.

▪Sempra Infrastructure has an equity method investment in Cameron LNG JV, which has debt agreements that require the establishment and funding of project accounts to which the proceeds of loans, project revenues and other amounts are deposited and applied in accordance with the debt agreements. The debt agreements require the JV to maintain reserve accounts in order to pay the project debt service, and also contain restrictions related to the payment of dividends and other distributions to the members of the JV. We discuss Cameron LNG JV’s debt agreements and the associated Sempra guarantees in Note 6. Under these restrictions, net assets of Cameron LNG JV of approximately $395 million are restricted at December 31, 2021.

▪Mexico requires domestic corporations to maintain minimum legal reserves as a percentage of capital stock, resulting in restricted net assets of $193 million at Sempra Infrastructure’s consolidated Mexican subsidiaries at December 31, 2021

▪IEnova has restrictions under trust and debt agreements related to pipeline projects to pay for rights-of-way, license fees, permits, topographic surveys and other costs. Under these restrictions, net assets totaling $20 million are restricted at December 31, 2021.

▪TAG JV, a 50% owned and unconsolidated JV of Sempra Infrastructure, has a long-term debt agreement that requires it to maintain a reserve account to pay the projects’ debt. Under these restrictions, net assets totaling $66 million are restricted at December 31, 2021.

OTHER INCOME (EXPENSE), NET

Other Income (Expense), Net on the Consolidated Statements of Operations consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Allowance for equity funds used during construction	$	133	$	128	$	94
Investment gains, net(1)	50		41		61
(Losses) gains on interest rate and foreign exchange instruments, net	(28)		(67)		34
Foreign currency transaction (losses) gains, net(2)	(18)		(25)		21
Non-service component of net periodic benefit cost	(67)		(102)		(132)


Interest on regulatory balancing accounts, net	6		14		14

Sundry, net	(18)		(37)		(15)
Total	$	58	$	(48)	$	77
SDG&E:
Allowance for equity funds used during construction	$	81	$	79	$	56
Non-service component of net periodic benefit cost	(13)		(20)		(20)

Interest on regulatory balancing accounts, net	6		9		13

Sundry, net	(10)		(16)		(10)
Total	$	64	$	52	$	39
SoCalGas:
Allowance for equity funds used during construction	$	48	$	41	$	34
Non-service component of net periodic benefit cost	(40)		(54)		(72)

Interest on regulatory balancing accounts, net	—		5		1

Sundry, net	(22)		(20)		(18)
Total	$	(14)	$	(28)	$	(55)

(1) Represents net investment gains 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 $23 in 2021, losses of $42 in 2020 and gains of $30 in 2019 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.

REVENUES - RECEIVABLES FROM REVENUES FROM CONTRACTS WITH CUSTOMERS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 1,139	$ 790	$ 721
Customers Under California Arrearage Payment Program
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	79
Accounts receivable – trade, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	1,084	786	710
Accounts receivable – other, net
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	10	4	11
Due from unconsolidated affiliates – current
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	2	2	2
Other long-term assets
Contract with Customer, Asset [Line Items]
Receivables from revenues from contracts with customers	$ 45	$ 0	$ 0

REGULATORY MATTERS (Tables)

12 Months Ended

Dec. 31, 2021

Schedule of Regulatory Assets


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	December 31,
	2021		2020		2019
SDG&E:
Fixed-price contracts and other derivatives	$	(50)	$	(53)	$	8
Deferred income taxes recoverable (refundable) in rates	125		22		(108)
Pension and other postretirement benefit plan obligations	(7)		50		103
Removal obligations	(2,251)		(2,121)		(2,056)
Environmental costs	62		56		45
Sunrise Powerlink fire mitigation	122		121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	77		72		102
Gas transportation	49		35		22
Safety and reliability	67		67		77
Public purpose programs	(107)		(158)		(124)
2019 GRC retroactive impacts	—		56		111
Wildfire mitigation plan	178		93		12
Liability insurance premium	110		79		24
Other balancing accounts	207		61		70
Other regulatory assets (liabilities), net(2)	119		72		(153)
Total SDG&E	(1,299)		(1,548)		(1,746)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	44		(82)		(203)
Pension and other postretirement benefit plan obligations	51		417		400
Employee benefit costs	31		37		44
Removal obligations	(627)		(685)		(728)
Environmental costs	34		36		40
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(146)		(56)		(118)
Safety and reliability	339		335		295
Public purpose programs	(183)		(253)		(273)
2019 GRC retroactive impacts	—		202		400
Liability insurance premium	16		7		4
Other balancing accounts	42		(65)		(11)
Other regulatory assets (liabilities), net(2)	142		75		(101)
Total SoCalGas	(257)		(32)		(251)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		80		83
Other regulatory assets	—		—		6
Total Sempra	$	(1,479)	$	(1,500)	$	(1,908)

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

Schedule of Regulatory Liabilities


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	December 31,
	2021		2020		2019
SDG&E:
Fixed-price contracts and other derivatives	$	(50)	$	(53)	$	8
Deferred income taxes recoverable (refundable) in rates	125		22		(108)
Pension and other postretirement benefit plan obligations	(7)		50		103
Removal obligations	(2,251)		(2,121)		(2,056)
Environmental costs	62		56		45
Sunrise Powerlink fire mitigation	122		121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	77		72		102
Gas transportation	49		35		22
Safety and reliability	67		67		77
Public purpose programs	(107)		(158)		(124)
2019 GRC retroactive impacts	—		56		111
Wildfire mitigation plan	178		93		12
Liability insurance premium	110		79		24
Other balancing accounts	207		61		70
Other regulatory assets (liabilities), net(2)	119		72		(153)
Total SDG&E	(1,299)		(1,548)		(1,746)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	44		(82)		(203)
Pension and other postretirement benefit plan obligations	51		417		400
Employee benefit costs	31		37		44
Removal obligations	(627)		(685)		(728)
Environmental costs	34		36		40
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(146)		(56)		(118)
Safety and reliability	339		335		295
Public purpose programs	(183)		(253)		(273)
2019 GRC retroactive impacts	—		202		400
Liability insurance premium	16		7		4
Other balancing accounts	42		(65)		(11)
Other regulatory assets (liabilities), net(2)	142		75		(101)
Total SoCalGas	(257)		(32)		(251)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		80		83
Other regulatory assets	—		—		6
Total Sempra	$	(1,479)	$	(1,500)	$	(1,908)

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

Proposed Revenue Requirement

The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations.


WILDFIRE FUND
(Dollars in millions)
		December 31,
	Location	2021		2020		2019
Wildfire Fund asset:
Current	Prepaid Expenses	$	29	$	29	$	29
Noncurrent	Wildfire Fund	331		363		392
Wildfire Fund obligation:
Current	Other Current Liabilities	$	13	$	13	$	13
Noncurrent	Deferred Credits and Other	64		75		86
		Years ended December 31,
		2021		2020		2019
Amortization of Wildfire Fund asset	Operation and Maintenance	$	29	$	29	$	12
Impairment of Wildfire Fund asset	Impairment Losses(1)	3		—		—
Accretion of Wildfire Fund obligation	Operation and Maintenance	2		2		1

(1) Included in O&M 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

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, subject to the CCM.


CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
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	%

SAN ONOFRE NUCLEAR GENERATING STATION

12 Months Ended

Dec. 31, 2021

SAN ONOFRE NUCLEAR GENERATING STATION

REGULATORY MATTERS

REGULATORY ASSETS AND LIABILITIES


REGULATORY ASSETS (LIABILITIES)
(Dollars in millions)
	December 31,
	2021		2020		2019
SDG&E:
Fixed-price contracts and other derivatives	$	(50)	$	(53)	$	8
Deferred income taxes recoverable (refundable) in rates	125		22		(108)
Pension and other postretirement benefit plan obligations	(7)		50		103
Removal obligations	(2,251)		(2,121)		(2,056)
Environmental costs	62		56		45
Sunrise Powerlink fire mitigation	122		121		121
Regulatory balancing accounts(1)(2)
Commodity – electric	77		72		102
Gas transportation	49		35		22
Safety and reliability	67		67		77
Public purpose programs	(107)		(158)		(124)
2019 GRC retroactive impacts	—		56		111
Wildfire mitigation plan	178		93		12
Liability insurance premium	110		79		24
Other balancing accounts	207		61		70
Other regulatory assets (liabilities), net(2)	119		72		(153)
Total SDG&E	(1,299)		(1,548)		(1,746)
SoCalGas:
Deferred income taxes recoverable (refundable) in rates	44		(82)		(203)
Pension and other postretirement benefit plan obligations	51		417		400
Employee benefit costs	31		37		44
Removal obligations	(627)		(685)		(728)
Environmental costs	34		36		40
Regulatory balancing accounts(1)(2)
Commodity – gas, including transportation	(146)		(56)		(118)
Safety and reliability	339		335		295
Public purpose programs	(183)		(253)		(273)
2019 GRC retroactive impacts	—		202		400
Liability insurance premium	16		7		4
Other balancing accounts	42		(65)		(11)
Other regulatory assets (liabilities), net(2)	142		75		(101)
Total SoCalGas	(257)		(32)		(251)
Sempra Infrastructure:
Deferred income taxes recoverable in rates	77		80		83
Other regulatory assets	—		—		6
Total Sempra	$	(1,479)	$	(1,500)	$	(1,908)

(2) Includes regulatory assets earning a return authorized by applicable regulators, which generally approximates the three-month commercial paper rate.

Regulatory Assets Not Earning a Return

▪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 Earning a Return

SEMPRA CALIFORNIA

COVID-19 Pandemic Protections

Disconnection OIR

CPUC GRC

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 Cost of Capital


CPUC AUTHORIZED COST OF CAPITAL AND RATE STRUCTURE, SUBJECT TO THE CCM

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
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	%

SDG&E

FERC Rate Matters

SDG&E files separately with the FERC for its authorized ROE on FERC-regulated electric transmission operations and assets.

Energy Efficiency Program Inquiry

SOCALGAS

OSCs – Energy Efficiency and Advocacy

SAN ONOFRE NUCLEAR GENERATING STATION

NUCLEAR DECOMMISSIONING AND FUNDING

Nuclear Decommissioning Trusts


NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Cost		Gross unrealized gains		Gross unrealized losses		Estimated fair value
At December 31, 2021:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies(1)	$	56	$	—	$	—	$	56
Municipal bonds(2)	309		13		(1)		321
Other securities(3)	255		7		(2)		260
Total debt securities	620		20		(3)		637
Equity securities	104		262		(2)		364
Short-term investments, primarily cash equivalents	3		—		—		3
Receivables (payables), net	8		—		—		8
Total	$	735	$	282	$	(5)	$	1,012
At December 31, 2020:
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	$	64	$	1	$	—	$	65
Municipal bonds	308		18		—		326
Other securities	253		17		—		270
Total debt securities	625		36		—		661
Equity securities	112		254		(2)		364
Short-term investments, primarily 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
Short-term investments, primarily cash equivalents	16		—		—		16
Receivables (payables), net	(8)		—		—		(8)
Total	$	729	$	360	$	(7)	$	1,082

(1) Maturity dates are 2022-2052.

(2) Maturity dates are 2022-2056.

(3) Maturity dates are 2022-2072.

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 NUCLEAR DECOMMISSIONING TRUSTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Proceeds from sales	$	961	$	1,439	$	914
Gross realized gains	67		156		24
Gross realized losses	(5)		(17)		(5)

ASSET RETIREMENT OBLIGATION

U.S. DEPARTMENT OF ENERGY NUCLEAR FUEL DISPOSAL

NUCLEAR INSURANCE

FAIR VALUE MEASUREMENTS - RECURRING FAIR VALUE MEASURES (Details) - USD ($) $ in Millions	Dec. 31, 2021	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
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	$ 1,004	$ 1,028	1,090
Short-term investments held in Rabbi Trust	81	61	66
Support Agreement, net of related guarantee fees	7	7
Assets fair value disclosure, total	19	8	18
Effect of netting and allocation of collateral			(14)
Support Agreement, net of related guarantee fees		4
Liabilities fair value disclosure, total	35	6	4
Fair Value, Recurring \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	3	3	16
Fair Value, Recurring \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	364	364	509
Fair Value, Recurring \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	56	65	57
Fair Value, Recurring \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	321	326	282
Fair Value, Recurring \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270	226
Fair Value, Recurring \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	637	661	565
Fair Value, Recurring \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	6	1	3
Derivative liability	8	47	28
Fair Value, Recurring \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	2	24	21
Derivative liability	1	11	7
Fair Value, Recurring \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	46	4	11
Effect of netting and allocation of collateral	58	21	43
Derivative liability	31	16	17
Fair Value, Recurring \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	131	128	122
Fair Value, Recurring \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	81	126	99
Effect of netting and allocation of collateral	18	6	9
Derivative liability	35	6	4
Effect of netting and allocation of collateral			(14)
Derivative Asset, Fair Value, Gross Asset	1	2	9
Fair Value, Recurring \| Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	419	408	563
Short-term investments held in Rabbi Trust	81	61	66
Support Agreement, net of related guarantee fees	0	0
Assets fair value disclosure, total	9	2	5
Effect of netting and allocation of collateral			(14)
Support Agreement, net of related guarantee fees		0
Liabilities fair value disclosure, total	0	0	0
Fair Value, Recurring \| Level 1 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	13	9	14
Fair Value, Recurring \| Level 1 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	358	358	503
Fair Value, Recurring \| Level 1 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	48	41	46
Fair Value, Recurring \| Level 1 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 1 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 1 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	48	41	46
Fair Value, Recurring \| Level 1 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring \| Level 1 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring \| Level 1 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Effect of netting and allocation of collateral	58	21	43
Derivative liability	0	0	0
Fair Value, Recurring \| Level 1 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	0	0	0
Fair Value, Recurring \| Level 1 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	12	5	1
Effect of netting and allocation of collateral	9	1	1
Derivative liability	0	0	0
Effect of netting and allocation of collateral			(14)
Derivative Asset, Fair Value, Gross Asset	0	1	4
Fair Value, Recurring \| Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	585	620	527
Short-term investments held in Rabbi Trust	0	0	0
Support Agreement, net of related guarantee fees	0	0
Assets fair value disclosure, total	10	6	13
Effect of netting and allocation of collateral			0
Support Agreement, net of related guarantee fees		0
Liabilities fair value disclosure, total	35	6	4
Fair Value, Recurring \| Level 2 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	(10)	(6)	2
Fair Value, Recurring \| Level 2 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	6	6	6
Fair Value, Recurring \| Level 2 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	8	24	11
Fair Value, Recurring \| Level 2 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	321	326	282
Fair Value, Recurring \| Level 2 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	260	270	226
Fair Value, Recurring \| Level 2 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	589	620	519
Fair Value, Recurring \| Level 2 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	6	1	3
Derivative liability	8	47	28
Fair Value, Recurring \| Level 2 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	2	24	21
Derivative liability	1	11	7
Fair Value, Recurring \| Level 2 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	46	4	11
Effect of netting and allocation of collateral	0	0	0
Derivative liability	31	16	17
Fair Value, Recurring \| Level 2 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	131	128	122
Fair Value, Recurring \| Level 2 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	3
Effect of netting and allocation of collateral	9	5	8
Derivative liability	35	6	4
Effect of netting and allocation of collateral			0
Derivative Asset, Fair Value, Gross Asset	1	1	5
Fair Value, Recurring \| Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Short-term investments held in Rabbi Trust	0	0	0
Support Agreement, net of related guarantee fees	7	7
Assets fair value disclosure, total	0	0	0
Effect of netting and allocation of collateral			0
Support Agreement, net of related guarantee fees		4
Liabilities fair value disclosure, total	0	0	0
Fair Value, Recurring \| Level 3 \| Short-term investments, primarily cash equivalents
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 3 \| Equity securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 3 \| Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 3 \| Municipal bonds
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 3 \| Other securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 3 \| Total debt securities
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total nuclear decommissioning trusts	0	0	0
Fair Value, Recurring \| Level 3 \| Interest rate instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring \| Level 3 \| Foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring \| Level 3 \| Commodity contracts not subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	0	0	0
Effect of netting and allocation of collateral	0	0	0
Derivative liability	0	0	0
Fair Value, Recurring \| Level 3 \| Interest rate and foreign exchange instruments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative liability	0	0	0
Fair Value, Recurring \| Level 3 \| Commodity contracts subject to rate recovery
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative asset	69	121	95
Effect of netting and allocation of collateral	0	0	0
Derivative liability	0	0	0
Effect of netting and allocation of collateral			0
Derivative Asset, Fair Value, Gross Asset	$ 0	$ 0	$ 0

REGULATORY MATTERS - COST OF CAPITAL & FERC RATES (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended				36 Months Ended
	Oct. 31, 2019	Dec. 31, 2021	Sep. 30, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2022	Jan. 01, 2022	Aug. 31, 2021
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
California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
CCM benchmark rate, variable rate (as a percent)					1.00%
CCM benchmark rate (as a percent)		4.029%
Common equity ratio (as a percent)					52.00%			54.00%
Authorized ROE (as a percent)					10.20%			10.55%
Cost of debt (as a percent)					4.59%			3.84%
Proposed return on base rate (as a percent)					7.55%			7.46%
CCM benchmark rate, percentage below (as a percent)			1.17%
Federal Energy Regulatory Commission
Public Utilities, General Disclosures [Line Items]
FERC, revenue requirement				$ 17
Common Equity \| Federal Energy Regulatory Commission
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)				10.05%
Forecast \| California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Authorized weighting, total (as a percent)						100.00%
Weighted return on rate base, total (as a percent)						7.30%
Authorized ROE (as a percent)							9.62%
Forecast \| Authorized weighting \| California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						45.60%
Forecast \| Authorized weighting \| California Public Utilities Commission \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						2.40%
Forecast \| Authorized weighting \| California Public Utilities Commission \| Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						52.00%
Forecast \| Return on Rate Base \| California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						4.23%
Forecast \| Return on Rate Base \| California Public Utilities Commission \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						6.00%
Forecast \| Return on Rate Base \| California Public Utilities Commission \| Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						10.05%
Forecast \| Weighted Return on Rate Base \| California Public Utilities Commission
Public Utilities, General Disclosures [Line Items]
Plan percentage of capital structure allocated to debt						1.93%
Forecast \| Weighted Return on Rate Base \| California Public Utilities Commission \| Preferred Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						0.14%
Forecast \| Weighted Return on Rate Base \| California Public Utilities Commission \| Common Equity
Public Utilities, General Disclosures [Line Items]
Return on rate base (as a percent)						5.23%

SEGMENT INFORMATION (Details) $ in Millions	12 Months Ended			21 Months Ended
SEGMENT INFORMATION (Details) $ in Millions	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2020 USD ($) segment	Oct. 01, 2021	Sep. 30, 2021	May 31, 2021	Apr. 30, 2021	May 31, 2019	May 16, 2019
Segment Reporting Information [Line Items]
Number of reportable segments \| segment				4
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	$ 12,857	$ 11,370	$ 10,829
DEPRECIATION AND AMORTIZATION	1,855	1,666	1,569
INTEREST INCOME	1	2	2
INTEREST EXPENSE	157	158	141
Income tax expense (benefit)	(310)	96	120
Earnings (losses) attributable to common shares	(427)	504	641
Earnings from discontinued operations attributable to common shares	0	1,840	328
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	5,015	4,676	3,708
ASSETS	20,324	18,460	17,077	$ 18,460
Long-lived assets	58,366	53,831	50,074	53,831
United States
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	11,154	10,205	9,574
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets	50,657	46,902	43,719	46,902
Mexico
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,703	1,165	1,255
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets	7,708	6,929	6,355	6,929
Asia
Segment Reporting Information, Additional Information [Abstract]
Long-lived assets	1	0	0	0
Operating Segments \| SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	5,504	5,313	4,925
DEPRECIATION AND AMORTIZATION	889	801	760
INTEREST INCOME	1	2	4
INTEREST EXPENSE	412	413	411
Income tax expense (benefit)	201	190	171
Earnings (losses) attributable to common shares	819	824	767
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	2,220	1,942	1,522
ASSETS	24,058	22,311	20,560	22,311
Operating Segments \| SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	5,515	4,748	4,525
DEPRECIATION AND AMORTIZATION	716	654	602
INTEREST INCOME	1	2	2
INTEREST EXPENSE	157	158	141
Income tax expense (benefit)	(310)	96	120
Earnings (losses) attributable to common shares	(427)	504	641
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	1,984	1,843	1,439
ASSETS	20,324	18,460	17,077	18,460
Operating Segments \| Sempra Texas Utilities
Segment Reporting Information, Profit (Loss) [Abstract]
Income tax expense (benefit)	0	1	0
Earnings (losses) attributable to common shares	616	579	528
Segment Reporting Information, Additional Information [Abstract]
ASSETS	13,047	12,542	11,619	12,542
Operating Segments \| Sempra Renewables
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	0	0	10
INTEREST INCOME	0	0	11
INTEREST EXPENSE	0	0	3
Income tax expense (benefit)	0	0	4
Earnings (losses) attributable to common shares	0	0	59
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	0	0	2
Operating Segments \| Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	1,997	1,400	1,454
DEPRECIATION AND AMORTIZATION	239	198	193
INTEREST INCOME	75	141	139
INTEREST EXPENSE	205	174	155
Income tax expense (benefit)	238	149	222
Earnings (losses) attributable to common shares	682	580	247
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	802	879	736
ASSETS	14,408	12,772	13,660	12,772
Adjustment and Elimination [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(1)	(3)	(3)
Earnings from discontinued operations attributable to common shares	0	1,840	328
Segment Reporting Information, Additional Information [Abstract]
Assets, discontinued operations	0	0	3,958	0
Intersegment Eliminations [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	(163)	(90)	(85)
INTEREST INCOME	(11)	(56)	(73)
INTEREST EXPENSE	(20)	(54)	(83)
Segment Reporting Information, Additional Information [Abstract]
ASSETS	(1,191)	(677)	(1,972)	(677)
Intersegment Eliminations [Member] \| SDG&E
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	10	5	5
Intersegment Eliminations [Member] \| SoCalGas
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	98	88	69
Intersegment Eliminations [Member] \| Sempra Infrastructure
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	55	(3)	11
All Other [Member]
Segment Reporting Information, Profit (Loss) [Abstract]
REVENUES	5	2	3
DEPRECIATION AND AMORTIZATION	11	13	14
INTEREST INCOME	3	7	4
INTEREST EXPENSE	444	390	450
Income tax expense (benefit)	(30)	(187)	(202)
Earnings (losses) attributable to common shares	(436)	(563)	(515)
Segment Reporting Information, Additional Information [Abstract]
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT	9	12	9
ASSETS	$ 1,399	$ 1,215	$ 763	$ 1,215
Sempra LNG Holding, LP \| Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	100.00%
IEnova
Segment Reporting Information [Line Items]
Ownership interest (as a percent)					99.90%	99.90%	96.40%	70.20%
IEnova \| Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	99.90%
SI Partners \| Sempra Infrastructure
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	80.00%
Oncor Electric Delivery Company LLC \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Ownership interest (as a percent)	80.25%
Sharyland Holdings, LP
Segment Reporting Information [Line Items]
Acquired percentage interest									50.00%	50.00%
Sharyland Holdings, LP \| Sempra Texas Utilities
Segment Reporting Information [Line Items]
Acquired percentage interest										50.00%

CONSOLIDATED BALANCE SHEETS - SCG (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	11,000,000	11,000,000
Preferred stock, shares outstanding (in shares)	0	0	1,000,000
Common stock, shares authorized (in shares)	750,000,000	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	316,919,782	288,470,244	291,712,925	273,769,513

EMPLOYEE BENEFIT PLANS - EMPLOYEE BENEFIT PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Liability, Defined Benefit Plan [Abstract]
Noncurrent liabilities	$ (25)	$ (92)	$ (153)
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Expected return on plan assets	6.75%
Pension Plan
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 2,829	2,526	2,148
Service cost	97	86	68
Interest cost	78	88	91
Contributions from plan participants	0	0	0
Actuarial (gain) loss	(83)	282	345
Plan amendments	0	0	2
Benefit payments	(63)	(60)	(59)
Settlements	(211)	(105)	(65)
Transfer of liability from other plans	0	12	(4)
Net obligation at December 31	2,647	2,829	2,526
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,969	1,737	1,385
Actual return on plan assets	243	243	320
Employer contributions	157	152	152
Contributions from plan participants	0	0	0
Benefit payments	(63)	(60)	(59)
Settlements	(211)	(105)	(65)
Transfer of assets from other plans	0	2	4
Fair value of plan assets at December 31	2,095	1,969	1,737
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	(552)	(860)	(789)
Net recorded (liability) asset at December 31	(552)	(860)	(789)
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	0	0	0
Current liabilities	(1)	(7)	(4)
Noncurrent liabilities	(551)	(853)	(785)
Net recorded (liability) asset	(552)	(860)	(789)
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	(15)	(14)	(7)
Prior service cost	(3)	(4)	(3)
Total	(18)	(18)	(10)
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	97	86	68
Interest cost	78	88	91
Expected return on assets	(113)	(107)	(94)
Amortization of prior service cost (credit)	8	8	8
Amortization of actuarial loss (gain)	36	26	16
Settlement charges	25	0	0
Net periodic benefit cost	131	101	89
Regulatory adjustment	23	53	63
Total expense recognized	154	154	152
CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net loss (gain)	2	6	2
Prior service cost	0	0	3
Transfer of actuarial loss (gain)	0	5	(4)
Transfer of prior service cost (credit)	0	3	(1)
Amortization of actuarial loss	(1)	(1)	(1)
Amortization of prior service cost	(1)	(1)	0
Settlements	(7)	(22)	(28)
Total recognized in OCI	0	12	(1)
Total recognized in net periodic benefit cost and OCI	$ 154	$ 166	$ 151
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.04%	2.79%	3.50%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.79%	3.50%	4.30%
Expected return on plan assets	6.75%	7.00%	7.00%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 152
EXPECTED BENEFIT PAYMENTS
2022	171
2023	163
2024	158
2025	156
2026	153
2027-2031	$ 725
Pension Plan \| Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
Pension Plan \| Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	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
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$ 749	$ 688	$ 646
Service cost	17	14	12
Interest cost	22	25	27
Contributions from plan participants	13	14	13
Actuarial (gain) loss	(49)	57	39
Plan amendments	0	0	0
Benefit payments	(46)	(49)	(49)
Settlements	0	0	0
Transfer of liability from other plans	0	0	0
Net obligation at December 31	706	749	688
CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	27	25	916
Actual return on plan assets	51	134	178
Employer contributions	1	1	1
Contributions from plan participants	13	14	13
Benefit payments	(46)	(49)	(49)
Settlements	0	0	0
Transfer of assets from other plans	0	0	0
Fair value of plan assets at December 31	33	27	25
Defined Benefit Plan, Funded (Unfunded) Status of Plan [Abstract]
Funded status at December 31	472	410	371
Net recorded (liability) asset at December 31	472	410	371
Liability, Defined Benefit Plan [Abstract]
Noncurrent assets	472	410	371
Current liabilities	0	0	0
Noncurrent liabilities	0	0	0
Net recorded (liability) asset	472	410	371
Accumulated Other Comprehensive (Income) Loss, Defined Benefit Plan, after Tax [Abstract]
Net actuarial (loss) gain	11	8	10
Prior service cost	0	0	0
Total	11	8	10
NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
Service cost	17	14	12
Interest cost	22	25	27
Expected return on assets	(48)	(43)	(58)
Amortization of prior service cost (credit)	(3)	(2)	(2)
Amortization of actuarial loss (gain)	(7)	(7)	(8)
Settlement charges	0	0	0
Net periodic benefit cost	(19)	(13)	(29)
Regulatory adjustment	19	13	29
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 (gain)	0	0	0
Transfer of prior service cost (credit)	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	$ 0
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Discount rate	3.05%	2.90%	3.55%
Interest crediting rate	1.94%	1.62%	2.28%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Discount rate	2.90%	3.55%	4.30%
Expected return on plan assets	4.70%	4.41%	6.38%
Interest crediting rate	1.62%	2.28%	3.36%
EXPECTED CONTRIBUTIONS
Expected employer contributions	$ 1
EXPECTED BENEFIT PAYMENTS
2022	33
2023	33
2024	33
2025	33
2026	33
2027-2031	$ 166
Other Postretirement Benefits Plan \| Pre-65Retiree
ASSUMED HEALTH CARE COST TREND RATES
Health care cost trend rate assumed for next year	6.00%	6.00%	6.25%
Rate to which the cost trend rate is assumed to decline (the ultimate trend)	4.75%	4.75%	4.75%
Other Postretirement Benefits Plan \| Retiree Aged 65 or Older
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 \| Minimum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	2.70%	2.70%	2.70%
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE NET PERIODIC BENEFIT COST
Rate of compensation increase	2.70%	2.70%	2.00%
Other Postretirement Benefits Plan \| Maximum
WEIGHTED-AVERAGE ASSUMPTIONS USED TO DETERMINE BENEFIT OBLIGATION
Rate of compensation increase	10.00%	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 \| Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	$ 2,612	$ 2,792	$ 2,505
Accumulated benefit obligation	2,277	2,431	2,208
Fair value of plan assets	2,095	1,969	1,737
Funded Plan \| Other Postretirement Benefits Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	34	33	32
Fair value of plan assets	33	27	25
Unfunded Plan \| Pension Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Projected benefit obligation	35	37	21
Accumulated benefit obligation	29	31	17
Unfunded Plan \| Other Postretirement Benefits Plan
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets [Abstract]
Accumulated benefit obligation	$ 12	$ 14	$ 16

INCOME TAXES - NET OPERATING LOSSES AND TAX CREDIT CARRYFORWARDS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating Loss Carryforwards [Line Items]
Valuation allowances	$ 183	$ 174	$ 144
U.S. federal
Operating Loss Carryforwards [Line Items]
NOLs	3,263
Valuation allowances	128	118	90
U.S. federal \| General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	436
U.S. federal \| Foreign tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	688
U.S. state
Operating Loss Carryforwards [Line Items]
NOLs	2,938
Valuation allowances	31	32	33
U.S. state \| General business tax credits
Operating Loss Carryforwards [Line Items]
Tax credits	6
Non-U.S.
Operating Loss Carryforwards [Line Items]
NOLs	248
Valuation allowances	$ 24	$ 24	$ 21

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - PRINCIPLES OF CONSOLIDATION (Details)	21 Months Ended
	Dec. 31, 2020 segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - NARRATIVE (Details) - USD ($)						12 Months Ended
	Feb. 25, 2022	Jan. 11, 2022	Nov. 17, 2021	Aug. 04, 2020	Jul. 01, 2020	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Jul. 06, 2020	Sep. 11, 2007
Shares issued (in shares)						0	0	16,906,185
Issuances of common stock, net						$ 5,000,000	$ 11,000,000	$ 1,830,000,000
Subsequent Event
Maximum amount of shares that may yet be purchased	$ 1,500,000,000
Shares may yet be purchased (in shares)	21,104,486
Common Stock
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 (in shares)			2,422,758	4,089,375
Common shares repurchased, average price (in dollars per share)			$ 123.83	$ 122.27
Common stock acquired (in shares)			$ 300,000,000
Common Stock \| Subsequent Event
ASR program, amount prepaid		$ 200,000,000
Common shares repurchased (in shares)		1,472,756
Common shares repurchased, average price (in dollars per share)		$ 135.80
Settlement of Forward Sale Contracts \| Common Stock
Shares issued (in shares)								7,156,185
Issuances of common stock, net								$ 728,000,000
Payments of stock issuance costs								$ 13,000,000
Price of shares issued net of underwriting discount (in dollars per share)								$ 101.74
July 2018 Common Stock Offering \| Common Stock
Shares issued (in shares)								9,750,000
Issuances of common stock, net								$ 1,066,000,000
Payments of stock issuance costs								$ 18,000,000
Price of shares issued net of underwriting discount (in dollars per share)								$ 109.33

CONSOLIDATED STATEMENTS OF OPERATIONS - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues
Electric	$ 4,666	$ 4,619	$ 4,267
Natural Gas	838	694	658
Total operating revenues	5,515	4,748	4,525
Operating expenses
Cost of electric fuel and purchased power	1,069	1,191	1,194
Cost of natural gas	1,369	783	977
Operation and maintenance	2,180	2,029	1,780
Depreciation and amortization	716	654	602
Franchise fees and other taxes	223	190	173
Total operating expenses	6,081	3,963	3,569
Operating Income	(566)	785	956
Other income, net	(14)	(28)	(55)
Interest income	1	2	2
Interest expense	(157)	(158)	(141)
Income (loss) before income taxes	(736)	601	762
Income tax expense	310	(96)	(120)
Net income	(426)	505	642
Earnings attributable to noncontrolling interest	0	0	(7)
Earnings attributable to common shares	$ (427)	$ 504	$ 641

PREFERRED STOCK (Details)	Jun. 19, 2020 USD ($) $ / shares shares	Dec. 31, 2021 USD ($) $ / shares shares	Jul. 15, 2021 shares	Jan. 15, 2021 shares	Dec. 31, 2020 USD ($) shares	Dec. 31, 2019 USD ($) shares
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		50,000,000			11,000,000	11,000,000
Number of preferred stock shares outstanding (in shares)		0			0	1,000,000
Preferred stock, shares issued (in shares)		0			0
Series A Preferred Stock
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)				17,250,000
Shares converted				17,250,000
Convertible Preferred Stock Series A
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)					17,250,000	17,250,000
Shares converted				13,781,025
Preferred stock conversion ratio				0.7989
Series B Preferred Stock
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)			5,750,000
Shares converted			5,750,000
Series C Preferred Stock
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)		900,000			900,000
Preferred stock, shares issued (in shares)	900,000
Stated percentage rate	4.875%
Preferred stock redemption price (in dollars per share) \| $ / shares	$ 1,000
Proceeds from issuance of preferred stock \| $	$ 889,000,000
Preferred stock, discount on shares \| $	11,000,000
Preferred stock, liquidation preference \| $	$ 1,000
Series C Preferred Stock \| Period three
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 \| Period one
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	4.875%
Liquidation preference (in dollars per share) \| $ / shares	$ 1,000
Series C Preferred Stock \| Period two
Preferred Stock [Line Items]
Preferred stock dividend rate (as a percent)	4.55%
Liquidation preference (in dollars per share) \| $ / shares	$ 1,000
Convertible Preferred Stock Series B
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)					5,750,000	5,750,000
Shares converted			4,256,720
Preferred stock conversion ratio			0.7403
So Cal Gas Series Preferred Stock [Member]
Preferred Stock [Line Items]
Preferred stock shares authorized (in shares)		5,000,000
Preferred stock outstanding \| $		$ 22,000,000			$ 22,000,000	$ 22,000,000
Twenty Five Dollar Par, Six Percent Series
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	3,000,000
Twenty Five Dollar Par, Six Percent Series A
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	19,000,000
So Cal Gas Preferred Stock Owned By Pacific Enterprises
Preferred Stock [Line Items]
Number of preferred stock shares outstanding (in shares)		50,970
Preferred stock outstanding held by parent \| $		$ (2,000,000)			(2,000,000)	(2,000,000)
Preferred Stock Of Subsidiaries
Preferred Stock [Line Items]
Preferred stock outstanding \| $		$ 20,000,000			$ 20,000,000	$ 20,000,000

REVENUES

12 Months Ended

Dec. 31, 2021

Revenue from Contract with Customer [Abstract]

REVENUES

REVENUESThe 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 Infrastructure		Sempra Renewables		Consolidating adjustments and Parent and other		Sempra
	Year ended December 31, 2021
By major service line:
Utilities	$	5,144	$	5,424	$	81	$	—	$	(109)	$	10,540
Energy-related businesses	—		—		1,165		—		(29)		1,136
Revenues from contracts with customers	$	5,144	$	5,424	$	1,246	$	—	$	(138)	$	11,676
By market:
Gas	$	790	$	5,424	$	856	$	—	$	(101)	$	6,969
Electric	4,354		—		390		—		(37)		4,707
Revenues from contracts with customers	$	5,144	$	5,424	$	1,246	$	—	$	(138)	$	11,676

Revenues from contracts with customers	$	5,144	$	5,424	$	1,246	$	—	$	(138)	$	11,676
Utilities regulatory revenues	360		91		—		—		—		451
Other revenues	—		—		751		—		(21)		730
Total revenues	$	5,504	$	5,515	$	1,997	$	—	$	(159)	$	12,857

	Year ended December 31, 2020
By major service line:
Utilities	$	4,920	$	4,571	$	58	$	—	$	(94)	$	9,455
Energy-related businesses	—		—		854		—		1		855
Revenues from contracts with customers	$	4,920	$	4,571	$	912	$	—	$	(93)	$	10,310
By market:
Gas	$	692	$	4,571	$	623	$	—	$	(90)	$	5,796
Electric	4,228		—		289		—		(3)		4,514
Revenues from contracts with customers	$	4,920	$	4,571	$	912	$	—	$	(93)	$	10,310

Revenues from contracts with customers	$	4,920	$	4,571	$	912	$	—	$	(93)	$	10,310
Utilities regulatory revenues	393		177		—		—		—		570
Other revenues	—		—		488		—		2		490
Total revenues	$	5,313	$	4,748	$	1,400	$	—	$	(91)	$	11,370

	Year ended December 31, 2019
By major service line:
Utilities	$	4,819	$	4,367	$	73	$	—	$	(75)	$	9,184
Energy-related businesses	—		—		951		5		1		957
Revenues from contracts with customers	$	4,819	$	4,367	$	1,024	$	5	$	(74)	$	10,141
By market:
Gas	$	587	$	4,367	$	711	$	—	$	(69)	$	5,596
Electric	4,232		—		313		5		(5)		4,545
Revenues from contracts with customers	$	4,819	$	4,367	$	1,024	$	5	$	(74)	$	10,141

Revenues from contracts with customers	$	4,819	$	4,367	$	1,024	$	5	$	(74)	$	10,141
Utilities regulatory revenues	106		158		—		—		—		264
Other revenues	—		—		430		5		(11)		424
Total revenues	$	4,925	$	4,525	$	1,454	$	10	$	(85)	$	10,829

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, SDG&E and SoCalGas pay franchise fees to operate in various municipalities. SDG&E and SoCalGas bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SDG&E’s and SoCalGas’ 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 Infrastructure’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.

SDG&E, SoCalGas and Ecogas recognize revenues based on regulator-approved revenue requirements, which allow the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While SDG&E’s and SoCalGas’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SDG&E and SoCalGas recognize annual authorized revenue for customers using seasonal factors established in applicable proceedings. This generally results in a significant portion of operating revenues being recognized in the third quarter of each year for SDG&E and in the first and fourth quarters of each year for SoCalGas.

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.

SDG&E and SoCalGas 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 SDG&E and SoCalGas 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. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts.

Energy-Related Businesses Revenues

Revenues at Sempra Infrastructure 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.

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 Infrastructure 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.

Sempra Infrastructure 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 Infrastructure, 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 April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments.

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.

Sempra Infrastructure sells natural gas to the CFE and other customers under supply agreements. Sempra Infrastructure 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.

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, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure. SoCalGas did not have any remaining performance obligations at December 31, 2021.


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2022	$	368	$	4
2023	367		4
2024	365		4
2025	362		4
2026	361		4
Thereafter	4,289		63
Total revenues to be recognized	$	6,112	$	83

(1) Excludes intercompany transactions.

Contract Liabilities 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’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in 2021, 2020 or 2019.


CONTRACT LIABILITIES
(Dollars in millions)
	2021		2020		2019
Sempra:
Contract liabilities at January 1	$	(207)	$	(163)	$	(70)
Revenue from performance obligations satisfied during reporting period	52		4		2
Payments received in advance	(123)		(48)		(95)
Contract liabilities at December 31(1)	$	(278)	$	(207)	$	(163)
SDG&E:
Contract liabilities at January 1	$	(87)	$	(91)	$	—
Revenue from performance obligations satisfied during reporting period	4		4		1
Payments received in advance	—		—		(92)
Contract liabilities at December 31(2)	$	(83)	$	(87)	$	(91)

(1) Balances at December 31, 2021, 2020 and 2019 include $116, $52 and $4, respectively, in Other Current Liabilities and $162, $155 and $159, respectively, in Deferred Credits and Other.

(2) Balances at December 31, 2021, 2020 and 2019 include $4, $4 and $4, respectively, in Other Current Liabilities and $79, $83 and $87, 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,
	2021		2020		2019
Sempra:
Accounts receivable – trade, net	$	1,886	$	1,447	$	1,163
Accounts receivable – other, net	19		12		16
Due from unconsolidated affiliates – current(1)	2		3		5
Other long-term assets	70		—		—
Total	$	1,977	$	1,462	$	1,184
SDG&E:
Accounts receivable – trade, net	$	715	$	573	$	398
Accounts receivable – other, net	9		8		5
Due from unconsolidated affiliates – current(1)	2		2		2
Other long-term assets	25		—		—
Total	$	751	$	583	$	405
SoCalGas:
Accounts receivable – trade, net	$	1,084	$	786	$	710
Accounts receivable – other, net	10		4		11
Other long-term assets	45		—		—
Total	$	1,139	$	790	$	721

(1) Amount 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 SDG&E and SoCalGas 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 SDG&E and SoCalGas to use a “decoupling” mechanism, which allows SDG&E and SoCalGas 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 SDG&E and SoCalGas 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 SDG&E and SoCalGas 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 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 Infrastructure generates lease revenues from certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and liquid fuels terminals. Certain PPAs at Sempra Renewables were accounted for as operating leases prior to sale of its wind assets in April 2019. We discuss the recognition of lease income in Note 16 of the Notes to Consolidated Financial Statements.

Sempra Infrastructure has an agreement with Tangguh PSC to supply LNG to the ECA Regas Facility. Under the terms of the agreement, Tangguh PSC must either deliver the contracted number of cargoes or pay a diversion fee for non-delivery of LNG cargoes.

Sempra Infrastructure also recognizes other revenues associated with derivatives related to the 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 these derivatives.

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-URI http://asc.fasb.org/topic&trid=49130388

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130551-203045

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 13
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130556-203045

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130550-203045

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130558-203045

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 606
-SubTopic 10
-Section 50
-Paragraph 12
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123351226&loc=SL49130554-203045

Schedule Of Preferred Stock

PREFERRED STOCK (Tables)

12 Months Ended

Dec. 31, 2021

Equity [Abstract]

The table below presents preferred stock outstanding at SoCalGas:


PREFERRED STOCK OUTSTANDING
(Dollars in millions, except per share amounts)
	December 31,
	2021		2020		2019
$25 par value, authorized 1,000,000 shares:
6% Series, 79,011 shares outstanding	$	3	$	3	$	3
6% Series A, 783,032 shares outstanding	19		19		19
SoCalGas - Total preferred stock	22		22		22
Less: 50,970 shares of the 6% Series outstanding owned by PE	(2)		(2)		(2)
Sempra - Total preferred stock of subsidiary	$	20	$	20	$	20

EMPLOYEE BENEFIT PLANS

12 Months Ended

Dec. 31, 2021

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 and its consolidated subsidiaries.

Sempra 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 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 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.

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 maintains dedicated assets, including a Rabbi Trust and investments in life insurance contracts, which totaled $567 million, $512 million and $488 million at December 31, 2021, 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, $3 million at SDG&E and $2 million at SoCalGas in 2019.

Oncor

In 2021, 2020 and 2019, we had $7 million, $11 million and $27 million, respectively, in AOCI representing an actuarial loss related to Oncor’s pension plans.

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 2021, 2020 and 2019, and a statement of the funded status at December 31, 2021, 2020 and 2019:


PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
Sempra:
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$	4,077	$	3,768	$	3,339	$	989	$	913	$	868
Service cost	145		129		110		23		18		17
Interest cost	112		129		139		28		33		36
Contributions from plan participants	—		—		—		21		22		21
Actuarial (gain) loss	(76)		351		445		(53)		79		45
Plan amendments	—		—		5		—		—		—
Benefit payments	(98)		(93)		(93)		(68)		(74)		(72)
Settlements	(303)		(207)		(177)		—		(2)		(2)
Net obligation at December 31	3,857		4,077		3,768		940		989		913

CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	3,002		2,662		2,160		1,399		1,281		1,108
Actual return on plan assets	340		350		496		51		164		218
Employer contributions	241		290		276		5		8		8
Contributions from plan participants	—		—		—		21		22		21
Benefit payments	(98)		(93)		(93)		(68)		(74)		(72)
Settlements	(303)		(207)		(177)		—		(2)		(2)
Fair value of plan assets at December 31	3,182		3,002		2,662		1,408		1,399		1,281
Funded status at December 31	$	(675)	$	(1,075)	(1,106)		$	468	$	410	$	368
Net recorded (liability) asset at December 31	$	(675)	$	(1,075)	(1,106)		$	468	$	410	$	368


PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
SDG&E:
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$	913	$	895	$	814	$	193	$	177	$	170
Service cost	35		31		30		5		4		4
Interest cost	25		30		34		5		6		7
Contributions from plan participants	—		—		—		7		8		7
Actuarial (gain) loss	(2)		37		61		(3)		17		7
Plan amendments	—		—		3		—		—		—
Benefit payments	(17)		(18)		(18)		(19)		(20)		(18)
Settlements	(69)		(52)		(39)		—		—		—
Transfer of liability from other plans	—		(10)		10		—		1		—
Net obligation at December 31	885		913		895		188		193		177

CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	819		739		600		213		197		172
Actual return on plan assets	73		94		135		(5)		26		36
Employer contributions	53		52		52		1		1		—
Contributions from plan participants	—		—		—		7		8		7
Benefit payments	(17)		(18)		(18)		(19)		(20)		(18)
Settlements	(69)		(52)		(39)		—		—		—
Transfer of assets from other plans	—		4		9		—		1		—
Fair value of plan assets at December 31	859		819		739		197		213		197
Funded status at December 31	$	(26)	$	(94)	(156)		$	9	$	20	$	20
Net recorded (liability) asset at December 31	$	(26)	$	(94)	(156)		$	9	$	20	$	20


PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
(Dollars in millions)	2021		2020		2019		2021		2020		2019
SoCalGas:
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$	2,829	$	2,526	$	2,148	$	749	$	688	$	646
Service cost	97		86		68		17		14		12
Interest cost	78		88		91		22		25		27
Contributions from plan participants	—		—		—		13		14		13
Actuarial (gain) loss	(83)		282		345		(49)		57		39
Plan amendments	—		—		2		—		—		—
Benefit payments	(63)		(60)		(59)		(46)		(49)		(49)
Settlements	(211)		(105)		(65)		—		—		—
Transfer of liability to other plans	—		12		(4)		—		—		—
Net obligation at December 31	2,647		2,829		2,526		706		749		688

CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,969		1,737		1,385		1,159		1,059		916
Actual return on plan assets	243		243		320		51		134		178
Employer contributions	157		152		152		1		1		1
Contributions from plan participants	—		—		—		13		14		13
Benefit payments	(63)		(60)		(59)		(46)		(49)		(49)
Settlements	(211)		(105)		(65)		—		—		—
Transfer of assets from other plans	—		2		4		—		—		—
Fair value of plan assets at December 31	2,095		1,969		1,737		1,178		1,159		1,059
Funded status at December 31	$	(552)	$	(860)	$	(789)	$	472	$	410	$	371
Net recorded (liability) asset at December 31	$	(552)	$	(860)	$	(789)	$	472	$	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 2021, 2020 and 2019, 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 companies’ actual mortality experience, in our calculations for each of those years.

▪Actuarial gains in pension plans at Sempra in 2021 were driven primarily by an increase in discount rates at SoCalGas, SDG&E and Sempra and updated census data at SoCalGas. These actuarial gains were partially offset by actuarial losses at SDG&E, SoCalGas and Sempra due to an increase in the interest crediting rate for the cash balance plans, at SDG&E and Sempra due to updated census data and at SoCalGas due to a decrease in the conversion rate used to determine lump-sum distributions.

▪Actuarial gains in PBOP plans at Sempra in 2021 were driven primarily by an increase in discount rates at SoCalGas, SDG&E and Sempra, updated census data at SoCalGas and a reduction in the 2022 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, 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. SDG&E and SoCalGas 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.

SDG&E and SoCalGas 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 SDG&E and SoCalGas are disclosed as regulatory adjustments in accordance with U.S. GAAP for rate-regulated entities.

The net (liability) asset is included in the following categories on the Consolidated Balance Sheets at December 31:


PENSION AND OTHER POSTRETIREMENT BENEFIT OBLIGATIONS, NET OF PLAN ASSETS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
Sempra:
Noncurrent assets	$	19	$	—	$	—	$	481	$	430	$	391
Current liabilities	(19)		(35)		(59)		(1)		(1)		(3)
Noncurrent liabilities	(675)		(1,040)		(1,047)		(12)		(19)		(20)
Net recorded (liability) asset	$	(675)	$	(1,075)	$	(1,106)	$	468	$	410	$	368
SDG&E:
Noncurrent assets	$	—	$	—	$	—	$	9	$	20	$	20
Current liabilities	(1)		(2)		(3)		—		—		—
Noncurrent liabilities	(25)		(92)		(153)		—		—		—
Net recorded (liability) asset	$	(26)	$	(94)	$	(156)	$	9	$	20	$	20
SoCalGas:
Noncurrent assets	$	—	$	—	$	—	$	472	$	410	$	371
Current liabilities	(1)		(7)		(4)		—		—		—
Noncurrent liabilities	(551)		(853)		(785)		—		—		—
Net recorded (liability) asset	$	(552)	$	(860)	$	(789)	$	472	$	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 benefits
	2021		2020		2019		2021		2020		2019
Sempra(1):
Net actuarial (loss) gain	$	(86)	$	(102)	$	(113)	$	11	$	8	$	10
Prior service cost	(8)		(11)		(14)		—		—		—
Total	$	(94)	$	(113)	$	(127)	$	11	$	8	$	10
SDG&E:
Net actuarial loss	$	(9)	$	(8)	$	(9)
Prior service cost	(1)		(2)		(7)
Total	$	(10)	$	(10)	$	(16)
SoCalGas:
Net actuarial loss	$	(15)	$	(14)	$	(7)
Prior service cost	(3)		(4)		(3)
Total	$	(18)	$	(18)	$	(10)

(1) Includes discontinued operations in 2020 and 2019.

Sempra, 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)
	2021		2020		2019
Sempra:
Projected benefit obligation	$	2,612	$	3,679	$	3,578
Accumulated benefit obligation	2,277		3,265		3,229
Fair value of plan assets	2,095		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	$	2,612	$	2,792	$	2,505
Accumulated benefit obligation	2,277		2,431		2,208
Fair value of plan assets	2,095		1,969		1,737

We also have unfunded pension plans at Sempra, 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)
	2021		2020		2019
Sempra:
Projected benefit obligation	$	178	$	184	$	190
Accumulated benefit obligation	139		146		158
SDG&E:
Projected benefit obligation	$	26	$	26	$	34
Accumulated benefit obligation	22		22		27
SoCalGas:
Projected benefit obligation	$	35	$	37	$	21
Accumulated benefit obligation	29		31		17

Sempra, SDG&E and SoCalGas each have a funded other postretirement benefit plan. At December 31, 2021, the assets for SDG&E’s and SoCalGas’ other postretirement benefit plans exceeded the plans’ obligations. 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)
	2021		2020		2019
Sempra:
Accumulated postretirement benefit obligation	$	34	$	33	$	32
Fair value of plan assets	33		27		25

We also have unfunded other postretirement benefit plans at Sempra. 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)
	2021		2020		2019
Sempra:
Accumulated postretirement benefit obligation	$	12	$	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
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
Sempra:
NET PERIODIC BENEFIT COST
Service cost	$	145	$	129	$	110	$	23	$	18	$	17
Interest cost	112		129		139		28		33		36
Expected return on assets	(173)		(169)		(144)		(61)		(55)		(71)
Amortization of:
Prior service cost (credit)	11		12		12		(2)		(2)		—
Actuarial loss (gain)	45		35		36		(9)		(10)		(10)
Settlement charges	38		22		28		—		—		—
Net periodic benefit cost (credit)	178		158		181		(21)		(16)		(28)
Regulatory adjustment	57		91		77		21		16		29
Total expense recognized	235		249		258		—		—		1

CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net (gain) loss	(5)		28		17		(4)		1		(3)
Prior service cost	—		—		5		—		—		—
Amortization of actuarial loss	(8)		(14)		(13)		—		—		—
Amortization of prior service cost	(4)		(4)		(3)		—		—		—
Settlements	(7)		(22)		(28)		—		—		—
Total recognized in OCI	(24)		(12)		(22)		(4)		1		(3)
Total recognized in net periodic benefit cost and OCI	$	211	$	237	$	236	$	(4)	$	1	$	(2)

(1) Includes discontinued operations in 2020 and 2019.


NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
SDG&E:
NET PERIODIC BENEFIT COST
Service cost	$	35	$	31	$	30	$	5	$	4	$	4
Interest cost	25		30		34		5		6		7
Expected return on assets	(50)		(49)		(38)		(10)		(10)		(11)
Amortization of:
Prior service cost	1		2		3		—		—		2
Actuarial loss (gain)	2		3		11		(2)		(3)		(2)
Settlement charges	6		—		—		—		—		—
Net periodic benefit cost (credit)	19		17		40		(2)		(3)		—
Regulatory adjustment	34		38		14		2		3		—
Total expense recognized	53		55		54		—		—		—

CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net loss	1		6		5		—		—		—
Prior service cost	—		—		2		—		—		—
Transfer of actuarial gain	—		(7)		—		—		—		—
Transfer of prior service credit	—		(5)		—		—		—		—
Amortization of actuarial loss	—		(1)		—		—		—		—
Amortization of prior service cost	(1)		(1)		(1)		—		—		—
Total recognized in OCI	—		(8)		6		—		—		—
Total recognized in net periodic benefit cost and OCI	$	53	$	47	$	60	$	—	$	—	$	—


NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
SOUTHERN CALIFORNIA GAS COMPANY
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
SoCalGas:
NET PERIODIC BENEFIT COST
Service cost	$	97	$	86	$	68	$	17	$	14	$	12
Interest cost	78		88		91		22		25		27
Expected return on assets	(113)		(107)		(94)		(48)		(43)		(58)
Amortization of:
Prior service cost (credit)	8		8		8		(3)		(2)		(2)
Actuarial loss (gain)	36		26		16		(7)		(7)		(8)
Settlement charges	25		—		—		—		—		—
Net periodic benefit cost (credit)	131		101		89		(19)		(13)		(29)
Regulatory adjustment	23		53		63		19		13		29
Total expense recognized	154		154		152		—		—		—

CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net loss	2		6		2		—		—		—
Prior service cost	—		—		3		—		—		—
Transfer of actuarial loss (gain)	—		5		(4)		—		—		—
Transfer of prior service cost (credit)	—		3		(1)		—		—		—
Amortization of actuarial loss	(1)		(1)		(1)		—		—		—
Amortization of prior service cost	(1)		(1)		—		—		—		—
Total recognized in OCI	—		12		(1)		—		—		—
Total recognized in net periodic benefit cost and OCI	$	154	$	166	$	151	$	—	$	—	$	—

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
	2021		2020		2019		2021		2020		2019
Sempra:
Discount rate	3.04	%	2.78	%	3.49	%	3.04	%	2.88	%	3.54	%
Interest crediting rate(1)(2)	1.94		1.62		2.28		1.94		1.62		2.28
Rate of compensation increase	2.70-10.00		2.70-10.00		2.70-10.00		2.70-10.00		2.70-10.00		2.70-10.00
SDG&E:
Discount rate	2.99	%	2.73	%	3.44	%	3.05	%	2.85	%	3.55	%
Interest crediting rate(1)(2)	1.94		1.62		2.28		1.94		1.62		2.28
Rate of compensation increase	3.50-10.00		2.70-10.00		2.70-10.00		3.50-10.00		2.70-10.00		2.70-10.00
SoCalGas:
Discount rate	3.04	%	2.79	%	3.50	%	3.05	%	2.90	%	3.55	%
Interest crediting rate(1)(2)	1.94		1.62		2.28		1.94	%	1.62		2.28
Rate of compensation increase	2.70-10.00		2.70-10.00		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
	2021		2020		2019		2021		2020		2019
Sempra:
Discount rate	2.78	%	3.49	%	4.29	%	2.88	%	3.54	%	4.29	%
Expected return on plan assets	6.47		7.00		7.00		4.76		4.64		6.48
Interest crediting rate(1)(2)	1.62		2.28		3.36		1.62		2.28		3.36
Rate of compensation increase	2.70-10.00		2.70-10.00		2.00-10.00		2.70-10.00		2.70-10.00		2.00-10.00
SDG&E:
Discount rate	2.73	%	3.44	%	4.29	%	2.85	%	3.55	%	4.30	%
Expected return on plan assets	6.25		7.00		7.00		4.81		5.51		6.92
Interest crediting rate(1)(2)	1.62		2.28		3.36		1.62		2.28		3.36
Rate of compensation increase	2.70-10.00		2.70-10.00		2.00-10.00		2.70-10.00		2.70-10.00		2.00-10.00
SoCalGas:
Discount rate	2.79	%	3.50	%	4.30	%	2.90	%	3.55	%	4.30	%
Expected return on plan assets	6.75		7.00		7.00		4.70		4.41		6.38
Interest crediting rate(1)(2)	1.62		2.28		3.36		1.62		2.28		3.36
Rate of compensation increase	2.70-10.00		2.70-10.00		2.00-10.00		2.70-10.00		2.70-10.00		2.00-10.00

(1) Interest crediting rate for pension benefits applies only to funded cash balance plans.

(2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas.

Health Care Cost Trend Rates

Assumed health care cost trend rates have a significant effect on the amounts that Sempra, SDG&E and SoCalGas 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
	2021		2020		2019		2021		2020		2019
Health care cost trend rate assumed for next year	6.00	%	6.00	%	6.25	%	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’s Pension Master Trust

Sempra’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 SDGE’s and SoCalGas’ PBOP plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra.

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:

▪31% domestic equity

▪21% international equity

▪21% long credit

▪10% diversified real assets

▪10% 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 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’s pension master trust and the trusts for SDG&E’s and SoCalGas’ 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.

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. Other investments 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.

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.

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.

Venture Capital Funds and Real Estate Funds – These funds consist of investments in venture capital funds and real estate funds that are held by limited partnerships or similar private entities following various investment strategies. The value is determined based on the NAV of our proportionate ownership interest in the entity.

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 the pension master trust at Sempra. 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, 2021
	Level 1		Level 2		Total
Sempra:
Cash and cash equivalents	$	18	$	—	$	18
Equity securities:
Domestic	844		5		849
International	384		1		385
Registered investment companies:
Domestic	204		21		225
International	33		—		33
Fixed income securities:
Domestic government and government agencies	463		24		487
International government bonds	—		11		11
Domestic corporate bonds	—		413		413
International corporate bonds	—		65		65
Other	1		—		1
Total investment assets in the fair value hierarchy	$	1,947	$	540	2,487
Accounts receivable/payable, net					(20)
Investments measured at NAV:
Common/collective trusts					657
Venture capital funds and real estate funds					58
Total investment assets					$	3,182
SDG&E’s proportionate share of investment assets					$	859
SoCalGas’ proportionate share of investment assets					$	2,095

	Fair value at December 31, 2020
	Level 1		Level 2		Total
Sempra:
Cash and cash equivalents	$	7	$	—	$	7
Equity securities:
Domestic	931		—		931
International	563		—		563
Registered investment companies:
Domestic	151		37		188
International	32		—		32
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
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
Venture capital funds and real estate 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 MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS
(Dollars in millions)
	Fair value at December 31, 2019
	Level 1		Level 2		Total
Sempra:
Cash and cash equivalents	$	17	$	—	$	17
Equity securities:
Domestic	923		—		923
International	555		1		556
Registered investment companies:
Domestic	93		2		95
International	3		—		3
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
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
Venture capital funds and real estate 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, 2021
	Level 1		Level 2		Total
SDG&E:
Equity securities:
Domestic	$	16	$	—	$	16
International	7		—		7
Registered investment companies:
Domestic	82		1		83
International	9		—		9
Fixed income securities:
Domestic government and government agencies	24		1		25
Domestic corporate bonds	—		8		8
International corporate bonds	—		1		1
Total investment assets in the fair value hierarchy	138		11		149
Accounts receivable/payable, net					(1)
Investments measured at NAV – Common/collective trusts					49
Total investment assets					197
SoCalGas:
Cash and cash equivalents	2		—		2
Equity securities:
Domestic	83		1		84
International	37		—		37
Registered investment companies:
Domestic	74		73		147
International	3		—		3
Fixed income securities:
Domestic government and government agencies	241		17		258
International government bonds	1		11		12
Domestic corporate bonds	—		337		337
International corporate bonds	—		49		49
Total investment assets in the fair value hierarchy	441		488		929
Accounts receivable/payable, net					(1)
Investments measured at NAV:
Common/collective trusts					244
Venture capital funds and real estate funds					6
Total investment assets					1,178
Other Sempra:
Equity securities:
Domestic	9		—		9
International	6		—		6
Registered investment companies – Domestic	2		—		2
Fixed income securities:
Domestic government and government agencies	2		1		3
Domestic corporate bonds	—		4		4
International corporate bonds	—		1		1
Total investment assets in the fair value hierarchy	19		6		25
Investments measured at NAV:
Common/collective trusts					7
Venture capital funds and real estate funds					1
Total other Sempra investment assets					33

Total Sempra investment assets in the fair value hierarchy	$	598	$	505
Total Sempra investment assets					$	1,408


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:
Domestic	69		7		76
International	11		—		11
Fixed income securities:
Domestic government and government agencies	38		2		40
Domestic corporate bonds	—		8		8
International corporate bonds	—		1		1
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:
Domestic	58		81		139
International	3		—		3
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
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:
Equity securities:
Domestic	10		—		10
International	6		—		6
Registered investment companies – Domestic	1		(1)		—
Fixed income securities:
Domestic government and government agencies	2		—		2
Domestic corporate bonds	—		4		4
International corporate bonds	—		1		1
Total investment assets in the fair value hierarchy	19		4		23
Investments measured at NAV – Common/collective trusts					4
Total other Sempra investment assets					27

Total Sempra investment assets in the fair value hierarchy	$	624	$	533
Total Sempra 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:
Domestic	57		8		65
International	11		—		11
Fixed income securities:
Domestic government and government agencies	32		1		33
Domestic corporate bonds	—		8		8
International corporate bonds	—		1		1
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 – Domestic	52		75		127
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
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:
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 investment assets					25

Total Sempra investment assets in the fair value hierarchy	$	602	$	478
Total Sempra investment assets					$	1,281

Future Payments

We expect to contribute the following amounts to our pension and PBOP plans in 2022:


EXPECTED CONTRIBUTIONS
(Dollars in millions)
	Sempra		SDG&E		SoCalGas
Pension plans	$	231	$	52	$	152
Other postretirement benefit plans	5		1		1

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				SDG&E				SoCalGas
	Pension benefits		Other postretirement benefits		Pension benefits		Other postretirement benefits		Pension benefits		Other postretirement benefits
2022	$	276	$	46	$	71	$	9	$	171	$	33
2023	261		46		69		10		163		33
2024	253		46		66		10		158		33
2025	244		46		65		10		156		33
2026	240		48		59		10		153		33
2027-2031	1,122		226		275		48		725		166

SAVINGS PLANS

Sempra, SDG&E and SoCalGas offer trusteed savings plans to all employees. Employee participation, employee contributions and employer matching contributions are subject to the provisions of the respective plans, and for employee contributions, limits imposed by the respective governmental authorities.

Employer contributions to the savings plans were as follows:


EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS
(Dollars in millions)
	2021		2020		2019
Sempra	$	52	$	47	$	44
SDG&E	18		16		15
SoCalGas	28		25		24

The market value of Sempra common stock held by the savings plans was $1.0 billion, $1.1 billion and $1.3 billion at December 31, 2021, 2020 and 2019, respectively.

The entire disclosure for retirement benefits.

Reference 1: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 55
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=123450688&loc=d3e4179-114921

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section S99
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=21916913&loc=d3e273930-122802

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (d)(i)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (o)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (p)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 70
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=49170846&loc=d3e28014-114942

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-URI http://asc.fasb.org/topic&trid=2235017

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 60
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=6414203&loc=d3e39689-114964

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (d)(iv)(03)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (q)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (r)(1)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (d)(iii)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (l)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 715
-SubTopic 20
-Section 50
-Paragraph 1
-Subparagraph (r)(2)
-URI http://asc.fasb.org/extlink&oid=123447040&loc=d3e1928-114920

Schedule Of Defined Benefit Plans, Change In Benefit Obligation And Fair Value Of Plan Assets

INCOME TAXES - ADDITIONAL INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2021
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 (benefit) expense related to increase in outside basis differences	$ (7)	51
Foreign undistributed earnings			$ 1,800
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested			59
Foreign earnings repatriated	$ 4,700	254
Release of regulatory liabilities		$ 38
Non-U.S.
Schedule of Effect of Changes in Legislation of Income Tax (Expense) [Line Items]
Undistributed earnings of foreign subsidiaries considered to be indefinitely reinvested			$ 600

DEBT AND CREDIT FACILITIES - SCHEDULE OF MATURITIES OF LONG-TERM DEBT (Details) $ in Millions	Dec. 31, 2021 USD ($)
Schedule Of Long Term Debt Maturities [Line Items]
2022	$ 63
2023	1,007
2024	548
2025	760
2026	1,324
Thereafter	16,397
Total	$ 20,099

EMPLOYEE BENEFIT PLANS (Tables)

12 Months Ended

Dec. 31, 2021

Retirement Benefits [Abstract]


PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
Sempra:
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$	4,077	$	3,768	$	3,339	$	989	$	913	$	868
Service cost	145		129		110		23		18		17
Interest cost	112		129		139		28		33		36
Contributions from plan participants	—		—		—		21		22		21
Actuarial (gain) loss	(76)		351		445		(53)		79		45
Plan amendments	—		—		5		—		—		—
Benefit payments	(98)		(93)		(93)		(68)		(74)		(72)
Settlements	(303)		(207)		(177)		—		(2)		(2)
Net obligation at December 31	3,857		4,077		3,768		940		989		913

CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	3,002		2,662		2,160		1,399		1,281		1,108
Actual return on plan assets	340		350		496		51		164		218
Employer contributions	241		290		276		5		8		8
Contributions from plan participants	—		—		—		21		22		21
Benefit payments	(98)		(93)		(93)		(68)		(74)		(72)
Settlements	(303)		(207)		(177)		—		(2)		(2)
Fair value of plan assets at December 31	3,182		3,002		2,662		1,408		1,399		1,281
Funded status at December 31	$	(675)	$	(1,075)	(1,106)		$	468	$	410	$	368
Net recorded (liability) asset at December 31	$	(675)	$	(1,075)	(1,106)		$	468	$	410	$	368


PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
SDG&E:
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$	913	$	895	$	814	$	193	$	177	$	170
Service cost	35		31		30		5		4		4
Interest cost	25		30		34		5		6		7
Contributions from plan participants	—		—		—		7		8		7
Actuarial (gain) loss	(2)		37		61		(3)		17		7
Plan amendments	—		—		3		—		—		—
Benefit payments	(17)		(18)		(18)		(19)		(20)		(18)
Settlements	(69)		(52)		(39)		—		—		—
Transfer of liability from other plans	—		(10)		10		—		1		—
Net obligation at December 31	885		913		895		188		193		177

CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	819		739		600		213		197		172
Actual return on plan assets	73		94		135		(5)		26		36
Employer contributions	53		52		52		1		1		—
Contributions from plan participants	—		—		—		7		8		7
Benefit payments	(17)		(18)		(18)		(19)		(20)		(18)
Settlements	(69)		(52)		(39)		—		—		—
Transfer of assets from other plans	—		4		9		—		1		—
Fair value of plan assets at December 31	859		819		739		197		213		197
Funded status at December 31	$	(26)	$	(94)	(156)		$	9	$	20	$	20
Net recorded (liability) asset at December 31	$	(26)	$	(94)	(156)		$	9	$	20	$	20


PROJECTED BENEFIT OBLIGATION, FAIR VALUE OF ASSETS AND FUNDED STATUS
(Dollars in millions)
	Pension benefits						Other postretirement benefits
(Dollars in millions)	2021		2020		2019		2021		2020		2019
SoCalGas:
CHANGE IN PROJECTED BENEFIT OBLIGATION
Net obligation at January 1	$	2,829	$	2,526	$	2,148	$	749	$	688	$	646
Service cost	97		86		68		17		14		12
Interest cost	78		88		91		22		25		27
Contributions from plan participants	—		—		—		13		14		13
Actuarial (gain) loss	(83)		282		345		(49)		57		39
Plan amendments	—		—		2		—		—		—
Benefit payments	(63)		(60)		(59)		(46)		(49)		(49)
Settlements	(211)		(105)		(65)		—		—		—
Transfer of liability to other plans	—		12		(4)		—		—		—
Net obligation at December 31	2,647		2,829		2,526		706		749		688

CHANGE IN PLAN ASSETS
Fair value of plan assets at January 1	1,969		1,737		1,385		1,159		1,059		916
Actual return on plan assets	243		243		320		51		134		178
Employer contributions	157		152		152		1		1		1
Contributions from plan participants	—		—		—		13		14		13
Benefit payments	(63)		(60)		(59)		(46)		(49)		(49)
Settlements	(211)		(105)		(65)		—		—		—
Transfer of assets from other plans	—		2		4		—		—		—
Fair value of plan assets at December 31	2,095		1,969		1,737		1,178		1,159		1,059
Funded status at December 31	$	(552)	$	(860)	$	(789)	$	472	$	410	$	371
Net recorded (liability) asset at December 31	$	(552)	$	(860)	$	(789)	$	472	$	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 benefits
	2021		2020		2019		2021		2020		2019
Sempra:
Noncurrent assets	$	19	$	—	$	—	$	481	$	430	$	391
Current liabilities	(19)		(35)		(59)		(1)		(1)		(3)
Noncurrent liabilities	(675)		(1,040)		(1,047)		(12)		(19)		(20)
Net recorded (liability) asset	$	(675)	$	(1,075)	$	(1,106)	$	468	$	410	$	368
SDG&E:
Noncurrent assets	$	—	$	—	$	—	$	9	$	20	$	20
Current liabilities	(1)		(2)		(3)		—		—		—
Noncurrent liabilities	(25)		(92)		(153)		—		—		—
Net recorded (liability) asset	$	(26)	$	(94)	$	(156)	$	9	$	20	$	20
SoCalGas:
Noncurrent assets	$	—	$	—	$	—	$	472	$	410	$	371
Current liabilities	(1)		(7)		(4)		—		—		—
Noncurrent liabilities	(551)		(853)		(785)		—		—		—
Net recorded (liability) asset	$	(552)	$	(860)	$	(789)	$	472	$	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 benefits
	2021		2020		2019		2021		2020		2019
Sempra(1):
Net actuarial (loss) gain	$	(86)	$	(102)	$	(113)	$	11	$	8	$	10
Prior service cost	(8)		(11)		(14)		—		—		—
Total	$	(94)	$	(113)	$	(127)	$	11	$	8	$	10
SDG&E:
Net actuarial loss	$	(9)	$	(8)	$	(9)
Prior service cost	(1)		(2)		(7)
Total	$	(10)	$	(10)	$	(16)
SoCalGas:
Net actuarial loss	$	(15)	$	(14)	$	(7)
Prior service cost	(3)		(4)		(3)
Total	$	(18)	$	(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)
	2021		2020		2019
Sempra:
Projected benefit obligation	$	2,612	$	3,679	$	3,578
Accumulated benefit obligation	2,277		3,265		3,229
Fair value of plan assets	2,095		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	$	2,612	$	2,792	$	2,505
Accumulated benefit obligation	2,277		2,431		2,208
Fair value of plan assets	2,095		1,969		1,737

We also have unfunded pension plans at Sempra, 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)
	2021		2020		2019
Sempra:
Projected benefit obligation	$	178	$	184	$	190
Accumulated benefit obligation	139		146		158
SDG&E:
Projected benefit obligation	$	26	$	26	$	34
Accumulated benefit obligation	22		22		27
SoCalGas:
Projected benefit obligation	$	35	$	37	$	21
Accumulated benefit obligation	29		31		17


OBLIGATIONS OF FUNDED OTHER POSTRETIREMENT BENEFIT PLANS
(Dollars in millions)
	2021		2020		2019
Sempra:
Accumulated postretirement benefit obligation	$	34	$	33	$	32
Fair value of plan assets	33		27		25

We also have unfunded other postretirement benefit plans at Sempra. 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)
	2021		2020		2019
Sempra:
Accumulated postretirement benefit obligation	$	12	$	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
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
Sempra:
NET PERIODIC BENEFIT COST
Service cost	$	145	$	129	$	110	$	23	$	18	$	17
Interest cost	112		129		139		28		33		36
Expected return on assets	(173)		(169)		(144)		(61)		(55)		(71)
Amortization of:
Prior service cost (credit)	11		12		12		(2)		(2)		—
Actuarial loss (gain)	45		35		36		(9)		(10)		(10)
Settlement charges	38		22		28		—		—		—
Net periodic benefit cost (credit)	178		158		181		(21)		(16)		(28)
Regulatory adjustment	57		91		77		21		16		29
Total expense recognized	235		249		258		—		—		1

CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI (1)
Net (gain) loss	(5)		28		17		(4)		1		(3)
Prior service cost	—		—		5		—		—		—
Amortization of actuarial loss	(8)		(14)		(13)		—		—		—
Amortization of prior service cost	(4)		(4)		(3)		—		—		—
Settlements	(7)		(22)		(28)		—		—		—
Total recognized in OCI	(24)		(12)		(22)		(4)		1		(3)
Total recognized in net periodic benefit cost and OCI	$	211	$	237	$	236	$	(4)	$	1	$	(2)

(1) Includes discontinued operations in 2020 and 2019.


NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
SDG&E:
NET PERIODIC BENEFIT COST
Service cost	$	35	$	31	$	30	$	5	$	4	$	4
Interest cost	25		30		34		5		6		7
Expected return on assets	(50)		(49)		(38)		(10)		(10)		(11)
Amortization of:
Prior service cost	1		2		3		—		—		2
Actuarial loss (gain)	2		3		11		(2)		(3)		(2)
Settlement charges	6		—		—		—		—		—
Net periodic benefit cost (credit)	19		17		40		(2)		(3)		—
Regulatory adjustment	34		38		14		2		3		—
Total expense recognized	53		55		54		—		—		—

CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net loss	1		6		5		—		—		—
Prior service cost	—		—		2		—		—		—
Transfer of actuarial gain	—		(7)		—		—		—		—
Transfer of prior service credit	—		(5)		—		—		—		—
Amortization of actuarial loss	—		(1)		—		—		—		—
Amortization of prior service cost	(1)		(1)		(1)		—		—		—
Total recognized in OCI	—		(8)		6		—		—		—
Total recognized in net periodic benefit cost and OCI	$	53	$	47	$	60	$	—	$	—	$	—


NET PERIODIC BENEFIT COST AND AMOUNTS RECOGNIZED IN OCI
SOUTHERN CALIFORNIA GAS COMPANY
(Dollars in millions)
	Pension benefits						Other postretirement benefits
	2021		2020		2019		2021		2020		2019
SoCalGas:
NET PERIODIC BENEFIT COST
Service cost	$	97	$	86	$	68	$	17	$	14	$	12
Interest cost	78		88		91		22		25		27
Expected return on assets	(113)		(107)		(94)		(48)		(43)		(58)
Amortization of:
Prior service cost (credit)	8		8		8		(3)		(2)		(2)
Actuarial loss (gain)	36		26		16		(7)		(7)		(8)
Settlement charges	25		—		—		—		—		—
Net periodic benefit cost (credit)	131		101		89		(19)		(13)		(29)
Regulatory adjustment	23		53		63		19		13		29
Total expense recognized	154		154		152		—		—		—

CHANGES IN PLAN ASSETS AND BENEFIT OBLIGATIONS RECOGNIZED IN OCI
Net loss	2		6		2		—		—		—
Prior service cost	—		—		3		—		—		—
Transfer of actuarial loss (gain)	—		5		(4)		—		—		—
Transfer of prior service cost (credit)	—		3		(1)		—		—		—
Amortization of actuarial loss	(1)		(1)		(1)		—		—		—
Amortization of prior service cost	(1)		(1)		—		—		—		—
Total recognized in OCI	—		12		(1)		—		—		—
Total recognized in net periodic benefit cost and OCI	$	154	$	166	$	151	$	—	$	—	$	—

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
	2021		2020		2019		2021		2020		2019
Sempra:
Discount rate	3.04	%	2.78	%	3.49	%	3.04	%	2.88	%	3.54	%
Interest crediting rate(1)(2)	1.94		1.62		2.28		1.94		1.62		2.28
Rate of compensation increase	2.70-10.00		2.70-10.00		2.70-10.00		2.70-10.00		2.70-10.00		2.70-10.00
SDG&E:
Discount rate	2.99	%	2.73	%	3.44	%	3.05	%	2.85	%	3.55	%
Interest crediting rate(1)(2)	1.94		1.62		2.28		1.94		1.62		2.28
Rate of compensation increase	3.50-10.00		2.70-10.00		2.70-10.00		3.50-10.00		2.70-10.00		2.70-10.00
SoCalGas:
Discount rate	3.04	%	2.79	%	3.50	%	3.05	%	2.90	%	3.55	%
Interest crediting rate(1)(2)	1.94		1.62		2.28		1.94	%	1.62		2.28
Rate of compensation increase	2.70-10.00		2.70-10.00		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
	2021		2020		2019		2021		2020		2019
Sempra:
Discount rate	2.78	%	3.49	%	4.29	%	2.88	%	3.54	%	4.29	%
Expected return on plan assets	6.47		7.00		7.00		4.76		4.64		6.48
Interest crediting rate(1)(2)	1.62		2.28		3.36		1.62		2.28		3.36
Rate of compensation increase	2.70-10.00		2.70-10.00		2.00-10.00		2.70-10.00		2.70-10.00		2.00-10.00
SDG&E:
Discount rate	2.73	%	3.44	%	4.29	%	2.85	%	3.55	%	4.30	%
Expected return on plan assets	6.25		7.00		7.00		4.81		5.51		6.92
Interest crediting rate(1)(2)	1.62		2.28		3.36		1.62		2.28		3.36
Rate of compensation increase	2.70-10.00		2.70-10.00		2.00-10.00		2.70-10.00		2.70-10.00		2.00-10.00
SoCalGas:
Discount rate	2.79	%	3.50	%	4.30	%	2.90	%	3.55	%	4.30	%
Expected return on plan assets	6.75		7.00		7.00		4.70		4.41		6.38
Interest crediting rate(1)(2)	1.62		2.28		3.36		1.62		2.28		3.36
Rate of compensation increase	2.70-10.00		2.70-10.00		2.00-10.00		2.70-10.00		2.70-10.00		2.00-10.00

(1) Interest crediting rate for pension benefits applies only to funded cash balance plans.

(2) Interest crediting rate for other postretirement benefits applies only to interest bearing health retirement accounts at SDG&E and SoCalGas.

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
	2021		2020		2019		2021		2020		2019
Health care cost trend rate assumed for next year	6.00	%	6.00	%	6.25	%	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
AT DECEMBER 31
	Other postretirement benefit plans
	Pre-65 retirees						Retirees aged 65 years and older
	2021		2020		2019		2021		2020		2019
Health care cost trend rate assumed for next year	6.00	%	6.00	%	6.25	%	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, 2021
	Level 1		Level 2		Total
Sempra:
Cash and cash equivalents	$	18	$	—	$	18
Equity securities:
Domestic	844		5		849
International	384		1		385
Registered investment companies:
Domestic	204		21		225
International	33		—		33
Fixed income securities:
Domestic government and government agencies	463		24		487
International government bonds	—		11		11
Domestic corporate bonds	—		413		413
International corporate bonds	—		65		65
Other	1		—		1
Total investment assets in the fair value hierarchy	$	1,947	$	540	2,487
Accounts receivable/payable, net					(20)
Investments measured at NAV:
Common/collective trusts					657
Venture capital funds and real estate funds					58
Total investment assets					$	3,182
SDG&E’s proportionate share of investment assets					$	859
SoCalGas’ proportionate share of investment assets					$	2,095

	Fair value at December 31, 2020
	Level 1		Level 2		Total
Sempra:
Cash and cash equivalents	$	7	$	—	$	7
Equity securities:
Domestic	931		—		931
International	563		—		563
Registered investment companies:
Domestic	151		37		188
International	32		—		32
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
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
Venture capital funds and real estate 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 MEASUREMENTS – INVESTMENT ASSETS OF PENSION PLANS
(Dollars in millions)
	Fair value at December 31, 2019
	Level 1		Level 2		Total
Sempra:
Cash and cash equivalents	$	17	$	—	$	17
Equity securities:
Domestic	923		—		923
International	555		1		556
Registered investment companies:
Domestic	93		2		95
International	3		—		3
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
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
Venture capital funds and real estate 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, 2021
	Level 1		Level 2		Total
SDG&E:
Equity securities:
Domestic	$	16	$	—	$	16
International	7		—		7
Registered investment companies:
Domestic	82		1		83
International	9		—		9
Fixed income securities:
Domestic government and government agencies	24		1		25
Domestic corporate bonds	—		8		8
International corporate bonds	—		1		1
Total investment assets in the fair value hierarchy	138		11		149
Accounts receivable/payable, net					(1)
Investments measured at NAV – Common/collective trusts					49
Total investment assets					197
SoCalGas:
Cash and cash equivalents	2		—		2
Equity securities:
Domestic	83		1		84
International	37		—		37
Registered investment companies:
Domestic	74		73		147
International	3		—		3
Fixed income securities:
Domestic government and government agencies	241		17		258
International government bonds	1		11		12
Domestic corporate bonds	—		337		337
International corporate bonds	—		49		49
Total investment assets in the fair value hierarchy	441		488		929
Accounts receivable/payable, net					(1)
Investments measured at NAV:
Common/collective trusts					244
Venture capital funds and real estate funds					6
Total investment assets					1,178
Other Sempra:
Equity securities:
Domestic	9		—		9
International	6		—		6
Registered investment companies – Domestic	2		—		2
Fixed income securities:
Domestic government and government agencies	2		1		3
Domestic corporate bonds	—		4		4
International corporate bonds	—		1		1
Total investment assets in the fair value hierarchy	19		6		25
Investments measured at NAV:
Common/collective trusts					7
Venture capital funds and real estate funds					1
Total other Sempra investment assets					33

Total Sempra investment assets in the fair value hierarchy	$	598	$	505
Total Sempra investment assets					$	1,408


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:
Domestic	69		7		76
International	11		—		11
Fixed income securities:
Domestic government and government agencies	38		2		40
Domestic corporate bonds	—		8		8
International corporate bonds	—		1		1
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:
Domestic	58		81		139
International	3		—		3
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
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:
Equity securities:
Domestic	10		—		10
International	6		—		6
Registered investment companies – Domestic	1		(1)		—
Fixed income securities:
Domestic government and government agencies	2		—		2
Domestic corporate bonds	—		4		4
International corporate bonds	—		1		1
Total investment assets in the fair value hierarchy	19		4		23
Investments measured at NAV – Common/collective trusts					4
Total other Sempra investment assets					27

Total Sempra investment assets in the fair value hierarchy	$	624	$	533
Total Sempra 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:
Domestic	57		8		65
International	11		—		11
Fixed income securities:
Domestic government and government agencies	32		1		33
Domestic corporate bonds	—		8		8
International corporate bonds	—		1		1
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 – Domestic	52		75		127
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
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:
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 investment assets					25

Total Sempra investment assets in the fair value hierarchy	$	602	$	478
Total Sempra 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 2022:


EXPECTED CONTRIBUTIONS
(Dollars in millions)
	Sempra		SDG&E		SoCalGas
Pension plans	$	231	$	52	$	152
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				SDG&E				SoCalGas
	Pension benefits		Other postretirement benefits		Pension benefits		Other postretirement benefits		Pension benefits		Other postretirement benefits
2022	$	276	$	46	$	71	$	9	$	171	$	33
2023	261		46		69		10		163		33
2024	253		46		66		10		158		33
2025	244		46		65		10		156		33
2026	240		48		59		10		153		33
2027-2031	1,122		226		275		48		725		166

Schedule Of Defined Benefit Plans Contributions

Employer contributions to the savings plans were as follows:


EMPLOYER CONTRIBUTIONS TO SAVINGS PLANS
(Dollars in millions)
	2021		2020		2019
Sempra	$	52	$	47	$	44
SDG&E	18		16		15
SoCalGas	28		25		24

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS - Acquisitions (Details) $ in Millions	Jan. 15, 2022 MW	Mar. 19, 2021 USD ($) MW	May 16, 2019 USD ($)	Mar. 31, 2021	Mar. 18, 2021	Dec. 31, 2020	May 31, 2019
Sharyland Holdings, LP
Business Acquisition [Line Items]
Acquired percentage interest			50.00%				50.00%
Consideration transferred			$ 95
Post closing adjustments			$ 7
Sempra Infrastructure \| ESJ Asset Acquisition
Business Acquisition [Line Items]
Purchase price		$ 65
Cash acquired		14
Debt assumed		277
Related party note payable assumed		$ 94
Subsequent acquisition, percentage		100.00%
Equity interest in acquiree, fair value		$ 34
Assets acquired		458
Liabilities assumed		$ 345
Generating capacity (in mw) \| MW		155
Intangible assets acquired		$ 190
Weighted average life of finite-lived intangible acquired		14 years
Sharyland Utilities \| Sharyland Holdings, LP
Business Acquisition [Line Items]
Acquired percentage interest			100.00%
ESJ
Business Acquisition [Line Items]
Ownership percentage held by noncontrolling owners		50.00%		50.00%	50.00%	50.00%
Subsequent Event \| Sempra Infrastructure \| ESJ Asset Acquisition
Business Acquisition [Line Items]
Generating capacity (in mw) \| MW	108

COMMITMENTS AND CONTINGENCIES - LEGAL PROCEEDINGS (Details) £ in Millions			1 Months Ended					12 Months Ended
	Feb. 18, 2022 lawsuit plaintiff	Nov. 04, 2021 USD ($)	Sep. 30, 2021 USD ($)	Oct. 31, 2020 GBP (£)	Nov. 30, 2019 customer	Oct. 31, 2018 plaintiff	Jan. 31, 2017 lawsuit	Dec. 31, 2021 USD ($) lawsuit claim	Dec. 31, 2021 GBP (£)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Sep. 27, 2021 USD ($)	Sep. 26, 2021 USD ($)	Aug. 31, 2017 lawsuit	Oct. 31, 2014 USD ($)	Oct. 31, 2014 GBP (£)
Loss Contingencies [Line Items]
Loss contingency accrual								$ 2,006,000,000
Number of alleged violations \| customer					324
Recoverable costs through insurance settlement								1,279,000,000
Reserve for Aliso Canyon costs								1,532,000,000		$ 141,000,000	$ (144,000,000)
Reserve for Aliso Canyon costs								1,980,000,000		150,000,000	9,000,000
Income (loss) from equity method investments								$ 614,000,000		294,000,000	$ 30,000,000
Proceeds from contribution from parent			$ 800,000,000
Proof of claims \| claim								28,000
Renewable energy transmission and consumption permits
Loss Contingencies [Line Items]
Other intangible assets, net related to self-supply permits								$ 14,000,000
Gas Transmission [Member]
Loss Contingencies [Line Items]
Net book value of pipeline								432,000,000
Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Loss contingency accrual								1,980,000,000		484,000,000
Net book value Of Aliso Canyon Natural Gas Storage Facility								883,000,000
Recorded estimated costs								3,221,000,000
Reserve for Aliso Canyon costs								1,983,000,000
Insurance receivable for Aliso Canyon costs								360,000,000
Proceeds from insurance settlement								$ 919,000,000
Shareholder Derivative Complaint [Member]
Loss Contingencies [Line Items]
Number of pending claims \| lawsuit								4						3
HMRC VAT Claim [Member]
Loss Contingencies [Line Items]
VAT tax claim paid upon appeal															$ 138,000,000
Damage awarded								$ 61,000,000	£ 45
Loss Contingency, Costs And Interest Assessed				£ 21				28,000,000
HMRC VAT Claim [Member] \| Parent Company
Loss Contingencies [Line Items]
VAT tax claim paid upon appeal \| £																£ 86
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
Property Class Action [Member] \| Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Estimate of possible loss													$ 40,000,000
Complaints Filed by Firefighters [Member] \| Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of plaintiffs \| plaintiff						51
R B S Sempra Commodities
Loss Contingencies [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue								50,000,000
Income (loss) from equity method investments										100,000,000
Individual Plaintiff Litigation \| Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Percentage of plaintiffs represented (as a percent)													80.00%
Estimate of possible loss													$ 1,800,000,000
Acceptance rate of plaintiffs (as a percent)													97.00%
Business Class Action \| Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Estimate of possible loss												$ 100,000
Proposition 65 Claims
Loss Contingencies [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue		$ 2,000,000
Subsequent Event \| Aliso Canyon Natural Gas Storage Facility Gas Leak [Member]
Loss Contingencies [Line Items]
Number of pending claims \| lawsuit	390
Number of plaintiffs \| plaintiff	36,000
Insurance Receivable for Aliso Canyon Costs [Member] \| Aliso Canyon Natural Gas Storage Facility Gas Leak [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]
Loss Contingencies [Line Items]
Loss contingency accrual								1,590,000,000		307,000,000
Loss accrual, net of tax								$ 1,150,000,000		$ 233,000,000

SAN ONOFRE NUCLEAR GENERATING STATION - ASSET RETIREMENT OBLIGATION AND SPENT NUCLEAR FUEL (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Decommissioning liability	$ 568
2022	79
2023	66
2024	77
2025	46
2026	52
Thereafter	$ 718

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SDG&E - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Common stock	Common stock Cumulative Effect, Period of Adoption, Adjusted Balance	Retained earnings	Retained earnings Cumulative Effect, Period of Adoption, Adjustment	Retained earnings Cumulative Effect, Period of Adoption, Adjusted Balance	Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss) Cumulative Effect, Period of Adoption, Adjustment	Accumulated other comprehensive income (loss) Cumulative Effect, Period of Adoption, Adjusted Balance	Sempra Energy shareholders' equity	Sempra Energy shareholders' equity Cumulative Effect, Period of Adoption, Adjustment	Sempra Energy shareholders' equity Cumulative Effect, Period of Adoption, Adjusted Balance	Non- controlling interests	Non- controlling interests Cumulative Effect, Period of Adoption, Adjusted Balance
Beginning Balance at Dec. 31, 2018	$ 4,258		$ 4,256	$ 866	$ 866	$ 3,390		$ 3,392	$ (20)		$ (24)	$ 6,015		$ 6,015	$ 100	$ 100
Beginning Balance (Accounting Standards Update 2018-02) at Dec. 31, 2018		$ (2)					$ 2			$ (4)			$ (2)
Net income	642					642						767			7
Other comprehensive income	1								1			(4)			2
Equity contribution from Sempra Energy	322			322								322
Contributions	175														175
Distributions	(3)			5								5			(3)
Deconsolidations	(281)														(281)
Common stock dividends declared	(150)					(150)						(1,086)
Ending balance at Dec. 31, 2019	4,748		$ 21,796	866	$ 7,480	3,883		$ 11,123	(23)		$ (939)	7,100		$ 19,922	0	$ 1,874
Net income	505					505						824			172
Other comprehensive income	(8)								(8)			6			(24)
Contributions	1														1
Distributions	(1)														(1)
Deconsolidations	(236)														(236)
Common stock dividends declared	(100)					(100)						(200)
Ending balance at Dec. 31, 2020	5,144			866		4,287			(31)			7,730
Net income	(426)					(426)						819			145
Other comprehensive income	171								160			160			11
Equity contribution from Sempra Energy	800			800
Contributions	4														4
Deconsolidations	1														1
Common stock dividends declared	(75)					(75)						(300)
Ending balance at Dec. 31, 2021	$ 5,442			$ 1,666		$ 3,785			$ (31)			$ 8,249			$ 0

Amount after tax and reclassification adjustments of other comprehensive income (loss).

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124509347&loc=SL7669619-108580

Reference 2: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=124431353&loc=SL124442407-227067

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=123467817&loc=d3e21463-112644

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32136-110900

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SX 210.5-03(21))
-URI http://asc.fasb.org/extlink&oid=123367319&loc=SL114868664-224227

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 55
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=124507222&loc=d3e1436-108581

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 20
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32211-110900

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6450520&loc=d3e32583-110901

Reference 9: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=124431353&loc=SL124442411-227067

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1B
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124509347&loc=SL7669625-108580

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-04(23))
-URI http://asc.fasb.org/extlink&oid=120399700&loc=SL114874048-224260

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 220
-Section S99
-Paragraph 1
-Subparagraph (SX 210.7-04(19))
-URI http://asc.fasb.org/extlink&oid=120400993&loc=SL114874131-224263

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1A
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=124509347&loc=SL7669619-108580

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (a)(1)
-URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 9
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22663-107794

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(4)(i))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442526-122756

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(4)(i))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442552-122756

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8736-108599

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8933-108599

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(5))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442526-122756

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(4)(iv))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442552-122756

Reference 12: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=124431353&loc=SL124452729-227067

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8906-108599

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 230
-SubTopic 10
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=123570139&loc=d3e3000-108585

Reference 15: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 19
-URI http://asc.fasb.org/extlink&oid=123454820&loc=SL4569616-111683

Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=114001798&loc=d3e33918-111571

Reference 17: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8933-108599

Reference 18: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(4)(iii)(A))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442552-122756

Reference 19: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721683-107760

Reference 20: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 21: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=123596393&loc=d3e14064-108612

Reference 22: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 235
-Section S99
-Paragraph 1
-Subparagraph (SX 210.9-05(b)(2))
-URI http://asc.fasb.org/extlink&oid=120399901&loc=d3e537907-122884

Reference 23: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8924-108599

Reference 24: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 45
-Paragraph 1B
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=124509347&loc=SL7669625-108580

Reference 25: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(4)(iv))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442526-122756

Reference 26: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(4)(iii)(A))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442526-122756

Reference 27: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(5))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442552-122756

Reference 28: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1B
-Subparagraph (SX 210.13-02(a)(4)(iii)(B))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442552-122756

Reference 29: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S99
-Paragraph 1A
-Subparagraph (SX 210.13-01(a)(4)(ii))
-URI http://asc.fasb.org/extlink&oid=124359900&loc=SL124442526-122756

Reference 30: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 50
-Paragraph 1A
-Subparagraph (c)(1)
-URI http://asc.fasb.org/extlink&oid=109239629&loc=SL4573702-111684

Reference 31: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4J
-URI http://asc.fasb.org/extlink&oid=120409616&loc=SL4591551-111686

Reference 32: http://www.xbrl.org/2003/role/exampleRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4K
-URI http://asc.fasb.org/extlink&oid=120409616&loc=SL4591552-111686

Reference 33: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22658-107794

Amount of stockholders' equity (deficit), net of receivables from officers, directors, owners, and affiliates of the entity, attributable to both the parent and noncontrolling interests. Amount excludes temporary equity. Alternate caption for the concept is permanent equity.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 45
-Paragraph 24
-URI http://asc.fasb.org/extlink&oid=124436220&loc=d3e21930-107793

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=120397183&loc=d3e187085-122770

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 45
-Paragraph 23
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124436220&loc=d3e21914-107793

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 7
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22644-107794

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 220
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=124431353&loc=SL124442411-227067

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 16
-URI http://asc.fasb.org/extlink&oid=123454820&loc=SL4568740-111683

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (e)(3)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 11: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 50
-Paragraph 28
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=123596393&loc=d3e14064-108612

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 45
-Paragraph 5
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124436220&loc=d3e21711-107793

Reference 13: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 323
-SubTopic 10
-Section 50
-Paragraph 3
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=114001798&loc=d3e33918-111571

Reference 14: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(g)(1)(ii))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

Reference 15: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6450520&loc=d3e32583-110901

Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (d)(2)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 17: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 17
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32136-110900

Reference 18: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (d)(3)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 19: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (f)(2)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 20: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (f)(2)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 21: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 55
-Paragraph 4I
-URI http://asc.fasb.org/extlink&oid=120409616&loc=SL4590271-111686

Reference 22: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (f)(1)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 23: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 830
-SubTopic 30
-Section 45
-Paragraph 20
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=118261656&loc=d3e32211-110900

Reference 24: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 810
-SubTopic 10
-Section 45
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=123454820&loc=SL4568447-111683

Reference 25: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (f)(1)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 26: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(3)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 27: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 28: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (a)(3)(iii)(03)

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net (loss) income	$ (426)	$ 505	$ 642
Other comprehensive income (loss):
Total other comprehensive (loss) income	171	(8)	1
Pretax amount
Net (loss) income	(736)	601	762
Other comprehensive income (loss):
Financial instruments	191	(146)	1
Pension and other postretirement benefits	28	(12)	1
Total other comprehensive (loss) income	213	(12)	2
Comprehensive income	(736)	589	764
Income tax (expense) benefit
Net (loss) income	310	(96)	(120)
Other comprehensive income (loss):
Financial instruments	(47)	33	0
Pension and other postretirement benefits	(6)	4	(1)
Total other comprehensive (loss) income	(53)	4	(1)
Comprehensive income	310	(92)	(121)
Net-of-tax amount
Net (loss) income	(426)	505	642
Other comprehensive income (loss):
Financial instruments	144	(113)	1
Pension and other postretirement benefits	22	(8)	0
Total other comprehensive (loss) income	160	(8)	1
Comprehensive income	$ (426)	$ 497	$ 643

Amount after tax and reclassification adjustments of other comprehensive income (loss).

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

INVESTMENTS IN UNCONSOLIDATED ENTITIES

INCOME TAXES - UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reconciliation of Unrecognized Tax Benefits
Beginning balance	$ 68	$ 64	$ 61
Increase in prior period tax positions	1	1	1
Decrease in prior period tax positions	(2)	(1)	0
Increase in current period tax positions	3	3	2
Settlements with taxing authorities	0	0	(32)
Expiration of statutes of limitations	0	0	(1)
Ending balance	72	68	64
Of the total, amounts related to tax positions that, if recognized, in future years, would decrease the effective tax rate	(63)	(59)	(55)
Of the total, amounts related to tax positions that, if recognized, in future years, would increase the effective tax rate	$ 33	$ 30	$ 26

INVESTMENTS IN UNCONSOLIDATED ENTITIES

12 Months Ended

Dec. 31, 2021

Investments [Abstract]

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’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax Expense 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,
	2021		2020		2019		2021		2020		2019
Sempra Texas Utilities:
Oncor Holdings(1)	100	%	100	%	100	%	$	12,947	$	12,440	$	11,519
Sempra Texas Utilities:
Sharyland Holdings(2)	50		50		50		$	100	$	102	$	100
Sempra Infrastructure:
Cameron LNG JV(3)	50.2		50.2		50.2		514		433		1,256
ESJ JV(4)	—		50		50		—		34		39
IMG JV(5)	40		40		40		523		440		337
TAG JV(6)	50		50		50		388		378		365
Total other equity method investments							1,525		1,387		2,097
Other							—		1		6
Total other investments							$	1,525	$	1,388	$	2,103

(1) The carrying value of our equity method investment is $2,844, $2,833 and $2,823 higher than the underlying equity in the net assets of the investee at December 31, 2021, 2020 and 2019, respectively, due to $2,868 of equity method goodwill and $69 in basis differences in AOCI, offset by $93, $104 and $114 at December 31, 2021, 2020 and 2019, respectively, due to a tax sharing liability to TTI under a tax sharing agreement.

(2) The carrying value of our equity method investment is $42 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 $276, $259 and $263 higher than the underlying equity in the net assets of the investee at December 31, 2021, 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.

(4) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. After the acquisition, ESJ is no longer accounted for as an equity method investment. The carrying value of our equity method investment is $12 higher than the underlying equity in the net assets of the investee at December 31, 2020 and 2019 due to the remeasurement of our retained investment to fair value in 2014.

(5) The carrying value of our equity method investment is $5 higher than the underlying equity in the net assets of the investee due to guarantees.

(6) The carrying value of our equity method investment is $130 higher than the underlying equity in the net assets of the investee due to equity method goodwill.


EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX(1):
Sempra Texas Utilities:
Sharyland Holdings	$	5	$	3	$	2
Sempra Infrastructure:
Cameron LNG JV(2)	559		391		24
Sempra Renewables:
Wind assets	—		—		5
Parent and other:
RBS Sempra Commodities	50		(100)		—
Other	—		—		(1)
	614		294		30
EARNINGS RECORDED NET OF INCOME TAX:
Sempra Texas Utilities:
Oncor Holdings	617		577		526
Sempra Infrastructure:
ESJ JV	2		5		2
IMG JV	83		103		9
TAG JV	27		36		13
	729		721		550
Total	$	1,343	$	1,015	$	580

(1) We provide our ETR calculation in Note 8.

(2) Includes $3 of basis differences in equity earnings related to AOCI in 2021.

We disclose distributions received from our investments, by segment, in the table below.


DISTRIBUTIONS FROM INVESTMENTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra Texas Utilities	$	688	$	286	$	246
Sempra Infrastructure	672		1,176		2
Sempra Renewables	—		—		1
Parent and other	—		—		7
Total	$	1,360	$	1,462	$	256

At December 31, 2021, 2020 and 2019 our share of the undistributed earnings of equity method investments was $1.5 billion, $1.1 billion and $634 million, respectively, including $1.1 billion at December 31, 2021 in undistributed earnings from investments for which we have more than 50% equity interests.

SEMPRA TEXAS UTILITIES

Oncor Holdings

We account for our 100% ownership interest in Oncor Holdings, which owns an 80.25% interest in Oncor, as an equity method investment. Sempra 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.

Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra. 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,
	2021		2020		2019
Operating revenues	$	4,764	$	4,511	$	4,347
Operating expense	(3,397)		(3,224)		(3,135)
Income from operations	1,367		1,287		1,212
Interest expense	(413)		(405)		(375)
Income tax expense	(163)		(146)		(131)
Net income	760		703		643
Noncontrolling interest held by TTI	(152)		(141)		(129)
Earnings attributable to Sempra(1)	608		562		514

	At December 31,
	2021		2020		2019
Current assets	$	1,039	$	1,045	$	913
Noncurrent assets	29,481		28,022		26,012
Current liabilities	2,220		1,120		1,626
Noncurrent liabilities	15,281		15,611		14,125
Noncontrolling interest held by TTI	2,916		2,737		2,473

(1) Excludes adjustments to equity earnings related to amortization of a tax sharing liability associated with a tax sharing arrangement and changes in basis differences in AOCI within the carrying value of our equity method investment.

In 2021, 2020 and 2019, Sempra contributed $566 million, $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.

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 INFRASTRUCTURE

Cameron LNG JV

Cameron LNG JV was formed in October 2014 and is a JV between Sempra and three project partners, TotalEnergies 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 operations, Sempra Infrastructure capitalized interest of $33 million in 2019 related to this equity method investment. In 2021, 2020 and 2019, Sempra Infrastructure contributed $2 million, $54 million and $77 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 JV 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, 2021 with maturity dates ranging between 2031 and 2039.

Interest. The weighted-average all-in cost of the loans that remain outstanding under the original Loan Facility Agreements 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. 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 3.69%.

Guarantees. In March 2021, Cameron LNG JV reached financial completion of the three-train liquefaction project, and Sempra’s guarantees related to agreements entered into in August 2014 and December 2019, for the benefit of all of Cameron LNG JV’s creditors under the original Loan Facility Agreements and the senior secured notes, were terminated.

In August 2014, Sempra 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, starting six months after financial completion of the three-train Cameron LNG JV project, Sempra 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 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 when due; insolvency of Cameron LNG JV; abandonment of the project; expropriation; and unenforceability or termination of the finance documents.

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 were 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 and the other project partners.

Sempra Promissory Note for SDSRA Distribution

Cameron LNG JV’s debt agreements require Cameron LNG JV to maintain the SDSRA, which is an additional reserve account beyond the Senior Debt Service Accrual Account, where funds accumulate from operations to satisfy senior debt obligations due and payable on the next payment date. Both accounts can be funded with cash or authorized investments. In June 2021, Sempra Infrastructure received a distribution of $165 million based on its proportionate share of the SDSRA, for which Sempra provided a promissory note and letters of credit to secure a proportionate share of Cameron LNG JV’s obligation to fund the SDSRA. Sempra’s maximum exposure to loss is replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA, or $165 million. We recorded a guarantee liability of $22 million in June 2021, with an associated carrying value of $22 million at December 31, 2021, for the fair value of the promissory note, which is being reduced over the duration of the guarantee through Sempra Infrastructure’s investment in Cameron LNG JV. The guarantee will terminate upon full repayment of Cameron LNG JV’s debt, scheduled to occur in 2039, or replenishment of the amount withdrawn by Sempra Infrastructure from the SDSRA.

Sempra 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 used its $753 million share of the proceeds for working capital and other general corporate purposes, including the repayment of indebtedness.

Sempra Infrastructure’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 has provided a guarantee pursuant to a Support Agreement, as amended on June 29, 2021, under which:

▪Sempra has severally guaranteed repayment of the bank debt plus accrued and unpaid interest if CFIN fails to pay the external lenders;

▪the external lenders may exercise an option to put the bank debt to Sempra Infrastructure upon the occurrence of certain events, including a failure by CFIN to meet its payment obligations under the bank debt;

▪the external lenders will put some or all of the bank debt to Sempra Infrastructure on the fifth, tenth, or fifteenth anniversary date of the affiliate loans, except the portion of the debt owed to any external lender that has elected not to participate in the put option six months prior to the respective anniversary date;

▪Sempra Infrastructure also has a right to call the bank debt back from, or to refinance the bank debt with, the external lenders at any time; and

▪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 Infrastructure.

In exchange for this guarantee, the external lenders will pay a guarantee fee that is based on the credit rating of Sempra’s long-term senior unsecured non-credit enhanced debt rating, which guarantee fee Sempra Infrastructure will recognize as interest income as earned. Sempra’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, 2021, the fair value of the Support Agreement was $7 million, which is included in Other Current Assets on Sempra’s Consolidated Balance Sheet.

ESJ JV

As we discuss in Note 5, in March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary. Prior to the acquisition date, Sempra Infrastructure owned 50% of ESJ and accounted for its interest as an equity method investment.

IMG JV

Sempra Infrastructure has a 40% interest in IMG JV, a JV with a subsidiary of TC Energy Corporation, 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 operations in September 2019.

SEMPRA RENEWABLES

Sempra Renewables completed the sale of its remaining wind assets and investments in April 2019. We discuss this divestiture further in Note 5.

RBS SEMPRA COMMODITIES

RBS Sempra Commodities is a United Kingdom limited liability partnership formed by Sempra and RBS in 2008 to own and operate the commodities-marketing businesses previously operated through wholly owned subsidiaries of Sempra. 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 2018, we fully impaired our remaining equity method investment in RBS Sempra Commodities. In 2020, we recorded a charge of $100 million in Equity Earnings on Sempra’s Consolidated Statement of Operations for losses from our investment in RBS Sempra Commodities. In 2021, we reduced this charge by $50 million based on the favorable outcome of a settlement with HMRC and revised assumptions on the High Court of Justice case. 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 and RBS Sempra Commodities) 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’s other equity method investments.


SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS
(Dollars in millions)
	Years ended December 31,
	2021(1)		2020		2019(2)
Gross revenues	$	2,721	$	2,341	$	798
Operating expense	(719)		(706)		(372)
Income from operations	2,002		1,635		426
Interest expense	(548)		(514)		(401)
Net income/Earnings(3)	1,388		1,132		85


	At December 31,
	2021(1)		2020		2019(2)
Current assets	$	788	$	1,035	$	1,124
Noncurrent assets	14,686		15,304		15,039
Current liabilities	1,230		1,342		1,232
Noncurrent liabilities	11,807		12,863		11,438

(1) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary.

(2) 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.

(3) Except for our investments in Mexico, there was no income tax recorded by the entities, as they are primarily domestic partnerships.

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - ANTIDILUTIVE SECURITIES EXCLUDED FROM COMPUTATION OF EPS (Details) - shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Stock options, RSAs and RSUs
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	211,155	187,028	80,281
Convertible Preferred Stock
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive securities excluded from the computation of EPS	2,272,117	17,889,365	17,471,375

COMMITMENTS AND CONTINGENCIES - LESSOR INFORMATION (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Jul. 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessor, Lease, Description [Line Items]
Carrying value	$ 44
Net investment in lease	62
Selling profit	$ 18
Property, plant and equipment		$ 23,104	$ 21,180	$ 19,362
Accumulated depreciation		(6,861)	(6,437)	(6,038)
Property, plant and equipment, net		16,243	14,743	13,324
Operating leases
2022		272
2023		272
2024		273
2025		272
2026		272
Thereafter		3,031
Total undiscounted cash flows		4,392
Fixed lease payments		256	195	200
Variable lease payments		10	1	6
Total revenues from operating leases		266	196	206
Depreciation expense		711	649	598
Sales-type leases
2022		16
2023		16
2024		17
2025		17
2026		9
Thereafter		0
Total undiscounted cash flows		75
Present value of lease payments (recognized as lease receivable)		55
Difference between undiscounted cash flows and discounted cash flows		20
Income recognized at lease commencement		18	1	0
Interest income		4	1	0
Total revenues from sales-type lease		22	2	0
Other current assets
Sales-type leases
Present value of lease payments (recognized as lease receivable)		9
Other long-term assets
Sales-type leases
Present value of lease payments (recognized as lease receivable)		46
Operating Leases, Assets
Lessor, Lease, Description [Line Items]
Property, plant and equipment		1,499	1,092	1,038
Accumulated depreciation		(276)	(228)	(179)
Property, plant and equipment, net		1,223	864	859
Operating leases
Depreciation expense		$ 48	$ 39	$ 38

CONSOLIDATED BALANCE SHEETS - SDG&E (Parentheticals) - shares	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Stockholders' Equity Attributable to Parent [Abstract]
Preferred stock, shares authorized (in shares)	50,000,000	11,000,000	11,000,000
Preferred stock, shares issued (in shares)	0	0
Common stock, shares authorized (in shares)	750,000,000	100,000,000	100,000,000
Common stock, shares outstanding (in shares)	316,919,782	288,470,244	291,712,925	273,769,513

CONSOLIDATED STATEMENTS OF CASH FLOWS - SDG&E - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net income	$ (426)	$ 505	$ 642
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	716	654	602
Deferred income taxes and investment tax credits	(494)	(112)	88
Other	19	59	(5)
Net change in other working capital components:
Accounts receivable	(383)	(101)	(73)
Due to/from unconsolidated affiliates, net	(25)	(27)	(1)
Income taxes receivable/payable, net	(43)	189	(156)
Inventories	(18)	(19)	1
Other current assets	(21)	(12)	(9)
Accounts payable	181	64	(7)
Regulatory balancing accounts, net	306	(160)	114
Other current liabilities	(92)	(21)	(21)
Wildfire fund, current and noncurrent	0	0	(323)
Changes in other noncurrent assets and liabilities, net	(304)	178	(322)
Net cash provided by operating activities	1,033	1,526	868
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,984)	(1,843)	(1,439)
Purchases of nuclear decommissioning trust assets	(961)	(1,439)	(914)
Proceeds from sales of nuclear decommissioning trust assets	961	1,439	914
Other	0	0	1
Net cash (used in) provided by investing activities	(1,984)	(1,843)	(1,438)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(75)	(100)	(150)
Equity contribution from Sempra Energy	800	0	0
Issuances of debt (maturities greater than 90 days)	0	949	349
Payments on debt (maturities greater than 90 days) and finance leases	(12)	(12)	(6)
Increase (decrease) in short-term debt, net	272	(517)	374
Proceeds from sales of noncontrolling interests, net	0	0	172
Debt issuance costs	0	(8)	(4)
Net cash provided by financing activities	984	311	562
Increase (decrease) in cash and cash equivalents	33	(6)	(8)
Cash and cash equivalents, January 1	4	10	18
Cash and cash equivalents, December 31	37	4	10
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	151	146	126
Income tax payments (refunds), net	227	19	188
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	222	208	205
Increase in finance lease obligations for investment in PP&E	19	47	22
Increase in ARO for investment in PP&E	$ 125	$ 107	$ 35

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - OTHER NONCONTROLLING INTERESTS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 21, 2021	Oct. 01, 2021	Dec. 31, 2020	Dec. 31, 2019
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 1,418			$ 1,541	$ 1,856
SI Partners
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		10.00%
SI Partners \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	20.00%		0.20%
Other noncontrolling interests	$ 1,384			0	0
SI Partners Subsidiaries \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Other noncontrolling interests	$ 34			$ 1,540	$ 1,622
SI Partners Subsidiaries \| Sempra Infrastructure \| Minimum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.10%			17.50%	10.00%
SI Partners Subsidiaries \| Sempra Infrastructure \| Maximum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	16.60%			29.80%	46.30%
PXISE Energy Solutions LLC \| Corporate and Other
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners				20.00%	20.00%
Other noncontrolling interests	$ 0			$ 1	$ 1
Chilquinta Energia subsidiaries \| Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Other noncontrolling interests	0			0	$ 23
Chilquinta Energia subsidiaries \| Discontinued Operations, Held-for-sale \| Minimum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners					19.70%
Chilquinta Energia subsidiaries \| Discontinued Operations, Held-for-sale \| Maximum
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners					43.40%
Luz del Sur \| Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners					16.40%
Other noncontrolling interests	0			0	$ 205
Tecsur \| Discontinued Operations, Held-for-sale
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners					9.80%
Other noncontrolling interests	$ 0			$ 0	$ 5

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Revenues
Natural Gas	$ 838	$ 694	$ 658
Electric	4,666	4,619	4,267
Energy-related businesses	1,866	1,345	1,381
Total revenues	12,857	11,370	10,829
EXPENSES AND OTHER INCOME
Operation and maintenance	(4,338)	(3,940)	(3,466)
Aliso canyon litigation and regulatory matters	(1,593)	(307)	0
Depreciation and amortization	(1,855)	(1,666)	(1,569)
Franchise fees and other taxes	(596)	(543)	(496)
Impairment losses	0	0	(37)
Gain (loss) on sale of assets	36	(3)	63
Other income (expense), net	(14)	(28)	(55)
Interest income	1	2	2
Interest expense	(157)	(158)	(141)
Income from continuing operations before income taxes and equity earnings	(736)	601	762
Income tax expense	310	(96)	(120)
Equity earnings	1,343	1,015	580
Income from continuing operations, net of tax	1,463	2,255	1,999
Income from discontinued operations, net of income tax	0	1,850	363
Net income	(426)	505	642
Earnings attributable to noncontrolling interest	0	0	(7)
Preferred dividends	(1)	(1)	(1)
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings attributable to common shares	$ (427)	$ 504	$ 641
Basic EPS:
Earnings from continuing operations attributable to common shares	$ 4.03	$ 6.61	$ 6.22
Earning from discontinued operations	0	6.32	1.18
Earnings	$ 4.03	$ 12.93	$ 7.40
Weighted-average common shares outstanding for basic EPS (in shares)	311,755	291,077	277,904
Diluted EPS:
Earnings from continuing operations - Diluted EPS (in dollars per share)	$ 4.01	$ 6.58	$ 6.13
Earnings from discontinued operations	0	6.30	1.16
Earnings	$ 4.01	$ 12.88	$ 7.29
Weighted Average Common Shares Outstanding	313,036	292,252	282,033
Cost of natural gas
EXPENSES AND OTHER INCOME
Operating expenses	$ (1,597)	$ (925)	$ (1,139)
Cost of electric fuel and purchased power
EXPENSES AND OTHER INCOME
Operating expenses	(1,010)	(1,187)	(1,188)
Energy-related businesses cost of sales
EXPENSES AND OTHER INCOME
Operating expenses	$ (611)	$ (276)	$ (344)

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - NONCONTROLLING INTERESTS (Details) $ / shares in Units, $ / shares in Units, $ in Millions, $ in Billions				1 Months Ended							3 Months Ended	12 Months Ended
	Oct. 01, 2021 USD ($)	Mar. 30, 2020 USD ($)	Feb. 07, 2019	Oct. 31, 2021 USD ($)	Sep. 30, 2021 USD ($) $ / shares shares	Sep. 30, 2021 MXN ($) $ / shares shares	Jul. 31, 2021 USD ($)	May 31, 2021 USD ($) shares	Dec. 31, 2020	Feb. 28, 2019 USD ($)	Mar. 31, 2020 USD ($)	Dec. 31, 2021 USD ($) shares	Dec. 31, 2020 USD ($) shares	Dec. 31, 2019 USD ($) shares	Feb. 16, 2022 shares	Dec. 21, 2021 USD ($)	Oct. 15, 2021 $ / shares	Apr. 30, 2021	Dec. 31, 2018
Noncontrolling Interest [Line Items]
Increase in the noncontrolling interest balance from the sale of noncontrolling interest												$ 2,712	$ 28	$ 5
Common stock exchange ratio								0.0323
Stock repurchased in the period												339	566	26
Increase in shareholders' equity					$ 72
Income tax expense (benefit)												(310)	96	120
Equitization of long-term debt for deficit held by NCI													(22)
Common Stock, Shares, Acquired \| shares					51,014,545	51,014,545		381,015,194
Noncontrolling Interest, Decrease from Deconsolidation												(1)	236	281
Proceeds from sales of noncontrolling interests, net												$ 0	$ 0	$ 172
Common stock acquired					$ 202	$ 4.0
Share price (in dollars per share) \| (per share)					$ 3.95	$ 78.97
Shares issued in IEnova exchange offer \| shares								12,306,777				12,306,777	0	0
Sempra Infrastructure
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
IEnova
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners												99.90%
Noncontrolling interest, percent of funding	20.00%
IEnova \| Sempra LNG
Noncontrolling Interest [Line Items]
Ownership percentage sold									16.60%
IEnova \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)									70.20%				70.20%	66.60%					66.50%
Bay Gas \| Sempra LNG
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)			9.10%
Cash consideration (fair value of total consideration)										$ 20
ICM Ventures Holdings B.V. [Member] \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners							17.50%
Ownership interest (as a percent)											82.50%			53.70%
Payments to acquire minority interest							$ 7
Liberty Gas Storage [Member] \| Sempra LNG
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners		24.60%
IEnova
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)	99.90%				99.90%	99.90%		96.40%										70.20%
Increase in shareholders' equity					$ 17			$ 1,400
Share price (in pesos per share) \| $ / shares																	$ 78.97
Noncontrolling Interest, Decrease from Deconsolidation					188			1,400
Purchase of noncontrolling interest, transaction costs					$ 4			$ 12
Noncontrolling interest, remaining shares of noncontrolling interest \| shares												1,212,981
IEnova \| Subsequent Event
Noncontrolling Interest [Line Items]
Noncontrolling interest, remaining shares of noncontrolling interest \| shares															629,784
IEnova \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership interest (as a percent)												99.90%
SI Partners
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners																10.00%
Ownership interest in partnership (as a percent)	80.00%
Distribution requirement (as a percent)	85.00%
SI Partners \| Abu Dhabi Investment Authority
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest, purchase price																$ 1,800
Sale of noncontrolling interest (as a percent)																10.00%
SI Partners \| KKR
Noncontrolling Interest [Line Items]
Sale of noncontrolling interest (as a percent)				20.00%
Income tax expense (benefit)				$ 72
SI Partners \| Sempra Infrastructure
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners	0.20%											20.00%
Sale of noncontrolling interest, purchase price	$ 3,400
Increase in the noncontrolling interest balance from the sale of noncontrolling interest	1,300
Sale of noncontrolling interest, change in equity	1,400
Sale of noncontrolling interest, transaction costs	173
Sale of noncontrolling interest, deferred income tax liability	490
Sale of noncontrolling interest, transaction costs reimbursed	$ 149
Ownership interest (as a percent)												80.00%
Bay Gas
Noncontrolling Interest [Line Items]
Sale of interest (as a percent)			100.00%
Liberty Gas Storage, LLC
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 \| Liberty Gas Storage [Member] \| Sempra LNG
Noncontrolling Interest [Line Items]
Ownership percentage held by noncontrolling owners									100.00%				100.00%

EMPLOYEE BENEFIT PLANS - NARRATIVE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Dedicated assets in support of certain benefit plans	$ 567	$ 512	$ 488
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	2
Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Plan amendments	0	0	0
Oncor Electric Delivery Company LLC \| Other Postretirement Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Gain (loss) arising during the period	$ 7	$ 11	$ 27

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - COMMON STOCK ACTIVITY (Details) - shares	1 Months Ended	12 Months Ended
	May 31, 2021	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Common stock, shares authorized (in shares)		750,000,000	100,000,000	100,000,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common shares outstanding, January 1		288,470,244	291,712,925	273,769,513
Conversion of mandatory convertible preferred stock		18,037,745	0	0
Shares issued in IEnova exchange offer	12,306,777	12,306,777	0	0
Shares issued under forward sale agreements		0	0	16,906,185
RSUs vesting		686,916	896,839	463,012
Stock options exercised		50,671	4,400	52,540
Savings plan issuance		0	201,431	475,774
Common stock investment plan		0	42,955	199,253
Issuance of RSUs held in our Deferred Compensation Plan		102,238	103,552	59,470
Shares repurchased		(2,734,809)	(4,491,858)	(212,822)
Common shares outstanding, December 31		316,919,782	288,470,244	291,712,925

DERIVATIVE FINANCIAL INSTRUMENTS - NOTIONALS AMOUNTS (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cross-currency swaps
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 306,000,000	$ 306,000,000	$ 306,000,000
Other foreign currency derivatives
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	106,000,000	1,764,000,000	1,796,000,000
Cash flow hedges \| Interest rate instruments
Derivatives, Fair Value [Line Items]
Notional amount of derivative liability	$ 462,000,000	$ 1,486,000,000	$ 1,445,000,000

FAIR VALUE MEASUREMENTS (Tables)

12 Months Ended

Dec. 31, 2021

Fair Value Disclosures [Abstract]

Recurring Fair Value Measures Table


RECURRING FAIR VALUE MEASURES – SEMPRA
(Dollars in millions)
	Fair value at December 31, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Short-term investments held in Rabbi Trust	81		—		—		81
Interest rate instruments	—		6		—		6
Foreign exchange instruments	—		2		—		2

Commodity contracts not subject to rate recovery	—		46		—		46
Effect of netting and allocation of collateral(2)	58		—		—		58
Commodity contracts subject to rate recovery	12		1		69		82
Effect of netting and allocation of collateral(2)	31		9		6		46
Support Agreement, net of related guarantee fees	—		—		7		7
Total	$	601	$	649	$	82	$	1,332
Liabilities:
Interest rate instruments	$	—	$	8	$	—	$	8
Foreign exchange instruments	—		1		—		1
Interest rate and foreign exchange instruments	—		131		—		131
Commodity contracts not subject to rate recovery	—		31		—		31
Commodity contracts subject to rate recovery	—		35		15		50


Total	$	—	$	206	$	15	$	221

(1) Excludes 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 – SEMPRA
(Dollars in millions)
	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	9	$	(6)	$	—	$	3
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)	408		620		—		1,028
Short-term investments held in Rabbi Trust	61		—		—		61
Interest rate instruments	—		1		—		1
Foreign exchange instruments	—		24		—		24
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	$	515	$	655	$	134	$	1,304
Liabilities:
Interest rate instruments	$	—	$	47	$	—	$	47
Foreign exchange instruments	—		11		—		11
Interest rate and foreign exchange instruments	—		128		—		128
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

(1) Excludes 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 – SEMPRA
(Dollars in millions)
	Fair value at December 31, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	14	$	2	$	—	$	16
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)	563		527		—		1,090
Short-term investments held in Rabbi Trust	66		—		—		66
Interest rate instruments	—		3		—		3
Foreign exchange instruments	—		21		—		21
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	$	688	$	578	$	101	$	1,367
Liabilities:
Interest rate instruments	$	—	$	28	$	—	$	28
Foreign exchange instruments	—		7		—		7
Interest rate and foreign exchange instruments	—		122		—		122
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 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, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	13	$	(10)	$	—	$	3
Equity securities	358		6		—		364
Debt securities:
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies	48		8		—		56
Municipal bonds	—		321		—		321
Other securities	—		260		—		260
Total debt securities	48		589		—		637
Total nuclear decommissioning trusts(1)	419		585		—		1,004
Commodity contracts subject to rate recovery	12		—		69		81
Effect of netting and allocation of collateral(2)	22		—		6		28
Total	$	453	$	585	$	75	$	1,113
Liabilities:


Commodity contracts subject to rate recovery	$	—	$	—	$	15	$	15

Total	$	—	$	—	$	15	$	15

	Fair value at December 31, 2020
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	9	$	(6)	$	—	$	3
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)	408		620		—		1,028
Commodity contracts subject to rate recovery	5		—		121		126
Effect of netting and allocation of collateral(2)	18		—		6		24
Total	$	431	$	620	$	127	$	1,178
Liabilities:
Commodity contracts subject to rate recovery	$	—	$	—	$	52	$	52
Total	$	—	$	—	$	52	$	52

(1) Excludes 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, 2019
	Level 1		Level 2		Level 3		Total
Assets:
Nuclear decommissioning trusts:
Short-term investments, primarily cash equivalents	$	14	$	2	$	—	$	16
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)	563		527		—		1,090
Commodity contracts subject to rate recovery	1		3		95		99
Effect of netting and allocation of collateral(2)	10		—		6		16
Total	$	574	$	530	$	101	$	1,205
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 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, 2021
	Level 1		Level 2		Level 3		Total
Assets:
Commodity contracts subject to rate recovery	$	—	$	1	$	—	$	1
Effect of netting and allocation of collateral(1)	9		9		—		18
Total	$	9	$	10	$	—	$	19

Liabilities:

Commodity contracts subject to rate recovery	$	—	$	35	$	—	$	35
Total	$	—	$	35	$	—	$	35

	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


LEVEL 3 RECONCILIATIONS(1)
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Balance at January 1	$	69	$	28	$	179
Realized and unrealized (losses) gains	(50)		19		(184)
Allocated transmission instruments	3		6		6
Settlements	32		16		27
Balance at December 31	$	54	$	69	$	28
Change in unrealized (losses) gains relating to instruments still held at December 31	$	(16)	$	34	$	(139)

(1) Excludes the effect of the contractual ability to settle contracts under master netting agreements.

The table below sets forth reconciliations of changes in the fair value of Sempra’s Support Agreement for the benefit of CFIN classified as Level 3 in the fair value hierarchy for Sempra.


LEVEL 3 RECONCILIATIONS
(Dollars in millions)
	Years ended December 31,
	2021		2020
Balance at January 1	$	3	$	—
Realized and unrealized gains(1)	11		6
Settlements	(7)		(3)
Balance at December 31(2)	$	7	$	3
Change in unrealized gains relating to instruments still held at December 31	$	11	$	3

(1) Net gains are included in Interest Income and net losses are included in Interest Expense on Sempra’s Consolidated Statements of Operations.

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
2022	$	(3.67)	to	$	6.96	$	(0.70)
2021		(1.81)	to		14.11		(0.12)
2020		(3.77)	to		6.03		(1.58)

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
2021	$	24.10	to	$	105.00	$	53.57
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)
	Carrying		Fair value
	amount		Level 1		Level 2		Level 3		Total
	December 31, 2021
Sempra:
Long-term note receivable(1)	$	300	$	—	$	—	$	327	$	327
Long-term amounts due from unconsolidated affiliates(2)	640		—		642		—		642
Long-term amounts due to unconsolidated affiliates	287		—		295		—		295
Total long-term debt(3)	20,099		—		22,126		—		22,126
SDG&E:
Total long-term debt(4)	$	6,417	$	—	$	7,236	$	—	$	7,236
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,367	$	—	$	5,367

	December 31, 2020
Sempra:
Long-term amounts due from unconsolidated affiliates(2)	$	786	$	—	$	817	$	—	$	817
Long-term amounts due to unconsolidated affiliates	275		—		266		—		266
Total long-term debt(3)	22,259		—		25,478		—		25,478
SDG&E:
Total long-term debt(4)	$	6,253	$	—	$	7,384	$	—	$	7,384
SoCalGas:
Total long-term debt(5)	$	4,759	$	—	$	5,655	$	—	$	5,655

	December 31, 2019
Sempra:
Long-term amounts due from unconsolidated affiliates	$	742	$	—	$	759	$	—	$	759
Long-term amounts due to unconsolidated affiliates	195		—		184		—		184
Total long-term debt(3)	21,247		—		22,638		26		22,664
SDG&E:
Total long-term debt(4)	$	5,140	$	—	$	5,662	$	—	$	5,662
SoCalGas:
Total long-term debt(5)	$	3,809	$	—	$	4,189	$	—	$	4,189

(1) Before allowances for credit losses of $8 and excluding transaction costs of $5 at December 31, 2021.

DERIVATIVE FINANCIAL INSTRUMENTS - INCOME STATEMENT (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivatives designated as hedging instruments: \| Cash flow hedges
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	$ 115	$ (232)	$ (187)
Pretax (loss) gain reclassified from AOCI into earnings	(92)	(67)	(11)
Derivatives designated as hedging instruments: \| Cash flow hedges \| Gain (Loss) on Sale of Assets \| Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(10)
Derivatives designated as hedging instruments: \| Cash flow hedges \| Interest Expense \| Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	0	0	0
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(1)
Derivatives designated as hedging instruments: \| Cash flow hedges \| Interest Expense \| Interest rate and foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	(4)	(6)	19
Pretax (loss) gain reclassified from AOCI into earnings	(1)	(1)	0
Derivatives designated as hedging instruments: \| Cash flow hedges \| Equity Earnings \| Interest rate instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	71	(185)	(164)
Pretax (loss) gain reclassified from AOCI into earnings	(73)	(46)	(3)
Derivatives designated as hedging instruments: \| Cash flow hedges \| Equity Earnings \| Foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	8	(3)	(10)
Pretax (loss) gain reclassified from AOCI into earnings	0	0	(2)
Derivatives designated as hedging instruments: \| Cash flow hedges \| Revenues: Energy- Related Businesses \| Foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax gain (loss) recognized in OCI	11	(4)	(8)
Pretax (loss) gain reclassified from AOCI into earnings	(1)	1	(2)
Derivatives designated as hedging instruments: \| Cash flow hedges \| Other Income (Expense), Net \| Interest rate and foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Pretax (loss) gain reclassified from AOCI into earnings	(6)	(11)	9
Derivatives not designated as hedging instruments:
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(219)	42	(100)
Derivatives not designated as hedging instruments: \| Revenues: Energy- Related Businesses \| Commodity contracts not subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(203)	17	12
Derivatives not designated as hedging instruments: \| Other Income (Expense), Net \| Foreign exchange instruments
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(22)	(56)	25
Derivatives not designated as hedging instruments: \| Cost of Natural Gas \| Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	(25)	(7)	3
Derivatives not designated as hedging instruments: \| Cost of Electric Fuel and Purchased Power \| Commodity contracts subject to rate recovery
Derivative Instruments, Gain (Loss) [Line Items]
Gain (loss) on derivative recognized in earnings	$ 31	$ 88	$ (140)

COMMITMENTS AND CONTINGENCIES - LESSEE MATURITY ANALYSIS OF LIABILITIES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Operating leases(1)
2022	$ 17
2023	13
2024	11
2025	10
2026	8
Thereafter	0
Total undiscounted lease payments	59
Less: imputed interest	(3)
Total lease liabilities	56	$ 74	$ 93
Less: current lease liabilities	(15)	(18)	(18)
Long-term lease liabilities	41	56	75
Finance leases
2022	12
2023	11
2024	11
2025	11
2026	8
Thereafter	13
Total undiscounted lease payments	66
Less: imputed interest	(5)
Total finance leases	1,274	1,276	1,270
Less: current lease liabilities	(11)	(10)	(6)
Long-term lease liabilities	50	$ 44	$ 13
Purchased-Power Contracts
Operating leases(1)
2022	9
2023	9
2024	9
2025	9
2026	9
Thereafter	$ 87

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE (Tables)

12 Months Ended

Dec. 31, 2021

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,
	2021		2020		2019
Sempra:
Numerator for continuing operations:
Income from continuing operations, net of income tax	$	1,463	$	2,255	$	1,999
Earnings attributable to noncontrolling interests	(145)		(162)		(129)
Preferred dividends	(63)		(168)		(142)
Preferred dividends of subsidiary	(1)		(1)		(1)
Earnings from continuing operations attributable to common shares	$	1,254	$	1,924	$	1,727

Numerator for discontinued operations:
Income from discontinued operations, net of income tax	$	—	$	1,850	$	363
Earnings attributable to noncontrolling interests	—		(10)		(35)
Earnings from discontinued operations attributable to common shares	$	—	$	1,840	$	328

Numerator for earnings:
Earnings attributable to common shares	$	1,254	$	3,764	$	2,055

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	311,755		291,077		277,904
Dilutive effect of stock options and RSUs(2)	752		1,175		1,585
Dilutive effect of common shares sold forward	—		—		2,544
Dilutive effect of mandatory convertible preferred stock	529		—		—
Weighted-average common shares outstanding for diluted EPS	313,036		292,252		282,033

Basic EPS:
Earnings from continuing operations	$	4.03	$	6.61	$	6.22
Earnings from discontinued operations	$	—	$	6.32	$	1.18
Earnings	$	4.03	$	12.93	$	7.40

Diluted EPS:
Earnings from continuing operations	$	4.01	$	6.58	$	6.13
Earnings from discontinued operations	$	—	$	6.30	$	1.16
Earnings	$	4.01	$	12.88	$	7.29

(1) Includes fully vested RSUs held in our Deferred Compensation Plan of 453 in 2021, 537 in 2020 and 617 in 2019. 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 common stock and the comparative indices used to determine the vesting percentage of our total shareholder return performance-based RSUs, which we discuss in Note 10, dilutive RSUs may vary widely from period-to-period.

Schedule Of Common Stock Activity

The following table provides common stock activity for the last three years.


COMMON STOCK ACTIVITY

	Years ended December 31,
	2021	2020	2019
Sempra:
Common shares outstanding, January 1	288,470,244	291,712,925	273,769,513
Conversion of mandatory convertible preferred stock	18,037,745	—	—
Shares issued in IEnova exchange offer	12,306,777	—	—
Shares issued under forward sale agreements	—	—	16,906,185
RSUs vesting(1)	686,916	896,839	463,012
Stock options exercised	50,671	4,400	52,540
Savings plan issuance	—	201,431	475,774
Common stock investment plan(2)	—	42,955	199,253
Issuance of RSUs held in our Deferred Compensation Plan	102,238	103,552	59,470
Shares repurchased(3)	(2,734,809)	(4,491,858)	(212,822)
Common shares outstanding, December 31	316,919,782	288,470,244	291,712,925

(1) Includes dividend equivalents.

(2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares.

(3) In 2021 and 2020, includes shares repurchased under the repurchase programs that we discuss above. Generally, we purchase shares of our common stock or units from LTIP participants who elect to sell to us a sufficient number of vested RSUs to meet minimum statutory tax withholding requirements.

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - REGULATED OPERATIONS (Details)	Dec. 31, 2021
Oncor Electric Delivery Company LLC \| Sempra Texas Utilities
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	80.25%
Sharyland Utilities, LP
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100.00%

SIGNIFICANT ACCOUNITNG POLICIES AND OTHER FINANCIAL DATA - NOTE RECEIVABLE (Details) - KKR $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Receivables with Imputed Interest [Line Items]
Note receivable issued	$ 300
Transaction costs	$ 5
Note receivable interest rate (as a percent)	5.00%
Other long-term assets
Receivables with Imputed Interest [Line Items]
Note receivable, net	$ 297
Other current assets
Receivables with Imputed Interest [Line Items]
Note receivable, net	$ 3

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Net income	$ (426)	$ 505	$ 642
Other comprehensive income (loss):
Total other comprehensive (loss) income	171	(8)	1
Preferred dividends of subsidiary	(1)	(1)	(1)
Pretax amount
Net income	(736)	601	762
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	191	(146)	1
Pension and other postretirement benefits	28	(12)	1
Total other comprehensive (loss) income	213	(12)	2
Comprehensive income	(736)	589	764
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	1,020	1,022	932
Income tax (expense) benefit
Net income	310	(96)	(120)
Other comprehensive income (loss):
Foreign currency translation adjustments	0	0	0
Financial instruments	(47)	33	0
Pension and other postretirement benefits	(6)	4	(1)
Total other comprehensive (loss) income	(53)	4	(1)
Comprehensive income	310	(92)	(121)
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	(201)	(192)	(169)
Net-of-tax amount
Net income	(426)	505	642
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	144	(113)	1
Pension and other postretirement benefits	22	(8)	0
Total other comprehensive (loss) income	160	(8)	1
Comprehensive income	(426)	497	643
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	819	830	763
Noncontrolling interests (after tax)
Net income	0	0	7
Other comprehensive income (loss):
Foreign currency translation adjustments	(3)	(12)	3
Financial instruments	14	(12)	2
Pension and other postretirement benefits	0	0	0
Total other comprehensive (loss) income	11	0	2
Comprehensive income	156	148	157
Preferred dividends of subsidiary	0	0	0
Total comprehensive income, after preferred dividends of subsidiaries	0	0	9
Total
Net income	819	824	774
Other comprehensive income (loss):
Foreign currency translation adjustments	(9)	535	(40)
Financial instruments	158	(125)	2
Pension and other postretirement benefits	22	6	(4)
Total other comprehensive (loss) income	171	6	(2)
Comprehensive income	1,634	4,527	2,222
Preferred dividends of subsidiary	(1)	(1)	(1)
Total comprehensive income, after preferred dividends of subsidiaries	$ 819	$ 830	$ 772

FAIR VALUE MEASUREMENTS - RECON OF LEVEL 3 ASSETS (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) $ / MWh	Dec. 31, 2021 USD ($) $ / MWh	Dec. 31, 2020 USD ($) $ / MWh	Dec. 31, 2019 USD ($) $ / MWh
Sempra Infrastructure
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 7	$ 3	$ 0
Realized and unrealized gains		11	6
Settlements		(7)	(3)
Ending balance		7	3	$ 0
Change in unrealized gains (losses) relating to instruments still held at the end of the period		11	3
Level 3
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Balance at beginning of period	54	69	28	179
Realized and unrealized (losses) gains		(50)	19	(184)
Allocated transmission instruments		3	6	6
Settlements		32	16	27
Balance at end of period		54	69	28
Change in unrealized gains (losses) relating to derivative instruments still held at the end of the period		(16)	34	$ (139)
Level 3 \| Other current assets
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance	$ 7	7
Ending balance		7	7
Level 3 \| Deferred Credits and Other
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance		$ 4
Ending balance			$ 4
Level 3 \| Minimum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh		(1.81)	(3.77)
Market electricity forward price inputs (in dollars per MWH) \| $ / MWh		24.10	19.60	21.00
Level 3 \| Minimum \| Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh	(3.67)
Level 3 \| Maximum
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh		14.11	6.03
Market electricity forward price inputs (in dollars per MWH) \| $ / MWh		105.00	78.10	61.15
Level 3 \| Maximum \| Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh	6.96
Level 3 \| Median
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh		(0.12)	(1.58)
Level 3 \| Median \| Forecast
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Congestion revenue rights (in dollars per MWH) \| $ / MWh	(0.70)
Level 3 \| Weighted Average
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Market electricity forward price inputs (in dollars per MWH) \| $ / MWh		53.57	39.71	37.92

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	$ 5,144	$ 4,748
AOCI, ending balance	5,442	5,144	$ 4,748
Foreign currency translation adjustments
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(64)	(607)	(564)
OCI before reclassifications(3)	(34)	(102)	(43)
Amounts reclassified from AOCI(3)	19	645	0
Total other comprehensive income (loss)	(15)	543	(43)
AOCI, ending balance	(79)	(64)	(607)
AOCI associated with noncontrolling interests	19
Foreign currency translation adjustments \| IEnova
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI associated with noncontrolling interests	28	4
Foreign currency translation adjustments \| Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			0
Financial instruments
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(13)	(13)	(12)
OCI before reclassifications(3)	0	0	0
Amounts reclassified from AOCI(3)	0	0	1
Total other comprehensive income (loss)	0	0	1
AOCI, ending balance	(13)	(13)	(13)
AOCI associated with noncontrolling interests	47
Financial instruments \| IEnova
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI associated with noncontrolling interests	16	3
Financial instruments \| Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(2)
Pension and other postretirement benefits
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(18)	(10)	(8)
OCI before reclassifications(3)	(2)	(10)	(4)
Amounts reclassified from AOCI(3)	2	2	4
Total other comprehensive income (loss)	0	(8)	0
AOCI, ending balance	(18)	(18)	(10)
Pension and other postretirement benefits \| San Diego Gas and Electric Company [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI(3)		3
Pension and other postretirement benefits \| SoCalGas
Accumulated Other Comprehensive Income (Loss) [Line Items]
Amounts reclassified from AOCI(3)		6	4
Pension and other postretirement benefits \| Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			(2)
Accumulated other comprehensive income (loss)
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance	(31)	(23)	(20)
OCI before reclassifications(3)	(2)	(10)	(4)
Amounts reclassified from AOCI(3)	2	2	5
Total other comprehensive income (loss)	0	(8)	1
AOCI, ending balance	$ (31)	$ (31)	(23)
Accumulated other comprehensive income (loss) \| Cumulative Effect, Period of Adoption, Adjustment
Accumulated Other Comprehensive Income (Loss) [Line Items]
AOCI, beginning balance			$ (4)

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 37	$ 4	$ 10
Restricted cash	19	22	31
Accounts receivable – trade, net	1,084	786	710
Accounts receivable – other, net	58	64	87
Due from unconsolidated affiliates	49	22	11
Income taxes receivable	23	0	161
Inventories	172	153	136
Prepaid expenses	174	153	120
Regulatory assets	40	16	7
Greenhouse gas allowances	75	390	52
Assets held for sale in discontinued operations	0	0	445
Other current assets	61	47	44
Total current assets	1,599	1,482	1,218
Other assets:
Restricted cash	3	3	3
Due from unconsolidated affiliates	637	780	742
Regulatory assets	1,148	1,208	1,407
Insurance receivable for Aliso Canyon costs	360	445	339
Greenhouse gas allowances	290	9	248
Nuclear decommissioning trusts	1,012	1,019	1,082
Dedicated assets in support of certain benefit plans	567	512	488
Deferred income taxes	151	136	155
Right-of-use assets – operating leases	57	74	94
Investment in Oncor Holdings	12,947	12,440	11,519
Other investments	1,525	1,388	2,103
Goodwill	1,602	1,602	1,602
Other intangible assets	370	202	213
Wildfire fund	331	363	392
Assets held for sale in discontinued operations	0	0	3,513
Other long-term assets	627	499	447
Total other assets	2,482	2,235	2,535
Property, plant and equipment:
Property, plant and equipment	23,104	21,180	19,362
Less accumulated depreciation and amortization	(6,861)	(6,437)	(6,038)
Property, plant and equipment, net	16,243	14,743	13,324
Total assets	20,324	18,460	17,077
Current liabilities:
Short-term debt	385	113	630
Accounts payable – trade	775	600	545
Accounts payable – other	142	122	110
Due to unconsolidated affiliates	36	31	47
Dividends and interest payable	563	551	515
Accrued compensation and benefits	202	189	182
Regulatory liabilities	345	79	243
Current portion of long-term debt and finance leases	46	919	1,464
Reserve for Aliso Canyon costs	1,980	150	9
Greenhouse gas obligations	75	390	52
Liabilities held for sale in discontinued operations	0	0	444
Other current liabilities	271	291	222
Total current liabilities	4,312	2,082	2,182
Long-term debt and finance leases	8,714	10,152	10,691
Deferred credits and other liabilities:
Due to unconsolidated affiliates	287	234	195
Regulatory liabilities	1,100	1,177	1,422
Reserve for Aliso Canyon costs	3	301	7
Greenhouse gas obligations	174	0	208
Pension and other postretirement benefit plan obligations, net of plan assets	25	92	153
Deferred income taxes	3,477	2,871	2,577
Asset retirement obligations	2,505	2,309	2,112
Liabilities held for sale in discontinued operations	0	0	1,052
Deferred credits and other	425	425	422
Total deferred credits and other liabilities	5,797	6,471	6,359
Commitments and contingencies (Note 16)
Equity:
Preferred stock	22	22	22
Common stock	1,666	866	866
Retained earnings	3,785	4,287	3,883
Accumulated other comprehensive income (loss)	(31)	(31)	(23)
Total shareholders’ equity	5,442	5,144	4,748
Preferred stock of subsidiary	20	20	20
Other noncontrolling interests	1,418	1,541	1,856
Total equity	5,442	5,144	4,748
Total liabilities and shareholders’ equity	20,324	18,460	17,077
Convertible Preferred Stock Series A
Equity:
Preferred stock	0	1,693	1,693
Convertible Preferred Stock Series B
Equity:
Preferred stock	0	565	565
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	$ 0

COMMITMENTS AND CONTINGENCIES - LEASE INCOME STATEMENT INFORMATION (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Lessee, Lease, Description [Line Items]
Operating lease costs	$ 20	$ 24	$ 27
Amortization of ROU assets	12	12	6
Interest on lease liabilities	2	2	0
Total finance lease costs	14	14	6
Short-term lease costs	0	0	0
Variable lease costs	10	10	10
Total lease costs	44	48	43
Depreciation and Amortization Expense
Lessee, Lease, Description [Line Items]
Amortization of ROU assets	$ 1	$ 18	$ 15

CONSOLIDATED BALANCE SHEETS - SCG - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 37	$ 4	$ 10
Accounts receivable – trade, net	1,084	786	710
Accounts receivable – other, net	58	64	87
Due from unconsolidated affiliates	49	22	11
Income taxes receivable, net	23	0	161
Inventories	172	153	136
Regulatory assets	40	16	7
Greenhouse gas allowances	75	390	52
Other current assets	61	47	44
Total current assets	1,599	1,482	1,218
Other assets:
Regulatory assets	1,148	1,208	1,407
Insurance receivable for Aliso Canyon costs	360	445	339
Greenhouse gas allowances	290	9	248
Right-of-use assets – operating leases	57	74	94
Other long-term assets	627	499	447
Total other assets	2,482	2,235	2,535
Property, plant and equipment:
Property, plant and equipment	23,104	21,180	19,362
Less accumulated depreciation and amortization	(6,861)	(6,437)	(6,038)
Property, plant and equipment, net	16,243	14,743	13,324
ASSETS	20,324	18,460	17,077
Current liabilities:
Short-term debt	385	113	630
Accounts payable – trade	775	600	545
Accounts payable – other	142	122	110
Due to unconsolidated affiliates	36	31	47
Accrued compensation and benefits	202	189	182
Regulatory liabilities	345	79	243
Current portion of long-term debt and finance leases	46	919	1,464
Customer deposits	13	48	71
Reserve for Aliso Canyon costs	1,980	150	9
Greenhouse gas obligations	75	390	52
Asset retirement obligations	77	59	65
Other current liabilities	271	291	222
Total current liabilities	4,312	2,082	2,182
Long-term debt and finance leases	8,714	10,152	10,691
Deferred credits and other liabilities:
Regulatory liabilities	1,100	1,177	1,422
Reserve for Aliso Canyon costs	3	301	7
Greenhouse gas obligations	174	0	208
Pension obligation, net of plan assets	551	853	785
Deferred income taxes	3,477	2,871	2,577
Asset retirement obligations	2,505	2,309	2,112
Deferred credits and other	425	425	422
Total deferred credits and other liabilities	5,797	6,471	6,359
Commitments and contingencies (Note 16)
Equity:
Preferred stock	22	22	22
Common stock	1,666	866	866
Retained earnings	3,785	4,287	3,883
Accumulated other comprehensive income (loss)	(31)	(31)	(23)
Total shareholders’ equity	5,442	5,144	4,748
Total liabilities and shareholders’ equity	20,324	18,460	17,077
Convertible Preferred Stock Series A
Equity:
Preferred stock	0	1,693	1,693
Convertible Preferred Stock Series B
Equity:
Preferred stock	0	565	565
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	$ 0

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Tables)

12 Months Ended

Dec. 31, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Cash, Cash Equivalents and Restricted Cash


RECONCILIATION OF CASH, CASH EQUIVALENTS AND RESTRICTED CASH
(Dollars in millions)
	At December 31,
	2021		2020		2019
Cash and cash equivalents	$	559	$	960	$	108
Restricted cash, current	19		22		31
Restricted cash, noncurrent	3		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	$	581	$	985	$	217

Schedule of Accounts Receivable, Allowance for Credit Loss


RECEIVABLES – ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Allowances for credit losses at January 1	$	138	$	29	$	21
Incremental allowance upon adoption of ASU 2016-13	—		1		—
Provisions for expected credit losses	45		124		22
Write-offs	(47)		(16)		(14)
Allowances for credit losses at December 31	$	136	$	138	$	29
SDG&E:
Allowances for credit losses at January 1	$	69	$	14	$	11
Provisions for expected credit losses	23		65		10
Write-offs	(26)		(10)		(7)
Allowances for credit losses at December 31	$	66	$	69	$	14
SoCalGas:
Allowances for credit losses at January 1	$	68	$	15	$	10
Provisions for expected credit losses	22		59		12
Write-offs	(21)		(6)		(7)
Allowances for credit losses at December 31	$	69	$	68	$	15

Allowances for credit losses are included in the Consolidated Balance Sheets as follows:


ALLOWANCES FOR CREDIT LOSSES
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
Accounts receivable – trade, net	$	94	$	111	$	7
Accounts receivable – other, net	39		27		22
Other long-term assets	3		—		—
Total allowances for credit losses	$	136	$	138	$	29
SDG&E:
Accounts receivable – trade, net	$	42	$	55	$	4
Accounts receivable – other, net	22		14		10
Other long-term assets	2		—		—
Total allowances for credit losses	$	66	$	69	$	14
SoCalGas:
Accounts receivable – trade, net	$	51	$	55	$	3
Accounts receivable – other, net	17		13		12
Other long-term assets	1		—		—
Total allowances for credit losses	$	69	$	68	$	15

Schedule of Inventory

The components of inventories are as follows:


INVENTORY BALANCES AT DECEMBER 31
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	2021		2020		2019		2021		2020		2019		2021		2020		2019
Natural gas	$	164	$	118	$	110	$	—	$	—	$	1	$	114	$	94	$	90
LNG	27		7		9		—		—		—		—		—		—
Materials and supplies	198		183		158		123		104		93		58		59		46
Total	$	389	$	308	$	277	$	123	$	104	$	94	$	172	$	153	$	136

Wildfire Fund

The following table summarizes the location of balances related to the Wildfire Fund on Sempra’s and SDG&E’s Consolidated Balance Sheets and Consolidated Statements of Operations.


WILDFIRE FUND
(Dollars in millions)
		December 31,
	Location	2021		2020		2019
Wildfire Fund asset:
Current	Prepaid Expenses	$	29	$	29	$	29
Noncurrent	Wildfire Fund	331		363		392
Wildfire Fund obligation:
Current	Other Current Liabilities	$	13	$	13	$	13
Noncurrent	Deferred Credits and Other	64		75		86
		Years ended December 31,
		2021		2020		2019
Amortization of Wildfire Fund asset	Operation and Maintenance	$	29	$	29	$	12
Impairment of Wildfire Fund asset	Impairment Losses(1)	3		—		—
Accretion of Wildfire Fund obligation	Operation and Maintenance	2		2		1

(1) Included in O&M 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, SUBJECT TO THE CCM

SDG&E							SoCalGas
Authorized weighting		Return on rate base		Weighted return on rate base			Authorized weighting		Return on rate base		Weighted return on rate base
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 December 31,
	2021		2020		2019		2021		2020			2019
SDG&E:
Natural gas operations	$	3,200	$	2,805	$	2,534	2.55	%	2.51	%		2.47	%
Electric distribution	9,471		8,592		7,985		3.93		3.90			3.94
Electric transmission(1)	7,577		7,156		6,577		3.02		3.10			2.79
Electric generation	2,446		2,440		2,415		4.74		4.56			4.50
Other electric	2,100		1,743		1,492		7.23		6.92			6.61
Construction work in progress(1)	1,662		1,700		1,501		NA		NA			NA
Total SDG&E	26,456		24,436		22,504
SoCalGas:
Natural gas operations	21,894		19,961		18,370		3.65		3.63			3.60
Other non-utility	50		45		34		2.23		3.80			5.08
Construction work in progress	1,160		1,174		958		NA		NA			NA
Total SoCalGas	23,104		21,180		19,362

Sempra Infrastructure and parent(2):							Estimated useful lives				Weighted-average useful life
Land and land rights	291		283		278		16 to 50 years(3)					36
Machinery and equipment:
Pipelines and storage	3,698		3,482		3,596		5 to 50 years					42
Generating plants	1,659		1,288		1,154		11 to 30 years					27
LNG terminals	1,138		1,138		1,134		43 years					43
Liquid fuels terminals	420		—		—		37 years					37
Other	370		359		180		3 to 50 years					13
Construction work in progress	1,494		1,514		895		NA					NA
Other	310		248		226		4 to 50 years					21
	9,380		8,312		7,463
Total Sempra	$	58,940	$	53,928	$	49,329

(2) Includes $211, $191 and $178 at December 31, 2021, 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,
	2021		2020		2019
Sempra	$	1,833	$	1,646	$	1,551
SDG&E	884		797		757
SoCalGas	711		649		598


ACCUMULATED DEPRECIATION AND AMORTIZATION
(Dollars in millions)
	December 31,
	2021		2020		2019
SDG&E:
Accumulated depreciation:
Natural gas operations	$	919	$	870	$	832
Electric transmission, distribution and generation(1)	5,489		5,145		4,705
Total SDG&E	6,408		6,015		5,537
SoCalGas:
Accumulated depreciation:
Natural gas operations	6,845		6,422		6,023
Other non-utility	16		15		15
Total SoCalGas	6,861		6,437		6,038
Sempra Infrastructure and parent:
Accumulated depreciation – other(2)	1,777		1,473		1,302
Total Sempra	$	15,046	$	13,925	$	12,877

(1) Includes $292 at December 31, 2021 related to SDG&E’s 86% interest in the Southwest Powerlink transmission line, jointly owned by SDG&E and other utilities.

(2) Includes $55, $51 and $49 at December 31, 2021, 2020, and 2019, respectively, of accumulated depreciation for utility plant at Ecogas.

Schedule Of Capitalized Financing Costs

The table below summarizes capitalized financing costs, comprised of AFUDC and capitalized interest.


CAPITALIZED FINANCING COSTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra	$	217	$	202	$	183
SDG&E	106		104		75
SoCalGas	64		55		47

Schedule Of Other Intangible Assets

Other Intangible Assets included on Sempra’s Consolidated Balance Sheets are as follows:


OTHER INTANGIBLE ASSETS
(Dollars in millions)
	Amortization period (years)	December 31,
		2021		2020		2019
Renewable energy transmission and consumption permits	15 to 19	$	169	$	169	$	169
O&M agreement	23	66		66		66
ESJ PPA	14	190		—		—
Other	10 to indefinite	15		15		15
		440		250		250
Less accumulated amortization:
Renewable energy transmission and consumption permits		(40)		(32)		(24)
O&M agreement		(12)		(9)		(6)
ESJ PPA		(10)		—		—
Other		(8)		(7)		(7)
		(70)		(48)		(37)
		$	370	$	202	$	213

Schedule Of Asset Retirement Obligations

The changes in AROs are as follows:


CHANGES IN ASSET RETIREMENT OBLIGATIONS
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	2021		2020		2019		2021		2020		2019		2021		2020		2019
Balance as of January 1(1)	$	3,289	$	3,083	$	2,972	$	876	$	866	$	874	$	2,368	$	2,177	$	2,063
Accretion expense	133		127		123		38		39		39		92		86		81
Liabilities incurred and acquired	20		2		2		2		—		—		—		—		—
Deconsolidation	—		—		(2)		—		—		(2)		—		—		—
Payments	(63)		(63)		(46)		(60)		(60)		(44)		(3)		(2)		(2)
Revisions(2)	159		140		34		34		31		(1)		125		107		35
Balance at December 31(1)	$	3,538	$	3,289	$	3,083	$	890	$	876	$	866	$	2,582	$	2,368	$	2,177

(1) Current portion of the ARO for Sempra is included in Other Current Liabilities on the Consolidated Balance Sheets.

(2) SDG&E’s increase in ARO in 2021 includes $22 million due to a revised estimate related to the decommissioning of SONGS, which is offset in noncurrent Regulatory Assets.

Schedule Of Changes In Accumulated Other Comprehensive Income By Component

The following tables present the changes in AOCI by component and amounts reclassified out of AOCI to net income, excluding amounts attributable to NCI.


CHANGES IN ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS) BY COMPONENT(1)
(Dollars in millions)
	Foreign currency translation adjustments		Financial instruments		Pension and other postretirement benefits		Total accumulated other comprehensive income (loss)
Sempra(2):
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)(4)	(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)
OCI before reclassifications(4)	(34)		62		8		36
Amounts reclassified from AOCI(5)	19		113		14		146
Net OCI(4)(5)	(15)		175		22		182
Balance as of December 31, 2021	$	(79)	$	(156)	$	(83)	$	(318)
SDG&E:
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)
OCI before reclassifications					(1)		(1)
Amounts reclassified from AOCI					1		1
Net OCI					—		—
Balance as of December 31, 2021					$	(10)	$	(10)
SoCalGas:

Balance as of December 31, 2018			$	(12)	$	(8)	$	(20)
Adoption of ASU 2018-02			(2)		(2)		(4)
OCI before reclassifications			—		(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(3)			—		2		2
Net OCI			—		(8)		(8)
Balance as of December 31, 2020			(13)		(18)		(31)

OCI before reclassifications			—		(2)		(2)
Amounts reclassified from AOCI			—		2		2
Net OCI			—		—		—
Balance as of December 31, 2021			$	(13)	$	(18)	$	(31)

(1) All amounts are net of income tax, if subject to tax, and exclude NCI.

(2) Includes discontinued operations in 2020 and 2019.

Schedule Of Reclassifications Out Of Accumulated Other Comprehensive Income


RECLASSIFICATIONS OUT OF ACCUMULATED OTHER COMPREHENSIVE INCOME (LOSS)
(Dollars in millions)
Details about accumulated other comprehensive income (loss) components	Amounts reclassified from accumulated other comprehensive income (loss)						Affected line item on Consolidated Statements of Operations
	Years ended December 31,
	2021		2020		2019
Sempra:
Foreign currency translation adjustments	$	—	$	645	$	—	Income from Discontinued Operations, Net of Income Tax

Financial instruments:
Interest rate instruments	$	—	$	—	$	10	Gain (Loss) on Sale of Assets
Interest rate instruments(1)	11		10		3		Interest Expense
Interest rate instruments	73		46		3		Equity Earnings(2)
Foreign exchange instruments	1		(1)		2		Revenues: Energy-Related Businesses

Foreign exchange instruments	—		—		2		Equity Earnings(2)
Interest rate and foreign exchange instruments	1		1		—		Interest Expense
	6		11		(9)		Other Income (Expense) , Net
Total before income tax	92		67		11
	(24)		(19)		(2)		Income Tax Expense
Net of income tax	68		48		9
	(2)		(1)		(1)		Earnings Attributable to Noncontrolling Interests
	$	66	$	47	$	8
Pension and other postretirement benefits(3):
Amortization of actuarial loss	$	8	$	8	$	12	Other Income (Expense), Net
Amortization of actuarial loss	—		6		1		Income from Discontinued Operations, Net of Income Tax
Amortization of prior service cost	4		4		3		Other Income (Expense), Net
Settlement charges	7		22		28		Other Income (Expense), Net
Total before income tax	19		40		44
	—		(2)		—		Income from Discontinued Operations, Net of Income Tax
	(5)		(9)		(12)		Income Tax Expense
Net of income tax	$	14	$	29	$	32

Total reclassifications for the period, net of tax	$	80	$	721	$	40
SDG&E:
Financial instruments:
Interest rate instruments(1)	$	—	$	—	$	3	Interest Expense
	—		—		(3)		Earnings Attributable to Noncontrolling Interest
	$	—	$	—	$	—
Pension and other postretirement benefits(3):
Amortization of actuarial loss	$	—	$	1	$	—	Other Income, Net
Amortization of prior service cost	1		1		1		Other Income, Net

Total before income tax	1		2		1
	—		(1)		—		Income Tax Expense
Net of income tax	$	1	$	1	$	1

Total reclassifications for the period, net of tax	$	1	$	1	$	1
SoCalGas:
Financial instruments:
Interest rate instruments	$	—	$	—	$	1	Interest Expense


Pension and other postretirement benefits(3):
Amortization of actuarial loss	$	1	$	1	$	1	Other Expense, Net
Amortization of prior service cost	1		1		—		Other Expense, Net
Total before income tax	2		2		1
	—		—		(1)		Income Tax Benefit (Expense)
Net of income tax	$	2	$	2	$	—

Total reclassifications for the period, net of tax	$	2	$	2	$	1

(1) Amounts in 2019 include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE.

(2) Equity earnings at our foreign equity method investees are recognized after tax.

(3) 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 held by noncontrolling interests
	December 31,						December 31,
	2021		2020		2019		2021		2020		2019
Sempra Infrastructure:
SI Partners	20.0	%	—	%	—	%	$	1,384	$	—	$	—
SI Partners subsidiaries(1)	0.1 - 16.6		17.5 - 29.8		10.0 - 46.3		34		1,540		1,622
Parent and other:
PXiSE	—		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							$	1,418	$	1,541	$	1,856

(1) SI Partners 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, SDG&E and SoCalGas in the following table.


AMOUNTS DUE FROM (TO) UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
Total due from various unconsolidated affiliates – current	$	23	$	20	$	32

Sempra Infrastructure:
ESJ JV – Note due December 31, 2022, net of negligible allowance for credit losses at December 31, 2020(1)	$	—	$	85	$	—
IMG JV – Note due March 15, 2022, net of allowance for credit losses of $1 and $3 at December 31, 2021 and 2020, respectively(2)	637		695		742
Total due from unconsolidated affiliates – noncurrent	$	637	$	780	$	742
Sempra Infrastructure – TAG Pipelines Norte, S. de R.L. de C.V. – Note due December 20, 2021(3)(4)	$	—	$	(41)	$	—
Various affiliates	—		(4)		(5)
Total due to unconsolidated affiliates – current	$	—	$	(45)	$	(5)

Sempra Infrastructure(4):
TAG Pipelines Norte, S. de R.L. de C.V.:
Note due December 20, 2021(3)	$	—	$	—	$	(39)
5.5% Note due January 9, 2024(5)	(69)		(68)		—
5.5% Note due January 14, 2025(5)	(21)		—		—
5.5% Note due July 16, 2025(5)	(20)		—		—
TAG JV – 5.74% Note due December 17, 2029(5)	(177)		(166)		(156)
Total due to unconsolidated affiliates – noncurrent	$	(287)	$	(234)	$	(195)
SDG&E:


Sempra	$	(40)	$	(38)	$	(37)
SoCalGas	(48)		(21)		(10)

Various affiliates	(9)		(5)		(6)
Total due to unconsolidated affiliates – current	$	(97)	$	(64)	$	(53)

Income taxes due from Sempra(6)	$	19	$	—	$	130
SoCalGas:
SDG&E	$	48	$	21	$	10
Various affiliates	1		1		1
Total due from unconsolidated affiliates – current	$	49	$	22	$	11

Sempra	$	(36)	$	(31)	$	(45)

Various affiliates	—		—		(2)
Total due to unconsolidated affiliates – current	$	(36)	$	(31)	$	(47)

Income taxes due from (to) Sempra(6)	$	6	$	(37)	$	152

(3) U.S. dollar-denominated loan at a variable interest rate based on 6-month LIBOR plus 290 bps (3.16% at December 31, 2020).

(4) Amounts include principal balances plus accumulated interest outstanding.

(5) U.S. dollar-denominated loan at a fixed interest rate.

The following table summarizes income statement information from unconsolidated affiliates.


INCOME STATEMENT IMPACT FROM UNCONSOLIDATED AFFILIATES
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Revenues	$	31	$	37	$	52
Cost of sales	11		45		50
Interest income	50		56		74
Interest expense	15		14		2
SDG&E:
Revenues	$	11	$	6	$	6
Cost of sales	103		79		74
SoCalGas:
Revenues	$	98	$	88	$	69
Cost of sales(1)	1		—		8

(1) Includes net commodity costs from natural gas transactions with unconsolidated affiliates.

Schedule Of Other Income (Expense)

Other Income (Expense), Net on the Consolidated Statements of Operations consists of the following:


OTHER INCOME (EXPENSE), NET
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Allowance for equity funds used during construction	$	133	$	128	$	94
Investment gains, net(1)	50		41		61
(Losses) gains on interest rate and foreign exchange instruments, net	(28)		(67)		34
Foreign currency transaction (losses) gains, net(2)	(18)		(25)		21
Non-service component of net periodic benefit cost	(67)		(102)		(132)


Interest on regulatory balancing accounts, net	6		14		14

Sundry, net	(18)		(37)		(15)
Total	$	58	$	(48)	$	77
SDG&E:
Allowance for equity funds used during construction	$	81	$	79	$	56
Non-service component of net periodic benefit cost	(13)		(20)		(20)

Interest on regulatory balancing accounts, net	6		9		13

Sundry, net	(10)		(16)		(10)
Total	$	64	$	52	$	39
SoCalGas:
Allowance for equity funds used during construction	$	48	$	41	$	34
Non-service component of net periodic benefit cost	(40)		(54)		(72)

Interest on regulatory balancing accounts, net	—		5		1

Sundry, net	(22)		(20)		(18)
Total	$	(14)	$	(28)	$	(55)

CONSOLIDATED STATEMENTS OF CASH FLOWS - SCG - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
CASH FLOWS FROM OPERATING ACTIVITIES
Net (loss) income	$ (426)	$ 505	$ 642
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	716	654	602
Deferred income taxes and investment tax credits	(494)	(112)	88
Impairment losses	0	0	37
Other	19	59	(5)
Net change in other working capital components:
Accounts receivable	(383)	(101)	(73)
Due to/from unconsolidated affiliates, net	(25)	(27)	(1)
Income taxes receivable/payable, net	(43)	189	(156)
Inventories	(18)	(19)	1
Other current assets	(21)	(12)	(9)
Accounts payable	181	64	(7)
Regulatory balancing accounts, net	306	(160)	114
Reserve for Aliso Canyon costs	1,532	141	(144)
Other current liabilities	(92)	(21)	(21)
Insurance receivable for Aliso Canyon costs	85	(106)	122
Reserve for Aliso Canyon costs, noncurrent	0	294	0
Changes in other noncurrent assets and liabilities, net	(304)	178	(322)
Net cash provided by operating activities	1,033	1,526	868
CASH FLOWS FROM INVESTING ACTIVITIES
Expenditures for property, plant and equipment	(1,984)	(1,843)	(1,439)
Other	0	0	1
Net cash used in investing activities	(1,984)	(1,843)	(1,438)
CASH FLOWS FROM FINANCING ACTIVITIES
Common dividends paid	(75)	(100)	(150)
Preferred dividends paid	(1)	(1)	(1)
Equity contribution from Sempra Energy	800	0	0
Issuances of debt (maturities greater than 90 days)	0	949	349
Payments on debt (maturities greater than 90 days) and finance leases	(12)	(12)	(6)
Increase (decrease) in short-term debt, net	272	(517)	374
Debt issuance costs	0	(8)	(4)
Net cash provided by financing activities	984	311	562
Increase (decrease) in cash and cash equivalents	33	(6)	(8)
Cash and cash equivalents, January 1	4	10	18
Cash and cash equivalents, December 31	37	4	10
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Interest payments, net of amounts capitalized	151	146	126
Income tax payments (refunds), net	227	19	188
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Accrued capital expenditures	222	208	205
Increase in finance lease obligations for investment in PP&E	19	47	22
Increase in ARO for investment in PP&E	$ 125	$ 107	$ 35

INCOME TAXES - CHANGES IN UNRECOGNIZED TAX BENEFITS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2021	Dec. 31, 2020
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Interest and penalties expense	$ 1
Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities
Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]
Possible change in unrecognized tax benefits in next 12 months	$ 2	$ 2	$ 2

DERIVATIVE FINANCIAL INSTRUMENTS - BALANCE SHEET (Details) - USD ($)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Other current assets
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	$ 1,000,000	$ 2,000,000
Additional margin posted for commodity contracts not subject to rate recovery	58,000,000	21,000,000
Additional margin posted for commodity contracts subject to rate recovery	18,000,000	6,000,000
Total	19,000,000	8,000,000
Other long-term assets
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 not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	0	0
Other current liabilities
Other Derivatives Not Designated as Hedging Instruments at Fair Value, Net [Abstract]
Net amount presented on balance sheet	(35,000,000)	(6,000,000)
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	(35,000,000)	(6,000,000)
Deferred credits and other
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 not subject to rate recovery	0	0
Additional margin posted for commodity contracts subject to rate recovery	0	0
Total	0	0
Derivatives designated as hedging instruments: \| Other current assets
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	0	0	$ 0
Foreign exchange instruments	1,000,000	0	0
Interest rate and foreign exchange instruments	0	0	0
Derivatives designated as hedging instruments: \| Other long-term assets
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	6,000,000	1,000,000	3,000,000
Foreign exchange instruments	1,000,000	0	0
Interest rate and foreign exchange instruments	0	0	0
Derivatives designated as hedging instruments: \| Other current liabilities
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	(6,000,000)	(16,000,000)	(11,000,000)
Foreign exchange instruments	(1,000,000)	(9,000,000)	(6,000,000)
Interest rate and foreign exchange instruments	(1,000,000)	(1,000,000)	0
Derivatives designated as hedging instruments: \| Deferred credits and other
Derivative Instruments in Hedges, at Fair Value, Net [Abstract]
Interest rate instruments	(2,000,000)	(31,000,000)	(17,000,000)
Foreign exchange instruments	0	(2,000,000)	(1,000,000)
Interest rate and foreign exchange instruments	(130,000,000)	(127,000,000)	(122,000,000)
Derivatives not designated as hedging instruments: \| Other current assets
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	136,000,000	82,000,000	34,000,000
Associated offsetting commodity contracts not subject to rate recovery	(93,000,000)	(82,000,000)	(32,000,000)
Commodity contracts subject to rate recovery	4,000,000	3,000,000	11,000,000
Associated offsetting commodity contracts subject to rate recovery	(3,000,000)	(1,000,000)	(2,000,000)
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			9,000,000
Additional margin posted for commodity contracts not subject to rate recovery			43,000,000
Additional margin posted for commodity contracts subject to rate recovery			9,000,000
Total			18,000,000
Derivatives not designated as hedging instruments: \| Other long-term assets
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	11,000,000	17,000,000	11,000,000
Associated offsetting commodity contracts not subject to rate recovery	(8,000,000)	(13,000,000)	(2,000,000)
Commodity contracts subject to rate recovery	0	0	0
Associated offsetting commodity contracts subject to rate recovery	0	0	0
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			0
Additional margin posted for commodity contracts not subject to rate recovery			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			0
Derivatives not designated as hedging instruments: \| Other current liabilities
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	(122,000,000)	(95,000,000)	(41,000,000)
Associated offsetting commodity contracts not subject to rate recovery	93,000,000	82,000,000	32,000,000
Commodity contracts subject to rate recovery	(38,000,000)	(7,000,000)	(6,000,000)
Associated offsetting commodity contracts subject to rate recovery	3,000,000	1,000,000	2,000,000
Associated cash collateral commodity contracts subject to rate recovery			14,000,000
Net amount presented on balance sheet			(4,000,000)
Additional margin posted for commodity contracts not subject to rate recovery			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			(4,000,000)
Derivatives not designated as hedging instruments: \| Deferred credits and other
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	(10,000,000)	(16,000,000)	(10,000,000)
Associated offsetting commodity contracts not subject to rate recovery	8,000,000	13,000,000	2,000,000
Commodity contracts subject to rate recovery	0	0	0
Associated offsetting commodity contracts subject to rate recovery	$ 0	$ 0	0
Associated cash collateral commodity contracts subject to rate recovery			0
Net amount presented on balance sheet			0
Additional margin posted for commodity contracts not subject to rate recovery			0
Additional margin posted for commodity contracts subject to rate recovery			0
Total			$ 0

SHARE-BASED COMPENSATION - RSAs AND RSUs (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Risk-free rate of return (as a percent)	0.41%	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 1 month 6 days
Share-Based Compensation, Restricted Stock Awards And Units
Share-based Compensation Arrangement by Share-based Payment Award, Fair Value Assumptions and Methodology [Abstract]
Stock price volatility (as a percent)	33.39%	16.35%	17.74%
Risk-free rate of return (as a percent)	0.16%	1.55%	2.46%
Performance-based restricted stock units
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)	893,961
Granted (in shares)	323,889
Vested (in shares)	(317,128)
Forfeited (in shares)	(29,945)
Nonvested, end of period (in shares)	870,777	893,961
Expected to vest (in shares)	854,697
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 121.61
Weighted average grant date fair value, granted (in dollars per share)	133.03	$ 155.62	$ 113.54
Weighted average grant date fair value, vested (in dollars per share)	105.03
Weighted average grant date fair value, forfeited (in dollars per share)	131.55
Weighted average grant date fair value, end of period (in dollars per share)	131.64	$ 121.61
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 131.47
Service-based restricted stock units
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)	343,577
Granted (in shares)	143,980
Vested (in shares)	(202,352)
Forfeited (in shares)	(7,905)
Nonvested, end of period (in shares)	277,300	343,577
Expected to vest (in shares)	271,197
Weighted average grant date fair value, beginning of period (in dollars per share)	$ 121.59
Weighted average grant date fair value, granted (in dollars per share)	124.84	$ 138.91	$ 112.50
Weighted average grant date fair value, vested (in dollars per share)	116.28
Weighted average grant date fair value, forfeited (in dollars per share)	161.49
Weighted average grant date fair value, end of period (in dollars per share)	127.54	$ 121.59
Weighted average grant date fair value, expected to vest (in dollars per share)	$ 127.47
Share-Based Compensation, Restricted Stock Units
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	$ 57	$ 70	$ 36
Nonvested awards, compensation cost not yet recognized	$ 17
Weighted average period over which unrecognized compensation cost will be recognized	1 year 6 months

DERIVATIVE FINANCIAL INSTRUMENTS

12 Months Ended

Dec. 31, 2021

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 may have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for SDG&E and SoCalGas 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 and hedge termination costs on interest rate swaps 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:

▪SDG&E and SoCalGas 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 Infrastructure 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 on the Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges.

▪From time to time, our various businesses, including SDG&E and SoCalGas, may use other energy derivatives to hedge exposures such as GHG allowances.

The following table summarizes net energy derivative volumes.


NET ENERGY DERIVATIVE VOLUMES
(Quantities in millions)
		December 31,
Commodity	Unit of measure	2021	2020	2019
Sempra:
Natural gas	MMBtu	184	189	231
Electricity	MWh	1	1	2
Congestion revenue rights	MWh	45	43	48

SDG&E:
Natural gas	MMBtu	7	16	37
Electricity	MWh	1	1	2
Congestion revenue rights	MWh	45	43	48
SoCalGas:
Natural gas	MMBtu	201	185	201

INTEREST RATE DERIVATIVES

We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra 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 those in our equity method investments, at December 31:


INTEREST RATE DERIVATIVES
(Dollars in millions)
	2021			2020			2019
	Notional debt		Maturities	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	462	2022-2034	$	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 Infrastructure 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 may 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 in 2020 and 2019 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 those in our equity method investments, at December 31.


FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	2021			2020			2019
	Notional amount		Maturities	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2022-2023	$	306	2021-2023	$	306	2020-2023
Other foreign currency derivatives	106		2022-2023	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, 2021
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	6	$	(6)	$	(2)
Foreign exchange instruments	1		1		(1)		—
Interest rate and foreign exchange instruments	—		—		(1)		(130)
Derivatives not designated as hedging instruments:


Commodity contracts not subject to rate recovery	136		11		(122)		(10)
Associated offsetting commodity contracts	(93)		(8)		93		8

Commodity contracts subject to rate recovery	38		52		(58)		—
Associated offsetting commodity contracts	(8)		—		8		—

Net amounts presented on the balance sheet	74		62		(87)		(134)
Additional cash collateral for commodity contracts not subject to rate recovery	58		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	46		—		—		—
Total(1)	$	178	$	62	$	(87)	$	(134)
SDG&E:
Derivatives not designated as hedging instruments:


Commodity contracts subject to rate recovery	$	34	$	52	$	(20)	$	—
Associated offsetting commodity contracts	(5)		—		5		—

Net amounts presented on the balance sheet	29		52		(15)		—

Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(1)	$	57	$	52	$	(15)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:


Commodity contracts subject to rate recovery	$	4	$	—	$	(38)	$	—
Associated offsetting commodity contracts	(3)		—		3		—

Net amounts presented on the balance sheet	1		—		(35)		—

Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total	$	19	$	—	$	(35)	$	—

(1) Normal purchase contracts previously measured at fair value are excluded.


DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2020
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	1	$	(16)	$	(31)
Foreign exchange instruments	—		—		(9)		(2)
Interest rate and foreign exchange instruments	—		—		(1)		(127)
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(1)	$	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(1)	$	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) 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 assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	3	$	(11)	$	(17)
Foreign exchange instruments	—		—		(6)		(1)
Interest rate and foreign exchange instruments	—		—		—		(122)
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(1)	$	126	$	85	$	(53)	$	(192)
SDG&E:
Derivatives not designated as hedging instruments:




Commodity contracts subject to rate recovery	$	30	$	76	$	(41)	$	(47)
Associated offsetting commodity contracts	(4)		(3)		4		3
Associated offsetting cash collateral	—		—		14		—
Net amounts presented on the balance sheet	26		73		(23)		(44)

Additional cash collateral for commodity contracts subject to rate recovery	16		—		—		—
Total(1)	$	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) Normal purchase contracts previously measured at fair value are excluded.

The following table 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 gain (loss) recognized in OCI							Pretax (loss) gain reclassified from AOCI into earnings
	Years ended December 31,							Years ended December 31,
	2021		2020		2019		Location	2021		2020		2019
Sempra:
Interest rate instruments	$	—	$	—	$	—	Gain (Loss) on Sale of Assets	$	—	$	—	$	(10)
Interest rate instruments(1)	29		(34)		(24)		Interest Expense(1)	(11)		(10)		(3)
Interest rate instruments	71		(185)		(164)		Equity Earnings(2)	(73)		(46)		(3)
Foreign exchange instruments	11		(4)		(8)		Revenues: Energy- Related Businesses	(1)		1		(2)

Foreign exchange instruments	8		(3)		(10)		Equity Earnings(2)	—		—		(2)
Interest rate and foreign exchange instruments	(4)		(6)		19		Interest Expense	(1)		(1)		—
							Other Income (Expense), Net	(6)		(11)		9
Total	$	115	$	(232)	$	(187)		$	(92)	$	(67)	$	(11)
SDG&E:
Interest rate instruments(1)	$	—	$	—	$	(1)	Interest Expense(1)	$	—	$	—	$	(3)
SoCalGas:
Interest rate instruments	$	—	$	—	$	—	Interest Expense	$	—	$	—	$	(1)

(1) Amounts include Otay Mesa VIE. All of SDG&E’s interest rate derivative activity relates to Otay Mesa VIE. In August 2019, OMEC LLC paid in full its variable-rate loan and terminated its interest rate swaps.

(2) Equity earnings at our foreign equity method investees are recognized after tax.

For Sempra, we expect that net losses of $47 million, which are net of income tax benefit, that are currently recorded in AOCI (including $1 million in NCI) 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, 2021 is approximately 13 years for Sempra. The maximum remaining term for which we are hedging exposure to the variability of cash flows at our equity method investees is 18 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 (loss) gain on derivatives recognized in earnings
		Years ended December 31,
	Location	2021		2020		2019
Sempra:

Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(203)	$	17	$	12


Commodity contracts subject to rate recovery	Cost of Natural Gas	(25)		(7)		3
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	31		88		(140)
Foreign exchange instruments	Other Income (Expense), Net	(22)		(56)		25
Total		$	(219)	$	42	$	(100)
SDG&E:

Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	31	$	88	$	(140)

SoCalGas:

Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(25)	$	(7)	$	3

CONTINGENT FEATURES

For Sempra, 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, the total fair value of this group of derivative instruments in a liability position at December 31, 2021, 2020 and 2019 was $88 million, $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, 2021, 2020 and 2019 was $36 million, $6 million and $4 million, respectively. SDG&E did not have this group of derivative instruments in a liability position at December 31, 2021 2020 or 2019. At December 31, 2021, if the credit ratings of Sempra or SoCalGas were reduced below investment grade, $88 million and $36 million, respectively, of additional assets could be required to be posted as collateral for these derivative contracts.

For Sempra, 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.

SEGMENT INFORMATION

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]

Segment Information

SEGMENT INFORMATION

We have four 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.

▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns an 80% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at December 31, 2021.

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’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, 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,
	2021		2020		2019
REVENUES
SDG&E	$	5,504	$	5,313	$	4,925
SoCalGas	5,515		4,748		4,525
Sempra Infrastructure	1,997		1,400		1,454
Sempra Renewables	—		—		10
All other	5		2		3
Adjustments and eliminations	(1)		(3)		(3)
Intersegment revenues(1)	(163)		(90)		(85)
Total	$	12,857	$	11,370	$	10,829
DEPRECIATION AND AMORTIZATION
SDG&E	$	889	$	801	$	760
SoCalGas	716		654		602
Sempra Infrastructure	239		198		193
All other	11		13		14
Total	$	1,855	$	1,666	$	1,569
INTEREST INCOME
SDG&E	$	1	$	2	$	4
SoCalGas	1		2		2
Sempra Infrastructure	75		141		139
Sempra Renewables	—		—		11
All other	3		7		4
Intercompany eliminations	(11)		(56)		(73)
Total	$	69	$	96	$	87
INTEREST EXPENSE
SDG&E	$	412	$	413	$	411
SoCalGas	157		158		141
Sempra Infrastructure	205		174		155
Sempra Renewables	—		—		3
All other	444		390		450
Intercompany eliminations	(20)		(54)		(83)
Total	$	1,198	$	1,081	$	1,077
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	201	$	190	$	171
SoCalGas	(310)		96		120
Sempra Texas Utilities	—		1		—
Sempra Infrastructure	238		149		222
Sempra Renewables	—		—		4
All other	(30)		(187)		(202)
Total	$	99	$	249	$	315
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	819	$	824	$	767
SoCalGas	(427)		504		641
Sempra Texas Utilities	616		579		528
Sempra Infrastructure	682		580		247
Sempra Renewables	—		—		59
Discontinued operations	—		1,840		328
All other	(436)		(563)		(515)
Total	$	1,254	$	3,764	$	2,055


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Years ended December 31 or at December 31,
	2021		2020		2019
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E	$	2,220	$	1,942	$	1,522
SoCalGas	1,984		1,843		1,439
Sempra Infrastructure	802		879		736
Sempra Renewables	—		—		2
All other	9		12		9
Total	$	5,015	$	4,676	$	3,708
ASSETS
SDG&E	$	24,058	$	22,311	$	20,560
SoCalGas	20,324		18,460		17,077
Sempra Texas Utilities	13,047		12,542		11,619
Sempra Infrastructure	14,408		12,772		13,660
Discontinued operations	—		—		3,958
All other	1,399		1,215		763
Intersegment receivables	(1,191)		(677)		(1,972)
Total	$	72,045	$	66,623	$	65,665
GEOGRAPHIC INFORMATION
Long-lived assets(2):
United States	$	50,657	$	46,902	$	43,719
Mexico	$	7,708	$	6,929	$	6,355
Asia	1		—		—
Total	$	58,366	$	53,831	$	50,074
Revenues(3):
United States	$	11,154	$	10,205	$	9,574
Mexico	1,703		1,165		1,255
Total	$	12,857	$	11,370	$	10,829

(1)Revenues for reportable segments include intersegment revenues of $10, $98, and $55 for 2021; $5, $88, and $(3) for 2020; and $5, $69, and $11 for 2019 for SDG&E, SoCalGas, and Sempra Infrastructure, respectively.

(2)Includes net PP&E and investments.

(3)Amounts are based on where the revenue originated, after intercompany eliminations.

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8924-108599

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8981-108599

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 21
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8721-108599

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e9031-108599

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8933-108599

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e9038-108599

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8933-108599

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8736-108599

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e9054-108599

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 15
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8657-108599

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 21
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123359005&loc=d3e8721-108599

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-URI http://asc.fasb.org/topic&trid=2134510

Revenue from Contract with Customer [Abstract]

EMPLOYEE BENEFIT PLANS - PLAN ASSETS (Details)	12 Months Ended
EMPLOYEE BENEFIT PLANS - PLAN ASSETS (Details)	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.75%
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	6.75%	7.00%	7.00%
Domestic Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	31.00%
International Equity [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	21.00%
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	10.00%
Ultra-long duration government securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	5.00%
Other Diversifying Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	2.00%
Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	30.00%
Asset allocations	38.00%
Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Targeted plan asset allocations	70.00%
Asset allocations	62.00%
Minimum \| Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%
Minimum \| Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	1.00%
Maximum \| Return Seeking Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	12.00%
Maximum \| Risk Mitigating Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on plan assets	4.00%

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning Balance	$ 2,368	$ 2,177	$ 2,063
Accretion expense	92	86	81
Liabilities incurred and acquired	0	0	0
Deconsolidation	0	0	0
Payments	(3)	(2)	(2)
Revisions	125	107	35
Ending Balance	2,582	$ 2,368	$ 2,177
Revisions for early decommissioning of SONGS	$ 22

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - TRANSACTIONS WITH AFFILIATES (Details)	12 Months Ended
	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2021 MXN ($)	Nov. 30, 2021 USD ($)
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	$ 49,000,000	$ 22,000,000	$ 11,000,000
Due from unconsolidated affiliates - noncurrent	637,000,000	780,000,000	742,000,000
Due to unconsolidated affiliates, noncurrent	(287,000,000)	(234,000,000)	(195,000,000)
Due to unconsolidated affiliates - current	(36,000,000)	(31,000,000)	(47,000,000)
Total facility	9,535,000,000				$ 1,000,000,000
Due to/from Sempra Energy
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(36,000,000)	(31,000,000)	(45,000,000)
Income taxes due (from) Sempra Energy	6,000,000	(37,000,000)	152,000,000
Due to/from SoCalGas
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	(48,000,000)	(21,000,000)	(10,000,000)
Due to/from Various Affiliates
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	1,000,000	1,000,000	1,000,000
Due to unconsolidated affiliates - current	(9,000,000)	(5,000,000)	(6,000,000)
Due to/from SDGE
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - current	48,000,000	21,000,000	10,000,000
Other related parties
Related Party Transaction [Line Items]
Due to unconsolidated affiliates - current	0	$ 0	(2,000,000)
LIBOR \| ESJ JV
Related Party Transaction [Line Items]
Variable percentage rate		1.96%
Related party transaction rate		2.11%
LIBOR \| TAG Pipeline Norte JV
Related Party Transaction [Line Items]
Variable percentage rate		2.90%
Related party transaction rate		3.16%
Sempra Infrastructure
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	(287,000,000)	$ (234,000,000)	(195,000,000)
Sempra Infrastructure \| ESJ JV
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	0	85,000,000	0
Accrued interest receivable		1,000,000
Sempra Infrastructure \| IMG JV
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	637,000,000	695,000,000	742,000,000
Due from affiliates, allowance for credit loss	1,000,000	3,000,000
Accrued interest receivable	2,000,000	2,000,000
Total facility	691,000,000			$ 14,200,000,000
Sempra Infrastructure \| Due From Sempra Mexico
Related Party Transaction [Line Items]
Due from unconsolidated affiliates - noncurrent	637,000,000	780,000,000	742,000,000
Sempra Infrastructure \| TAG Pipeline Norte JV
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	0	0	(39,000,000)
Sempra Infrastructure \| TAG Pipeline Norte JV \| Other Long term Debt Currently Through December 2021
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	0	(41,000,000)	0
Sempra Infrastructure \| TAG Pipeline Norte JV \| Other Long term Debt Currently Through January 2024
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (69,000,000)	(68,000,000)	0
Stated percentage rate	5.50%			5.50%
Sempra Infrastructure \| TAG Pipeline Norte JV \| Five Point Five Notes Due January 2025
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (21,000,000)	0	0
Stated percentage rate	5.50%			5.50%
Sempra Infrastructure \| TAG Pipeline Norte JV \| Five Point Five Notes Due July 2025
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (20,000,000)	0	0
Stated percentage rate	5.50%			5.50%
Sempra Infrastructure \| TAG JV Notes
Related Party Transaction [Line Items]
Due to unconsolidated affiliates, noncurrent	$ (177,000,000)	$ (166,000,000)	$ (156,000,000)
Stated percentage rate	5.74%			5.74%
Sempra Infrastructure \| Interbank Equilibrium Rate \| IMG JV
Related Party Transaction [Line Items]
Variable percentage rate	2.20%
Related party transaction rate	8.06%

INCOME TAXES - DEFERRED INCOME TAXES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets	$ 1,444	$ 1,322	$ 1,246
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	47	46	153
Regulatory balancing accounts	215	362	327
Right-of-use assets – operating leases	16	21	22
Property taxes	17	17	14
Other deferred income tax liabilities	1	1	1
Total deferred income tax liabilities	1,693	1,723	1,610
Deferred income tax assets:
Tax credits	3	3	3
Net operating losses	706	1,299	911
Postretirement benefits	18	123	120
Compensation-related items	33	36	25
Operating lease liabilities	16	21	22
Other deferred income tax assets	18	15	13
Bad debt allowance	15	15	1
State income taxes	12	11	8
Accrued expenses not yet deductible	539	93	15
Deferred income tax assets before valuation allowances	2,934	3,198	2,663
Less: valuation allowances	183	174	144
Total deferred income tax assets	654	317	207
Net deferred income tax liability	1,039	1,406	1,403
Deferred income taxes assets, noncurrent	151	136	155
Deferred income tax liabilities, noncurrent	$ 3,477	$ 2,871	$ 2,577

REVENUES (Tables)

12 Months Ended

Dec. 31, 2021

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 Infrastructure		Sempra Renewables		Consolidating adjustments and Parent and other		Sempra
	Year ended December 31, 2021
By major service line:
Utilities	$	5,144	$	5,424	$	81	$	—	$	(109)	$	10,540
Energy-related businesses	—		—		1,165		—		(29)		1,136
Revenues from contracts with customers	$	5,144	$	5,424	$	1,246	$	—	$	(138)	$	11,676
By market:
Gas	$	790	$	5,424	$	856	$	—	$	(101)	$	6,969
Electric	4,354		—		390		—		(37)		4,707
Revenues from contracts with customers	$	5,144	$	5,424	$	1,246	$	—	$	(138)	$	11,676

Revenues from contracts with customers	$	5,144	$	5,424	$	1,246	$	—	$	(138)	$	11,676
Utilities regulatory revenues	360		91		—		—		—		451
Other revenues	—		—		751		—		(21)		730
Total revenues	$	5,504	$	5,515	$	1,997	$	—	$	(159)	$	12,857

	Year ended December 31, 2020
By major service line:
Utilities	$	4,920	$	4,571	$	58	$	—	$	(94)	$	9,455
Energy-related businesses	—		—		854		—		1		855
Revenues from contracts with customers	$	4,920	$	4,571	$	912	$	—	$	(93)	$	10,310
By market:
Gas	$	692	$	4,571	$	623	$	—	$	(90)	$	5,796
Electric	4,228		—		289		—		(3)		4,514
Revenues from contracts with customers	$	4,920	$	4,571	$	912	$	—	$	(93)	$	10,310

Revenues from contracts with customers	$	4,920	$	4,571	$	912	$	—	$	(93)	$	10,310
Utilities regulatory revenues	393		177		—		—		—		570
Other revenues	—		—		488		—		2		490
Total revenues	$	5,313	$	4,748	$	1,400	$	—	$	(91)	$	11,370

	Year ended December 31, 2019
By major service line:
Utilities	$	4,819	$	4,367	$	73	$	—	$	(75)	$	9,184
Energy-related businesses	—		—		951		5		1		957
Revenues from contracts with customers	$	4,819	$	4,367	$	1,024	$	5	$	(74)	$	10,141
By market:
Gas	$	587	$	4,367	$	711	$	—	$	(69)	$	5,596
Electric	4,232		—		313		5		(5)		4,545
Revenues from contracts with customers	$	4,819	$	4,367	$	1,024	$	5	$	(74)	$	10,141

Revenues from contracts with customers	$	4,819	$	4,367	$	1,024	$	5	$	(74)	$	10,141
Utilities regulatory revenues	106		158		—		—		—		264
Other revenues	—		—		430		5		(11)		424
Total revenues	$	4,925	$	4,525	$	1,454	$	10	$	(85)	$	10,829

Schedule of Timing of Remaining Performance Obligations


REMAINING PERFORMANCE OBLIGATIONS(1)
(Dollars in millions)
	Sempra		SDG&E
2022	$	368	$	4
2023	367		4
2024	365		4
2025	362		4
2026	361		4
Thereafter	4,289		63
Total revenues to be recognized	$	6,112	$	83

(1) Excludes intercompany transactions.

Schedule of Contract Liabilities

Activities within Sempra’s and SDG&E’s contract liabilities are presented below. There were no contract liabilities at SoCalGas in 2021, 2020 or 2019.


CONTRACT LIABILITIES
(Dollars in millions)
	2021		2020		2019
Sempra:
Contract liabilities at January 1	$	(207)	$	(163)	$	(70)
Revenue from performance obligations satisfied during reporting period	52		4		2
Payments received in advance	(123)		(48)		(95)
Contract liabilities at December 31(1)	$	(278)	$	(207)	$	(163)
SDG&E:
Contract liabilities at January 1	$	(87)	$	(91)	$	—
Revenue from performance obligations satisfied during reporting period	4		4		1
Payments received in advance	—		—		(92)
Contract liabilities at December 31(2)	$	(83)	$	(87)	$	(91)

(1) Balances at December 31, 2021, 2020 and 2019 include $116, $52 and $4, respectively, in Other Current Liabilities and $162, $155 and $159, respectively, in Deferred Credits and Other.

(2) Balances at December 31, 2021, 2020 and 2019 include $4, $4 and $4, respectively, in Other Current Liabilities and $79, $83 and $87, respectively, in Deferred Credits and Other.

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,
	2021		2020		2019
Sempra:
Accounts receivable – trade, net	$	1,886	$	1,447	$	1,163
Accounts receivable – other, net	19		12		16
Due from unconsolidated affiliates – current(1)	2		3		5
Other long-term assets	70		—		—
Total	$	1,977	$	1,462	$	1,184
SDG&E:
Accounts receivable – trade, net	$	715	$	573	$	398
Accounts receivable – other, net	9		8		5
Due from unconsolidated affiliates – current(1)	2		2		2
Other long-term assets	25		—		—
Total	$	751	$	583	$	405
SoCalGas:
Accounts receivable – trade, net	$	1,084	$	786	$	710
Accounts receivable – other, net	10		4		11
Other long-term assets	45		—		—
Total	$	1,139	$	790	$	721

(1) Amount is presented net of amounts due to unconsolidated affiliates on the Consolidated Balance Sheets, when right of offset exists.

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - RECLASSIFICATION FROM ACCUMULATED OTHER COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	$ 0	$ 1,840	$ 328
Gain (loss) on sale of assets	36	(3)	63
Interest expense	(157)	(158)	(141)
Equity earnings	1,343	1,015	580
Energy-related businesses	1,866	1,345	1,381
Other (expense) income, net	14	28	55
Income from continuing operations before income taxes and equity earnings	(736)	601	762
Income tax benefit (expense)	310	(96)	(120)
Income from continuing operations, net of income tax	1,463	2,255	1,999
Earnings attributable to noncontrolling interest	0	0	(7)
Reclassification out of Accumulated Other Comprehensive Income
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	2	2	1
Reclassification out of Accumulated Other Comprehensive Income \| Foreign currency translation adjustments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	0	645	0
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Income from continuing operations before income taxes and equity earnings	92	67	11
Income tax benefit (expense)	(24)	(19)	(2)
Income from continuing operations, net of income tax	68	48	9
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments \| Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Gain (loss) on sale of assets	0	0	10
Interest expense	0	0	3
Equity earnings	73	46	3
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments \| Foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Equity earnings	0	0	2
Energy-related businesses	1	(1)	2
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments \| Interest rate and foreign exchange instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	1	1	0
Other (expense) income, net	6	11	(9)
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments attributable to Noncontrolling interests
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings attributable to noncontrolling interest	0	0	(3)
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments attributable to parent
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Net Income (Loss) Attributable to Parent	0	0	0
Reclassification out of Accumulated Other Comprehensive Income \| Financial instruments attributable to parent \| Interest rate instruments
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Interest expense	0	0	1
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of actuarial loss
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	0	6	1
Other (expense) income, net	1	1	1
Reclassification out of Accumulated Other Comprehensive Income \| Amortization of prior service cost
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	1	1	0
Reclassification out of Accumulated Other Comprehensive Income \| Accumulated Defined Benefit Plans Adjustment, Net Settlements Attributable to Parent
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Other (expense) income, net	7	22	28
Reclassification out of Accumulated Other Comprehensive Income \| Pension and other postretirement benefits
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items]
Earnings from discontinued operations attributable to common shares	0	(2)	0
Income from continuing operations before income taxes and equity earnings	2	2	1
Income tax benefit (expense)	0	0	(1)
Income from continuing operations, net of income tax	$ 2	$ 2	$ 0

DERIVATIVE FINANCIAL INSTRUMENTS - CASH FLOW HEDGES ADDITIONAL INFORMATION (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Derivative Instruments, Gain (Loss) [Line Items]
Cash flow hedge gain (loss) to be reclassified within 12 months	$ (1)
Maximum length of time hedged in cash flow hedge	13 years
Cash flow hedge gain (loss) to be reclassified within 12 months, attributable to noncontrolling interest	$ (1)
Equity Method Investee
Derivative Instruments, Gain (Loss) [Line Items]
Maximum length of time hedged in cash flow hedge	18 years

DEBT AND CREDIT FACILITIES - LONG-TERM DEBT NARRATIVE (Details)					1 Months Ended
	Feb. 18, 2022 USD ($)	Jan. 11, 2022 USD ($)	Oct. 13, 2021 USD ($)	Oct. 08, 2021 USD ($)	Dec. 31, 2021 USD ($)	Nov. 30, 2021 USD ($)	Aug. 31, 2021 USD ($)	Mar. 31, 2021 USD ($) lender	Dec. 31, 2020 USD ($) MMBbls	Mar. 19, 2021	Mar. 18, 2021	Dec. 31, 2019 USD ($)
Debt Instrument [Line Items]
Unsecured Debt					$ 309,000,000
First mortgage bonds available for future issuance					1,900,000,000
Term of contract						3 years
Total facility					9,535,000,000	$ 1,000,000,000
Gross long-term debt					$ 8,923,000,000				$ 11,247,000,000			$ 12,298,000,000
ESJ
Debt Instrument [Line Items]
Variable percentage rate								2.63%
Underwriting discounts and debt issuance costs				$ 18,000,000				$ 6,000,000
Debt Instrument, Face Amount Issued, Percentage Of Principal								90.00%
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt								$ 177,000,000
Business Combination, Debt Assumed, Number Of Lenders \| lender								5
Debt Instrument, Fixed Rate								6.13%
Debt Instrument, Remaining Principal Balance, Percent								10.00%
Debt Instrument, Basis Spread On Variable Rate, Increase Every Four Years								0.25%
Write off of Deferred Debt Issuance Costs, After Tax and Noncontrolling Interest				10,000,000
Repayments of assumed debt				$ 175,000,000
Subsequent Event \| Secured Debt [Member]
Debt Instrument [Line Items]
Term of contract	2 years
Debt amount	$ 400,000,000
Proceeds from issuance of debt	200,000,000
Aggregate amount of borrowings that may be requested	$ 400,000,000
Variable percentage rate	0.625%
ECA LNG JV
Debt Instrument [Line Items]
Ownership percentage in consolidated entity									16.60%
ESJ
Debt Instrument [Line Items]
Ownership percentage held by noncontrolling owners								50.00%	50.00%	50.00%	50.00%
Loan Agreement To Finance Natural Gas Liquefaction Export Facility
Debt Instrument [Line Items]
Term of contract									5 years
Total facility									$ 1,600,000,000
Name plate capacity (in Mtpa) \| MMBbls									3.25
Initial offtake capacity (in Mtpa) \| MMBbls									2.5
Stated percentage rate									2.70%
Long-term debt outstanding									$ 17,000,000
Weighted average rate					2.93%				2.82%
Loan at variable rates (2.93% at December 31, 2021) December 9, 2025
Debt Instrument [Line Items]
Stated percentage rate					2.93%
Gross long-term debt					$ 341,000,000				$ 17,000,000			0
Green First Mortgage Bonds Due 2051
Debt Instrument [Line Items]
Stated percentage rate							2.95%
Debt amount							$ 750,000,000
Proceeds from issuance of debt							737,000,000
Underwriting discounts and debt issuance costs							$ 13,000,000
Senior Unsecured Notes Maturing 2022 Through 2025
Debt Instrument [Line Items]
Underwriting discounts and debt issuance costs					126,000,000
Debt issuance costs (after tax)					92,000,000
Repayments of Other Debt					$ 2,350,000,000
4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instrument [Line Items]
Stated percentage rate					4.125%	4.125%
Gross long-term debt					$ 1,000,000,000				0			0
Debt amount						$ 1,000,000,000
Proceeds from issuance of debt						988,000,000
Underwriting discounts and debt issuance costs						$ 12,000,000
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed						102.00%
Debt instrument, redemption price (as a percent)						100.00%
4.125% Junior Subordinated Notes April 1, 2052(1) \| US Treasury (UST) Interest Rate
Debt Instrument [Line Items]
Variable percentage rate						2.868%
5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instrument [Line Items]
Stated percentage rate					5.75%
Gross long-term debt					$ 758,000,000				$ 758,000,000			$ 758,000,000
Senior Notes 3.25% Due 2032 \| Subsequent Event
Debt Instrument [Line Items]
Stated percentage rate		3.25%
Debt amount		$ 400,000,000
Proceeds from issuance of debt		$ 390,000,000
Variable percentage rate		0.25%
Underwriting discounts and debt issuance costs		$ 10,000,000
Debt Instrument, Face Amount Issued, Percentage Of Principal		98.903%
Debt instrument, redemption price (as a percent)		101.00%
Senior Notes 3.25% Due 2032 \| Subsequent Event \| Period one
Debt Instrument [Line Items]
Debt instrument, redemption price (as a percent)		100.00%
Variable Rate Loan Payable Maturing 2033 \| Ventika
Debt Instrument [Line Items]
Write off of Deferred Debt Issuance Costs, After Tax and Noncontrolling Interest			$ 20,000,000
Repayments of debt			375,000,000
Write off of Deferred Debt Issuance Cost			$ 36,000,000

INCOME TAXES (Tables)

12 Months Ended

Dec. 31, 2021

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,
	2021			2020			2019
Sempra:
Income tax expense from continuing operations	$	99		$	249		$	315

Income from continuing operations before income taxes and equity earnings	$	219		$	1,489		$	1,734
Equity earnings, before income tax(1)	614			294			30
Pretax income	$	833		$	1,783		$	1,764

Effective income tax rate	12		%	14		%	18		%
SDG&E:
Income tax expense	$	201		$	190		$	171
Income before income taxes	$	1,020		$	1,014		$	945
Effective income tax rate	20		%	19		%	18		%
SoCalGas:
Income tax (benefit) expense	$	(310)		$	96		$	120
(Loss) income before income taxes	$	(736)		$	601		$	762
Effective income tax rate	42		%	16		%	16		%

(1) We discuss how we recognize equity earnings in Note 6.

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,
	2021		2020		2019
Sempra:
U.S. federal statutory income tax rate	21	%	21	%	21	%
Outside basis differences	9		—		—
Utility depreciation	8		3		3
Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate(1)	5		2		3
Foreign exchange and inflation effects(2)	1		(3)		4
Valuation allowances	1		(1)		—
Tax credits	—		(1)		(2)
Excess deferred income taxes outside of ratemaking	—		—		(4)
Compensation-related items	(1)		(1)		—
Impairment losses	(1)		1		—

Noncontrolling interests	(2)		—		—
Allowance for equity funds used during construction	(3)		(1)		(1)
Amortization of excess deferred income taxes	(3)		(1)		(1)
Remeasurement of deferred taxes	(4)		—		—
State income taxes, net of federal income tax benefit	(4)		1		2
Utility self-developed software expenditures	(5)		(3)		(2)
Utility repairs expenditures	(9)		(4)		(3)
Other, net	(1)		1		(2)
Effective income tax rate	12	%	14	%	18	%
SDG&E:
U.S. federal statutory income tax rate	21	%	21	%	21	%
State income taxes, net of federal income tax benefit	5		5		6
Depreciation	3		3		3
Excess deferred income taxes outside of ratemaking	—		—		(3)
Self-developed software expenditures	(1)		(4)		(3)
Amortization of excess deferred income taxes	(2)		(1)		(1)
Allowance for equity funds used during construction	(2)		(2)		(1)
Repairs expenditures	(4)		(3)		(3)
Other, net	—		—		(1)
Effective income tax rate	20	%	19	%	18	%
SoCalGas:
U.S. federal statutory income tax rate	21	%	21	%	21	%
State income taxes, net of federal income tax benefit	11		2		4
Repairs expenditures	5		(7)		(4)
Self-developed software expenditures	5		(4)		(2)
Amortization of excess deferred income taxes	2		(1)		(1)
Allowance for equity funds used during construction	1		(1)		(1)
Nondeductible expenditures	—		2		—
Excess deferred income taxes outside of ratemaking	—		—		(5)
Depreciation	(5)		5		4
Other, net	2		(1)		—
Effective income tax rate	42	%	16	%	16	%

(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 (Expense), Net, on the Consolidated Statements of Operations from foreign currency derivatives that are partially hedging Sempra Infrastructure’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
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
By geographic components:
U.S.	$	346	$	1,461	$	1,191
Non-U.S.	487		322		573
Total(1)	$	833	$	1,783	$	1,764

(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,
	2021		2020		2019
Sempra:
Current:
U.S. state	$	(6)	$	(22)	$	(14)
Non-U.S.	183		112		140
Total	177		90		126
Deferred:
U.S. federal	(9)		157		87
U.S. state	(37)		36		21
Non-U.S.	(31)		(34)		84
Total	(77)		159		192
Deferred investment tax credits	(1)		—		(3)
Total income tax expense	$	99	$	249	$	315
SDG&E:
Current:
U.S. federal	$	35	$	121	$	35
U.S. state	13		34		31
Total	48		155		66
Deferred:
U.S. federal	99		11		75
U.S. state	54		25		32
Total	153		36		107
Deferred investment tax credits	—		(1)		(2)
Total income tax expense	$	201	$	190	$	171
SoCalGas:
Current:
U.S. federal	$	134	$	163	$	8
U.S. state	50		45		24
Total	184		208		32
Deferred:
U.S. federal	(334)		(85)		79
U.S. state	(159)		(28)		10
Total	(493)		(113)		89
Deferred investment tax credits	(1)		1		(1)
Total income tax (benefit) expense	$	(310)	$	96	$	120

Schedule Of Components Of Deferred Tax Assets And Liabilities

The tables below present the components of deferred income taxes:


DEFERRED INCOME TAXES – SEMPRA
(Dollars in millions)
	December 31,
	2021		2020		2019
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets(1)	$	5,230	$	4,891	$	4,052
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	47		46		153
Regulatory balancing accounts	538		587		468
Right-of-use assets – operating leases	160		144		131
Property taxes	52		51		44
Other deferred income tax liabilities	50		40		93
Total deferred income tax liabilities	6,077		5,759		4,941
Deferred income tax assets:
Tax credits	1,135		1,161		1,136
Net operating losses	706		1,299		911
Postretirement benefits	30		162		200
Compensation-related items	164		169		161
Operating lease liabilities	140		125		131
Other deferred income tax assets	130		97		60
State income taxes	21		20		8
Bad debt allowance	33		35		4
Accrued expenses not yet deductible	575		130		52
Deferred income tax assets before valuation allowances	2,934		3,198		2,663
Less: valuation allowances	183		174		144
Total deferred income tax assets	2,751		3,024		2,519
Net deferred income tax liability(2)	$	3,326	$	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, 2021, 2020, and 2019, includes $151, $136, and $155, respectively, recorded as a noncurrent asset and $3,477, $2,871, and $2,577, 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,
	2021		2020		2019		2021		2020		2019
Deferred income tax liabilities:
Differences in financial and tax bases of utility plant and other assets	$	1,970	$	1,833	$	1,735	$	1,444	$	1,322	$	1,246
Regulatory balancing accounts	323		224		141		215		362		327
Right-of-use assets – operating leases	52		28		32		16		21		22
Property taxes	35		34		30		17		17		14
Other	1		2		14		1		1		1
Total deferred income tax liabilities	2,381		2,121		1,952		1,693		1,723		1,610
Deferred income tax assets:
Tax credits	5		5		6		3		3		3
Postretirement benefits	—		14		37		18		123		120
Compensation-related items	12		12		6		33		36		25
Operating lease liabilities	52		28		32		16		21		22
Bad debt allowance	16		18		3		15		15		1
State income taxes	4		8		7		12		11		8
Accrued expenses not yet deductible	16		14		9		539		93		15
Other	1		3		4		18		15		13
Total deferred income tax assets	106		102		104		654		317		207
Net deferred income tax liability	$	2,275	$	2,019	$	1,848	$	1,039	$	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, 2021		Year expiration begins
Sempra:
U.S. federal:
NOLs(1)	$	3,263	Indefinite
General business tax credits(1)	436		2032
Foreign tax credits(2)	688		2024
U.S. state(2):
NOLs	2,938		2022
General business tax credits	6		2022
Non-U.S.(2) – NOLs	248		2022

(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, 2021		Year expiration begins
Sempra:
U.S. federal:
NOLs(1)	$	3,263	Indefinite
General business tax credits(1)	436		2032
Foreign tax credits(2)	688		2024
U.S. state(2):
NOLs	2,938		2022
General business tax credits	6		2022
Non-U.S.(2) – NOLs	248		2022

(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.

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” table.


VALUATION ALLOWANCES
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
U.S. federal	$	128	$	118	$	90

U.S. state	31		32		33

Non-U.S.	24		24		21








	$	183	$	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)
	2021		2020		2019
Sempra:
Balance at January 1	$	99	$	93	$	119
Increase in prior period tax positions	3		3		5
Decrease in prior period tax positions	(2)		(1)		—
Increase in current period tax positions	204		4		2
Settlements with taxing authorities	—		—		(32)
Expiration of statutes of limitations	—		—		(1)
Balance at December 31	$	304	$	99	$	93
Of December 31 balance, amounts related to tax positions that if recognized in future years would
decrease the effective tax rate(1)	$	(105)	$	(87)	$	(81)
increase the effective tax rate(1)	34		31		27
SDG&E:
Balance at January 1	$	13	$	12	$	11
Increase in prior period tax positions	1		1		1
Balance at December 31	$	14	$	13	$	12
Of December 31 balance, amounts related to tax positions that if recognized in future years would
decrease the effective tax rate(1)	$	(11)	$	(10)	$	(9)
increase the effective tax rate(1)	1		1		1
SoCalGas:
Balance at January 1	$	68	$	64	$	61
Increase in prior period tax positions	1		1		1
Increase in current period tax positions	3		3		2
Balance at December 31	$	72	$	68	$	64
Of December 31 balance, amounts related to tax positions that if recognized in future years would
decrease the effective tax rate(1)	$	(63)	$	(59)	$	(55)
increase the effective tax rate(1)	33		30		26

(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,
	2021		2020		2019
Sempra:
Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities	$	8	$	8	$	8
SDG&E:
Potential resolution of audit issues with various U.S. federal, state and local taxing authorities	$	6	$	6	$	6
SoCalGas:
Potential resolution of audit issues with various U.S. federal, state and local taxing authorities	$	2	$	2	$	2

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SCG - USD ($) $ in Millions	Total	Cumulative Effect, Period of Adoption, Adjustment	Cumulative Effect, Period of Adoption, Adjusted Balance	Preferred stock	Preferred stock Cumulative Effect, Period of Adoption, Adjusted Balance	Common stock	Common stock Cumulative Effect, Period of Adoption, Adjusted Balance	Retained earnings	Retained earnings Cumulative Effect, Period of Adoption, Adjustment	Retained earnings Cumulative Effect, Period of Adoption, Adjusted Balance	Accumulated other comprehensive income (loss)	Accumulated other comprehensive income (loss) Cumulative Effect, Period of Adoption, Adjustment	Accumulated other comprehensive income (loss) Cumulative Effect, Period of Adoption, Adjusted Balance
Beginning Balance at Dec. 31, 2018	$ 4,258		$ 4,256	$ 22	$ 22	$ 866	$ 866	$ 3,390		$ 3,392	$ (20)		$ (24)
Beginning Balance (Accounting Standards Update 2018-02) at Dec. 31, 2018		$ (2)							$ 2			$ (4)
Net (loss) income	642							642
Other comprehensive income	1										1
Preferred stock dividends declared	(1)							(1)
Common stock dividends declared	(150)							(150)
Equity contribution from Sempra Energy	322					322
Ending balance at Dec. 31, 2019	4,748		$ 21,796	22	$ 2,258	866	$ 7,480	3,883		$ 11,123	(23)		$ (939)
Net (loss) income	505							505
Other comprehensive income	(8)										(8)
Preferred stock dividends declared	(1)							(1)
Common stock dividends declared	(100)							(100)
Ending balance at Dec. 31, 2020	5,144			22		866		4,287			(31)
Net (loss) income	(426)							(426)
Other comprehensive income	171										160
Preferred stock dividends declared	(1)							(1)
Common stock dividends declared	(75)							(75)
Equity contribution from Sempra Energy	800					800
Ending balance at Dec. 31, 2021	$ 5,442			$ 22		$ 1,666		$ 3,785			$ (31)

Amount after tax and reclassification adjustments of other comprehensive income (loss).

Commitments and Contingencies Disclosure [Abstract]

The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

COMMITMENTS AND CONTINGENCIES (Tables)

12 Months Ended

Dec. 31, 2021

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									SDG&E									SoCalGas
	December 31,
	2021			2020			2019			2021			2020			2019			2021			2020			2019
ROU assets:
Operating leases:
ROU assets	$	594		$	543		$	591		$	185		$	102		$	130		$	57		$	74		$	94

Finance leases:
PP&E	1,473			1,429			1,353			1,381			1,356			1,326			92			73			27
Accumulated depreciation	(138)			(99)			(64)			(107)			(80)			(57)			(31)			(19)			(7)
PP&E, net	1,335			1,330			1,289			1,274			1,276			1,269			61			54			20
Total ROU assets	$	1,929		$	1,873		$	1,880		$	1,459		$	1,378		$	1,399		$	118		$	128		$	114

Lease liabilities:
Operating leases:
Other current liabilities	$	49		$	52		$	52		$	26		$	27		$	27		$	15		$	18		$	18
Deferred credits and other	470			407			445			159			73			102			41			56			75
	519			459			497			185			100			129			56			74			93
Finance leases:
Current portion of long-term debt and finance leases	43			36			26			32			26			20			11			10			6
Long-term debt and finance leases	1,292			1,294			1,263			1,242			1,250			1,250			50			44			13
	1,335			1,330			1,289			1,274			1,276			1,270			61			54			19
Total lease liabilities	$	1,854		$	1,789		$	1,786		$	1,459		$	1,376		$	1,399		$	117		$	128		$	112

Weighted-average remaining lease term (in years):
Operating leases	14			13			13			11			6			6			4			5			6
Finance leases	17			18			19			17			19			20			7			7			6
Weighted-average discount rate:
Operating leases	5.45		%	5.81		%	6.01		%	3.22		%	3.62		%	3.55		%	1.98		%	2.03		%	3.73		%
Finance leases	14.25		%	14.45		%	14.76		%	14.48		%	14.65		%	14.83		%	2.91		%	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						SDG&E						SoCalGas
	Years ended December 31,
	2021		2020		2019		2021		2020		2019		2021		2020		2019

Operating lease costs	$	89	$	92	$	96	$	32	$	31	$	33	$	20	$	24	$	27

Finance lease costs:
Amortization of ROU assets(2)	39		35		24		27		23		18		12		12		6
Interest on lease liabilities	186		188		173		184		186		173		2		2		—
Total finance lease costs	225		223		197		211		209		191		14		14		6

Short-term lease costs(3)	7		7		6		1		3		2		—		—		—
Variable lease costs(3)	432		477		482		422		467		471		10		10		10
Total lease costs	$	753	$	799	$	781	$	666	$	710	$	697	$	44	$	48	$	43

(1) Includes costs capitalized in PP&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 and supplemental noncash information were as follows:


LESSEE INFORMATION ON THE CONSOLIDATED STATEMENTS OF CASH FLOWS
(Dollars in millions)
	Sempra						SDG&E						SoCalGas
	Years ended December 31
	2021		2020		2019		2021		2020		2019		2021		2020		2019
Operating activities:
Cash paid for operating leases	$	78	$	79	$	101	$	32	$	31	$	33	$	20	$	24	$	27
Cash paid for finance leases	171		173		173		169		171		173		2		2		—
Financing activities:
Cash paid for finance leases	39		35		24		27		23		18		12		12		6
Increase (decrease) in operating lease obligations for ROU assets	116		20		585		112		(1)		158		1		1		118
Increase in finance lease obligations for investment in PP&E	43		77		38		24		30		16		19		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, 2021
	Sempra				SDG&E				SoCalGas
	Operating leases(1)		Finance leases(2)		Operating leases(1)		Finance leases(2)		Operating leases		Finance leases
2022	$	73	$	209	$	30	$	197	$	17	$	12
2023	66		208		27		197		13		11
2024	62		203		25		192		11		11
2025	50		199		16		188		10		11
2026	48		196		15		188		8		8
Thereafter	493		2,292		105		2,279		—		13
Total undiscounted lease payments	792		3,307		218		3,241		59		66
Less: imputed interest	(273)		(1,972)		(33)		(1,967)		(3)		(5)
Total lease liabilities	519		1,335		185		1,274		56		61
Less: current lease liabilities	(49)		(43)		(26)		(32)		(15)		(11)
Long-term lease liabilities	$	470	$	1,292	$	159	$	1,242	$	41	$	50

(1) Includes $9 in each of 2022 through 2026 and $87 thereafter related to purchased-power contracts.

(2) 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, 2021
	Sempra				SDG&E				SoCalGas
	Operating leases(1)		Finance leases(2)		Operating leases(1)		Finance leases(2)		Operating leases		Finance leases
2022	$	73	$	209	$	30	$	197	$	17	$	12
2023	66		208		27		197		13		11
2024	62		203		25		192		11		11
2025	50		199		16		188		10		11
2026	48		196		15		188		8		8
Thereafter	493		2,292		105		2,279		—		13
Total undiscounted lease payments	792		3,307		218		3,241		59		66
Less: imputed interest	(273)		(1,972)		(33)		(1,967)		(3)		(5)
Total lease liabilities	519		1,335		185		1,274		56		61
Less: current lease liabilities	(49)		(43)		(26)		(32)		(15)		(11)
Long-term lease liabilities	$	470	$	1,292	$	159	$	1,242	$	41	$	50

(1) Includes $9 in each of 2022 through 2026 and $87 thereafter related to purchased-power contracts.

(2) Substantially all amounts are related to purchased-power contracts.

Lessor, Operating Lease, Payments to be Received, Maturity


LESSOR INFORMATION – SEMPRA
(Dollars in millions)
	December 31,
	2021		2020		2019
Assets subject to operating leases:
Property, plant and equipment(1)	$	1,499	$	1,092	$	1,038
Accumulated depreciation	(276)		(228)		(179)
Property, plant and equipment, net	$	1,223	$	864	$	859

			December 31, 2021
Maturity analysis of lease payments:			Operating leases		Sales-type leases
2022			$	272	$	16
2023			272		16
2024			273		17
2025			272		17
2026			272		9
Thereafter			3,031		—
Total undiscounted cash flows			$	4,392	75
Present value of lease payments (recognized as lease receivable)(2)					55
Difference between undiscounted cash flows and discounted cash flows					$	20

(1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.

(2) Includes $9 in Other Current Assets and $46 in Other Long-Term Assets on the Consolidated Balance Sheet.

Operating Lease, Lease Income


LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sales-type leases:
Income recognized at lease commencement	$	18	$	1	$	—
Interest income	4		1		—
Total revenues from sales-type leases(1)	$	22	$	2	—

Operating leases:
Fixed lease payments	$	256	$	195	$	200
Variable lease payments	10		1		6
Total revenues from operating leases(1)	$	266	$	196	$	206

Depreciation expense	$	48	$	39	$	38

(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, 2021, the future minimum payments under existing natural gas contracts and natural gas storage and transportation contracts are as follows:


FUTURE MINIMUM PAYMENTS
(Dollars in millions)
	Sempra						SoCalGas
	Storage and transportation		Natural gas(1)		Total(1)		Transportation
2022	$	214	$	20	$	234	$	134
2023	204		39		243		132
2024	181		15		196		114
2025	141		7		148		77
2026	137		—		137		75
Thereafter	903		—		903		310
Total minimum payments	$	1,780	$	81	$	1,861	$	842

(1) Excludes amounts related to the LNG purchase agreement discussed below.

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 and SoCalGas were as follows:


PAYMENTS UNDER NATURAL GAS CONTRACTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra	$	1,691	$	989	$	1,326
SoCalGas	1,590		935		1,181

Schedule Of L N G Commitment Amounts

At December 31, 2021, the following LNG commitment amounts are based on the assumption that all LNG cargoes, less those already confirmed to be diverted, under the agreement are delivered:


LNG COMMITMENT AMOUNTS
(Dollars in millions)
Sempra:
2022	$	435
2023	553
2024	516
2025	518
2026	519
Thereafter	1,381
Total	$	3,922

Schedule Of Estimated Future Payments Under Purchased Power Contracts

At December 31, 2021, the future minimum payments under long-term purchased-power contracts for Sempra and SDG&E are as follows:


FUTURE MINIMUM PAYMENTS – PURCHASED-POWER CONTRACTS
(Dollars in millions)
2022	$	218
2023	188
2024	162
2025	105
2026	100
Thereafter	817
Total minimum payments(1)	$	1,590

(1) Excludes purchase agreements accounted for as operating leases and 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,
	2021		2020		2019
Sempra	$	95	$	76	$	80
SDG&E	32		39		39
SoCalGas	63		37		41

Schedule Of Environmental Remediation Costs, Status Of Remediation Sites

The table below shows the status at December 31, 2021 of SDG&E’s and SoCalGas’ manufactured-gas sites and the third-party waste-disposal sites for which we have been identified as a PRP:


STATUS OF ENVIRONMENTAL SITES

	# Sites complete(1)	# Sites in process
SDG&E:
Manufactured-gas sites	3	—
Third-party waste-disposal sites	2	1
SoCalGas:
Manufactured-gas sites	39	3
Third-party waste-disposal sites	5	2

(1) There may be ongoing compliance obligations for completed sites, such as regular inspections, adherence to land use covenants and water quality monitoring.

Schedule of Environmental Loss Contingencies by Site


ACCRUED LIABILITIES FOR ENVIRONMENTAL MATTERS
(Dollars in millions)
	Manufactured- gas sites		Waste disposal sites (PRP)(1)		Other hazardous waste sites		Total(2)
SDG&E(3)	$	—	$	6	$	12	$	18
SoCalGas(4)	34		3		1		38
Other	—		1		—		1
Total Sempra	$	34	$	10	$	13	$	57

(1) Sites for which we have been identified as a PRP.

(3) Does not include SDG&E’s liability for SONGS marine environment mitigation.

Sales-type Lease, Lease Income


LESSOR INFORMATION ON THE CONSOLIDATED STATEMENTS OF OPERATIONS – SEMPRA
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sales-type leases:
Income recognized at lease commencement	$	18	$	1	$	—
Interest income	4		1		—
Total revenues from sales-type leases(1)	$	22	$	2	—

Operating leases:
Fixed lease payments	$	256	$	195	$	200
Variable lease payments	10		1		6
Total revenues from operating leases(1)	$	266	$	196	$	206

Depreciation expense	$	48	$	39	$	38

(1) Included in Revenues: Energy-Related Businesses on the Consolidated Statements of Operations.

Sales-type and Direct Financing Leases, Lease Receivable, Maturity


LESSOR INFORMATION – SEMPRA
(Dollars in millions)
	December 31,
	2021		2020		2019
Assets subject to operating leases:
Property, plant and equipment(1)	$	1,499	$	1,092	$	1,038
Accumulated depreciation	(276)		(228)		(179)
Property, plant and equipment, net	$	1,223	$	864	$	859

			December 31, 2021
Maturity analysis of lease payments:			Operating leases		Sales-type leases
2022			$	272	$	16
2023			272		16
2024			273		17
2025			272		17
2026			272		9
Thereafter			3,031		—
Total undiscounted cash flows			$	4,392	75
Present value of lease payments (recognized as lease receivable)(2)					55
Difference between undiscounted cash flows and discounted cash flows					$	20

(1) Included in Machinery and Equipment — Pipelines and Storage within the major functional categories of PP&E.

(2) Includes $9 in Other Current Assets and $46 in Other Long-Term Assets on the Consolidated Balance Sheet.

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SCG (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Preferred stock, dividends declared per share (USD per share)	$ 1.50	$ 1.50	$ 1.50
Common stock dividends declared (USD per share)	$ 0.82	$ 1.10	$ 1.64
Sale	$ 2,712	$ 28	$ 5

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR DECOMMISSIONING TRUSTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Securities, Available-for-sale [Line Items]
Cost	$ 735	$ 731	$ 729
Gross unrealized gains	282	290	360
Gross unrealized losses	(5)	(2)	(7)
Estimated fair value	1,012	1,019	1,082
Proceeds from sales	961	1,439	914
Gross realized gains	67	156	24
Gross realized losses	(5)	(17)	(5)
Debt securities issued by the U.S. Treasury and other U.S. government corporations and agencies
Debt Securities, Available-for-sale [Line Items]
Cost	56	64	57
Gross unrealized gains	0	1	0
Gross unrealized losses	0	0	0
Estimated fair value	56	65	57
Municipal bonds
Debt Securities, Available-for-sale [Line Items]
Cost	309	308	270
Gross unrealized gains	13	18	12
Gross unrealized losses	(1)	0	0
Estimated fair value	321	326	282
Other securities
Debt Securities, Available-for-sale [Line Items]
Cost	255	253	218
Gross unrealized gains	7	17	9
Gross unrealized losses	(2)	0	(1)
Estimated fair value	260	270	226
Debt Securities
Debt Securities, Available-for-sale [Line Items]
Cost	620	625	545
Gross unrealized gains	20	36	21
Gross unrealized losses	(3)	0	(1)
Estimated fair value	637	661	565
Equity securities
Debt Securities, Available-for-sale [Line Items]
Cost	104	112	176
Gross unrealized gains	262	254	339
Gross unrealized losses	(2)	(2)	(6)
Estimated fair value	364	364	509
Cash and cash equivalents
Debt Securities, Available-for-sale [Line Items]
Cost	3	3	16
Gross unrealized gains	0	0	0
Gross unrealized losses	0	0	0
Estimated fair value	3	3	16
Accounts Payable
Debt Securities, Available-for-sale [Line Items]
Cost	8	(9)	(8)
Gross unrealized gains	0	0	0
Gross unrealized losses	0	0	0
Estimated fair value	$ 8	$ (9)	$ (8)

SAN ONOFRE NUCLEAR GENERATING STATION - NARRATIVE (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Jointly Owned Utility Plant Interests [Line Items]
Period of environmental exit	10 years
Percentage of environmental exit costs incurred	20.00%
San Onofre Nuclear Generating Station (SONGS)
Jointly Owned Utility Plant Interests [Line Items]
Ownership percentage	20.00%
SONGS 2 and 3 Decommissioning
Jointly Owned Utility Plant Interests [Line Items]
Nuclear decommissioning trust authorized withdrawal amount	$ 78

ACQUISTIONS, DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)

12 Months Ended

Dec. 31, 2021

Business Combination and Asset Acquisition [Abstract]

Schedule Of Assets Held for Sale and Deconsolidation of Subsidiaries Table

Summarized results from discontinued operations were as follows:


DISCONTINUED OPERATIONS
(Dollars in millions)
	Years ended December 31,
	2020(1)		2019
Revenues	$	570	$	1,614
Cost of sales	(364)		(1,012)
Gain on sale of discontinued operations	2,899		—
Operating expenses	(66)		(159)
Interest and other	(3)		(11)
Income before income taxes and equity earnings	3,036		432
Income tax expense	(1,186)		(72)
Equity earnings	—		3
Income from discontinued operations, net of income tax	1,850		363
Earnings attributable to noncontrolling interests	(10)		(35)
Earnings from discontinued operations attributable to common shares	$	1,840	$	328

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.

Tabular disclosure of information related to a disposal group. Includes, but is not limited to, a discontinued operation, disposal classified as held-for-sale or disposed of by means other than sale or disposal of an individually significant component.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 360
-SubTopic 10
-Section 50
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=109226691&loc=SL51724579-110230

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109222650&loc=d3e1474-107760

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5D
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721677-107760

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 45
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=109222160&loc=SL51721533-107759

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 3A
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721659-107760

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721665-107760

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 360
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=109226691&loc=d3e2941-110230

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5C
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721675-107760

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721683-107760

Reference 10: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=109222650&loc=d3e1361-107760

Reference 11: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5A
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721671-107760

Reference 12: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 5B
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721673-107760

Reference 13: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 205
-SubTopic 20
-Section 50
-Paragraph 4A
-URI http://asc.fasb.org/extlink&oid=109222650&loc=SL51721663-107760

INCOME TAXES - RECONCILIATION TO EFFECTIVE TAX RATE (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Effective Income Tax Rate, Continuing Operations, Tax Rate Reconciliation [Line Items]
Income tax expense (benefit)	$ (310)	$ 96	$ 120
Income from continuing operations before income taxes and equity earnings	(736)	601	762
Income (loss) from equity method investments	614	294	30
Pretax income	$ (736)	$ 601	$ 762
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. federal statutory income tax rate	21.00%	21.00%	21.00%
Outside basis differences	9.00%	0.00%	0.00%
Depreciation	(5.00%)	5.00%	4.00%
Non-U.S. earnings taxed at lower statutory income tax rates	5.00%	2.00%	3.00%
Foreign exchange and inflation effects	1.00%	(3.00%)	4.00%
Valuation allowances	1.00%	(1.00%)	0.00%
Tax credits	0.00%	(1.00%)	(2.00%)
Excess deferred income taxes outside of ratemaking	0.00%	0.00%	(5.00%)
Compensation-related items	(1.00%)	(1.00%)	0.00%
Impairment losses	(1.00%)	1.00%	0.00%
Noncontrolling interests	(2.00%)	0.00%	0.00%
Allowance for equity funds used during construction	1.00%	(1.00%)	(1.00%)
Amortization of excess deferred income taxes	2.00%	(1.00%)	(1.00%)
Remeasurement of deferred taxes	(4.00%)	0.00%	0.00%
State income taxes, net of federal income tax benefit	11.00%	2.00%	4.00%
Self-developed software expenditures	5.00%	(4.00%)	(2.00%)
Utility repairs expenditures	5.00%	(7.00%)	(4.00%)
Other, net	2.00%	(1.00%)	0.00%
Nondeductible expenditures	0.00%	2.00%	0.00%
Effective income tax rate	42.00%	16.00%	16.00%

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - SDG&E (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Common stock dividends declared (USD per share)	$ 0.82	$ 1.10	$ 1.64

INCOME TAXES - COMPONENTS OF INCOME TAX EXPENSE (BENEFIT) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Income Tax Expense (Benefit), Continuing Operations [Abstract]
U.S.	$ 346	$ 1,461	$ 1,191
Non-U.S.	487	322	573
Pretax income	(736)	601	762
Current:
U.S. federal	134	163	8
U.S. state	50	45	24
Non-U.S.	183	112	140
Total	184	208	32
Deferred:
U.S. federal	(334)	(85)	79
U.S. state	(159)	(28)	10
Non-U.S.	(31)	(34)	84
Total	(493)	(113)	89
Deferred investment tax credits	(1)	1	(1)
Total income tax expense	$ (310)	$ 96	$ 120

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA (Policies)	12 Months Ended
	Dec. 31, 2021
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Principles of Consolidation	PRINCIPLES OF CONSOLIDATION Sempra Sempra’s Consolidated Financial Statements include the accounts of Sempra Energy, a California-based holding company doing business as Sempra, and its consolidated entities. In the fourth quarter of 2021, we formed Sempra Infrastructure, a new segment that includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Through an internal reorganization, we consolidated the assets of our LNG business (previously included in our Sempra LNG segment) and our ownership of IEnova (previously included in our Sempra Mexico segment) under Sempra Global (previously included in Parent and other), which was renamed SI Partners. This reorganization simplifies Sempra’s ownership and management of its non-utility, energy infrastructure assets in North America by consolidating them under a single platform. As a result, the Sempra LNG and Sempra Mexico segments no longer exist. Our historical segment disclosures have been restated to conform with the current presentation, so that all discussions of our reportable segments reflect the revised segment information of our four separate reportable segments, 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. SoCalGas SoCalGas’ common stock is wholly owned by PE, which is a wholly owned subsidiary of Sempra.
Basis of Presentation	BASIS OF PRESENTATION This is a combined report of Sempra, 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” are to Sempra and its consolidated entities, collectively, unless otherwise stated or indicated by the context. We sometimes refer to SDG&E and SoCalGas collectively as Sempra California. SI Partners (formerly Sempra Global) is the holding company for our subsidiaries that are not subject to California or Texas utility regulation. 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; ▪the Consolidated Financial Statements and related Notes of SDG&E; 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.
Discontinued Operations	Discontinued Operations We completed the sales of our equity interests in our Peruvian businesses in April 2020 and our Chilean businesses in June 2020. 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 upon our decision to sell them in January 2019. These businesses are presented as discontinued operations, which we discuss further in Note 5. Our discussions in the Notes below relate only to our continuing operations unless otherwise noted.
Subsequent Events	Subsequent Events We evaluated events and transactions that occurred after December 31, 2021 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.
Regulated Operations	REGULATED OPERATIONS SDG&E’s and SoCalGas’ 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, SDG&E and SoCalGas record regulatory liabilities when the CPUC or, in the case of SDG&E, 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 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 Infrastructure’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. Our Sempra Texas Utilities segment is comprised of our equity method investments in Oncor Holdings, which 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 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 Infrastructure 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, short-term investments, 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 Infrastructure. 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 accounts receivable and accounts payable. 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 short-term investments that consist of money market and mutual funds 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). ▪As we discuss in Note 6, in July 2020, Sempra 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 Infrastructure.” Fair Value of Financial InstrumentsThe fair values of certain of our financial instruments (cash, accounts 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.
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: ▪for Sempra Infrastructure, funds 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 ▪for Parent and other, funds held in a delisting trust for the purpose of purchasing the remaining publicly owned IEnova shares
Credit Losses	CREDIT LOSSES We are exposed to credit losses from financial assets measured at amortized cost, including trade and other accounts receivable, amounts due from unconsolidated affiliates, our net investment in a sales-type lease and a note receivable. We are also exposed to credit losses from off-balance sheet arrangements through Sempra’s guarantee related to Cameron LNG JV’s SDSRA, which we discuss in Note 6. 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 receivables and customer payment patterns, historical and industry trends, counterparty creditworthiness, economic conditions and specific events, such as bankruptcies, pandemics and other factors. 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.
Concentration of Credit Risk	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	INVENTORIES SDG&E and SoCalGas 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. SDG&E and SoCalGas generally value materials and supplies at the lower of average cost or net realizable value. Sempra Infrastructure values natural gas inventory and materials and supplies at the lower of average cost or net realizable value, and 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 SDG&E and SoCalGas over the estimated service lives of the properties as required by the CPUC. Under the regulatory accounting treatment required for flow-through temporary differences, SDG&E, SoCalGas and Sempra Infrastructure 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 because they 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.
Greenhouse Gas Allowances and Obligations and Emissions and Renewable Energy Certificates	GREENHOUSE GAS ALLOWANCES AND OBLIGATIONS SDG&E, SoCalGas and Sempra Infrastructure 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 SDG&E and SoCalGas, 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. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Sempra Infrastructure records 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 EQUIPMENTPP&E is recorded at cost and primarily represents the buildings, equipment and other facilities used by SDG&E and SoCalGas to provide natural gas and electric utility services, and by the Sempra Infrastructure 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 for our non-regulated projects 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. Depreciation expense is computed using the straight-line method over the asset’s estimated composite useful life, the CPUC-prescribed period for SDG&E and SoCalGas, or the remaining term of the site leases, whichever is shortest.
Capitalized Finance Costs	SDG&E and SoCalGas finance 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. SDG&E and SoCalGas 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 under construction by Sempra Infrastructure that are both subject to certain regulation and meet U.S. GAAP regulatory accounting requirements record the impact of AFUDC. We capitalize interest costs incurred to finance capital projects and interest at equity method investments that have not commenced planned principal operations.
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. For our annual goodwill impairment testing, we have the option to first make a qualitative assessment of whether it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount before applying the quantitative goodwill impairment test. If we elect to perform the qualitative assessment, we evaluate relevant events and circumstances, including but not limited to, macroeconomic conditions, industry and market considerations, cost factors and the overall financial performance of the reporting unit. If, after assessing these qualitative factors, we determine that it is more-likely-than-not that the fair value of a reporting unit is less than its carrying amount, then we perform the quantitative goodwill impairment test. If, after performing the quantitative goodwill impairment test, we determine that goodwill is impaired, we 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. Other Intangible Assets at December 31, 2021 primarily include: ▪renewable energy transmission and consumption permits previously granted by the CRE at the Ventika wind power generation facilities, Don Diego Solar and Border Solar; ▪a favorable O&M agreement acquired in connection with the acquisition of DEN; and ▪the relative fair value of the PPA that was acquired in connection with the acquisition of ESJ in March 2021.
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. We will continue to evaluate our VIEs for any changes that may impact our determination of whether an entity is a VIE and if we are the primary beneficiary.
Asset Retirement Obligations	ASSET RETIREMENT OBLIGATIONS For tangible long-lived assets, we record AROs for the present value of liabilities of future costs expected to be incurred when assets are retired from service, if the retirement process is legally required and if a reasonable estimate of fair value can be made. We also record a liability if a legal obligation to perform an asset retirement exists and can be reasonably estimated, but performance is conditional upon a future event. We record the estimated retirement cost using the present value of the obligation at the time the asset is placed into service, and recognize that cost over the life of the related asset by depreciating the asset retirement cost and accreting the obligation until the liability is settled. Our rate-regulated entities 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 if: ▪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 or a range of possible losses 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, and in some cases have exceeded, applicable insurance coverage and could materially adversely affect our business, results of operations, financial condition, cash flows and/or prospects. Unless otherwise indicated, we are unable to reasonably estimate possible losses or a range of 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 The Consolidated Statements of Comprehensive Income (Loss) show the changes in the components of OCI, including the amounts attributable to NCI.
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 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 Sempra’s Consolidated Statements of Cash Flows.
New Accounting Standards	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 and cash conversion features. The standard also amends certain guidance in ASC 260, “Earnings Per Share,” for the computation of EPS for convertible instruments and contracts on an entity’s own equity. For public entities, ASU 2020-06 is effective for fiscal years beginning after December 15, 2021, with early adoption permitted. 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 will adopt the standard on January 1, 2022 using a modified retrospective approach and do not expect the adoption will materially impact our financial statements or per-share amounts.
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, SDG&E and SoCalGas pay franchise fees to operate in various municipalities. SDG&E and SoCalGas bill these franchise fees to their customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SDG&E’s and SoCalGas’ 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 Infrastructure’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. SDG&E, SoCalGas and Ecogas recognize revenues based on regulator-approved revenue requirements, which allow the utilities to recover their reasonable operating costs and provides the opportunity to realize their authorized rates of return on their investments. While SDG&E’s and SoCalGas’ revenues are not affected by actual sales volumes, the pattern of their revenue recognition during the year is affected by seasonality. SDG&E and SoCalGas recognize annual authorized revenue for customers using seasonal factors established in applicable proceedings. This generally results in a significant portion of operating revenues being recognized in the third quarter of each year for SDG&E and in the first and fourth quarters of each year for SoCalGas. 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. SDG&E and SoCalGas 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 SDG&E and SoCalGas 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. SDG&E and SoCalGas balance costs and revenues associated with the GHG program through regulatory balancing accounts. Energy-Related Businesses Revenues Revenues at Sempra Infrastructure 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. 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 Infrastructure 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. Sempra Infrastructure 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 Infrastructure, 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 April 2019, Sempra Renewables completed the sale of its remaining wind assets and investments. 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. Sempra Infrastructure sells natural gas to the CFE and other customers under supply agreements. Sempra Infrastructure 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. 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, 2021, we expect to recognize revenue related to the fixed fee component of the consideration as shown below. Sempra’s remaining performance obligations primarily relate to capacity agreements for natural gas storage and transportation at Sempra Infrastructure. SoCalGas did not have any remaining performance obligations at December 31, 2021. 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 SDG&E and SoCalGas 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 SDG&E and SoCalGas to use a “decoupling” mechanism, which allows SDG&E and SoCalGas 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 SDG&E and SoCalGas 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 SDG&E and SoCalGas 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 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 Infrastructure generates lease revenues from certain of its natural gas and ethane pipelines, compressor stations, LPG storage facilities, a rail facility and liquid fuels terminals. Certain PPAs at Sempra Renewables were accounted for as operating leases prior to sale of its wind assets in April 2019. We discuss the recognition of lease income in Note 16 of the Notes to Consolidated Financial Statements. Sempra Infrastructure has an agreement with Tangguh PSC to supply LNG to the ECA Regas Facility. Under the terms of the agreement, Tangguh PSC must either deliver the contracted number of cargoes or pay a diversion fee for non-delivery of LNG cargoes. Sempra Infrastructure also recognizes other revenues associated with derivatives related to the 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 these derivatives.
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’s income tax on earnings from these equity method investees, other than Oncor Holdings as we discuss below, is included in Income Tax Expense 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. Oncor is a domestic partnership for U.S. federal income tax purposes and is not included in the consolidated income tax return of Sempra. 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.
Employee Benefit Plans	Plan Assets Investment Allocation Strategy for Sempra’s Pension Master Trust Sempra’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 SDGE’s and SoCalGas’ PBOP plans. Other than through indexing strategies, the trusts do not invest in securities of Sempra. 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: ▪31% domestic equity ▪21% international equity ▪21% long credit ▪10% diversified real assets ▪10% 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 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 or four years. However, for awards granted to retirement-eligible participants, the expense is recognized over the initial year in which the award was granted as the award requires service through the end of the year in which it was granted. For awards granted to participants who become eligible for retirement during the requisite service period, the expense is recognized over the period between the date of grant and the later of the end of the year in which the award was granted or the date the participant first becomes eligible for retirement. Substantially all awards outstanding are classified as equity instruments; therefore, we recognize additional paid in capital as we recognize the compensation expense associated with the awards. We recognize in earnings the tax benefits (or deficiencies) resulting from tax deductions that are in excess of (or less than) tax benefits related to compensation cost recognized for share-based payments. SEMPRA NONQUALIFIED STOCK OPTIONSWe 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’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.SEMPRA RESTRICTED STOCK UNITSWe use a Monte-Carlo simulation model to estimate the fair value of our RSUs that vest based on Sempra’s total return to shareholders. Our determination of fair value is affected by the historical volatility of the common stock price for Sempra and its peer group companies. The valuation also is affected by the risk-free rates of return and a number of other variables.
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 may have derivatives that are (1) cash flow hedges, (2) fair value hedges, or (3) undesignated. Depending on the applicability of hedge accounting and, for SDG&E and SoCalGas 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 and hedge termination costs on interest rate swaps 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: ▪SDG&E and SoCalGas 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 Infrastructure 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 on the Consolidated Statements of Operations. Certain of these derivatives may also be designated as cash flow hedges. ▪From time to time, our various businesses, including SDG&E and SoCalGas, may use other energy derivatives to hedge exposures such as GHG allowances. INTEREST RATE DERIVATIVES We are exposed to interest rates primarily as a result of our current and expected use of financing. SDG&E and SoCalGas, as well as Sempra 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 Infrastructure 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 may 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 in 2020 and 2019 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	As the lessee for both operating and finance leases, we have elected to combine lease and nonlease components as a single lease component for real estate, fleet vehicles, power generating facilities, and pipelines, whereby fixed or in-substance fixed payments allocable to the nonlease component are accounted for as part of the related lease liability and ROU asset. As the lessor, we have elected to combine lease and nonlease components as a single lease component for real estate, power generating facilities and liquid fuels terminals if the timing and pattern of transfer of the lease and nonlease components are the same and the lease component would be classified as an operating lease if accounted for separately.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. SDG&E and SoCalGas 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. SDG&E and SoCalGas 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. Our leases do not contain any material residual value guarantees, restrictions or covenants.
Lessor, Leases	Generally, we recognize operating lease income on a straight-line basis over the lease term, and sales-type lease income based on the effective interest method over the lease term. 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 SDG&E and SoCalGas, 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 Leak as we discuss above or resolved during the last three years, include (1) investigation and remediation of SDG&E’s and SoCalGas’ manufactured-gas sites, (2) cleanup of third-party waste-disposal sites used by SDG&E and SoCalGas 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. We record environmental liabilities when our liability is probable and the costs can be reasonably estimated. In many cases, however, investigations are not yet at a stage where we can determine whether we are liable or, if the liability is probable, to reasonably estimate the amount or range of amounts of the costs. Estimates of our liability are further subject to uncertainties such as the nature and extent of site contamination, evolving cleanup standards and imprecise engineering evaluations. We review our accruals periodically and, as investigations and cleanups proceed, we make adjustments as necessary.
Segment Reporting	We have four 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. ▪Sempra Infrastructure includes the operating companies of our subsidiary, SI Partners, as well as a holding company and certain services companies. Sempra Infrastructure develops, builds, operates and invests in energy infrastructure to help enable the energy transition in North American markets and globally. Sempra Infrastructure owns an 80% interest in SI Partners, which held a 100% ownership interest in Sempra LNG Holding, LP and a 99.9% ownership interest in IEnova at December 31, 2021. 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’s reported earnings and cash flows. SDG&E and SoCalGas operate in essentially separate service territories, under separate regulatory frameworks and rate structures set by the CPUC and, in the case of SDG&E, 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.

SHARE-BASED COMPENSATION - SHARE-BASED COMPENSATION EXPENSE/ OPTIONS (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Number of shares available for future grants (in shares)	5,986,241
Number of shares authorized for issuance (in shares)	5,986,241
Share-based compensation expense, before income taxes	$ 14.0	$ 14.0	$ 15.0
Income tax benefit	(4.0)	(4.0)	(4.0)
Share-based Payment Arrangement, Expense, after Tax	10.0	10.0	11.0
Capitalized share-based compensation cost	4.0	4.0	5.0
Excess income tax (benefit) deficiency	$ (1.0)	$ (3.0)	$ 1.0
Stock option exercise period (in years)	3 years
Weighted-average fair value for options granted (in dollars per share)	$ 19.07	$ 19.76	$ 13.20
Stock price volatility (as a percent)	26.57%	18.78%	18.63%
Expected term (in years)	5 years 4 months 9 days	5 years 4 months 2 days	5 years 4 months 2 days
Risk-free rate of return (as a percent)	0.41%	1.68%	2.49%
Annual dividend yield (as a percent)	3.38%	2.60%	3.35%
Common shares under options
Beginning balance (in shares)	365,395
Options grants in period (in shares)	222,620	154,860	261,075
Exercised (in shares)	(50,671)	(4,400)	(52,540)
Ending balance (in shares)	537,344	365,395
Vested at period end (in shares)	537,344
Exercisable at period end (in shares)	152,189
Weighted- average exercise price
Beginning balance (in dollars per share)	$ 120.93
Granted (in dollars per share)	123.80
Exercised (in dollars per share)	106.76
Ending balance (in dollars per share)	123.45	$ 120.93
Vested at period end, Weighted- average exercise price (in dollars per share)	123.45
Exercisable at period end, Weighted- average exercise price (in dollars per share)	$ 118.10
Outstanding at period end, Weighted- average remaining contractual term	8 years 21 days
Vested at period end, Weighted- average remaining contractual term	8 years 21 days
Exercisable at period end, Weighted- average remaining contractual term	7 years 3 months 7 days
Outstanding at period end, Aggregate intrinsic value	$ 5.0
Vested at period end, Aggregate intrinsic value	5.0
Exercisable at period end, Aggregate intrinsic value	2.0
Aggregate intrinsic value of options exercised	$ 1.4	$ 0.4	$ 4.0
Weighted average period over which unrecognized compensation cost will be recognized	1 year 1 month 6 days
Weighted-average per share fair value for nonqualified stock options granted (in dollars per share)		$ 149.12	$ 106.76
Cash received from exercise of options	$ 5.0		$ 3.0
Share-based Payment Arrangement, Option
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Expiration period	10 years
Awards Granted In 2020 and 2019 \| Share-based Payment Arrangement, Option
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awarded during or after 2015 \| Performance Shares
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 \| Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	4 years
Awarded During Or After 2014
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting rights maximum additional award	100.00%
Awards Granted in 2019 \| Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Awards Granted During 2015 Through 2018 \| Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award vesting period	3 years
Minimum \| Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	3 years
Maximum \| Restricted Stock Units (RSUs), Service-based
Share-based Payment Arrangement, Expensed and Capitalized, Amount [Line Items]
Award requisite service period	4 years

EMPLOYEE BENEFIT PLANS - SAVINGS PLANS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Savings Plan [Line Items]
Employer contributions to defined benefit plan	$ 28	$ 25	$ 24
Market value of employer stock held by plan	$ 1,000	$ 1,100	$ 1,300

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - CASH FLOWS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	$ 1,033	$ 1,526	$ 868
Expenditures for property, plant and equipment	(1,984)	(1,843)	(1,439)
Disbursement for note receivable	(305)	0	0
Distributions from investments	941	651	247
Other	0	0	1
Net cash (used in) provided by investing activities	(1,984)	(1,843)	(1,438)
Common stock dividends paid	(75)	(100)	(150)
Preferred dividends paid	(1)	(1)	(1)
Proceeds from Issuance of Preferred Stock and Preference Stock	0	891	0
Issuances of common stock, net	5	11	1,830
Repurchases of common stock	(339)	(566)	(26)
Issuances of long-term debt	0	949	349
Payments on long-term debt	(12)	(12)	(6)
Increase in loans from affiliates, net	38	7	3
Purchases of noncontrolling interest	(224)	(248)	(30)
Debt issuance costs	0	(8)	(4)
Other	(199)	(50)	(49)
Net cash provided by financing activities	984	311	562
Effect of exchange rate changes in continuing operations	2	0	0
Increase (decrease) in cash and cash equivalents	33	(6)	(8)
Cash and cash equivalents, January 1	4	10	18
Cash and cash equivalents, December 31	37	4	10
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Common dividends issued in stock	0	22	55
Conversion of mandatory convertible preferred stock	2,258	0	0
Preferred dividends declared but not paid	1	1	1
Parent Company
Condensed Cash Flow Statements, Captions [Line Items]
Net cash provided by operating activities	(255)	(978)	294
Expenditures for property, plant and equipment	(8)	(9)	(8)
Capital contributions to investees	(1,005)	(364)	(1,528)
Disbursement for note receivable	(305)	0	0
Distributions from investments	1,552	3,616	0
(Increase) decrease in loans to affiliates, net	(20)	2	0
Other	0	0	4
Net cash (used in) provided by investing activities	214	3,245	(1,532)
Common stock dividends paid	(1,331)	(1,174)	(993)
Preferred dividends paid	(99)	(157)	(142)
Proceeds from Issuance of Preferred Stock and Preference Stock	0	891	0
Issuances of common stock, net	5	11	1,830
Repurchases of common stock	(339)	(566)	(26)
Issuances of long-term debt	990	1,599	758
Payments on long-term debt	(3,200)	(3,700)	(1,500)
Increase in short-term debt	1,240	0	0
Increase in loans from affiliates, net	1,092	1,194	1,328
Purchases of noncontrolling interest	(217)	0	0
Proceeds from sale of noncontrolling interest	1,846	0	0
Equity transaction costs with third parties	0	(4)	0
Debt issuance costs	0	(1)	(25)
Make-whole premiums related to early redemptions of debt	(121)	0	0
Other	(2)	0	0
Net cash provided by financing activities	(136)	(1,907)	1,230
Effect of exchange rate changes in continuing operations	(1)	0	0
Increase (decrease) in cash and cash equivalents	(178)	360	(8)
Cash and cash equivalents, January 1	366	6	14
Cash and cash equivalents, December 31	188	366	6
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Issuance of common stock in exchange for NCI and related AOCI	1,373	0	0
Common dividends issued in stock	0	22	55
Common dividends declared but not paid	349	301	283
Conversion of mandatory convertible preferred stock	2,258	0	0
Preferred dividends declared but not paid	11	47	36
Equitization of amounts due from affiliates	$ 4,351	$ 0	$ 0

INCOME TAXES

12 Months Ended

Dec. 31, 2021

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

We provide our calculations of ETRs in the following table.


INCOME TAX EXPENSE (BENEFIT) AND EFFECTIVE INCOME TAX RATES
(Dollars in millions)
	Years ended December 31,
	2021			2020			2019
Sempra:
Income tax expense from continuing operations	$	99		$	249		$	315

Income from continuing operations before income taxes and equity earnings	$	219		$	1,489		$	1,734
Equity earnings, before income tax(1)	614			294			30
Pretax income	$	833		$	1,783		$	1,764

Effective income tax rate	12		%	14		%	18		%
SDG&E:
Income tax expense	$	201		$	190		$	171
Income before income taxes	$	1,020		$	1,014		$	945
Effective income tax rate	20		%	19		%	18		%
SoCalGas:
Income tax (benefit) expense	$	(310)		$	96		$	120
(Loss) income before income taxes	$	(736)		$	601		$	762
Effective income tax rate	42		%	16		%	16		%

(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 Infrastructure has similar flow-through treatment.

We record income tax (expense) benefit from the transactional effects of foreign currency and inflation. Through the first quarter of 2021, such effects are offset by net gains (losses) from foreign currency derivatives that were hedging Sempra Infrastructure’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,
	2021		2020		2019
Sempra:
U.S. federal statutory income tax rate	21	%	21	%	21	%
Outside basis differences	9		—		—
Utility depreciation	8		3		3
Non-U.S. earnings taxed at rates different from the U.S. statutory income tax rate(1)	5		2		3
Foreign exchange and inflation effects(2)	1		(3)		4
Valuation allowances	1		(1)		—
Tax credits	—		(1)		(2)
Excess deferred income taxes outside of ratemaking	—		—		(4)
Compensation-related items	(1)		(1)		—
Impairment losses	(1)		1		—

Noncontrolling interests	(2)		—		—
Allowance for equity funds used during construction	(3)		(1)		(1)
Amortization of excess deferred income taxes	(3)		(1)		(1)
Remeasurement of deferred taxes	(4)		—		—
State income taxes, net of federal income tax benefit	(4)		1		2
Utility self-developed software expenditures	(5)		(3)		(2)
Utility repairs expenditures	(9)		(4)		(3)
Other, net	(1)		1		(2)
Effective income tax rate	12	%	14	%	18	%
SDG&E:
U.S. federal statutory income tax rate	21	%	21	%	21	%
State income taxes, net of federal income tax benefit	5		5		6
Depreciation	3		3		3
Excess deferred income taxes outside of ratemaking	—		—		(3)
Self-developed software expenditures	(1)		(4)		(3)
Amortization of excess deferred income taxes	(2)		(1)		(1)
Allowance for equity funds used during construction	(2)		(2)		(1)
Repairs expenditures	(4)		(3)		(3)
Other, net	—		—		(1)
Effective income tax rate	20	%	19	%	18	%
SoCalGas:
U.S. federal statutory income tax rate	21	%	21	%	21	%
State income taxes, net of federal income tax benefit	11		2		4
Repairs expenditures	5		(7)		(4)
Self-developed software expenditures	5		(4)		(2)
Amortization of excess deferred income taxes	2		(1)		(1)
Allowance for equity funds used during construction	1		(1)		(1)
Nondeductible expenditures	—		2		—
Excess deferred income taxes outside of ratemaking	—		—		(5)
Depreciation	(5)		5		4
Other, net	2		(1)		—
Effective income tax rate	42	%	16	%	16	%

(1) Related to operations in Mexico.

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 $1.8 billion of foreign undistributed earnings in the foreseeable future, and have accrued $59 million of U.S. state deferred income tax liability at December 31, 2021 for repatriations that we expect will begin in 2022 as cash is generated. We repatriated approximately $4.7 billion and $254 million to the U.S. in 2020 and 2019, respectively.

We have not recorded deferred income taxes with respect to remaining basis differences of approximately $600 million between financial statement and income tax investment amounts in our non-U.S. subsidiaries because we consider them to be indefinitely reinvested as of December 31, 2021. However, the sale of NCI in SI Partners to ADIA, which we discuss in Note 1, would affect our indefinite reinvestment assertion. 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
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
By geographic components:
U.S.	$	346	$	1,461	$	1,191
Non-U.S.	487		322		573
Total(1)	$	833	$	1,783	$	1,764

(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 2021 compared to 2020 and 2019 primarily due to the 2021 charges at SoCalGas related to civil litigation pertaining to the Leak, which we describe in Note 16.

The components of income tax expense are as follows.


INCOME TAX EXPENSE (BENEFIT)
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Current:
U.S. state	$	(6)	$	(22)	$	(14)
Non-U.S.	183		112		140
Total	177		90		126
Deferred:
U.S. federal	(9)		157		87
U.S. state	(37)		36		21
Non-U.S.	(31)		(34)		84
Total	(77)		159		192
Deferred investment tax credits	(1)		—		(3)
Total income tax expense	$	99	$	249	$	315
SDG&E:
Current:
U.S. federal	$	35	$	121	$	35
U.S. state	13		34		31
Total	48		155		66
Deferred:
U.S. federal	99		11		75
U.S. state	54		25		32
Total	153		36		107
Deferred investment tax credits	—		(1)		(2)
Total income tax expense	$	201	$	190	$	171
SoCalGas:
Current:
U.S. federal	$	134	$	163	$	8
U.S. state	50		45		24
Total	184		208		32
Deferred:
U.S. federal	(334)		(85)		79
U.S. state	(159)		(28)		10
Total	(493)		(113)		89
Deferred investment tax credits	(1)		1		(1)
Total income tax (benefit) expense	$	(310)	$	96	$	120

The tables below present the components of deferred income taxes:


DEFERRED INCOME TAXES – SEMPRA
(Dollars in millions)
	December 31,
	2021		2020		2019
Deferred income tax liabilities:
Differences in financial and tax bases of fixed assets, investments and other assets(1)	$	5,230	$	4,891	$	4,052
U.S. state and non-U.S. withholding tax on repatriation of foreign earnings	47		46		153
Regulatory balancing accounts	538		587		468
Right-of-use assets – operating leases	160		144		131
Property taxes	52		51		44
Other deferred income tax liabilities	50		40		93
Total deferred income tax liabilities	6,077		5,759		4,941
Deferred income tax assets:
Tax credits	1,135		1,161		1,136
Net operating losses	706		1,299		911
Postretirement benefits	30		162		200
Compensation-related items	164		169		161
Operating lease liabilities	140		125		131
Other deferred income tax assets	130		97		60
State income taxes	21		20		8
Bad debt allowance	33		35		4
Accrued expenses not yet deductible	575		130		52
Deferred income tax assets before valuation allowances	2,934		3,198		2,663
Less: valuation allowances	183		174		144
Total deferred income tax assets	2,751		3,024		2,519
Net deferred income tax liability(2)	$	3,326	$	2,735	$	2,422


DEFERRED INCOME TAXES – SDG&E AND SOCALGAS
(Dollars in millions)
	SDG&E						SoCalGas
	December 31,						December 31,
	2021		2020		2019		2021		2020		2019
Deferred income tax liabilities:
Differences in financial and tax bases of utility plant and other assets	$	1,970	$	1,833	$	1,735	$	1,444	$	1,322	$	1,246
Regulatory balancing accounts	323		224		141		215		362		327
Right-of-use assets – operating leases	52		28		32		16		21		22
Property taxes	35		34		30		17		17		14
Other	1		2		14		1		1		1
Total deferred income tax liabilities	2,381		2,121		1,952		1,693		1,723		1,610
Deferred income tax assets:
Tax credits	5		5		6		3		3		3
Postretirement benefits	—		14		37		18		123		120
Compensation-related items	12		12		6		33		36		25
Operating lease liabilities	52		28		32		16		21		22
Bad debt allowance	16		18		3		15		15		1
State income taxes	4		8		7		12		11		8
Accrued expenses not yet deductible	16		14		9		539		93		15
Other	1		3		4		18		15		13
Total deferred income tax assets	106		102		104		654		317		207
Net deferred income tax liability	$	2,275	$	2,019	$	1,848	$	1,039	$	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, 2021		Year expiration begins
Sempra:
U.S. federal:
NOLs(1)	$	3,263	Indefinite
General business tax credits(1)	436		2032
Foreign tax credits(2)	688		2024
U.S. state(2):
NOLs	2,938		2022
General business tax credits	6		2022
Non-U.S.(2) – NOLs	248		2022

(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.

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” table.


VALUATION ALLOWANCES
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
U.S. federal	$	128	$	118	$	90

U.S. state	31		32		33

Non-U.S.	24		24		21








	$	183	$	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)
	2021		2020		2019
Sempra:
Balance at January 1	$	99	$	93	$	119
Increase in prior period tax positions	3		3		5
Decrease in prior period tax positions	(2)		(1)		—
Increase in current period tax positions	204		4		2
Settlements with taxing authorities	—		—		(32)
Expiration of statutes of limitations	—		—		(1)
Balance at December 31	$	304	$	99	$	93
Of December 31 balance, amounts related to tax positions that if recognized in future years would
decrease the effective tax rate(1)	$	(105)	$	(87)	$	(81)
increase the effective tax rate(1)	34		31		27
SDG&E:
Balance at January 1	$	13	$	12	$	11
Increase in prior period tax positions	1		1		1
Balance at December 31	$	14	$	13	$	12
Of December 31 balance, amounts related to tax positions that if recognized in future years would
decrease the effective tax rate(1)	$	(11)	$	(10)	$	(9)
increase the effective tax rate(1)	1		1		1
SoCalGas:
Balance at January 1	$	68	$	64	$	61
Increase in prior period tax positions	1		1		1
Increase in current period tax positions	3		3		2
Balance at December 31	$	72	$	68	$	64
Of December 31 balance, amounts related to tax positions that if recognized in future years would
decrease the effective tax rate(1)	$	(63)	$	(59)	$	(55)
increase the effective tax rate(1)	33		30		26

(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,
	2021		2020		2019
Sempra:
Potential resolution of audit issues with various U.S. federal, state and local and non-U.S. taxing authorities	$	8	$	8	$	8
SDG&E:
Potential resolution of audit issues with various U.S. federal, state and local taxing authorities	$	6	$	6	$	6
SoCalGas:
Potential resolution of audit issues with various U.S. federal, state and local taxing authorities	$	2	$	2	$	2

Amounts accrued for interest and penalties associated with unrecognized income tax benefits are included in Income Tax Expense on the Consolidated Statements of Operations. Sempra accrued negligible amounts at December 31, 2021 and 2020 and $1 million for interest expense and penalties at December 31, 2019 on the Consolidated Balance Sheets, and recorded negligible amounts for interest and penalties in the Consolidated Statements of Operations for all periods presented. SDG&E and SoCalGas

each accrued negligible amounts for interest expense and penalties at December 31, 2021, 2020, and 2019 on the Consolidated Balance Sheets, and recorded negligible amounts of interest expense and penalties in the Consolidated Statements of Operations for all periods presented.

INCOME TAX AUDITS

Sempra 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 2017. 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 2009 and 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 2017 and state tax years after 2012.

In addition, Sempra 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.

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 21
-URI http://asc.fasb.org/extlink&oid=121826272&loc=d3e32857-109319

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SAB Topic 11.C)
-URI http://asc.fasb.org/extlink&oid=122134291&loc=d3e330215-122817

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 17
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=121826272&loc=d3e32809-109319

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SAB TOPIC 6.I.5.Q1)
-URI http://asc.fasb.org/extlink&oid=122134291&loc=d3e330036-122817

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 50
-Paragraph 14
-URI http://asc.fasb.org/extlink&oid=121826272&loc=d3e32705-109319

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 270
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6424409&loc=d3e44925-109338

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-URI http://asc.fasb.org/topic&trid=2144680

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 30
-Section 50
-Paragraph 2
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=6424122&loc=d3e41874-109331

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(h)(2))
-URI http://asc.fasb.org/extlink&oid=120395691&loc=d3e23780-122690

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CASH, CASH EQUIVALENTS AND RESTRICTED CASH (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Presentation Of Restricted Cash [Line Items]
Cash and cash equivalents	$ 37	$ 4	$ 10
Restricted cash, current	19	22	31
Restricted cash, noncurrent	3	3	3
Cash, cash equivalents and restricted cash in discontinued operations	0	0	75
Total cash, cash equivalents and restricted cash on the Consolidated Statements of Cash Flows	$ 581	985	217	$ 246
Discontinued Operations, Held-for-sale \| Sempra South American Utilities
Presentation Of Restricted Cash [Line Items]
Cash, cash equivalents and restricted cash in discontinued operations			1
Cash and cash equivalents		$ 4,600	$ 74

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE

12 Months Ended

Dec. 31, 2021

Earnings Per Share [Abstract]

SEMPRA – SHAREHOLDERS’ EQUITY AND EARNINGS PER COMMON SHARE

SEMPRA 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 ASR program was completed on August 4, 2020 with an aggregate of 4,089,375 shares of Sempra 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 were repurchased under this authorization in 2020.

Beginning on November 17, 2021, we executed a series of open market repurchases for which we paid $300 million to repurchase shares of our common stock in the open market. The repurchases were completed on December 7, 2021 with an aggregate of 2,422,758 shares of Sempra common stock repurchased at a weighted-average purchase price of $123.83 per share, excluding commissions.

On January 11, 2022, we entered into an ASR program under which we prepaid $200 million to repurchase shares of our common stock in a share forward transaction. A total of 1,472,756 shares were purchased under this program at an average price of $135.80 per share. The total number of shares purchased was determined by dividing the $200 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 January 12, 2022 through February 11, 2022, minus a fixed discount. The ASR program was completed on February 11, 2022. As of February 25, 2022, a maximum of $1.5 billion and no more than 21,104,486 shares may yet be purchased under the July 6, 2020 repurchase authorization.

SETTLEMENT OF FORWARD SALE AGREEMENTS

In 2019, we received $728 million (net of underwriting discounts of $13 million) from the settlement of 7,156,185 shares of our common stock at a forward sale price of $101.74 per share related to our January 2018 common stock offering.

In 2019, we received $1,066 million (net of underwriting discounts of $18 million) from the settlement of 9,750,000 shares of our common stock at a forward sale price of $109.33 per share related to our July 2018 common stock offering.

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,
	2021		2020		2019
Sempra:
Numerator for continuing operations:
Income from continuing operations, net of income tax	$	1,463	$	2,255	$	1,999
Earnings attributable to noncontrolling interests	(145)		(162)		(129)
Preferred dividends	(63)		(168)		(142)
Preferred dividends of subsidiary	(1)		(1)		(1)
Earnings from continuing operations attributable to common shares	$	1,254	$	1,924	$	1,727

Numerator for discontinued operations:
Income from discontinued operations, net of income tax	$	—	$	1,850	$	363
Earnings attributable to noncontrolling interests	—		(10)		(35)
Earnings from discontinued operations attributable to common shares	$	—	$	1,840	$	328

Numerator for earnings:
Earnings attributable to common shares	$	1,254	$	3,764	$	2,055

Denominator:
Weighted-average common shares outstanding for basic EPS(1)	311,755		291,077		277,904
Dilutive effect of stock options and RSUs(2)	752		1,175		1,585
Dilutive effect of common shares sold forward	—		—		2,544
Dilutive effect of mandatory convertible preferred stock	529		—		—
Weighted-average common shares outstanding for diluted EPS	313,036		292,252		282,033

Basic EPS:
Earnings from continuing operations	$	4.03	$	6.61	$	6.22
Earnings from discontinued operations	$	—	$	6.32	$	1.18
Earnings	$	4.03	$	12.93	$	7.40

Diluted EPS:
Earnings from continuing operations	$	4.01	$	6.58	$	6.13
Earnings from discontinued operations	$	—	$	6.30	$	1.16
Earnings	$	4.01	$	12.88	$	7.29

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 2021, 2020 and 2019 excludes potentially dilutive shares related to stock options and RSUs of 211,155, 187,028 and 80,281, 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 until the mandatory conversion date. After the mandatory conversion date, the converted shares are included in weighted-average common shares outstanding for basic EPS. As we discuss in Note 13, we converted our series A preferred stock into common stock on January 15, 2021 and our series B preferred stock into common stock on July 15, 2021. The computation of diluted EPS for the years ended December 31, 2021, 2020 and 2019 excludes 2,272,117, 17,889,365 and 17,471,375 potentially dilutive shares related to our mandatory convertible preferred stock, respectively, because to include them would be antidilutive for those periods.

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,
	2021	2020	2019
Sempra:
Common shares outstanding, January 1	288,470,244	291,712,925	273,769,513
Conversion of mandatory convertible preferred stock	18,037,745	—	—
Shares issued in IEnova exchange offer	12,306,777	—	—
Shares issued under forward sale agreements	—	—	16,906,185
RSUs vesting(1)	686,916	896,839	463,012
Stock options exercised	50,671	4,400	52,540
Savings plan issuance	—	201,431	475,774
Common stock investment plan(2)	—	42,955	199,253
Issuance of RSUs held in our Deferred Compensation Plan	102,238	103,552	59,470
Shares repurchased(3)	(2,734,809)	(4,491,858)	(212,822)
Common shares outstanding, December 31	316,919,782	288,470,244	291,712,925

(1) Includes dividend equivalents.

(2) Participants in the Direct Stock Purchase Plan may reinvest dividends to purchase newly issued shares.

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - INVENTORIES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Inventory [Line Items]
Natural Gas	$ 114	$ 94	$ 90
LNG	0	0	0
Materials And Supplies	58	59	46
Inventories	$ 172	$ 153	$ 136

SEMPRA - SHAREHOLDERS' EQUITY AND EARNINGS PER COMMON SHARE - EARNINGS (LOSSES) PER COMMON SHARE COMPUTATIONS (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Earnings Per Share [Abstract]
Income from continuing operations, net of income tax	$ 1,463	$ 2,255	$ 1,999
Earnings attributable to noncontrolling interests	(145)	(162)	(129)
Preferred dividends	(1)	(1)	(1)
Preferred dividends of subsidiary	(1)	(1)	(1)
Earnings from continuing operations attributable to common shares	1,254	1,924	1,727
Income from discontinued operations, net of income tax	0	1,850	363
Earnings attributable to noncontrolling interests	0	(10)	(35)
Earnings from discontinued operations attributable to common shares	0	1,840	328
Earnings attributable to common shares	(427)	504	641
Earnings attributable to common shares, diluted	$ 1,254	$ 3,764	$ 2,055
Weighted-average common shares outstanding for basic EPS (in shares)	311,755	291,077	277,904
Dilutive effect of stock options and RSUs (in shares)	752	1,175	1,585
Dilutive effect of common shares sold forward (in shares)	0	0	2,544
Dilutive effect of mandatory convertible preferred stock (in shares)	529	0	0
Weighted-average number of shares outstanding, diluted (in shares)	313,036	292,252	282,033
Earnings from continuing operations attributable to common shares	$ 4.03	$ 6.61	$ 6.22
Earnings (losses) from discontinued operations attributable to common shares	0	6.32	1.18
Basic earnings per common share (in shares)	4.03	12.93	7.40
Earnings from continuing operations (in dollars per share)	4.01	6.58	6.13
Earnings (losses) from discontinued operations (in dollars per share)	0	6.30	1.16
Diluted earnings per common share (in dollars per share)	$ 4.01	$ 12.88	$ 7.29
Fully vested RSUs included in the computation of EPS	453	537	617

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - BALANCE SHEETS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
ASSETS
Cash and cash equivalents	$ 37	$ 4	$ 10
Due from affiliates	49	22	11
Income taxes receivable	23	0	161
Other current assets	61	47	44
Total current assets	1,599	1,482	1,218
Due from affiliates	637	780	742
Deferred income taxes	151	136	155
Other long-term assets	627	499	447
Total assets	20,324	18,460	17,077
Liabilities and shareholders’ equity:
Short-term debt	385	113	630
Current portion of long-term debt	46	919	1,464
Due to affiliates	36	31	47
Other current liabilities	271	291	222
Total current liabilities	4,312	2,082	2,182
Long-term debt	8,714	10,152	10,691
Due to affiliates	287	234	195
Commitments and contingencies (Note 4)
Total shareholders’ equity	5,442	5,144	4,748
Total liabilities and shareholders’ equity	20,324	18,460	17,077
Parent Company
ASSETS
Cash and cash equivalents	186	366	6
Restricted cash	2	0	0
Due from affiliates	446	58	98
Income taxes receivable	0	42	0
Other current assets	31	26	34
Total current assets	665	492	138
Investments in subsidiaries	33,308	33,898	32,604
Due from affiliates	21	1	3
Deferred income taxes	626	2,187	1,766
Other long-term assets	1,090	717	682
Total assets	35,710	37,295	35,193
Liabilities and shareholders’ equity:
Short-term debt	1,240	0	0
Current portion of long-term debt	0	850	1,399
Due to affiliates	185	224	369
Income taxes payable, net	4	0	274
Other current liabilities	531	536	561
Total current liabilities	1,960	1,610	2,603
Long-term debt	5,969	7,317	8,856
Due to affiliates	1,151	4,375	3,138
Other long-term liabilities	649	620	667
Commitments and contingencies (Note 4)
Total shareholders’ equity	25,981	23,373	19,929
Total liabilities and shareholders’ equity	$ 35,710	$ 37,295	$ 35,193

CONSOLIDATED BALANCE SHEETS - SDG&E - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 37	$ 4	$ 10
Accounts receivable – trade, net	1,084	786	710
Accounts receivable – other, net	58	64	87
Income taxes receivable, net	23	0	161
Inventories	172	153	136
Prepaid expenses	174	153	120
Regulatory assets	40	16	7
Greenhouse gas allowances	75	390	52
Other current assets	61	47	44
Total current assets	1,599	1,482	1,218
Other assets:
Regulatory assets	1,148	1,208	1,407
Greenhouse gas allowances	290	9	248
Nuclear decommissioning trusts	1,012	1,019	1,082
Right-of-use assets – operating leases	57	74	94
Wildfire fund	331	363	392
Other long-term assets	627	499	447
Total other assets	2,482	2,235	2,535
Property, plant and equipment:
Property, plant and equipment	23,104	21,180	19,362
Less accumulated depreciation and amortization	(6,861)	(6,437)	(6,038)
Property, plant and equipment, net	16,243	14,743	13,324
ASSETS	20,324	18,460	17,077
Current liabilities:
Short-term debt	385	113	630
Accounts payable	775	600	545
Due to unconsolidated affiliates	36	31	47
Accrued compensation and benefits	202	189	182
Regulatory liabilities	345	79	243
Current portion of long-term debt and finance leases	46	919	1,464
Customer deposits	13	48	71
Greenhouse gas obligations	75	390	52
Asset retirement obligations	77	59	65
Other current liabilities	271	291	222
Total current liabilities	4,312	2,082	2,182
Long-term debt and finance leases	8,714	10,152	10,691
Deferred credits and other liabilities:
Regulatory liabilities	1,100	1,177	1,422
Greenhouse gas obligations	174	0	208
Pension obligation, net of plan assets	25	92	153
Deferred income taxes	3,477	2,871	2,577
Asset retirement obligations	2,505	2,309	2,112
Deferred credits and other	425	425	422
Total deferred credits and other liabilities	5,797	6,471	6,359
Commitments and contingencies (Note 16)
Equity:
Preferred stock	22	22	22
Common stock	1,666	866	866
Retained earnings	3,785	4,287	3,883
Accumulated other comprehensive income (loss)	(31)	(31)	(23)
Total shareholders’ equity	5,442	5,144	4,748
Total liabilities and shareholders’ equity	20,324	18,460	17,077
Convertible Preferred Stock Series A
Equity:
Preferred stock	0	1,693	1,693
Convertible Preferred Stock Series B
Equity:
Preferred stock	0	565	565
Series C Preferred Stock
Equity:
Preferred stock	$ 889	$ 889	$ 0

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - VARIABLE INTEREST ENTITIES (Details)	9 Months Ended	12 Months Ended
	Oct. 03, 2019 MW	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Variable Interest Entity [Line Items]
Total finance leases		$ 1,274,000,000	$ 1,276,000,000	$ 1,270,000,000
Property, plant and equipment, net		16,243,000,000	14,743,000,000	13,324,000,000
Equity method investment		12,947,000,000	12,440,000,000	11,519,000,000
Assets		20,324,000,000	18,460,000,000	17,077,000,000
Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Total finance leases		1,217,000,000	1,237,000,000	1,255,000,000
Sempra Infrastructure \| Variable Interest Entity, Not Primary Beneficiary
Variable Interest Entity [Line Items]
Debt instrument, maximum borrowing amount		979,000,000
Sempra Infrastructure \| Cameron LNG JV
Variable Interest Entity [Line Items]
Equity method investment		514,000,000	433,000,000	1,256,000,000
Sempra Infrastructure \| ECA LNG JV \| Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Assets		632,000,000	207,000,000
Liabilities		$ 455,000,000	49,000,000
Oncor Electric Delivery Company LLC
Variable Interest Entity [Line Items]
Ownership percentage held by noncontrolling owners		80.25%
Oncor Holdings \| Sempra Texas Utilities
Variable Interest Entity [Line Items]
Equity method investment		$ 12,947,000,000	$ 12,440,000,000	$ 11,519,000,000
Sempra Texas Holdings Corp \| Oncor Holdings
Variable Interest Entity [Line Items]
Ownership percentage in consolidated entity		100.00%
Otay Mesa VIE \| Variable Interest Entity, Primary Beneficiary
Variable Interest Entity [Line Items]
Generating capacity (in mw) \| MW	605

SHARE-BASED COMPENSATION

12 Months Ended

Dec. 31, 2021

Share-based Payment Arrangement, Noncash Expense [Abstract]

Share-based Compensation

SHARE-BASED COMPENSATION

SEMPRA EQUITY COMPENSATION PLANS

Sempra has share-based compensation plans intended to align employee and shareholder objectives related to the long-term growth of Sempra. 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 SDG&E and SoCalGas, participate in Sempra’s share-based compensation plans as a component of their compensation package.

In the three years ended December 31, 2021, Sempra had the following types of equity awards outstanding:

▪Nonqualified Stock Options: Options to purchase common stock have an exercise price equal to the market price of the common stock at the date of grant, are service-based, become exercisable over a three-year period and expire 10 years from the date of grant. Unvested option awards are subject to forfeiture following a termination of employment, except where the retirement criteria under such awards have been met and subject to certain other exceptions described below.

▪Performance-Based Restricted Stock Units: These RSU awards generally vest in Sempra common stock at the end of three-year performance periods based on Sempra’s total return to shareholders relative to that of specified market indices or based on the compound annual growth rate of Sempra’s EPS. The comparative market indices for the awards that vest based on total return to shareholders are the S&P 500 Utilities Index (excluding water companies) and the S&P 500 Index. We use long-term analyst consensus growth estimates for S&P 500 Utilities Index peer companies (excluding water companies) to develop our targets for awards that vest based on EPS growth. These RSU awards are subject to forfeiture prior to vesting following a termination of employment, except where the retirement criteria under such awards have been met and subject to certain other exceptions described below.

◦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 2016 and certain awards granted in 2017 and 2018 that vest based on Sempra’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 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’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’s board of directors determined that Sempra 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-year service periods (for awards granted after 2018), or at the end of three-year (for awards granted during 2016 through 2018) or four-year service periods (for awards granted prior to 2015). These awards are subject to earlier forfeiture upon termination of employment, subject to certain exceptions described below.

For awards that would otherwise be forfeited upon termination of employment, the Compensation and Talent Development Committee of Sempra’s board of directors may waive the forfeiture requirement and, with respect to options and service-based RSUs, may accelerate vesting. Awards are also subject to accelerated vesting upon a change in control under the applicable LTIP, in accordance with severance pay agreements or to the extent otherwise required by the terms of the applicable award. 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, 2021, 5,986,241 common shares were authorized and available for future grants of share-based awards. Our practice is to satisfy share-based awards by issuing new shares rather than by open-market purchases.

We measure and recognize compensation expense for all share-based payment awards made to our employees and directors based on estimated fair values on the date of grant. We recognize compensation costs net of an estimated forfeiture rate (based on historical experience) and recognize the compensation costs for nonqualified stock options and RSUs on a straight-line basis over

the requisite service period of the award, which is generally three or four years. However, for awards granted to retirement-eligible participants, the expense is recognized over the initial year in which the award was granted as the award requires service through the end of the year in which it was granted. For awards granted to participants who become eligible for retirement during the requisite service period, the expense is recognized over the period between the date of grant and the later of the end of the year in which the award was granted or the date the participant first becomes eligible for retirement. Substantially all awards outstanding are classified as equity instruments; therefore, we recognize additional paid in capital as we recognize the compensation expense associated with the awards. We recognize in earnings the tax benefits (or deficiencies) resulting from tax deductions that are in excess of (or less than) tax benefits related to compensation cost recognized for share-based payments.

Sempra 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 plans’ corporate staff costs. Total share-based compensation expense for all of Sempra’s share-based awards was comprised as follows:


SHARE-BASED COMPENSATION EXPENSE
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra:
Share-based compensation expense, before income taxes(1)	$	58	$	62	$	66
Income tax benefit(1)	(16)		(17)		(18)
	$	42	$	45	$	48

Capitalized share-based compensation cost	$	9	$	11	$	11
Excess income tax (benefit) deficiency	$	(9)	$	(19)	$	4
SDG&E:
Share-based compensation expense, before income taxes	$	10	$	11	$	10
Income tax benefit	(3)		(3)		(3)
	$	7	$	8	$	7

Capitalized share-based compensation cost	$	5	$	7	$	6
Excess income tax (benefit) deficiency	$	(1)	$	(3)	$	1
SoCalGas:
Share-based compensation expense, before income taxes	$	14	$	14	$	15
Income tax benefit	(4)		(4)		(4)
	$	10	$	10	$	11

Capitalized share-based compensation cost	$	4	$	4	$	5
Excess income tax (benefit) deficiency	$	(1)	$	(3)	$	1

(1) Includes activity of awards issued from the IEnova 2013 LTIP, which settled in cash upon vesting based on the price of IEnova’s common stock.

SEMPRA 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’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 2021, 2020 and 2019, Sempra’s board of directors granted 222,620, 154,860 and 261,075 nonqualified stock options, respectively, that are exercisable over a three-year period. The weighted-average per-share fair value for options granted was $19.07, $19.76 and $13.20 in 2021, 2020 and 2019, respectively. 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,
	2021		2020		2019
Sempra:
Stock price volatility	26.57	%	18.78	%	18.63	%
Expected term	5.36 years		5.34 years		5.34 years
Risk-free rate of return	0.41	%	1.68	%	2.49	%
Annual dividend yield	3.38	%	2.60	%	3.35	%

The following table shows a summary of nonqualified stock options at December 31, 2021 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)
Sempra:
Outstanding at January 1, 2021	365,395	$	120.93
Granted	222,620	$	123.80
Exercised	(50,671)	$	106.76

Outstanding at December 31, 2021	537,344	$	123.45	8.06	$	5

Vested or expected to vest at December 31, 2021	537,344	$	123.45	8.06	$	5
Exercisable at December 31, 2021	152,189	$	118.10	7.27	$	2

The aggregate intrinsic value at December 31, 2021 is the total of the difference between Sempra’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:

▪$1.4 million in 2021

▪$0.4 million in 2020

▪$4 million in 2019

We expect a negligible amount of total compensation cost related to nonvested stock options not yet recognized as of December 31, 2021 to be recognized over a weighted-average period of 1.1 years. The weighted-average per-share fair values for nonqualified stock options granted in 2020 and 2019 was $149.12 and $106.76, respectively.

We received cash of $5 million, a negligible amount and $3 million from stock option exercises in 2021, 2020 and 2019, respectively.

SEMPRA RESTRICTED STOCK UNITS

We use a Monte-Carlo simulation model to estimate the fair value of our RSUs that vest based on Sempra’s total return to shareholders. Our determination of fair value is affected by the historical volatility of the common stock price for Sempra 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,
	2021		2020		2019
Sempra:
Stock price volatility	33.39	%	16.35	%	17.74	%
Risk-free rate of return	0.16	%	1.55	%	2.46	%

The following table shows a summary of RSUs at December 31, 2021 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
Sempra:
Nonvested at January 1, 2021	893,961	$	121.61	343,577	$	121.59
Granted	323,889	$	133.03	143,980	$	124.84
Vested	(317,128)	$	105.03	(202,352)	$	116.28
Forfeited	(29,945)	$	131.55	(7,905)	$	161.49
Nonvested at December 31, 2021(1)	870,777	$	131.64	277,300	$	127.54
Expected to vest at December 31, 2021	854,697	$	131.47	271,197	$	127.47

In 2021, 2020 and 2019, the total fair value of RSU shares vested during the year was $57 million, $70 million and $36 million, respectively.

We expect $17 million of total compensation cost related to nonvested RSUs not yet recognized as of December 31, 2021 to be recognized over a weighted-average period of 1.5 years. The weighted-average per-share fair values for performance-based RSUs granted were $155.62 and $113.54 in 2020 and 2019, respectively. The weighted-average per-share fair values for service-based RSUs granted were $138.91 and $112.50 in 2020 and 2019, respectively.

INVESTMENTS IN UNCONSOLIDATED ENTITIES (Tables)

12 Months Ended

Dec. 31, 2021

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,
	2021		2020		2019		2021		2020		2019
Sempra Texas Utilities:
Oncor Holdings(1)	100	%	100	%	100	%	$	12,947	$	12,440	$	11,519
Sempra Texas Utilities:
Sharyland Holdings(2)	50		50		50		$	100	$	102	$	100
Sempra Infrastructure:
Cameron LNG JV(3)	50.2		50.2		50.2		514		433		1,256
ESJ JV(4)	—		50		50		—		34		39
IMG JV(5)	40		40		40		523		440		337
TAG JV(6)	50		50		50		388		378		365
Total other equity method investments							1,525		1,387		2,097
Other							—		1		6
Total other investments							$	1,525	$	1,388	$	2,103

(2) The carrying value of our equity method investment is $42 higher than the underlying equity in the net assets of the investee due to equity method goodwill.

(5) The carrying value of our equity method investment is $5 higher than the underlying equity in the net assets of the investee due to guarantees.

(6) The carrying value of our equity method investment is $130 higher than the underlying equity in the net assets of the investee due to equity method goodwill.


EARNINGS (LOSSES) FROM EQUITY METHOD INVESTMENTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
EARNINGS (LOSSES) RECORDED BEFORE INCOME TAX(1):
Sempra Texas Utilities:
Sharyland Holdings	$	5	$	3	$	2
Sempra Infrastructure:
Cameron LNG JV(2)	559		391		24
Sempra Renewables:
Wind assets	—		—		5
Parent and other:
RBS Sempra Commodities	50		(100)		—
Other	—		—		(1)
	614		294		30
EARNINGS RECORDED NET OF INCOME TAX:
Sempra Texas Utilities:
Oncor Holdings	617		577		526
Sempra Infrastructure:
ESJ JV	2		5		2
IMG JV	83		103		9
TAG JV	27		36		13
	729		721		550
Total	$	1,343	$	1,015	$	580

(1) We provide our ETR calculation in Note 8.

(2) Includes $3 of basis differences in equity earnings related to AOCI in 2021.

We disclose distributions received from our investments, by segment, in the table below.


DISTRIBUTIONS FROM INVESTMENTS
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
Sempra Texas Utilities	$	688	$	286	$	246
Sempra Infrastructure	672		1,176		2
Sempra Renewables	—		—		1
Parent and other	—		—		7
Total	$	1,360	$	1,462	$	256

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,
	2021		2020		2019
Operating revenues	$	4,764	$	4,511	$	4,347
Operating expense	(3,397)		(3,224)		(3,135)
Income from operations	1,367		1,287		1,212
Interest expense	(413)		(405)		(375)
Income tax expense	(163)		(146)		(131)
Net income	760		703		643
Noncontrolling interest held by TTI	(152)		(141)		(129)
Earnings attributable to Sempra(1)	608		562		514

	At December 31,
	2021		2020		2019
Current assets	$	1,039	$	1,045	$	913
Noncurrent assets	29,481		28,022		26,012
Current liabilities	2,220		1,120		1,626
Noncurrent liabilities	15,281		15,611		14,125
Noncontrolling interest held by TTI	2,916		2,737		2,473


SUMMARIZED FINANCIAL INFORMATION – OTHER EQUITY METHOD INVESTMENTS
(Dollars in millions)
	Years ended December 31,
	2021(1)		2020		2019(2)
Gross revenues	$	2,721	$	2,341	$	798
Operating expense	(719)		(706)		(372)
Income from operations	2,002		1,635		426
Interest expense	(548)		(514)		(401)
Net income/Earnings(3)	1,388		1,132		85


	At December 31,
	2021(1)		2020		2019(2)
Current assets	$	788	$	1,035	$	1,124
Noncurrent assets	14,686		15,304		15,039
Current liabilities	1,230		1,342		1,232
Noncurrent liabilities	11,807		12,863		11,438

(1) In March 2021, Sempra Infrastructure completed the acquisition of the remaining 50% equity interest in ESJ and ESJ became a wholly owned, consolidated subsidiary.

(2) 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.

(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 - SCHEDULE OF LONG-TERM DEBT INSTRUMENTS (Details) - USD ($) $ in Millions	Dec. 31, 2021	Nov. 30, 2021	Dec. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Gross long-term debt	$ 8,923		$ 11,247	$ 12,298
Long-term lease liabilities	50		44	13
Long term debt and lease obligations, including current maturities	4,820		4,813	3,828
Finance lease obligations	1,274		1,276	1,270
Finance lease obligations and other long term debt	370		363	28
Current portion of long-term debt	(46)		(919)	(1,464)
Unamortized discount on long-term debt	(65)		(55)	(35)
Unamortized debt issuance costs	(98)		(121)	(108)
Total debt and lease obligations	4,773		4,763	3,788
Long-term debt and finance leases	8,714		$ 10,152	10,691
3% August 15, 2021
Debt Instrument [Line Items]
Stated percentage rate			3.00%
Gross long-term debt	$ 0		$ 350	350
1.914% payable 2015 through February 2022
Debt Instrument [Line Items]
Stated percentage rate	1.914%
Gross long-term debt	$ 17		53	89
3.6% September 1, 2023
Debt Instrument [Line Items]
Stated percentage rate	3.60%
Gross long-term debt	$ 450		450	450
2.5% May 15, 2026
Debt Instrument [Line Items]
Stated percentage rate	2.50%
Gross long-term debt	$ 500		500	500
First Mortgage Bonds Due June 2026
Debt Instrument [Line Items]
Stated percentage rate	2.60%
Gross long-term debt	$ 500		500	500
1.7% October 1, 2030
Debt Instrument [Line Items]
Stated percentage rate	1.70%
Gross long-term debt	$ 800		800	$ 0
5.875% January and February 2034(1)
Debt Instrument [Line Items]
Stated percentage rate				5.875%
Gross long-term debt	$ 0		0	$ 176
5.35% May 15, 2035
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250		250	250
6.125% September 15, 2037
Debt Instrument [Line Items]
Stated percentage rate	6.125%
Gross long-term debt	$ 250		250	$ 250
4% May 1, 2039(1)
Debt Instrument [Line Items]
Stated percentage rate				4.00%
Gross long-term debt	$ 0		0	$ 75
6% June 1, 2039
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 300		300	300
5.35% May 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	5.35%
Gross long-term debt	$ 250		250	250
4.5% August 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	4.50%
Gross long-term debt	$ 500		500	500
3.95% November 15, 2041
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 250		250	250
4.3% April 1, 2042
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 250		250	250
3.75% June 1, 2047
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 400		400	400
4.15% May 15, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.15%
Gross long-term debt	$ 400		400	400
4.1% June 15, 2049
Debt Instrument [Line Items]
Stated percentage rate	4.10%
Gross long-term debt	$ 400		400	400
3.32% April 15, 2050
Debt Instrument [Line Items]
Stated percentage rate	3.32%
Gross long-term debt	$ 400		400	0
2.95% August 15, 2051
Debt Instrument [Line Items]
Stated percentage rate	2.95%
Gross long-term debt	$ 750		0	0
Purchased-power contracts
Debt Instrument [Line Items]
Long-term lease liabilities	1,217		1,237	1,255
Other
Debt Instrument [Line Items]
Long-term lease liabilities	57		39	15
Other Long-term Debt
Debt Instrument [Line Items]
Long term debt and lease obligations, including current maturities	$ 1,274		1,476	1,270
3.15% September 15, 2024
Debt Instrument [Line Items]
Stated percentage rate	3.15%
Gross long-term debt	$ 500		500	500
3.2% June 15, 2025
Debt Instrument [Line Items]
Stated percentage rate	3.20%
Gross long-term debt	$ 350		350	350
2.55% February 1, 2030
Debt Instrument [Line Items]
Stated percentage rate	2.55%
Gross long-term debt	$ 650		650	0
5.75% November 15, 2035
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 250		250	250
5.125% November 15, 2040
Debt Instrument [Line Items]
Stated percentage rate	5.125%
Gross long-term debt	$ 300		300	300
3.75% September 15, 2042
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 350		350	350
4.45% March 15, 2044
Debt Instrument [Line Items]
Stated percentage rate	4.45%
Gross long-term debt	$ 250		250	250
4.125% June 1, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.125%
Gross long-term debt	$ 400		400	400
4.3% January 15, 2049
Debt Instrument [Line Items]
Stated percentage rate	4.30%
Gross long-term debt	$ 550		550	550
3.95% February 15, 2050
Debt Instrument [Line Items]
Stated percentage rate	3.95%
Gross long-term debt	$ 350		350	350
Notes at variable rates (0.55% at December 31, 2021) September 14, 2023(1)
Debt Instrument [Line Items]
Stated percentage rate	0.55%
Gross long-term debt	$ 300		300	0
1.875% Notes May 14, 2026(1)
Debt Instrument [Line Items]
Stated percentage rate	1.875%
Gross long-term debt	$ 4		4	4
5.67% Notes January 18, 2028(2)
Debt Instrument [Line Items]
Stated percentage rate	5.67%
Gross long-term debt	$ 5		5	$ 5
2.4% Notes February 1, 2020
Debt Instrument [Line Items]
Stated percentage rate				2.40%
Gross long-term debt	0		0	$ 500
2.4% Notes March 15, 2020
Debt Instrument [Line Items]
Stated percentage rate				2.40%
Gross long-term debt	0		0	$ 500
2.85% Notes November 15, 2020
Debt Instrument [Line Items]
Stated percentage rate				2.85%
Gross long-term debt	0		0	$ 400
Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instrument [Line Items]
Gross long-term debt	0		$ 0	700
Other Long Term Debt, Variable Rate Notes Due March 2021 [Member]
Debt Instrument [Line Items]
Stated percentage rate			0.95%
Gross long-term debt	0		$ 850	850
Fixed interest rate after floating to fixed interest rate swaps			3.069%
2.875% Notes October 1, 2022
Debt Instrument [Line Items]
Stated percentage rate			2.875%
Gross long-term debt	0		$ 500	500
2.9% Notes February 1, 2023
Debt Instrument [Line Items]
Stated percentage rate			2.90%
Gross long-term debt	0		$ 500	500
4.05% Notes December 1, 2023
Debt Instrument [Line Items]
Stated percentage rate			4.05%
Gross long-term debt	0		$ 500	500
3.55% Notes June 15, 2024
Debt Instrument [Line Items]
Stated percentage rate			3.55%
Gross long-term debt	0		$ 500	500
3.75% Notes November 15, 2025
Debt Instrument [Line Items]
Stated percentage rate			3.75%
Gross long-term debt	$ 0		$ 350	350
3.25% Notes June 15, 2027
Debt Instrument [Line Items]
Stated percentage rate	3.25%
Gross long-term debt	$ 750		750	750
3.4% Notes February 1, 2028
Debt Instrument [Line Items]
Stated percentage rate	3.40%
Gross long-term debt	$ 1,000		1,000	1,000
3.8% Notes February 1, 2038
Debt Instrument [Line Items]
Stated percentage rate	3.80%
Gross long-term debt	$ 1,000		1,000	1,000
6% Notes October 15, 2039
Debt Instrument [Line Items]
Stated percentage rate	6.00%
Gross long-term debt	$ 750		750	750
4% Notes February 1, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.00%
Gross long-term debt	$ 800		800	800
4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instrument [Line Items]
Stated percentage rate	4.125%	4.125%
Gross long-term debt	$ 1,000		0	0
5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instrument [Line Items]
Stated percentage rate	5.75%
Gross long-term debt	$ 758		758	758
6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013)
Debt Instrument [Line Items]
Stated percentage rate	6.30%
Gross long-term debt	$ 189		197	207
Fixed interest rate after floating to fixed interest rate swaps	4.124%
Loan at variable rates (2.93% at December 31, 2021) December 9, 2025
Debt Instrument [Line Items]
Stated percentage rate	2.93%
Gross long-term debt	$ 341		17	0
Notes at 2.87% to 3.51% October 1, 2026(1)
Debt Instrument [Line Items]
Gross long-term debt	0		0	$ 22
Notes at 2.87% to 3.51% October 1, 2026(1) \| Minimum
Debt Instrument [Line Items]
Stated percentage rate				2.87%
Notes at 2.87% to 3.51% October 1, 2026(1) \| Maximum
Debt Instrument [Line Items]
Stated percentage rate				3.51%
Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets(2)
Debt Instrument [Line Items]
Gross long-term debt	$ 154		196	$ 237
Fixed interest rate after floating to fixed interest rate swaps	5.13%
3.75% Notes January 14, 2028
Debt Instrument [Line Items]
Stated percentage rate	3.75%
Gross long-term debt	$ 300		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
Debt Instrument [Line Items]
Gross long-term debt	0		$ 398	423
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 \| Weighted Average
Debt Instrument [Line Items]
Stated percentage rate			6.87%
Gross long-term debt			$ 234
Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)
Debt Instrument [Line Items]
Gross long-term debt	0		0	11
Other Long-term Debt, Variable Rate Payable Through November 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 200		200	200
Fixed interest rate after floating to fixed interest rate swaps	4.0275%
Other Long Term Debt 2.9% Loan Due 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 241		241	0
Other Long-term Debt, Variable Rate Loan Due November 2034
Debt Instrument [Line Items]
Gross long-term debt	$ 100		100	0
Fixed interest rate after floating to fixed interest rate swaps	2.38%
4.875% Notes January 14, 2048
Debt Instrument [Line Items]
Stated percentage rate	4.875%
Gross long-term debt	$ 540		540	540
Other Long-term Debt, 4.75% Notes Due September 2051
Debt Instrument [Line Items]
Stated percentage rate	4.75%
Gross long-term debt	$ 800		$ 800	$ 0
LIBOR \| Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instrument [Line Items]
Stated percentage rate				2.50%
LIBOR \| 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
Debt Instrument [Line Items]
Stated percentage rate			3.45%
Gross long-term debt			$ 34
LIBOR \| 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 \| Weighted Average
Debt Instrument [Line Items]
Gross long-term debt			$ 130
Fixed interest rate after floating to fixed interest rate swaps			6.54%
LIBOR \| Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)
Debt Instrument [Line Items]
Stated percentage rate				5.75%

REGULATORY MATTERS - BILLING PRACTICES (Details) - California Public Utilities Commission - USD ($)		1 Months Ended	12 Months Ended
	Feb. 03, 2022	Feb. 28, 2022	Dec. 31, 2020
Energy Efficiency Program Inquiry
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
Energy Efficiency and Advocacy \| Subsequent Event
Public Utilities, General Disclosures [Line Items]
Energy Efficiency Program Inquiry fines that reduce revenue	$ 10,000,000	$ 150,000

DERIVATIVE FINANCIAL INSTRUMENTS (Tables)

12 Months Ended

Dec. 31, 2021

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	2021	2020	2019
Sempra:
Natural gas	MMBtu	184	189	231
Electricity	MWh	1	1	2
Congestion revenue rights	MWh	45	43	48

SDG&E:
Natural gas	MMBtu	7	16	37
Electricity	MWh	1	1	2
Congestion revenue rights	MWh	45	43	48
SoCalGas:
Natural gas	MMBtu	201	185	201

Notional Amounts Of Interest Rate Derivatives Table

The following table presents the net notional amounts of our interest rate derivatives, excluding those in our equity method investments, at December 31:


INTEREST RATE DERIVATIVES
(Dollars in millions)
	2021			2020			2019
	Notional debt		Maturities	Notional debt		Maturities	Notional debt		Maturities
Sempra:
Cash flow hedges	$	462	2022-2034	$	1,486	2021-2034	$	1,445	2020-2034

The following table presents the net notional amounts of our foreign currency derivatives, excluding those in our equity method investments, at December 31.


FOREIGN CURRENCY DERIVATIVES
(Dollars in millions)
	2021			2020			2019
	Notional amount		Maturities	Notional amount		Maturities	Notional amount		Maturities
Sempra:
Cross-currency swaps	$	306	2022-2023	$	306	2021-2023	$	306	2020-2023
Other foreign currency derivatives	106		2022-2023	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, 2021
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	6	$	(6)	$	(2)
Foreign exchange instruments	1		1		(1)		—
Interest rate and foreign exchange instruments	—		—		(1)		(130)
Derivatives not designated as hedging instruments:


Commodity contracts not subject to rate recovery	136		11		(122)		(10)
Associated offsetting commodity contracts	(93)		(8)		93		8

Commodity contracts subject to rate recovery	38		52		(58)		—
Associated offsetting commodity contracts	(8)		—		8		—

Net amounts presented on the balance sheet	74		62		(87)		(134)
Additional cash collateral for commodity contracts not subject to rate recovery	58		—		—		—
Additional cash collateral for commodity contracts subject to rate recovery	46		—		—		—
Total(1)	$	178	$	62	$	(87)	$	(134)
SDG&E:
Derivatives not designated as hedging instruments:


Commodity contracts subject to rate recovery	$	34	$	52	$	(20)	$	—
Associated offsetting commodity contracts	(5)		—		5		—

Net amounts presented on the balance sheet	29		52		(15)		—

Additional cash collateral for commodity contracts subject to rate recovery	28		—		—		—
Total(1)	$	57	$	52	$	(15)	$	—
SoCalGas:
Derivatives not designated as hedging instruments:


Commodity contracts subject to rate recovery	$	4	$	—	$	(38)	$	—
Associated offsetting commodity contracts	(3)		—		3		—

Net amounts presented on the balance sheet	1		—		(35)		—

Additional cash collateral for commodity contracts subject to rate recovery	18		—		—		—
Total	$	19	$	—	$	(35)	$	—

(1) Normal purchase contracts previously measured at fair value are excluded.


DERIVATIVE INSTRUMENTS ON THE CONSOLIDATED BALANCE SHEETS
(Dollars in millions)
	December 31, 2020
	Other current assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	1	$	(16)	$	(31)
Foreign exchange instruments	—		—		(9)		(2)
Interest rate and foreign exchange instruments	—		—		(1)		(127)
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(1)	$	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(1)	$	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) 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 assets		Other long-term assets		Other current liabilities		Deferred credits and other
Sempra:
Derivatives designated as hedging instruments:
Interest rate instruments	$	—	$	3	$	(11)	$	(17)
Foreign exchange instruments	—		—		(6)		(1)
Interest rate and foreign exchange instruments	—		—		—		(122)
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(1)	$	126	$	85	$	(53)	$	(192)
SDG&E:
Derivatives not designated as hedging instruments:




Commodity contracts subject to rate recovery	$	30	$	76	$	(41)	$	(47)
Associated offsetting commodity contracts	(4)		(3)		4		3
Associated offsetting cash collateral	—		—		14		—
Net amounts presented on the balance sheet	26		73		(23)		(44)

Additional cash collateral for commodity contracts subject to rate recovery	16		—		—		—
Total(1)	$	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) Normal purchase contracts previously measured at fair value are excluded.

Cash Flow Hedge Impact on the Consolidated Statements Of Operations Table

The following table 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 gain (loss) recognized in OCI							Pretax (loss) gain reclassified from AOCI into earnings
	Years ended December 31,							Years ended December 31,
	2021		2020		2019		Location	2021		2020		2019
Sempra:
Interest rate instruments	$	—	$	—	$	—	Gain (Loss) on Sale of Assets	$	—	$	—	$	(10)
Interest rate instruments(1)	29		(34)		(24)		Interest Expense(1)	(11)		(10)		(3)
Interest rate instruments	71		(185)		(164)		Equity Earnings(2)	(73)		(46)		(3)
Foreign exchange instruments	11		(4)		(8)		Revenues: Energy- Related Businesses	(1)		1		(2)

Foreign exchange instruments	8		(3)		(10)		Equity Earnings(2)	—		—		(2)
Interest rate and foreign exchange instruments	(4)		(6)		19		Interest Expense	(1)		(1)		—
							Other Income (Expense), Net	(6)		(11)		9
Total	$	115	$	(232)	$	(187)		$	(92)	$	(67)	$	(11)
SDG&E:
Interest rate instruments(1)	$	—	$	—	$	(1)	Interest Expense(1)	$	—	$	—	$	(3)
SoCalGas:
Interest rate instruments	$	—	$	—	$	—	Interest Expense	$	—	$	—	$	(1)

(2) Equity earnings at our foreign equity method investees are recognized after tax.

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 (loss) gain on derivatives recognized in earnings
		Years ended December 31,
	Location	2021		2020		2019
Sempra:

Commodity contracts not subject to rate recovery	Revenues: Energy-Related Businesses	$	(203)	$	17	$	12


Commodity contracts subject to rate recovery	Cost of Natural Gas	(25)		(7)		3
Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	31		88		(140)
Foreign exchange instruments	Other Income (Expense), Net	(22)		(56)		25
Total		$	(219)	$	42	$	(100)
SDG&E:

Commodity contracts subject to rate recovery	Cost of Electric Fuel and Purchased Power	$	31	$	88	$	(140)

SoCalGas:

Commodity contracts subject to rate recovery	Cost of Natural Gas	$	(25)	$	(7)	$	3

Tabular disclosure of pertinent information about a derivative or group of derivatives on a disaggregated basis, such as for individual instruments, or small groups of similar instruments. May include a combination of the type of instrument, risks being hedged, notional amount, hedge designation, related hedged item, inception date, maturity date, or other relevant item.

Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4B
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5624163-113959

Reference 2: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1B
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5580258-113959

Reference 3: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41620-113959

Reference 4: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5579245-113959

Reference 5: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41638-113959

Reference 6: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41678-113959

Reference 7: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=125515794&loc=d3e41641-113959

Reference 8: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 4C
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5624171-113959

Reference 9: http://fasb.org/us-gaap/role/ref/legacyRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=125515794&loc=SL5579240-113959

Schedule of Segment Reporting Information, by Segment

INVESTMENTS IN UNCONSOLIDATED ENTITIES - SUMMARY OF INVESTMENTS (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Mar. 31, 2021	Mar. 19, 2021	Mar. 18, 2021
Schedule of Equity Method Investments [Line Items]
Equity method investment	$ 12,947	$ 12,440	$ 11,519
Other investments	1,525	1,388	2,103
Goodwill	1,602	1,602	1,602
Earnings (losses) recorded before income tax	614	294	30
Earnings recorded net of income tax	729	721	550
Total equity earnings	1,343	1,015	580
Distributions from investments	$ 1,360	1,462	256
ESJ
Schedule of Equity Method Investments [Line Items]
Difference between carrying amount of equity method investment and underlying equity		$ 12	$ 12
Ownership percentage held by noncontrolling owners		50.00%		50.00%	50.00%	50.00%
Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	100.00%	100.00%	100.00%
Equity method investment	$ 12,947	$ 12,440	$ 11,519
Difference between carrying amount of equity method investment and underlying equity	2,844	2,833	2,823
Goodwill	2,868	2,868	2,868
Equity method investment, difference between carrying amount and underlying equity, aoci	69	69	69
Difference between carrying amount and underlying equity, tax sharing liability	93	104	114
Earnings recorded net of income tax	$ 617	$ 577	$ 526
Sharyland Holdings, LP
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%	50.00%
Equity method investment	$ 100	$ 102	$ 100
Difference between carrying amount of equity method investment and underlying equity	42
Earnings (losses) recorded before income tax	$ 5	$ 3	$ 2
Cameron LNG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.20%	50.20%	50.20%
Other investments	$ 514	$ 433	$ 1,256
Difference between carrying amount of equity method investment and underlying equity	276	259	263
Earnings (losses) recorded before income tax	$ 559	$ 391	$ 24
ESJ JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	0.00%	50.00%	50.00%
Other investments	$ 0	$ 34	$ 39
Earnings recorded net of income tax	$ 2	$ 5	$ 2
IMG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	40.00%	40.00%	40.00%
Other investments	$ 523	$ 440	$ 337
Difference between carrying amount of equity method investment and underlying equity	5
Earnings recorded net of income tax	$ 83	$ 103	$ 9
TAG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee	50.00%	50.00%	50.00%
Other investments	$ 388	$ 378	$ 365
Difference between carrying amount of equity method investment and underlying equity	130
Earnings recorded net of income tax	27	36	13
Total other equity method investments
Schedule of Equity Method Investments [Line Items]
Other investments	1,525	1,387	2,097
Other
Schedule of Equity Method Investments [Line Items]
Other investments	0	1	6
Earnings (losses) recorded before income tax	0	0	(1)
Wind Assets
Schedule of Equity Method Investments [Line Items]
Earnings (losses) recorded before income tax	0	0	5
R B S Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Earnings (losses) recorded before income tax	50	(100)	$ 0
Total equity earnings	$ 50	$ (100)

SEGMENT INFORMATION (Tables)

12 Months Ended

Dec. 31, 2021

Segment Reporting [Abstract]


SEGMENT INFORMATION
(Dollars in millions)
	Years ended December 31,
	2021		2020		2019
REVENUES
SDG&E	$	5,504	$	5,313	$	4,925
SoCalGas	5,515		4,748		4,525
Sempra Infrastructure	1,997		1,400		1,454
Sempra Renewables	—		—		10
All other	5		2		3
Adjustments and eliminations	(1)		(3)		(3)
Intersegment revenues(1)	(163)		(90)		(85)
Total	$	12,857	$	11,370	$	10,829
DEPRECIATION AND AMORTIZATION
SDG&E	$	889	$	801	$	760
SoCalGas	716		654		602
Sempra Infrastructure	239		198		193
All other	11		13		14
Total	$	1,855	$	1,666	$	1,569
INTEREST INCOME
SDG&E	$	1	$	2	$	4
SoCalGas	1		2		2
Sempra Infrastructure	75		141		139
Sempra Renewables	—		—		11
All other	3		7		4
Intercompany eliminations	(11)		(56)		(73)
Total	$	69	$	96	$	87
INTEREST EXPENSE
SDG&E	$	412	$	413	$	411
SoCalGas	157		158		141
Sempra Infrastructure	205		174		155
Sempra Renewables	—		—		3
All other	444		390		450
Intercompany eliminations	(20)		(54)		(83)
Total	$	1,198	$	1,081	$	1,077
INCOME TAX EXPENSE (BENEFIT)
SDG&E	$	201	$	190	$	171
SoCalGas	(310)		96		120
Sempra Texas Utilities	—		1		—
Sempra Infrastructure	238		149		222
Sempra Renewables	—		—		4
All other	(30)		(187)		(202)
Total	$	99	$	249	$	315
EARNINGS (LOSSES) ATTRIBUTABLE TO COMMON SHARES
SDG&E	$	819	$	824	$	767
SoCalGas	(427)		504		641
Sempra Texas Utilities	616		579		528
Sempra Infrastructure	682		580		247
Sempra Renewables	—		—		59
Discontinued operations	—		1,840		328
All other	(436)		(563)		(515)
Total	$	1,254	$	3,764	$	2,055


SEGMENT INFORMATION (CONTINUED)
(Dollars in millions)
	Years ended December 31 or at December 31,
	2021		2020		2019
EXPENDITURES FOR PROPERTY, PLANT & EQUIPMENT
SDG&E	$	2,220	$	1,942	$	1,522
SoCalGas	1,984		1,843		1,439
Sempra Infrastructure	802		879		736
Sempra Renewables	—		—		2
All other	9		12		9
Total	$	5,015	$	4,676	$	3,708
ASSETS
SDG&E	$	24,058	$	22,311	$	20,560
SoCalGas	20,324		18,460		17,077
Sempra Texas Utilities	13,047		12,542		11,619
Sempra Infrastructure	14,408		12,772		13,660
Discontinued operations	—		—		3,958
All other	1,399		1,215		763
Intersegment receivables	(1,191)		(677)		(1,972)
Total	$	72,045	$	66,623	$	65,665
GEOGRAPHIC INFORMATION
Long-lived assets(2):
United States	$	50,657	$	46,902	$	43,719
Mexico	$	7,708	$	6,929	$	6,355
Asia	1		—		—
Total	$	58,366	$	53,831	$	50,074
Revenues(3):
United States	$	11,154	$	10,205	$	9,574
Mexico	1,703		1,165		1,255
Total	$	12,857	$	11,370	$	10,829

(2)Includes net PP&E and investments.

(3)Amounts are based on where the revenue originated, after intercompany eliminations.

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - FOOTNOTES (Details)	1 Months Ended		12 Months Ended
	Dec. 31, 2021 USD ($) lender	Nov. 30, 2021 USD ($)	Dec. 31, 2021 USD ($) lender	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Debt Instruments [Abstract]
Total facility	$ 9,535,000,000	$ 1,000,000,000	$ 9,535,000,000
Letters of credit outstanding	682,000,000		682,000,000
Gross long-term debt	8,923,000,000		8,923,000,000	$ 11,247,000,000	$ 12,298,000,000
Current portion of long-term debt	(46,000,000)		(46,000,000)	(919,000,000)	(1,464,000,000)
Unamortized discount on long-term debt	(65,000,000)		(65,000,000)	(55,000,000)	(35,000,000)
Unamortized debt issuance costs	(98,000,000)		(98,000,000)	(121,000,000)	(108,000,000)
Long-term debt	8,714,000,000		8,714,000,000	10,152,000,000	$ 10,691,000,000
Long term debt maturities after 2026	16,397,000,000		16,397,000,000
Operating leases(1)
Total operating lease commitments	59,000,000		59,000,000
2022	17,000,000		17,000,000
2023	13,000,000		13,000,000
2024	11,000,000		11,000,000
2025	10,000,000		10,000,000
Thereafter	0		0
Letter of Credit
Debt Instruments [Abstract]
Long-term debt outstanding	682,000,000		682,000,000
2.4% Notes February 1, 2020
Debt Instruments [Abstract]
Stated percentage rate					2.40%
Gross long-term debt	0		0	0	$ 500,000,000
2.4% Notes March 15, 2020
Debt Instruments [Abstract]
Stated percentage rate					2.40%
Gross long-term debt	0		0	0	$ 500,000,000
2.85% Notes November 15, 2020
Debt Instruments [Abstract]
Stated percentage rate					2.85%
Gross long-term debt	0		0	0	$ 400,000,000
Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Gross long-term debt	0		0	$ 0	700,000,000
Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021
Debt Instruments [Abstract]
Stated percentage rate				0.95%
Fixed interest rate after floating to fixed interest rate swaps				3.069%
Gross long-term debt	0		0	$ 850,000,000	850,000,000
2.875% Notes October 1, 2022
Debt Instruments [Abstract]
Stated percentage rate				2.875%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
2.9% Notes February 1, 2023
Debt Instruments [Abstract]
Stated percentage rate				2.90%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
4.05% Notes December 1, 2023
Debt Instruments [Abstract]
Stated percentage rate				4.05%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
3.55% Notes June 15, 2024
Debt Instruments [Abstract]
Stated percentage rate				3.55%
Gross long-term debt	0		0	$ 500,000,000	500,000,000
3.75% Notes November 15, 2025
Debt Instruments [Abstract]
Stated percentage rate				3.75%
Gross long-term debt	$ 0		$ 0	$ 350,000,000	350,000,000
3.25% Notes June 15, 2027
Debt Instruments [Abstract]
Stated percentage rate	3.25%		3.25%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
3.4% Notes February 1, 2028
Debt Instruments [Abstract]
Stated percentage rate	3.40%		3.40%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
3.8% Notes February 1, 2038
Debt Instruments [Abstract]
Stated percentage rate	3.80%		3.80%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
6% Notes October 15, 2039
Debt Instruments [Abstract]
Stated percentage rate	6.00%		6.00%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
4% Notes February 1, 2048
Debt Instruments [Abstract]
Stated percentage rate	4.00%		4.00%
Gross long-term debt	$ 800,000,000		$ 800,000,000	800,000,000	800,000,000
5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instruments [Abstract]
Stated percentage rate	5.75%		5.75%
Gross long-term debt	$ 758,000,000		$ 758,000,000	758,000,000	758,000,000
Senior Unsecured Notes Maturing 2022 Through 2025
Debt Instruments [Abstract]
Underwriting discounts and debt issuance costs	126,000,000		126,000,000
Debt issuance costs (after tax)	92,000,000		92,000,000
Parent Company
Basis of Presentation
Cash dividends received			375,000,000	300,000,000	150,000,000
Debt Instruments [Abstract]
Total facility	4,400,000,000		4,400,000,000
Amount available	$ 3,100,000,000		$ 3,100,000,000
Number of lenders \| lender	23		23
Share of facility held by lenders (as a percent)	6.00%		6.00%
Allowed increase in letters of credit	$ 500,000,000		$ 500,000,000
Letters of credit outstanding	$ 0		$ 0
Ratio of indebtedness to total capitalization (as a percent)	65.00%		65.00%
Gross long-term debt	$ 6,058,000,000		$ 6,058,000,000	8,258,000,000	10,358,000,000
Current portion of long-term debt	0		0	(850,000,000)	(1,399,000,000)
Unamortized discount on long-term debt	(37,000,000)		(37,000,000)	(32,000,000)	(35,000,000)
Unamortized debt issuance costs	(52,000,000)		(52,000,000)	(59,000,000)	(68,000,000)
Long-term debt	5,969,000,000		5,969,000,000	7,317,000,000	8,856,000,000
Long term debt maturities after 2026	6,100,000,000		6,100,000,000
Operating leases(1)
Total operating lease commitments	279,000,000		279,000,000
2022	11,000,000		11,000,000
2023	12,000,000		12,000,000
2024	12,000,000		12,000,000
2025	12,000,000		12,000,000
Thereafter	220,000,000		220,000,000
Parent Company \| Letter of Credit
Debt Instruments [Abstract]
Long-term debt outstanding	$ 200,000,000		$ 200,000,000
Parent Company \| 2.4% Notes February 1, 2020
Debt Instruments [Abstract]
Stated percentage rate	2.40%		2.40%
Gross long-term debt	$ 0		$ 0	0	500,000,000
Parent Company \| 2.4% Notes March 15, 2020
Debt Instruments [Abstract]
Stated percentage rate	2.40%		2.40%
Gross long-term debt	$ 0		$ 0	0	500,000,000
Parent Company \| 2.85% Notes November 15, 2020
Debt Instruments [Abstract]
Stated percentage rate	2.85%		2.85%
Gross long-term debt	$ 0		$ 0	0	400,000,000
Parent Company \| Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Gross long-term debt	$ 0		$ 0	0	700,000,000
Parent Company \| Notes at variable rates (3.069% after floating-to-fixed rate swaps effective 2019) March 15, 2021
Debt Instruments [Abstract]
Fixed interest rate after floating to fixed interest rate swaps	3.069%		3.069%
Gross long-term debt	$ 0		$ 0	850,000,000	850,000,000
Parent Company \| 2.875% Notes October 1, 2022
Debt Instruments [Abstract]
Stated percentage rate	2.875%		2.875%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company \| 2.9% Notes February 1, 2023
Debt Instruments [Abstract]
Stated percentage rate	2.90%		2.90%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company \| 4.05% Notes December 1, 2023
Debt Instruments [Abstract]
Stated percentage rate	4.05%		4.05%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company \| 3.55% Notes June 15, 2024
Debt Instruments [Abstract]
Stated percentage rate	3.55%		3.55%
Gross long-term debt	$ 0		$ 0	500,000,000	500,000,000
Parent Company \| 3.75% Notes November 15, 2025
Debt Instruments [Abstract]
Stated percentage rate	3.75%		3.75%
Gross long-term debt	$ 0		$ 0	350,000,000	350,000,000
Parent Company \| 3.25% Notes June 15, 2027
Debt Instruments [Abstract]
Stated percentage rate	3.25%		3.25%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
Parent Company \| 3.4% Notes February 1, 2028
Debt Instruments [Abstract]
Stated percentage rate	3.40%		3.40%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
Parent Company \| 3.8% Notes February 1, 2038
Debt Instruments [Abstract]
Stated percentage rate	3.80%		3.80%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	1,000,000,000	1,000,000,000
Parent Company \| 6% Notes October 15, 2039
Debt Instruments [Abstract]
Stated percentage rate	6.00%		6.00%
Gross long-term debt	$ 750,000,000		$ 750,000,000	750,000,000	750,000,000
Parent Company \| 4% Notes February 1, 2048
Debt Instruments [Abstract]
Stated percentage rate	4.00%		4.00%
Gross long-term debt	$ 800,000,000		$ 800,000,000	800,000,000	800,000,000
Parent Company \| 4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instruments [Abstract]
Stated percentage rate	4.125%	4.125%	4.125%
Gross long-term debt	$ 1,000,000,000		$ 1,000,000,000	0	0
Proceeds from issuance of debt		$ 988,000,000
Underwriting discounts and debt issuance costs		12,000,000
Debt amount		1,000,000,000
Repayments of senior notes		$ 2,350,000,000
Parent Company \| 5.75% Junior Subordinated Notes July 1, 2079(1)
Debt Instruments [Abstract]
Stated percentage rate	5.75%		5.75%
Gross long-term debt	$ 758,000,000		$ 758,000,000	$ 758,000,000	$ 758,000,000
Parent Company \| Senior Unsecured Notes Maturing 2022 Through 2025
Debt Instruments [Abstract]
Proceeds from issuance of debt	$ 2,350,000,000
LIBOR \| Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Stated percentage rate					2.50%
LIBOR \| Parent Company \| Notes at variable rates (2.50% at December 31, 2019) January 15, 2021(1)
Debt Instruments [Abstract]
Stated percentage rate	2.50%		2.50%
LIBOR \| Parent Company \| 4.125% Junior Subordinated Notes April 1, 2052(1)
Debt Instruments [Abstract]
Variable percentage rate		2.868%

INVESTMENTS IN UNCONSOLIDATED ENTITIES - NARRATIVE (Details)		1 Months Ended			12 Months Ended
	May 16, 2019 USD ($)	Jun. 30, 2021 USD ($)	Jul. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2021 USD ($) MT Bcf	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Mar. 31, 2021	Mar. 19, 2021	Mar. 18, 2021	May 31, 2019	Jun. 30, 2015 USD ($)	Nov. 30, 2014 USD ($)
Schedule of Equity Method Investments [Line Items]
Undistributed earnings from equity method investments				$ 634,000,000	$ 1,500,000,000	$ 1,100,000,000	$ 634,000,000
Undistributed earnings, equity method investments, over 50 percent owned					1,100,000,000
Interest costs capitalized					64,000,000	55,000,000	47,000,000
Equitization of long-term debt for deficit held by NCI					0	22,000,000	0
Return on investments					366,000,000	761,000,000	9,000,000
Equity earnings					$ 1,343,000,000	$ 1,015,000,000	$ 580,000,000
Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee				100.00%	100.00%	100.00%	100.00%
Cash contributed to fund the acquisition				$ 1,067,000,000			$ 1,067,000,000
R B S Sempra Commodities
Schedule of Equity Method Investments [Line Items]
Equity earnings					$ 50,000,000	$ (100,000,000)
IMG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee				40.00%	40.00%	40.00%	40.00%
ESJ JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee				50.00%	0.00%	50.00%	50.00%
Cameron LNG
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee					50.20%
Indirect economic and beneficial and ownership interest after financial completion					10.00%
Sempra Infrastructure \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Current guarantor obligations					$ 7,000,000
Sempra Infrastructure \| IMG JV
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity method investee					40.00%
Transportation service contract term					35 years
Sempra Infrastructure \| Cameron LNG
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments					$ 2,000,000	$ 54,000,000	$ 77,000,000
Project capacity \| MT					13.9
Proved undeveloped reserve \| MT					12
Proved undeveloped reserve per day \| Bcf					1.7
Interest costs capitalized						33,000,000
Debt amount					$ 7,400,000,000
Equitization of long-term debt for deficit held by NCI				$ 3,000,000,000
Fixed percentage interest rate					3.39%
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)					3.69%
Sempra Infrastructure \| Cameron LNG \| Corporate Joint Venture
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 Infrastructure \| Cameron LNG \| Corporate Joint Venture \| Promissory Note for SDSRA Distribution
Schedule of Equity Method Investments [Line Items]
Cash dividends received		$ 165,000,000
Sempra Infrastructure \| Cameron LNG \| Corporate Joint Venture \| Variable Interest Entity, Not Primary Beneficiary
Schedule of Equity Method Investments [Line Items]
Proceeds from related parties			$ 753,000,000
Return on investments					753,000,000
Sempra Infrastructure \| Cameron LNG \| Corporate Joint Venture \| Deferred Credits and Other \| Promissory Note for SDSRA Distribution
Schedule of Equity Method Investments [Line Items]
Guaranty liability		$ 22,000,000			$ 22,000,000
Sempra Infrastructure \| LIBOR \| Cameron LNG
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
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest	50.00%										50.00%
Payments to acquire equity method investments	$ 95,000,000
Post-closing adjustments	$ 7,000,000
Cash invested in equity method investment							3,000,000
ESJ \| Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Acquired percentage interest									50.00%
Oncor Holdings
Schedule of Equity Method Investments [Line Items]
Payments to acquire equity method investments					$ 566,000,000	$ 632,000,000	$ 1,587,000,000
Oncor Holdings \| Sempra Texas Holdings Corp
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity					100.00%
Oncor Electric Delivery Company LLC
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners					80.25%
Cameron LNG \| Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage in consolidated entity					50.20%
ESJ
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners						50.00%		50.00%	50.00%	50.00%
ESJ \| ESJ \| Sempra Infrastructure
Schedule of Equity Method Investments [Line Items]
Ownership percentage held by noncontrolling owners										50.00%

DERIVATIVE FINANCIAL INSTRUMENTS - CONTINGENT FEATURES (Details) - USD ($) $ in Millions	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Derivative Instruments, Gain (Loss) [Line Items]
Aggregate fair value of net liability position	$ 36	$ 6	$ 4
Aggregate fair value of additional collateral	$ 36

REVENUES - CONTRACT LIABILITIES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Contract with Customer, Liability [Roll Forward]
Beginning balance	$ (87)	$ (91)	$ 0
Revenue from performance obligations satisfied during reporting period	4	4	1
Payments received in advance	0	0	(92)
Ending balance	(83)	(87)	(91)
Other Current Liabilities
Contract with Customer, Liability [Roll Forward]
Beginning balance	(4)	(4)
Ending balance	(4)	(4)	(4)
Deferred Credits and Other
Contract with Customer, Liability [Roll Forward]
Beginning balance	(83)	(87)
Ending balance	$ (79)	$ (83)	$ (87)

SIGNIFICANT ACCOUNTING POLICIES AND OTHER FINANCIAL DATA - CREDIT LOSSES (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Beginning Balance	$ 68	$ 15	$ 10
Provisions for expected credit losses	22	59	12
Write-offs	(21)	(6)	(7)
Allowances for credit losses at December 31	69	68	15
KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Note receivable issued	300
Accounts receivable – trade, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	51	55	3
Accounts receivable – other, net
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Current	17	13	12
Other long-term assets
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	1	0	0
Other long-term assets \| KKR
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Other long-term assets	8
Due from Unconsolidated Affiliates - Noncurrent
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Financing receivable, allowance for credit loss	1	3
Deferred Credits and Other \| Sempra Infrastructure
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Allowance for credit loss related to guarantees	7
Cumulative Effect, Period of Adoption, Adjustment
Accounts Receivable, Allowance for Credit Loss [Roll Forward]
Accounts Receivable, Allowance for Credit Loss, Beginning Balance	$ 0	1	0
Allowances for credit losses at December 31		$ 0	$ 1

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT - STATEMENT OF COMPREHENSIVE INCOME (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Condensed Statement of Income Captions [Line Items]
Net income	$ (426)	$ 505	$ 642
Total other comprehensive (loss) income	171	(8)	1
Pretax amount
Condensed Statement of Income Captions [Line Items]
Net income	(736)	601	762
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	191	(146)	1
Pension and other postretirement benefits	28	(12)	1
Total other comprehensive (loss) income	213	(12)	2
Total comprehensive income, after preferred dividends of subsidiaries	1,020	1,022	932
Income tax benefit (expense)
Condensed Statement of Income Captions [Line Items]
Net income	310	(96)	(120)
Foreign currency translation adjustments	0	0	0
Financial instruments	(47)	33	0
Pension and other postretirement benefits	(6)	4	(1)
Total other comprehensive (loss) income	(53)	4	(1)
Total comprehensive income, after preferred dividends of subsidiaries	(201)	(192)	(169)
Net-of-tax amount
Condensed Statement of Income Captions [Line Items]
Net income	(426)	505	642
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	144	(113)	1
Pension and other postretirement benefits	22	(8)	0
Total other comprehensive (loss) income	160	(8)	1
Total comprehensive income, after preferred dividends of subsidiaries	819	830	763
Parent Company
Condensed Statement of Income Captions [Line Items]
Net income	1,317	3,932	2,197
Parent Company \| Pretax amount
Condensed Statement of Income Captions [Line Items]
Net income	1,127	3,756	2,034
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	191	(146)	(161)
Pension and other postretirement benefits	28	11	25
Total other comprehensive (loss) income	213	412	(179)
Total comprehensive income, after preferred dividends of subsidiaries	1,340	4,168	1,855
Parent Company \| Income tax benefit (expense)
Condensed Statement of Income Captions [Line Items]
Net income	190	176	163
Foreign currency translation adjustments	0	0	0
Financial instruments	(47)	33	53
Pension and other postretirement benefits	(6)	1	(7)
Total other comprehensive (loss) income	(53)	34	46
Total comprehensive income, after preferred dividends of subsidiaries	137	210	209
Parent Company \| Net-of-tax amount
Condensed Statement of Income Captions [Line Items]
Net income	1,317	3,932	2,197
Foreign currency translation adjustments	(6)	547	(43)
Financial instruments	144	(113)	(108)
Pension and other postretirement benefits	22	12	18
Total other comprehensive (loss) income	160	446	(133)
Total comprehensive income, after preferred dividends of subsidiaries	$ 1,477	$ 4,378	$ 2,064

SCHEDULE I - CONDENSED FINANCIAL INFORMATION OF PARENT (Tables)

12 Months Ended

Dec. 31, 2021

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,
	2021		2020		2019
Interest income	$	11	$	4	$	3
Interest expense	(576)		(495)		(521)
Operating expenses	(92)		(86)		(124)
Other income (expense), net	20		(38)		59
Income tax benefit	190		176		163
Loss before equity in earnings of subsidiaries	(447)		(439)		(420)
Equity in earnings of subsidiaries, net of income taxes	1,764		4,371		2,617
Net income	1,317		3,932		2,197
Preferred dividends	(63)		(168)		(142)
Earnings	$	1,254	$	3,764	$	2,055

Basic EPS:
Earnings	$	4.03	$	12.93	$	7.40
Weighted-average common shares outstanding	311,755		291,077		277,904

Diluted EPS:
Earnings	$	4.01	$	12.88	$	7.29
Weighted-average common shares outstanding	313,036		292,252		282,033

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, 2021, 2020 and 2019
	Pretax amount		Income tax benefit (expense)		Net-of-tax amount
2021:
Net income	$	1,127	$	190	$	1,317
Other comprehensive income (loss):
Foreign currency translation adjustments	(6)		—		(6)
Financial instruments	191		(47)		144
Pension and other postretirement benefits	28		(6)		22
Total other comprehensive income	213		(53)		160
Comprehensive income	$	1,340	$	137	$	1,477
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

See Notes to Condensed Financial Information of Parent.

Schedule Of Condensed Balance Sheets


SEMPRA ENERGY
CONDENSED BALANCE SHEETS
(Dollars in millions)
	December 31,
	2021		2020		2019
Assets:
Cash and cash equivalents	$	186	$	366	$	6
Restricted cash	2		—		—
Due from affiliates	446		58		98
Income taxes receivable, net	—		42		—
Other current assets	31		26		34
Total current assets	665		492		138

Investments in subsidiaries	33,308		33,898		32,604
Due from affiliates	21		1		3
Deferred income taxes	626		2,187		1,766
Other long-term assets	1,090		717		682
Total assets	$	35,710	$	37,295	$	35,193

Liabilities and shareholders’ equity:
Short-term debt	$	1,240	$	—	$	—
Current portion of long-term debt	—		850		1,399
Due to affiliates	185		224		369
Income taxes payable, net	4		—		274
Other current liabilities	531		536		561
Total current liabilities	1,960		1,610		2,603

Long-term debt	5,969		7,317		8,856
Due to affiliates	1,151		4,375		3,138
Other long-term liabilities	649		620		667

Commitments and contingencies (Note 4)

Shareholders’ equity	25,981		23,373		19,929
Total liabilities and shareholders’ equity	$	35,710	$	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,
	2021		2020		2019
Net cash (used in) provided by operating activities	$	(255)	$	(978)	$	294

Expenditures for property, plant and equipment	(8)		(9)		(8)
Capital contributions to investees	(1,005)		(364)		(1,528)
Disbursement for note receivable	(305)		—		—
Distribution from investments	1,552		3,616		—
(Increase) decrease in loans to affiliates, net	(20)		2		—
Other	—		—		4
Net cash provided by (used in) investing activities	214		3,245		(1,532)

Common stock dividends paid	(1,331)		(1,174)		(993)
Preferred dividends paid	(99)		(157)		(142)
Issuances of preferred stock, net	—		891		—
Issuances of common stock, net	5		11		1,830
Repurchases of common stock	(339)		(566)		(26)
Issuances of long-term debt	990		1,599		758
Payments on long-term debt	(3,200)		(3,700)		(1,500)
Increase in short-term debt	1,240		—		—
Increase in loans from affiliates, net	1,092		1,194		1,328
Purchases of noncontrolling interest	(217)		—		—
Proceeds from sale of noncontrolling interest	1,846		—		—
Equity transaction costs with third parties	—		(4)		—
Debt issuance costs	—		(1)		(25)
Make-whole premiums related to early redemptions of debt	(121)		—		—
Other financing	(2)		—		—
Net cash (used in) provided by financing activities	(136)		(1,907)		1,230

Effect of exchange rate changes on cash and cash equivalents	(1)		—		—

(Decrease) increase in cash and cash equivalents	(178)		360		(8)
Cash and cash equivalents, January 1	366		6		14
Cash, cash equivalents and restricted cash, December 31	$	188	$	366	$	6

SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING AND FINANCING ACTIVITIES
Issuance of common stock in exchange for NCI and related AOCI	$	1,373	$	—	$	—
Common dividends issued in stock	—		22		55
Common dividends declared but not paid	349		301		283
Conversion of mandatory convertible preferred stock	2,258		—		—
Preferred dividends declared but not paid	11		47		36
Equitization of amounts due from affiliates	4,351		—		—

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,
	2021		2020		2019
SDG&E:
First mortgage bonds (collateralized by plant assets):
3% August 15, 2021	$	—	$	350	$	350
1.914% payable 2015 through February 2022	17		53		89
3.6% September 1, 2023	450		450		450
2.5% May 15, 2026	500		500		500
6% June 1, 2026	250		250		250
1.7% October 1, 2030	800		800		—
5.875% January and February 2034(1)	—		—		176
5.35% May 15, 2035	250		250		250
6.125% September 15, 2037	250		250		250
4% May 1, 2039(1)	—		—		75
6% June 1, 2039	300		300		300
5.35% May 15, 2040	250		250		250
4.5% August 15, 2040	500		500		500
3.95% November 15, 2041	250		250		250
4.3% April 1, 2042	250		250		250
3.75% June 1, 2047	400		400		400
4.15% May 15, 2048	400		400		400
4.1% June 15, 2049	400		400		400
3.32% April 15, 2050	400		400		—
2.95% August 15, 2051	750		—		—
	6,417		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	1,217		1,237		1,255
Other	57		39		15
	1,274		1,476		1,270
	7,691		7,529		6,410
Current portion of long-term debt	(49)		(611)		(56)
Unamortized discount on long-term debt	(17)		(13)		(12)
Unamortized debt issuance costs	(44)		(39)		(36)
Total SDG&E	7,581		6,866		6,306

SoCalGas:
First mortgage bonds (collateralized by plant assets):
3.15% September 15, 2024	$	500	$	500	$	500
3.2% June 15, 2025	350		350		350
2.6% June 15, 2026	500		500		500
2.55% February 1, 2030	650		650		—
5.75% November 15, 2035	250		250		250
5.125% November 15, 2040	300		300		300
3.75% September 15, 2042	350		350		350
4.45% March 15, 2044	250		250		250
4.125% June 1, 2048	400		400		400
4.3% January 15, 2049	550		550		550
3.95% February 15, 2050	350		350		350

	4,450		4,450		3,800
Other long-term debt (uncollateralized):
Notes at variable rates (0.55% at December 31, 2021) September 14, 2023(1)	300		300		—
1.875% Notes May 14, 2026(1)	4		4		4
5.67% Notes January 18, 2028(2)	5		5		5
Finance lease obligations	61		54		19
	370		363		28
	4,820		4,813		3,828
Current portion of long-term debt	(11)		(10)		(6)
Unamortized discount on long-term debt	(7)		(8)		(7)
Unamortized debt issuance costs	(29)		(32)		(27)
Total SoCalGas	4,773		4,763		3,788


LONG-TERM DEBT AND FINANCE LEASES (CONTINUED)
(Dollars in millions)
	December 31,
	2021		2020		2019
Sempra:
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		750
3.4% Notes February 1, 2028	1,000		1,000		1,000
3.8% Notes February 1, 2038	1,000		1,000		1,000
6% Notes October 15, 2039	750		750		750
4% Notes February 1, 2048	800		800		800
4.125% Junior Subordinated Notes April 1, 2052(1)	1,000		—		—
5.75% Junior Subordinated Notes July 1, 2079(1)	758		758		758


Sempra Infrastructure:
Other long-term debt (uncollateralized unless otherwise noted):
6.3% Notes February 2, 2023 (4.124% after cross-currency swap effective 2013)	189		197		207
Loan at variable rates (2.93% at December 31, 2021) December 9, 2025	341		17		—
Notes at 2.87% to 3.51% October 1, 2026(1)	—		—		22
Notes at variable rates (5.13% after floating-to-fixed rate swaps effective 2014), payable 2016 through December 2026, collateralized by plant assets(2)	154		196		237
3.75% Notes January 14, 2028	300		300		300
Loan at variable rates (5.75% at December 31, 2019) July 31, 2028(1)	—		—		11
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
Loan at variable rates (4.0275% after floating-to-fixed rate swap effective 2019) payable 2022 through November 2034(1)	200		200		200
2.9% Loan November 15, 2034(1)	241		241		—
Loan at variable rates (2.38% after floating-to-fixed rate swap effective 2020) payable November 2034(1)	100		100		—
4.875% Notes January 14, 2048	540		540		540
4.75% Notes January 15, 2051	800		800		—
	8,923		11,247		12,298
Current portion of long-term debt	(46)		(919)		(1,464)
Unamortized discount on long-term debt	(65)		(55)		(35)

Unamortized debt issuance costs	(98)		(121)		(108)
Total other Sempra	8,714		10,152		10,691
Total Sempra	$	21,068	$	21,781	$	20,785

(1) Callable long-term debt not subject to make-whole provisions.

(2) Debt is not callable.

The following table shows the detail and maturities of long-term debt outstanding:


LONG-TERM DEBT
(Dollars in millions)
	December 31,
	2021		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		750
3.4% Notes February 1, 2028	1,000		1,000		1,000
3.8% Notes February 1, 2038	1,000		1,000		1,000
6% Notes October 15, 2039	750		750		750
4% Notes February 1, 2048	800		800		800
4.125% Junior Subordinated Notes April 1, 2052(1)	1,000		—		—
5.75% Junior Subordinated Notes July 1, 2079(1)	758		758		758
	6,058		8,258		10,358
Current portion of long-term debt	—		(850)		(1,399)
Unamortized discount on long-term debt	(37)		(32)		(35)
Unamortized debt issuance costs	(52)		(59)		(68)
Total long-term debt	$	5,969	$	7,317	$	8,856

(1) Callable long-term debt not subject to make-whole provisions.

COMMITMENTS AND CONTINGENCIES - LEASES THAT HAVE NOT YET COMMENCED (Details) $ in Millions	12 Months Ended
	Dec. 31, 2021 USD ($)
Lessee, Lease, Description [Line Items]
Lease not yet commenced, due in 2022	$ 1
Lease not yet commenced, due in 2023	2
Lease not yet commenced, due in 2024	2
Lease not yet commenced, due in 2025	2
Lease not yet commenced, due in 2026	2
Lease not yet commenced, due thereafter	$ 6

SAN ONOFRE NUCLEAR GENERATING STATION - NUCLEAR INSURANCE (Details) $ in Millions	Dec. 31, 2021 USD ($)
Public Utilities, General Disclosures [Line Items]
Maximum required nuclear liability insurance available	$ 450.0
Maximum secondary financial protection available	110.0
Maximum nuclear liability loss coverage per incident	560.0
Federal nuclear property damage insurance	130.0
Federal nuclear property damage insurance, minimum required	50.0
Maximum premium assessment under nuclear property damage insurance	4.3
Maximum nuclear property insurance terrorism coverage	$ 3,240.0

DEBT AND CREDIT FACILITIES - SCHEDULES OF SUMMARIES OF LINES OF CREDIT (Details) - USD ($)	12 Months Ended
	Dec. 31, 2021	Nov. 30, 2021
Line of Credit Facility [Line Items]
Total facility	$ 9,535,000,000	$ 1,000,000,000
Line of credit outstanding	(749,000,000)
Available unused credit	6,760,000,000
Sempra Energy Line Of Credit Due May 2024
Line of Credit Facility [Line Items]
Total facility	1,250,000,000
Line of credit outstanding	0
Available unused credit	1,250,000,000
IEnova Committed Line Of Credit Due 2023
Line of Credit Facility [Line Items]
Total facility	350,000,000
Line of credit outstanding	(350,000,000)
Available unused credit	0
IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Total facility	1,500,000,000
Line of credit outstanding	(399,000,000)
Available unused credit	1,101,000,000
Commercial paper
Line of Credit Facility [Line Items]
Line of credit outstanding	(2,026,000,000)
Commercial paper \| Sempra Energy Line Of Credit Due May 2024
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Commercial paper \| IEnova Committed Line Of Credit Due 2023
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Commercial paper \| IEnova Committed Line Of Credit Due 2024
Line of Credit Facility [Line Items]
Line of credit outstanding	0
Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	470,000,000
Line of credit outstanding	(321,000,000)
Available unused credit	149,000,000
Letter of Credit
Line of Credit Facility [Line Items]
Long-term debt outstanding	682,000,000
Foreign Uncommitted Revolving Credit Facility September 2022 \| Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	250,000,000
Line of credit outstanding	(250,000,000)
Available unused credit	$ 0
Foreign Uncommitted Revolving Credit Facility September 2022 \| Foreign Line of Credit \| LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate	0.10%
Foreign Uncommitted Revolving Credit Facility Due August 2023 \| Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	$ 100,000,000
Line of credit outstanding	(63,000,000)
Available unused credit	$ 37,000,000
Foreign Uncommitted Revolving Credit Facility Due August 2023 \| Foreign Line of Credit \| LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate	1.05%
Foreign Uncommitted Revolving Credit Facility Due October 2023 \| Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	$ 100,000,000
Line of credit outstanding	(8,000,000)
Available unused credit	$ 92,000,000
Foreign Uncommitted Revolving Credit Facility Due October 2023 \| Foreign Line of Credit \| LIBOR
Line of Credit Facility [Line Items]
Variable percentage rate	0.52%
Foreign Uncommitted Revolving Credit Facility Due October 2023-2 \| Foreign Line of Credit
Line of Credit Facility [Line Items]
Total facility	$ 20,000,000
Line of credit outstanding	0
Available unused credit	$ 20,000,000

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Preferred stock, dividends declared per share (USD per share)	$ 1.50	$ 1.50
Common stock dividends declared (USD per share)	1.10	1.64
Preferred Class A
Preferred stock, dividends declared per share (USD per share)	6.00	6.00
Preferred Class B
Preferred stock, dividends declared per share (USD per share)	6.75	$ 6.75
Series C Preferred Stock
Preferred stock, dividends declared per share (USD per share)	$ 27.90

Label	Element	Value
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2018-02 [Member]
Accounting Standards Update 2016-02 [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2016-02 [Member]
Accounting Standards Update 2018-02 [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2018-02 [Member]
Accounting Standards Update [Extensible Enumeration]	us-gaap_AccountingStandardsUpdateExtensibleList	Accounting Standards Update 2018-02 [Member]

Indicates amendment to accounting standards.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 2: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 3: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (f)(2)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 4: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (e)(2)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 5: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (f)(1)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 6: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 7: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 8: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 9: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (h)(2)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 7
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL122642865-165497

Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (d)(3)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 15: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (c)(2)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 16: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(4)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 17: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (c)(1)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL121967933-165497

Reference 18: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (b)(3)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 19: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 5
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL120254526-165497

Reference 20: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (b)(1)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 21: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(iv)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 22: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 23: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(iii)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 24: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 25: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (b)(2)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 26: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (h)(1)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 27: http://www.xbrl.org/2009/role/commonPracticeRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 250
-SubTopic 10
-Section 50
-Paragraph 1
-Subparagraph (c)(2)
-URI http://asc.fasb.org/extlink&oid=124431687&loc=d3e22499-107794

Reference 28: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 29: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (a)(2)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 30: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 740
-SubTopic 10
-Section 65
-Paragraph 8
-Subparagraph (d)(2)
-URI http://asc.fasb.org/extlink&oid=123459177&loc=SL121830611-158277

Reference 31: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 32: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (a)(3)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 33: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(ii)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 34: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 35: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (f)(2)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 36: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 848
-SubTopic 10
-Section 65
-Paragraph 1
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=122150657&loc=SL122150809-237846

Reference 37: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(1)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 38: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 7
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL122642865-165497

Reference 39: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 470
-SubTopic 10
-Section S65
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=124359872&loc=SL124427846-239511

Reference 40: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124402435&loc=SL124402458-218513

Reference 41: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 20
-Section 65
-Paragraph 2
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=124402435&loc=SL124402458-218513

Reference 42: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 825
-SubTopic 10
-Section 65
-Paragraph 5
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=123597120&loc=SL120254526-165497

Reference 43: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (a)(1)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 44: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 45: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (g)(2)(i)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 46: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 47: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 48: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (d)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 49: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 105
-SubTopic 10
-Section 65
-Paragraph 6
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=124434974&loc=SL124442142-165695

Reference 50: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (e)(3)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 51: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (c)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 52: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (e)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 53: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (a)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 54: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 55: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 326
-SubTopic 10
-Section 65
-Paragraph 4
-Subparagraph (e)(4)
-URI http://asc.fasb.org/extlink&oid=122640432&loc=SL121648383-210437

Reference 56: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 718
-SubTopic 10
-Section 65
-Paragraph 15
-Subparagraph (g)(2)
-URI http://asc.fasb.org/extlink&oid=121322162&loc=SL121327923-165333

Reference 57: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (e)(3)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 58: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 944
-SubTopic 40
-Section 65
-Paragraph 2
-Subparagraph (f)(1)
-URI http://asc.fasb.org/extlink&oid=124501264&loc=SL117420844-207641

Reference 59: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (e)(4)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 60: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 815
-SubTopic 40
-Section 65
-Paragraph 1
-Subparagraph (f)
-URI http://asc.fasb.org/extlink&oid=123482062&loc=SL123482106-238011

Reference 61: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (a)

Reference 62: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (a)(1)

Reference 63: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (a)(2)

Reference 64: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (a)(3)(iii)(01)

Reference 65: http://www.xbrl.org/2003/role/disclosureRef
-Topic 848
-SubTopic 10
-Name Accounting Standards Codification
-Section 65
-Paragraph 2
-Publisher FASB
-Subparagraph (a)(3)(iii)(03)