Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “non-accelerated filer,” “smaller reporting company” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date. At July ~~31, 2019,~~17, 2020, Dominion Energy South Carolina, Inc. had outstanding 40,296,147 shares of common stock, all of which were held by SCANA Corporation, a wholly-owned subsidiary of Dominion Energy, Inc.

Dominion Energy South Carolina, Inc. meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and therefore is filing this Form with the reduced disclosure format allowed under General Instruction H(2).

The following abbreviations or ~~terms~~acronyms used in ~~the text have the meanings set forth below unless the context requires otherwise:~~this Form 10-Q are defined below:

Abbreviation or Acronym		Definition
~~2015 Task Order~~		~~Retail services agreement between DESC and the DOE, which includes a potential FERC jurisdictional charge for operating and maintaining DOE transmission facilities at the Savannah River Site~~
2017 Tax Reform Act		An Act to Provide for Reconciliation Pursuant to Titles II and V of the Concurrent Resolution on the Budget for Fiscal Year 2018 (previously known as The Tax Cuts and Jobs Act) enacted on December 22, 2017
ACE Rule		Affordable Clean Energy Rule
AOCI		Accumulated other comprehensive income (loss)
ARO		Asset retirement obligation
BACT		Best available control technology
BLRA		South Carolina Base Load Review Act
CAA		Clean Air Act
CARES Act		Coronavirus Aid, Relief and Economic Security Act enacted on March 27, 2020
CCR		Coal combustion residual
CEO		Chief Executive Officer
CERCLA		Comprehensive Environmental Response, Compensation and Liability Act of 1980, also known as Superfund
CFO		Chief Financial Officer
CO₂		Carbon dioxide
Consortium		A consortium consisting of Westinghouse and WECTEC
~~CSAPR~~CUA		~~Cross-State Air Pollution Rule~~Capacity Use Area
CWA		Clean Water Act
DECG		Dominion Energy Carolina Gas Transmission, LLC
DESC		The legal entity, Dominion Energy South Carolina, Inc. ~~(formerly known as South Carolina Electric & Gas Company)~~, one or more of its consolidated ~~affiliates~~entities or operating ~~segments,~~segment, or the entirety of Dominion Energy South Carolina, Inc. and its consolidated ~~affiliates~~entities
DESS		Dominion Energy Southeast Services, Inc. ~~(formerly known as SCANA Services, Inc.)~~
~~DOE~~		~~U.S. Department of Energy~~
Dominion Energy		The legal entity, Dominion Energy, Inc., one or more of its consolidated subsidiaries (other than ~~SCANA and~~ DESC) or operating segments, or the entirety of Dominion Energy, Inc. and its consolidated subsidiaries
Dominion Energy Gas		The legal entity, Dominion Energy Gas Holdings, LLC, a wholly-owned subsidiary of Dominion Energy, one or more of its consolidated subsidiaries or operating segment, or the entirety of Dominion Energy Gas Holdings, LLC and its consolidated subsidiaries
Dominion Energy South Carolina		Dominion Energy South Carolina operating segment
DSM		Demand-side management
~~Electric Operations~~		~~Electric Operations Group operating segment~~
ELG Rule		Effluent limitations guidelines for the steam electric power generating category
EMANI		European Mutual Association for Nuclear Insurance
EPA		U.S. Environmental Protection Agency
Exchange Act		Securities Exchange Act of 1934, as amended
FERC		Federal Energy Regulatory Commission
FILOT		Fee in lieu of taxes
Fuel Company		South Carolina Fuel Company, Inc.
GAAP		U.S. generally accepted accounting principles
~~Gas Distribution~~		~~Gas Distribution Group operating segment~~
GENCO		South Carolina Generating Company, Inc.
GHG		Greenhouse gas
IAA		Interim Assessment Agreement dated March 28, 2017, as amended, among DESC, Santee Cooper, Westinghouse and WECTEC
kV		Kilovolt
MATS		Utility Mercury and Air Toxics Standard Rule
MD&A		Management's Discussion and Analysis of Financial Condition and Results of Operations
MGD		Million gallons a day

(millions)	June 30, 2019			December 31, 2018			June 30, 2020			December 31, 2019
ASSETS
Utility plant in service	$	12,986		$	12,803		$	13,472		$	13,208
Accumulated depreciation and amortization		(4,750	)		(4,581	)		(4,933	)		(4,851	)
Construction work in progress		282			350			372			339
Nuclear fuel, net of accumulated amortization		193			211			201			219
Utility plant, net ($690 and $711 related to VIEs)		8,711			8,783
Utility plant, net ($706 and $727 related to VIEs)								9,112			8,915
Nonutility Property and Investments:
Nonutility property, net of accumulated depreciation		71			72			51			69
Assets held in trust, net-nuclear decommissioning		206			190
Other investments		—			1
Assets held in trust, nuclear decommissioning								223			214
Nonutility property and investments, net		277			263			274			283
Current Assets:
Cash and cash equivalents		5			377			7			4
Restricted cash and equivalents		117			—
Receivables:
Customer, net of allowance for uncollectible accounts of $7 and $4		327			331
Customer, net of allowance for uncollectible accounts of $9 and $3								322			320
Affiliated and related party		19			359			—			14
Other		55			68			123			119
Inventories (at average cost):
Fuel		107			89			104			104
Materials and supplies		160			158			171			168
Prepayments		111			82			121			91
Regulatory assets		259			223			261			271
Other current assets		19			1			32			27
Total current assets ($133 and $96 related to VIEs)		1,179			1,688
Total current assets ($126 and $143 related to VIEs)								1,141			1,118
Deferred Debits and Other Assets:
Regulatory assets		3,759			4,046			3,821			3,892
Other		357			183			92			93
Total deferred debits and other assets ($34 and $34 related to VIEs)		4,116			4,229
Total deferred debits and other assets ($38 and $32 related to VIEs)								3,913			3,985
Total assets	$	14,283		$	14,963		$	14,440		$	14,301

(millions)	June 30, 2019			December 31, 2018			June 30, 2020			December 31, 2019
CAPITALIZATION AND LIABILITIES
Common Stock - no par value, 40.3 million shares outstanding	$	3,635		$	2,860		$	3,695		$	3,695
Retained earnings		72			1,279			177			20
Accumulated other comprehensive loss		(4	)		(3	)		(3	)		(3	)
Total common equity		3,703			4,136			3,869			3,712
Noncontrolling interest		173			179			183			180
Total equity		3,876			4,315			4,052			3,892
Long-term debt, net								3,359			3,358
Affiliated long-term debt		230			—			230			230
Long-term debt, net		3,934			5,132
Finance leases								18			20
Total long-term debt		4,164			5,132			3,607			3,608
Total capitalization		8,040			9,447			7,659			7,500
Current Liabilities:
Short-term borrowings		—			73
Current portion of long-term debt		7			14
Securities due within one year								7			7
Accounts payable		150			267			136			245
Affiliated and related party payables		368			347			769			624
Customer deposits and customer prepayments		75			73			71			76
Revenue subject to refund		14			77
Taxes accrued		163			228			121			218
Interest accrued		62			72			92			88
Regulatory liabilities		269			126			287			256
Reserves for litigation and regulatory proceedings		278			11			473			492
Other		62			42			42			60
Total current liabilities		1,448			1,330			1,998			2,066
Deferred Credits and Other Liabilities:
Deferred income taxes, net		555			989
Deferred income taxes and investment tax credits								690			629
Asset retirement obligations		498			542			587			489
Pension and other postretirement benefits		223			232			200			203
Regulatory liabilities		3,277			2,264			3,098			3,210
Affiliated liabilities								14			15
Other		227			143			194			189
Other affiliate		15			16
Total deferred credits and other liabilities		4,795			4,186			4,783			4,735
Commitments and Contingencies (see Note 11)
Commitments and Contingencies (see Note 12)
Total capitalization and liabilities	$	14,283		$	14,963		$	14,440		$	14,301

	Three Months Ended June 30,					Six Months Ended June 30,					Three Months Ended June 30,						Six Months Ended June 30,
(millions)	2019			2018		2019			2018		2020			2019			2020		2019
Operating Revenues:
Electric⁽¹⁾	$	621		$	553	$	141		$	1,100
Gas		77			79		222			234
Total operating revenues		698			632		363			1,334
Operating Revenue⁽¹⁾											$	624		$	698		$	1,296	$	363
Operating Expenses:
Fuel used in electric generation⁽¹⁾		143			155		280			315		95			143			199		280
Purchased power⁽¹⁾		12			15		20			67		25			12			38		20
Gas purchased for resale⁽¹⁾		44			45		121			121		34			44			91		121
Other operations and maintenance		123			113		219			215		93			123			183		219
Other operations and maintenance - affiliated suppliers		72			51		120			95		50			72			105		120
Impairment of assets and other charges		100			—		371			4		—			100			2		371
Depreciation and amortization		115			81		217			161		118			115			236		217
Other taxes⁽¹⁾		72			65		141			129		65			72			127		141
Total operating expenses		681			525		1,489			1,107		480			681			981		1,489
Operating income (loss)		17			107		(1,126	)		227		144			17			315		(1,126	)
Other income (expense), net		(9	)		2		(14	)		125		2			(9	)		5		(14	)
Interest charges, net of allowance for borrowed funds used during construction of $2, $3, $2 and $5⁽¹⁾		63			76		136			152
Interest charges, net of allowance for borrowed funds used during construction of $1, $2, $3 and $2⁽¹⁾												58			63			116		136
Income (loss) before income tax expense (benefit)		(55	)		33		(1,276	)		200		88			(55	)		204		(1,276	)
Income tax expense (benefit)		15			2		(103	)		41		21			15			44		(103	)
Net Income (Loss) and Other Comprehensive Income (Loss)		(70	)		31		(1,173	)		159		67			(70	)		160		(1,173	)
Comprehensive Income Attributable to Noncontrolling Interest		8			5		14			9
Comprehensive Income (Loss) Attributable to Noncontrolling Interest												(2	)		8			3		14
Comprehensive Income (Loss) Available (Attributable) to Common Shareholder	$	(78	)	$	26	$	(1,187	)	$	150	$	69		$	(78	)	$	157	$	(1,187	)

	Six Months Ended June 30,						Six Months Ended June 30,
(millions)	2019			2018			2020			2019
Operating Activities
Net income (loss)	$	(1,173	)	$	159		$	160		$	(1,173	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Impairment of assets and other charges		371			4			2			371
Provision for refunds to customers		950			—			—			950
Deferred income taxes, net		(434	)		58			61			(434	)
Depreciation and amortization		223			165			236			223
Amortization of nuclear fuel		27			27			21			27
Other adjustments		(4	)		(7	)		7			(4	)
Changes in certain assets and liabilities:
Receivables								(23	)		—
Receivables - affiliated and related party		(3	)		(12	)		5			(3	)
Income tax receivable		—			(8	)
Inventories		(48	)		(11	)		(3	)		(48	)
Prepayments		(29	)		(34	)		(30	)		(29	)
Pension and other postretirement benefits								(3	)		—
Regulatory assets		187			(9	)		3			187
Regulatory liabilities		195			(107	)		(111	)		195
Accounts payable		(72	)		(19	)		(35	)		(72	)
Accounts payable - affiliated and related party		17			8			4			17
Revenue subject to refund		(63	)		156			—			(63	)
Taxes accrued		(65	)		(93	)		(97	)		(65	)
Other assets		(138	)		(131	)
Other liabilities		59			55
Interest accrued								3			—
Other assets and liabilities								(12	)		(79	)
Net cash provided by operating activities		—			201			188			—
Investing Activities
Property additions and construction expenditures		(226	)		(464	)		(330	)		(226	)
Proceeds from investments and sales of assets		12			31			5			12
Purchase of investments		(23	)		(17	)		(5	)		(23	)
Purchase of investments - affiliate		—			(113	)
Proceeds from interest rate derivative contract settlement		—			115
Investment in affiliate, net		343			(75	)
Purchase of investments - affiliated								(1	)		—
Short-term investments - affiliated								9			343
Net cash provided by (used in) investing activities		106			(523	)		(322	)		106
Financing Activities
Proceeds from issuance of debt		—			100
Proceeds from issuance of affiliated debt		230			—			—			230
Repayment of long-term debt, including redemption premiums		(1,247	)		(170	)		—			(1,247	)
Dividend to parent		(30	)		(156	)		—			(30	)
Contribution from parent		775			20			—			775
Contribution returned to parent		(20	)		—			—			(20	)
Money pool borrowings, net		4			150			—			4
Short-term borrowings, net		(73	)		205			—			(73	)
Short-term borrowings - affiliated, net								141			—
Other								(4	)		—
Net cash provided by (used in) financing activities		(361	)		149			137			(361	)
Net decrease in cash, restricted cash and equivalents		(255	)		(173	)
Cash, restricted cash and equivalents at beginning of period		377			395
Cash, restricted cash and equivalents at end of period	$	122		$	222
Net increase (decrease) in cash, restricted cash and equivalents								3			(255	)
Cash, restricted cash and equivalents at beginning of period⁽¹⁾								4			377
Cash, restricted cash and equivalents at end of period⁽¹⁾							$	7		$	122
Supplemental Cash Flow Information
Noncash investing and financing activities:⁽¹⁾
Significant noncash investing and financing activities:
Accrued construction expenditures	$	39		$	19		$	41		$	39
Leases⁽²⁾		5			—			2			5

~~(2) Includes $3 million of financing leases and $2 million of operating leases.~~

	Common Stock																Common Stock
(millions)	Shares		Amount		Retained Earnings			AOCI			Noncontrolling Interest			Total Equity			Shares		Amount		Retained Earnings			AOCI			Noncontrolling Interest			Total Equity
March 31, 2018		40	$	2,860	$	2,034		$	(4	)	$	144		$	5,034
Total comprehensive income available to common shareholder						26						5			31
Capital contribution from parent												20			20
June 30, 2018		40	$	2,860	$	2,060		$	(4	)	$	169		$	5,085

March 31, 2019		40	$	3,535	$	151		$	(4	)	$	185		$	3,867			40	$	3,535	$	151		$	(4	)	$	185		$	3,867
Total comprehensive income (loss) available (attributable) to common shareholder						(78	)					8			(70	)						(78	)					8			(70	)
Capital contribution from parent				100											100				100												100
Capital contribution returned to parent												(20	)		(20	)												(20	)		(20	)
Other						(1	)								(1	)						(1	)								(1	)
June 30, 2019		40	$	3,635	$	72		$	(4	)	$	173		$	3,876			40	$	3,635	$	72		$	(4	)	$	173		$	3,876

March 31, 2020																		40	$	3,695	$	108		$	(3	)	$	185		$	3,985
Total comprehensive income (loss) available (attributable) to common shareholder																						69						(2	)		67
June 30, 2020																		40	$	3,695	$	177		$	(3	)	$	183		$	4,052

	Common Stock																Common Stock
(millions)	Shares		Amount		Retained Earnings			AOCI			Noncontrolling Interest			Total Equity			Shares		Amount		Retained Earnings			AOCI			Noncontrolling Interest			Total Equity
December 31, 2017		40	$	2,860	$	1,982		$	(4	)	$	142		$	4,980
Total comprehensive income available to common shareholder						150						9			159
Capital contribution from parent												20			20
Dividend to parent						(72	)					(2	)		(74	)
June 30, 2018		40	$	2,860	$	2,060		$	(4	)	$	169		$	5,085

December 31, 2018		40	$	2,860	$	1,279		$	(3	)	$	179		$	4,315			40	$	2,860	$	1,279		$	(3	)	$	179		$	4,315
Cumulative-effect of change in accounting principle						1			(1	)					—							1			(1	)					—
Total comprehensive income (loss) available (attributable) to common shareholder						(1,187	)					14			(1,173	)						(1,187	)					14			(1,173	)
Capital contribution from parent				775											775				775												775
Capital contribution returned to parent												(20	)		(20	)												(20	)		(20	)
Dividend to parent						(20	)								(20	)						(20	)								(20	)
Other						(1	)								(1	)						(1	)								(1	)
June 30, 2019		40	$	3,635	$	72		$	(4	)	$	173		$	3,876			40	$	3,635	$	72		$	(4	)	$	173		$	3,876

December 31, 2019																		40	$	3,695	$	20		$	(3	)	$	180		$	3,892
Total comprehensive income available to common shareholder																						157						3			160
June 30, 2020																		40	$	3,695	$	177		$	(3	)	$	183		$	4,052

The following notes should be read in conjunction with the Notes to Consolidated Financial Statements appearing in DESC's Annual Report on Form 10-K for the year ended December 31, 2018. DESC filed such annual report on a combined basis with SCANA. Accordingly, the information presented in such notes is presented on a combined basis and therefore some of the information may apply only to SCANA and not DESC. DESC makes no representation as to any such information.2019.

These are interim financial statements and, due to the seasonality of DESC's business and matters that may occur during the rest of the year, the amounts reported in the Consolidated Statements of Comprehensive Income (Loss) are not necessarily indicative of amounts expected for the full year. In the opinion of management, the information furnished herein reflects all adjustments which are necessary for a fair statement of the results for the interim periods reported, and such adjustments are of a normal recurring nature. In addition, the preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amount of revenues and expenses during the reporting period. Actual results could differ from those estimates.

Certain amounts in DESC's ~~2018~~2019 Consolidated Financial Statements and Notes have been reclassified to conform to the ~~2019~~2020 presentation for comparative purposes; however, such reclassifications did not affect DESC's net income (loss) and other comprehensive income (loss), total assets, liabilities, equity or cash flows.

DESC is a wholly-owned subsidiary of SCANA, which ~~effective January 2019,~~ is a wholly-owned subsidiary of Dominion Energy.

DESC has determined that it has a controlling financial interest in each of GENCO and Fuel Company (which are considered to be VIEs) and, accordingly, DESC's Consolidated Financial Statements include, after eliminating intercompany balances and transactions, the accounts of DESC, GENCO and Fuel Company. ~~The equity interests~~See Note 1 to the Consolidated Financial Statements included in DESC’s Annual Report on Form 10-K for the year ended December 31, 2019 for a description of GENCO and Fuel Company are held solely by SCANA, DESC’s parent. As a result, GENCO and Fuel Company’s equity and results of operations are reflected as noncontrolling interest in the Consolidated Financial Statements.

GENCO owns a coal-fired electric generating station with a 605 MW net generating capacity (summer rating). GENCO’s electricity is sold, pursuant to a FERC-approved tariff, solely to DESC under the terms of a power purchase agreement and related operating agreement. The effects of these transactions are eliminated in consolidation. GENCO’s property (carrying value of $497 million) previously served as collateral for its long-term borrowings. In May 2019, GENCO redeemed its 5.49% senior secured notes and was able to release the first mortgage lien in June 2019 that had previously secured these notes. Fuel Company acquires, owns and provides financing for DESC’s nuclear fuel, certain fossil fuels and emission and other environmental allowances. See also Note 5.Company.

Additionally, DESC purchases shared services from DESS, an affiliated VIE that provides accounting, legal, finance and certain administrative and technical services to all SCANA subsidiaries, including DESC. DESC has determined that it is not the primary beneficiary of DESS as it does not have either the power to direct the activities that most significantly impact its economic performance or an obligation to absorb losses and benefits which could be significant to it. See Note 14 for amounts attributable to affiliates.

There have been no significant changes from Note 12 to the Consolidated Financial Statements in DESC's Annual Report on Form 10-K for the year ended December 31, ~~2018, with the exception of the item described below.~~

DESC leases certain assets including vehicles, real estate, office equipment and other assets under both operating and finance leases. For operating leases, rent expense is recognized on a straight-line basis over the term of the lease agreement, subject to regulatory framework. Rent expense associated with operating leases, short-term leases and variable leases is primarily recorded in other operations and maintenance expense in the Consolidated Statements of Comprehensive Income (Loss). Rent expense associated with finance leases results in the separate presentation of interest expense on the lease liability and amortization expense of the related right-of-use asset in the Consolidated Statements of Comprehensive Income (Loss). Amortization expense and interest charges associated with finance leases are recorded in depreciation and amortization and interest charges, respectively, in the Consolidated Statements of Comprehensive Income (Loss) or deferred within regulatory assets in the Consolidated Balance Sheets.

Certain leases include one or more options to renew, with renewal terms that can extend the lease from one to 70 years. The exercise of renewal options is solely at DESC's discretion and is included in the lease term if the option is reasonably certain to be exercised. A right-of-use asset and corresponding lease liability for leases with original lease terms of one year or less are not included in the Consolidated Balance Sheets, unless such leases contain renewal options that DESC is reasonably certain will be exercised.

The determination of the discount rate utilized has a significant impact on the calculation of the present value of the lease liability included in the Consolidated Balance Sheets. For DESC’s leased assets, the discount rate implicit in the lease is generally unable to be determined from a lessee perspective. As such, DESC uses internally-developed incremental borrowing rates as a discount rate in the calculation of the present value of the lease liability. The incremental borrowing rates are determined based on an analysis of DESC's publicly available secured borrowing rates over various lengths of time that most closely corresponds to DESC's lease maturities.

In February 2016, the Financial Accounting Standards Board issued revised accounting guidance for the recognition, measurement, presentation and disclosure of leasing arrangements. The update requires that a liability and corresponding right-of-use asset are recorded on the balance sheet for all leases, including those leases classified as operating leases, while also refining the definition of a lease. In addition, lessees will be required to disclose key information about the amount, timing, and uncertainty of cash flows arising from leasing arrangements. Lessor accounting remains largely unchanged.

~~The guidance became effective for DESC's interim and annual reporting periods beginning January 1,~~ 2019. DESC adopted this revised accounting guidance using a modified retrospective approach, which requires lessees and lessors to recognize and measure leases at the date of adoption. Under this approach, DESC utilized the transition practical expedient to maintain historical presentation for periods before January 1, 2019. DESC also applied the other practical expedients, which required no reassessment of whether existing contracts are or contain leases, no reassessment of lease classification for existing leases and no evaluation of existing or expired land easements that were not previously accounted for as leases. In connection with the adoption of this revised accounting guidance, DESC recorded $19 million of offsetting right-of-use assets and liabilities for operating leases in effect at the adoption date. See Note 12 for additional information.

As a result of issues generated in the ordinary course of business, DESC is involved in various regulatory matters. Certain regulatory matters may ultimately result in a loss; however, as such matters are in an initial procedural phase, involve uncertainty as to the outcome of pending reviews or orders, and/or involve significant factual issues that need to be resolved, it is not possible for DESC to estimate a range of possible loss. For regulatory matters that DESC cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the regulatory process such that DESC is able to estimate a range of possible loss. For regulatory matters that DESC is able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any estimated range is based on currently available information, involves elements of judgment and significant uncertainties and may not represent DESC’s maximum possible loss exposure. The circumstances of such regulatory matters will change from time to time and actual results may vary significantly from the current estimate. For current matters not specifically reported below, management does not anticipate that the outcome from such matters would have a material effect on DESC’s financial position, liquidity or results of operations.

In June 2019, DESC submitted the 2015 Task Order as a stand-alone rate schedule, which governs DESC’s provision of retail service to the DOE at the Savannah River Site. The 2015 Task Order also includes provisions that govern the operations and maintenance of certain transmission facilities, which DESC has determined to be services that are likely subject to FERC’s jurisdiction. DESC requested that the FERC accept the 2015 Task Order for filing to become effective in August 2019 and accept the refund analysis included in the filing. At June 30, 2019, DESC’s Consolidated Balance Sheets include reserves of $10 million included within revenue subject to refund for the potential refund of amounts collected under the 2015 Task Order as well as under two prior task orders commencing in 1995 and each covering ten-year periods. During the second quarter of 2019, DESC recorded a $6 million ($4 million after-tax) charge primarily within interest charges in DESC’s Consolidated Statements of Comprehensive Income (Loss). This matter is pending.

In July 2018, the South Carolina Commission issued orders implementing a legislatively-mandated temporary reduction in revenues that could be collected by DESC from customers under the BLRA. These orders reduced the portion of DESC’s retail electric rates associated with the NND Project from approximately 18% of the average residential electric customer's bill to approximately 3%, which equates to a reduction in revenues of approximately $31 million per month, retroactive to April 1, 2018. As a result, in the

In January 2020, GENCO filed to modify its formula rate to incorporate a mechanism to decrease or increase its income tax allowances by any excess deferred income taxes resulting from the 2017 Tax Reform Act, and future changes in tax laws. These modifications are expected to decrease charges to DESC ~~recorded a charge of $109 million ($~~82 ~~million after-tax)~~for the power it purchases from GENCO. In April 2020, the FERC approved GENCO’s request. There have been no other changes to ~~operating revenues~~the 2017 Tax Reform Act matters discussed in Note 3 to the Consolidated Financial Statements in DESC’s ~~Consolidated Statements of Comprehensive Income (Loss). The temporary rate reduction remained in effect until February 2019 when rates pursuant to~~Annual Report on Form 10-K for the ~~SCANA Merger Approval Order became effective.~~

Other than the following ~~matter,~~matters, there have been no significant developments regarding the pending regulatory matters disclosed in Note 23 to the Consolidated Financial Statements in DESC's Annual Report on Form 10-K for the year ended December 31, ~~2018 or Note 2 to the Consolidated Financial Statements in DESC’s Quarterly Report on Form 10-Q for the quarter ended March 31,~~ 2019.

Pursuant to the SCANA Merger Approval Order, DESC will not file an application for a general rate case with the South Carolina Commission with a requested effective date for new rates earlier than January 2021. In April 2020, the South Carolina Commission issued an order vacating the portion of the SCANA Merger Approval Order requiring that new retail electric rates be implemented by January 1, 2021. In July 2020, DESC filed a notice of intent with the South Carolina Commission to file for an increase to base rates for retail electric service no earlier than 30 days following the notice. The net lost revenue recovery portion of the DSM rider would be adjusted lower simultaneously with any approved retail electric base rate increases.

In February 2020, DESC filed with the South Carolina Commission a proposal to decrease the total fuel cost component of retail electric rates. DESC’s proposed decrease would reduce annual base fuel component recoveries by $44 million and is projected to return to customers the existing over-collected balance while recovering DESC’s current base fuel costs over the 12-month period beginning with the first billing cycle of May 2020. In addition, DESC proposed an increase to its variable environmental and distributed energy resource components. In April 2020, the South Carolina Commission approved the filing.

In 2020, DESC began several electric transmission projects in connection with 2 new nuclear plants under development by Southern. These transmission projects are required to be in place prior to these plants beginning operations to maintain reliability. DESC anticipates the projects to go into service in phases, costing approximately $75 million in aggregate. In February 2020, DESC filed an application with the South Carolina Commission requesting approval to construct and operate 28 miles of 230 kV transmission lines in Aiken County, South Carolina estimated to cost approximately $30 million. In June 2020, the South Carolina Commission approved the filing.

DESC has approval for a DSM rider through which it recovers expenditures related to its DSM programs. In January 2020, DESC submitted its annual DSM programs filing to the South Carolina Commission seeking approval to recover $40 million of costs and net lost revenues associated with DSM programs, along with an incentive to invest in such programs. In April 2020, the South Carolina Commission approved the filing.

DESC utilizes a pension costs rider approved by the South Carolina Commission which is designed to allow recovery of projected pension costs, including under-collected balances or net of over-collected balances, as applicable. The rider is typically reviewed for adjustment every 12 months with any resulting increase or decrease going into effect beginning with the first billing cycle in May. In February 2020, DESC requested that the South Carolina Commission approve an adjustment to this rider to decrease annual revenue by $11 million. In April 2020, the South Carolina Commission approved the filing.

In June ~~2019,~~2020, DESC filed with the South Carolina Commission its monitoring report for the 12-month period ended March 31, ~~2019~~2020 with a total revenue requirement of ~~$437~~$409 million. This represents a $7$9 million overall annual increase to its natural gas rates under the terms of the Natural Gas Rate Stabilization Act effective ~~for~~with the ~~rate year beginning~~first billing cycle of November ~~2019.~~2020. This matter is pending.

Rate-regulated utilities recognize in their financial statements certain revenues and expenses in different periods than do other enterprises. As a result, DESC has recorded regulatory assets and regulatory liabilities which are summarized in the following ~~tables.~~table. Except for NND Project costs and certain other unrecovered plant costs, substantially all regulatory assets are either explicitly excluded from rate base or are effectively excluded from rate base due to their being offset by related liabilities.

June 30,

December 31,

(millions)

2019

2018

Regulatory assets:

NND Project costs

$
138

$
127

Deferred employee benefit plan costs

16

16

Other unrecovered plant

14

14

DSM programs

16

14

Other

75

52

Regulatory assets - current

259

223

NND Project costs

2,572

2,641

AROs

324

380

Deferred employee benefit plan costs

230

256

Deferred losses on interest rate derivatives

308

442

Other unrecovered plant

73

79

DSM programs

53

51

Environmental remediation costs

21

24

Deferred storm damage costs

34

35

Deferred transmission operating costs

27

15

Other

117

123

Regulatory assets - noncurrent

3,759

4,046

Total regulatory assets

$
4,018

$
4,269

Regulatory liabilities:

Monetization of guaranty settlement

$
67

$
61

Income taxes refundable through future rates

48

52

Reserve for refunds to electric utility customers

136

—

Other

18

13

Regulatory liabilities - current

269

126

Monetization of guaranty settlement

1,003

1,037

Income taxes refundable through future rates

826

607

Asset removal costs

552

541

Deferred gains on interest rate derivatives

77

75

Reserve for refunds to electric utility customers

813

—

Other

6

4

Regulatory liabilities - noncurrent

3,277

2,264

Total regulatory liabilities

$
3,546

$
2,390

	June 30,		December 31,
(millions)	2020		2019
Regulatory assets:
NND Project costs⁽¹⁾	$	138	$	138
Deferred employee benefit plan costs⁽²⁾		10		13
Other unrecovered plant⁽³⁾		14		14
DSM programs⁽⁴⁾		17		17
AROs⁽⁵⁾		27		28
Cost of fuel under-collections⁽⁶⁾		11		13
Other		44		48
Regulatory assets - current		261		271
NND Project costs⁽¹⁾		2,434		2,503
AROs⁽⁵⁾		289		293
Cost of reacquired debt⁽⁷⁾		251		259
Deferred employee benefit plan costs⁽²⁾		194		196
Deferred losses on interest rate derivatives⁽⁸⁾		315		305
Other unrecovered plant⁽³⁾		64		69
DSM programs⁽⁴⁾		57		54
Environmental remediation costs⁽⁹⁾		21		22
Deferred storm damage costs⁽¹⁰⁾		44		44
Deferred transmission operating costs⁽¹¹⁾		49		37
Other⁽¹²⁾		103		110
Regulatory assets - noncurrent		3,821		3,892
Total regulatory assets	$	4,082	$	4,163
Regulatory liabilities:
Monetization of guaranty settlement⁽¹³⁾	$	67	$	67
Income taxes refundable through future rates⁽¹⁴⁾		23		16
Reserve for refunds to electric utility customers⁽¹⁵⁾		134		143
Cost of fuel over-collections⁽⁶⁾		55		12
Other		8		18
Regulatory liabilities - current		287		256
Monetization of guaranty settlement⁽¹³⁾		936		970
Income taxes refundable through future rates⁽¹⁴⁾		929		948
Asset removal costs⁽¹⁶⁾		565		552
Deferred gains on interest rate derivatives⁽⁸⁾		70		71
Reserve for refunds to electric utility customers⁽¹⁵⁾		588		656
Other		10		13
Regulatory liabilities - noncurrent		3,098		3,210
Total regulatory liabilities	$	3,385	$	3,466

Regulatory assets have been recorded based on the probability of their recovery. All regulatory assets represent incurred costs that may be deferred under GAAP for regulated operations. The South Carolina Commission or the FERC has reviewed and approved through specific orders certain of the items shown as regulatory assets. In addition, regulatory assets include, but are not limited to, certain costs which have not been specifically approved for recovery by one of these regulatory agencies, including deferred transmission operating costs that are the subject of regulatory proceedings discussed in Note ~~11.~~12. While such costs are not currently being recovered, management believes they would be allowable under existing rate-making concepts embodied in rate orders or applicable state law and expects to recover these costs through rates in future periods. In the future, as a result of deregulation, changes in state law, other changes in the regulatory environment or changes in accounting requirements or other adverse legislative or regulatory developments, DESC could be required to write off all or a portion of its regulatory assets and liabilities. Such an event could have a material effect on DESC's financial statements in the period the write-off would be recorded.

NND Project costs reflects expenditures associated with the NND Project, which pursuant to the SCANA Merger Approval Order, will be recovered from electric service customers over a 20-year period ending in 2039. See Note 11 for more information.

AROs represent deferred depreciation and accretion expense related to legal obligations associated with the future retirement of generation, transmission and distribution properties. The AROs primarily relate to DESC’s electric generating facilities, including Summer, and are expected to be recovered over the related property lives and periods of decommissioning which may range up to approximately 106 years.

Employee benefit plan costs have historically been recovered as they have been recorded under GAAP. Deferred employee benefit plan costs represent amounts of pension and other postretirement benefit costs which were accrued as liabilities and treated as regulatory assets pursuant to FERC guidance, and costs deferred pursuant to specific South Carolina Commission regulatory orders. DESC expects to recover deferred pension costs through utility rates over periods through 2044. DESC expects to recover other deferred benefit costs through utility rates, primarily over average service periods of participating employees up to 11 years.

Deferred losses or gains on interest rate derivatives represent (i) the changes in fair value and payments made or received upon settlement of certain interest rate derivatives designated as cash flow hedges and (ii) the changes in fair value and payments made or received upon settlement of certain other interest rate derivatives not so designated. The amounts recorded with respect to (i) are expected to be amortized to interest expense over the lives of the underlying debt through 2043. The amounts recorded with respect to (ii) are expected to be similarly amortized to interest expense through 2065.

Other unrecovered plant represents the carrying value of coal-fired generating units, including related materials and supplies inventory, retired from service prior to being fully depreciated. DESC is amortizing these amounts through cost of service rates over the units' previous estimated remaining useful lives through 2025. Unamortized amounts are included in rate base and are earning a current return.

~~DSM programs represent deferred costs associated with electric demand reduction programs, and such deferred costs are currently being recovered over five years through an approved rate rider.~~

Environmental remediation costs are associated with the assessment and clean-up of sites currently or formerly owned by DESC. Such remediation costs are expected to be recovered over periods of up to 16 years. See also Note 11.

~~Deferred storm damage costs represent storm restoration costs for which DESC expects to receive future recovery through customer rates.~~

Deferred transmission operating costs includes deferred depreciation and property taxes associated with certain transmission assets for which DESC expects recovery from customers through future rates. See also Note 11.

~~Various other regulatory assets are expected to be recovered through rates over varying periods through 2047.~~

Monetization of guaranty settlement represents proceeds related to the monetization of the Toshiba Settlement. In accordance with the SCANA Merger Approval Order, this balance, net of amounts that may be required to satisfy certain liens, will be refunded to electric customers over a 20-year period ending in 2039. See Note 11.

Income taxes refundable through future rates includes (i) excess deferred income taxes arising from the remeasurement of deferred income taxes in connection with the enactment of the 2017 Tax Reform Act (certain of which are protected under normalization rules and will be amortized over the remaining lives of related property, and certain of which will be amortized to the benefit of customers over prescribed periods as instructed by regulators) and (ii) deferred income taxes arising from investment tax credits, offset by (iii) deferred income taxes that arise from utility operations that have not been included in customer rates (a portion of which relate to depreciation and are expected to be recovered over the remaining lives of the related property which may range up to 85 years). See also Note 6.

Reserve for refunds to electric utility customers reflects amounts previously collected from retail electric customers of DESC for the NND Project to be credited to customers over an estimated 11-year period in connection with the SCANA Merger Approval Order. See Note 11.

~~Asset removal costs represent estimated net collections through depreciation rates of amounts to be expended for the removal of assets in the future.~~

	Three Months Ended					Three Months Ended				Six Months Ended				Six Months Ended				Three Months Ended				Three Months Ended					Six Months Ended				Six Months Ended
	June 30, 2019					June 30, 2018				June 30, 2019				June 30, 2018				June 30, 2020				June 30, 2019					June 30, 2020				June 30, 2019
(millions)	Electric			Gas		Electric		Gas		Electric		Gas		Electric		Gas		Electric		Gas		Electric			Gas		Electric		Gas		Electric		Gas
Customer class:
Residential	$	281		$	31	$	243	$	34	$	10	$	109	$	495	$	120	$	261	$	33	$	281		$	31	$	513	$	112	$	10	$	109
Commercial		206			23		171		22		67		61		340		61		177		20		206			23		352		53		67		61
Industrial		100			19		106		21		18		45		191		45		83		12		100			19		163		29		18		45
Other		35			4		30		2		45		7		68		7		27		4		35			4		57		8		45		7
Revenues from contracts with customers		622			77		550		79		140		222		1,094		233		548		69		622			77		1,085		202		140		222
Other revenues		(1	)		—		3		—		1		—		6		1		7		—		(1	)		—		9		—		1		—
Total Operating Revenues	$	621		$	77	$	553	$	79	$	141	$	222	$	1,100	$	234	$	555	$	69	$	621		$	77	$	1,094	$	202	$	141	$	222

Contract liabilities represent the obligation to transfer goods or services to a customer for which consideration has already been received from the customer. DESC had contract liability balances of $5 million and $4$9 million at June 30, ~~2019~~2020 and December 31, ~~2018,~~2019, respectively. During the six months ended June 30, 2020 and 2019, DESC recognized revenue of $5 million and $3 million, respectively, from the beginning contract liability balances as DESC fulfilled its obligations to provide service to its customers. Contract liabilities are recorded in customer deposits and customer prepayments in the Consolidated Balance Sheets.

For all periods presented, DESC's authorized shares of common stock, no par value, were 50 million, of which 40.3 million were issued and outstanding, and DESC's authorized shares of preferred stock, no par value, were 20 million, of which 1,000 shares were issued and outstanding. All outstanding shares of common and preferred stock are held by SCANA.

~~In February~~During the three and six months ended June 30, 2019, DESC received an equity ~~contribution~~contributions of ~~$675~~$100 million and $775 million, respectively, from its parent that was funded by Dominion Energy. DESC used these funds to redeem long-term ~~debt. See Note 5.~~

~~In June 2019, DESC received an equity contribution of $100 million from its parent that was funded by Dominion Energy. DESC used these funds~~debt and to repay intercompany credit agreement borrowings from Dominion Energy.

See Note 6 to the Consolidated Financial Statements in DESC’s ~~bond indenture under which it issues first mortgage bonds contains provisions that could limit the payment of cash dividends~~Annual Report on its common stock. DESC's bond indenture permits the payment of dividends on DESC's common stock only either (1) out of its Surplus (as defined in the bond indenture) or (2) in case there is no Surplus, out of its net profitsForm 10-K for the ~~fiscal~~ year ~~in which the dividend is declared and/or the preceding fiscal year. In addition, the Federal Power Act requires the appropriation of a portion of certain earnings from hydroelectric projects.~~ ended December 31, 2019.

At June 30, 2019 and December 31, 2018, retained earnings of $126 million and $115 million, respectively, were restricted by this requirement as to payment of cash dividends on DESC’s common stock. In addition, pursuant to the SCANA Merger Approval Order, the amount of any DESC dividends paid must be reasonable and consistent with the long-term payout ratio of the electric utility industry and gas distribution industry.

~~At June 30, 2019,~~2020, DESC’s retained earnings ~~are below~~exceed the balance established by the Federal Power Act as a reserve on earnings attributable to hydroelectric generation plants. As a result, DESC is ~~prohibited from the payment of~~permitted to pay dividends without additional regulatory approval ~~until~~provided that such amounts would not bring the ~~balance of its~~ retained earnings ~~increases.~~balance below the threshold. There have been no other significant changes to dividend restrictions affecting DESC described in Note 45 to the Consolidated Financial Statements in DESC’s Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

In February 2019, DESC launched tender offers for certain of its first mortgage bonds pursuant to which it purchased first mortgage bonds having an aggregate purchase price equal to $1.2 billion. DESC incurred a loss on reacquired debt of $187 million in connection with these tender offers, which is recorded in other deferred debits on the Consolidated Balance Sheets.

In May 2019, GENCO issued a $230 million 3.05% promissory note due to Dominion Energy that matures in May 2024. The issuance by GENCO was approved by the South Carolina Commission. Proceeds from the issuance were used to redeem GENCO’s 5.49% senior secured notes due in 2024 at the remaining principal outstanding of $33 million plus accrued interest, repay money pool borrowings and to return $20 million of contributed equity capital to SCANA.

~~In March 2019, DESC became a co-borrower under Dominion Energy's $6 billion joint revolving credit facility.~~ DESC's short-term financing is supported through its access as co-borrower to ~~this~~Dominion Energy’s $6.0 billion joint revolving credit facility, which can be used for working capital, as support for the combined commercial paper programs of DESC, Dominion Energy, Virginia Power, Dominion Energy Gas and ~~certain other of its subsidiaries (co-borrowers),~~Questar Gas, and for other general corporate purposes.

At June 30, 2020, DESC's share of commercial paper and letters of credit outstanding under its joint credit facility with Dominion Energy, ~~were~~was as follows:

A maximum of $1.0 billion of the facility is available to DESC, less any amounts outstanding to co-borrowers. A sub-limit for DESC is set within the facility limit but can be changed at the option of the co-borrowers multiple times per year. At June 30, 2019, the sub-limit for DESC was $500 million. If DESC has liquidity needs in excess of its sub-limit, the sub-limit may be changed or such needs may be satisfied through short-term borrowings from DESC's parent or from Dominion Energy. This credit facility matures in March 2023 and can be used to support bank borrowings and the issuance of commercial paper, as well as to support up to $1.0 billion (or the sub-limit, whichever is less) of letters of credit.

Also in March 2019, DESC canceled its previous committed long-term facility which was a revolving line of credit under a credit agreement with a syndicate of banks. This previous credit agreement was used for general corporate purposes, including liquidity support for DESC's commercial paper program and working capital needs, and was set to expire in December 2020.

(millions)

Facility Limit⁽¹⁾

Outstanding

Commercial Paper

Outstanding

Letters of Credit

Facility Limit

Outstanding

Commercial Paper

Outstanding

Letters of Credit

At December 31, 2018

1,200

—

Joint revolving credit facility⁽¹⁾

1,000

—

~~The weighted-average interest rate of the outstanding commercial paper supported by this credit facility was 3.82% at December 31, 2018.~~

In ~~April 2019,~~January 2020, DESC ~~renewed its~~and GENCO applied to FERC for a two-year short-term borrowing authorization. In March 2020, FERC granted DESC authority through March 2021 to issue short-term indebtedness (pursuant to Section 204 of the Federal Power Act)~~. DESC may issue unsecured promissory notes, commercial paper and direct loans~~ in amounts not to exceed $2.2 billion outstanding with maturity dates of one year or less. In addition, in ~~April 2019,~~March 2020, FERC granted GENCO ~~renewed its FERC~~ authority through March 2021 to issue short-term indebtedness not to exceed $200 million outstanding with maturity dates of one year or less. The authorities described herein will expire in April 2020, which reflects a one-year authorization period rather than the two-year period DESC and GENCO had requested. In granting the authorization for a shorter period, FERC cited certain regulatory and legislative proceedings at the state level, as well as certain legal proceedings, arising from the NND Project that could affect DESC's and GENCO's circumstances. Were adverse developments to occur with respect to these uncertainties, the ability of DESC or GENCO to secure renewal of this short-term borrowing authority may be adversely impacted.

DESC is obligated with respect to an aggregate of $68 million of industrial revenue bonds which are secured by letters of ~~credit issued by TD Bank N.A.~~credit. These letters of credit expire, subject to renewal, in the fourth quarter of ~~2019.~~2020.

DESC received FERC approval to enter into an inter-company credit agreement in April 2019 with Dominion Energy under which DESC may have short-term borrowings outstanding up to $900 million. At June 30, 2020 and December 31, 2019, DESC had borrowings outstanding under this credit agreement totaling ~~$61~~$480 million and $355 million, respectively, which are recorded in affiliated and related party payables in DESC’s Consolidated Balance Sheets. For the three and six months ended June 30, 2020, DESC recorded interest charges of $3 million and $5 million, respectively. For the three and six months ended June 30, 2019, DESC recorded interest charges of less than $1 million.

DESC participated in a utility money pool with SCANA and another regulated subsidiary of SCANA through April 2019. Fuel Company and GENCO ~~remained~~remain in the utility money pool. Money pool borrowings and investments bear interest at short-term market rates. For the three and six months ended June 30, 2020, DESC recorded interest income from money pool transactions of $1 million and $2 million, respectively, and for the same period DESC recorded interest expense from money pool transactions of $1 million and $2 million, respectively. For the three and six months ended June 30, 2019, DESC recorded interest income from money pool transactions of $3 million and $6 million, respectively, and for the same ~~periods~~period DESC recorded interest expense from money pool transactions of $3 million and $6 million, respectively. ~~Interest income and interest expense for the corresponding periods in 2018 were not significant. DESC~~Fuel Company had outstanding money pool borrowings due to an affiliate of ~~$224~~$233 million and GENCO had investments due from an affiliate of $9$2 million at June 30, ~~2019.~~2020. At December 31, ~~2018, DESC~~2019, Fuel Company had outstanding money pool borrowings due to an affiliate of ~~$282~~$219 million and GENCO had investments due from an affiliate of ~~$353~~$9 million. On its Consolidated Balance Sheets, DESC includes money pool borrowings within affiliated and related party payables and money pool investments within affiliated and related party receivables.

DESC has recorded an estimate of excess deferred income tax amortization in 2020. The reversal of these excess deferred income taxes will impact the effective tax rate and rates charged to customers. See Note 3 to the Consolidated Financial Statements in DESC’s Annual Report on Form 10-K for the year ended December 31, 2019 for more information.

DESC’s effective tax rate for the six months ended June 30, ~~2019~~2020 is ~~8.1%~~21.5% compared to ~~20.5%~~8.1% for the six months ended June 30, ~~2018.~~2019. Variances in the effective tax rate are primarily driven by the absence of charges resulting from the SCANA Combination. In connection with the SCANA Merger Approval Order, Dominion Energy committed to forgo, or limit, the recovery of certain income tax-related regulatory assets associated with the NND Project. DESC's 2019 effective tax rate reflects income tax expense of $198 million in satisfaction of this commitment.

In Also in the first ~~quarter,~~six months of 2019, DESC’s unrecognized tax benefits increased by ~~$51~~$75 million and income tax expense increased by ~~$40~~$63 million related to afederal and state income tax position taken in prior years. In the second quarter, DESC’s unrecognized tax benefits increased by $24 million and income tax expense increased by $23 million primarily related to a federal income tax positionpositions taken in prior years.

In March 2020, the CARES Act was enacted which includes several significant business tax provisions that modify or temporarily suspend certain provisions of the 2017 Tax Reform Act. The CARES Act provisions are intended to improve cash flow and liquidity by, among other things, providing a temporary five-year carryback for certain net operating losses, accelerating the refund of previously generated corporate alternative minimum tax credits, and temporarily loosening the business interest limitation to 50% of adjusted taxable income for certain businesses. While DESC intends to utilize the income tax provisions of the CARES Act to accelerate the recognition of certain tax attributes, where applicable, they are not expected to provide a material benefit.

In July 2020, the U.S. Department of Treasury issued final regulations providing guidance about the limitation on the deduction for business interest expenses and issued proposed regulations on the application of these rules to certain pass-through entities and partners in those entities under the 2017 Tax Reform Act as modified by the CARES Act. DESC is currently assessing the impact of these regulations but expects interest expense to be deductible in 2020.

As of June 30, ~~2019,~~2020, there have been no other material changes in DESC’s unrecognized tax benefits. See Note 67 to the Consolidated Financial Statements in DESC's Annual Report on Form 10-K for the year ended December 31, ~~2018~~2019 for a discussion of these unrecognized tax ~~benefits and potential changes due to the SCANA Combination.~~benefits.

DESC has significant federal and state net operating loss carryforward-related deferred tax assets where the utilization of these tax benefits may be limited in future periods due to the SCANA Combination. For the period ended June 30, 2019, DESC has concluded a valuation allowance is not required on these deferred tax assets. If DESC concludes a valuation allowance is required in future periods, the impact could be material.

The 2017 Tax Reform Act limits the deductibility of interest expense to 30% of adjusted taxable income for certain businesses, with any disallowed interest carried forward indefinitely. Subject to additional guidance in yet to be finalized regulations, DESC expects its interest expense to be deductible in 2019.

DESC’s accounting policies, objectives, and strategies for using derivative instruments are discussed in Note 72 in the Consolidated Financial Statements in DESC’s Annual Report on Form 10-K for the year ended December 31, ~~2018. Derivative assets and liabilities are presented gross on the Consolidated Balance Sheets and are measured at fair value.~~2019. See Note 8 for further information about fair value measurements and associated valuation methods for derivatives.

Derivative assets and liabilities are presented gross on the Consolidated Balance Sheets. DESC’s derivative contracts include over-the-counter ~~transactions, which~~transactions. Over-the-counter contracts are bilateral contracts that are transacted directly with a third party. Certain over-the-counter contracts contain contractual rights of setoff through master netting arrangements and contract default provisions. In addition, the contracts are subject to conditional rights of setoff through counterparty nonperformance, insolvency, or other conditions.

In general, most over-the-counter transactions are subject to collateral requirements. Types of collateral for over-the-counter contracts include cash, letters of credit, and, in some cases, other forms of security, none of which are subject to restrictions. Cash collateral is used in the table below to offset derivative assets and liabilities.

~~Pursuant~~All of DESC’s derivative instruments contain credit-related contingent provisions. These provisions require DESC to ~~regulatory orders, interest rate~~provide collateral upon the occurrence of specific events, primarily a credit rating downgrade. If the credit-related contingent features underlying the instruments that are in a liability position and not fully collateralized with cash were fully triggered as of June 30, 2020, DESC would have been required to post $10 million of additional collateral to its counterparties. The collateral that would be required to be posted includes the impacts of any amounts already posted for derivatives ~~entered into by~~per contractual terms. DESC ~~after October 2013 have~~had posted $3 million of collateral at June 30, 2020 related to derivatives with credit-related contingent provisions that are in a liability position and not ~~been designated for accounting purposes as cash flow hedges, and~~fully collateralized with cash. The aggregate fair value ~~changes~~of all derivative instruments with credit-related contingent provisions that are in a liability position and ~~settlement amounts~~not fully collateralized with cash was $13 million at June 30, 2020. DESC’s derivatives with credit related to them have been recorded as regulatory assets and liabilities. Settlement losses on swaps generally have been amortized over the lives of subsequent debt issuances, and gains have been amortized to interest expense or have been applied as otherwise directed by the South Carolina Commission. See Note 15 regarding the settlement gains realizedcontingent provisions that were in ~~the first quarter of 2018.~~a liability position were fully collateralized with cash at December 31,2019.

The table below presents derivative balances by type of financial instrument, if the gross amounts recognized in the Consolidated Balance Sheets were netted with derivative instruments and cash collateral received or paid:

	June 30, 2019								December 31, 2018								June 30, 2020								December 31, 2019
	Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet								Gross Amounts Not Offset in the Consolidated Balance Sheet
(millions)	Gross Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Gross Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Gross Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts		Gross Liabilities Presented in the Consolidated Balance Sheet		Financial Instruments		Cash Collateral Paid		Net Amounts
Interest rate contracts:
Over-the-counter	$	19	$	—	$	19	$	—	$	11	$	—	$	11	$	—	$	31	$	—	$	21	$	10	$	19	$	—	$	19	$	—
Total derivatives	$	19	$	—	$	19	$	—	$	11	$	—	$	11	$	—	$	31	$	—	$	21	$	10	$	19	$	—	$	19	$	—

The following table presents the volume of derivative activity at June 30, ~~2019.~~2020. These volumes are based on open derivative positions and represent the combined absolute value of their long and short positions.

The following tables present the fair values of derivatives and where they are presented in the Consolidated Balance Sheets:

(millions)	Fair Value - Derivatives under Hedge Accounting		Fair Value - Derivatives not under Hedge Accounting		Total Fair Value		Fair Value - Derivatives under Hedge Accounting		Fair Value - Derivatives not under Hedge Accounting		Total Fair Value
At June 30, 2019
At June 30, 2020
Current Liabilities
Interest rate	$	1	$	1	$	2	$	1	$	1	$	2
Total current derivative liabilities⁽¹⁾		1		1		2		1		1		2
Noncurrent Liabilities
Interest rate		11		6		17		17		12		29
Total noncurrent derivative liabilities⁽²⁾		11		6		17		17		12		29
Total derivative liabilities	$	12	$	7	$	19	$	18	$	13	$	31
At December 31, 2018
At December 31, 2019
Current Liabilities
Interest rate	$	1	$	—	$	1	$	1	$	1	$	2
Total current derivative liabilities⁽¹⁾		1		—		1		1		1		2
Noncurrent Liabilities
Interest rate		7		3		10		11		6		17
Total noncurrent derivative liabilities⁽²⁾		7		3		10		11		6		17
Total derivative liabilities	$	8	$	3	$	11	$	12	$	7	$	19

The following tables present the gains and losses on derivatives, as well as where the associated activity is presented in ~~its~~the Consolidated Balance Sheets and Statements of Comprehensive Income (Loss):

(millions)	Gain (loss) Reclassified from Deferred Accounts into Income			Increase (Decrease) in Derivatives Subject to Regulatory Treatment⁽¹⁾			Gain (loss) Reclassified from Deferred Accounts into Income		Increase (Decrease) in Derivatives Subject to Regulatory Treatment⁽¹⁾
Three Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽²⁾							$	—	$	2
Total							$	—	$	2
Three Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	—		$	—		$	—	$	—
Total	$	—		$	—		$	—	$	—
Three Months Ended June 30, 2018
Six Months Ended June 30, 2020
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	(1	)	$	—		$	—	$	(4	)
Total	$	(1	)	$	—		$	—	$	(4	)
Six Months Ended June 30, 2019
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	—		$	(2	)	$	—	$	(2	)
Total	$	—		$	(2	)	$	—	$	(2	)
Six Months Ended June 30, 2018
Derivative type and location of gains (losses):
Interest rate⁽²⁾	$	(1	)	$	2
Total	$	(1	)	$	2

(millions)

Increase (Decrease) in
Derivatives Subject to
Regulatory Treatment⁽¹⁾

Amount of Gain (Loss)
Recognized in Income on
Derivatives⁽²⁾

Three Months Ended June 30,

2019

2018

Location

2019

2018

Derivative type and location of gains (losses):

Interest rate contracts:

Interest charges

$
—

$
(1
)

Other income

—

—

Total interest rate contracts

$
(2
)

$
—

$
—

$
(1
)
Six Months Ended June 30,

Derivative type and location of gains (losses):

Interest rate contracts:

Interest charges

$
—

$
(1
)

Other income

—

115

Total interest rate contracts

$
(3
)

$
65

$
—

$
114

Certain derivative contracts contain contingent credit features. These features may include (i) material adverse change clauses or payment acceleration clauses that could result in immediate payments or (ii) the posting of letters of credit or termination of the derivative contract before maturity if specific events occur, such as a credit rating downgrade below investment grade or failure to post collateral.

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. Fair values are based on assumptions that market participants would use when pricing an asset or liability, including assumptions about risk and the risks inherent in valuation techniques and the inputs to valuations. This includes not only the credit standing of counterparties involved and the impact of credit enhancements but also the impact of DESC’s own nonperformance risk on their liabilities. Fair value measurements assume that the transaction occurs in the principal market for the asset or liability (the market with the most volume and activity for the asset or liability from the perspective of the reporting entity), or in the absence of a principal market, the most advantageous market for the asset or liability (the market in which the reporting entity would be able to maximize the amount received or minimize the amount paid). DESC applies fair value measurements ~~to interest rate assets and liabilities. DESC’s interest rate swap agreements~~ are ~~valued using discounted cash flow models with independently sourced data. DESC applies credit adjustments to its derivative fair values~~made in accordance with the ~~requirements described above.~~

Fair value is based on actively-quoted market prices, if available. In the absence of actively-quoted market prices, price information is sought from external sources, including industry publications, and to a lesser extent, broker quotes. When evaluating pricing information, DESC considers the ability to transact at the quoted price. Periodically, inputs to valuation models are reviewed and revised as needed, based on historical information, updated market data, market liquidity and relationships, and changespolicies discussed in ~~third-party sources.~~

~~The inputs and assumptions used in measuring fair value for interest rate derivative contracts include the following:~~

~~DESC utilizes the following fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value into three broad levels:~~

The fair value hierarchy gives the highest priority to quoted prices in active markets (Level 1) and the lowest priority to unobservable data (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. In these cases, the lowest level input that is significant to a fair value measurement in its entirety determines the applicable level in the fair value hierarchy. Assessing the significance of a particular inputNote 9 to the ~~fair value measurement~~Consolidated Financial Statements in ~~its entirety requires judgment, considering factors specific to~~DESC’s Annual Report on Form 10-K for the ~~asset or liability.~~year ended December 31, 2019. See Note 7 in this report for further information about DESC’s derivatives and hedge accounting activities.

~~Fair value measurements~~The following table presents DESC’s liabilities that are ~~separately disclosed by level within the~~measured at fair value ~~hierarchy.~~on a recurring basis for each hierarchy level, including both current and noncurrent portions:

All of DESC's interest rate swap agreements were in a liability position for all periods presented. Such agreements are valued using discounted cash flow models with independently sourced data, and are considered to be Level 2 fair value measurements. The fair value of these derivatives at June 30, 2019 was $19 million, and at December 31, 2018 was $11 million.

Substantially all of DESC’s financial instruments are recorded at fair value, with the exception of the instruments described below, which are reported at historical cost. Estimated fair values have been determined using available market information and valuation methodologies considered appropriate by management. The carrying amount of financial instruments classified within current assets and current liabilities are representative of fair value because of the short-term nature of these instruments. For financial instruments that are not recorded at fair value, the carrying amounts and estimated fair values are as follows:

	June 30, 2019				December 31, 2018				June 30, 2020				December 31, 2019
(millions)	Carrying Amount		Estimated Fair Value⁽¹⁾		Carrying Amount		Estimated Fair Value⁽²⁾		Carrying Amount		Estimated Fair Value⁽¹⁾		Carrying Amount		Estimated Fair Value⁽¹⁾
Long-term debt⁽³⁾⁽²⁾	$	4,171	$	4,982	$	5,146	$	5,470	$	3,359	$	4,586	$	3,358	$	4,262
Affiliated long-term debt										230		230		230		230

A liability for the present value of an ARO is recognized when incurred if the liability can be reasonably estimated. Uncertainty about the timing or method of settlement of a conditional ARO is factored into the measurement of the liability when sufficient information exists, but such uncertainty is not a basis upon which to avoid liability recognition.

A reconciliation of the beginning and ending aggregate carrying amount of AROs is as follows:

In May 2019, DESC entered into an agreement to sell certain warranty service contract assets for total consideration of $7 million. DESC expects the transaction to close in the third quarter of 2019 and estimates the transaction to result in a $7 million ($5 million after-tax) gain. Pursuant to the agreement, upon closing DESC expects to enter into a commission agreement with the buyer under which the buyer will compensate DESC in connection with the right to use DESC’s brand in marketing materials and other services over a ten-year term.

DESC jointly owns and is the operator of Summer. Each joint owner provides its own financing and shares the direct expenses and generation output in proportion to its ownership. DESC’s share of the direct expenses in Summer is 66.7%. In May 2019, DESC and Santee Cooper entered into an agreement in which DESC agreed to purchase 11.7% of Santee Cooper’s ownership interest in the NND Project nuclear fuel, which will be used at Summer, for $8 million to true up the ownership percentage from the 55% ownership percentage that was applicable for the NND Project to the 66.7% ownership percentage applicable for Summer.

(millions)	Pension Benefits						Other Postretirement Benefits				Pension Benefits						Other Postretirement Benefits
Three Months Ended June 30,	2019			2018			2019		2018		2020			2019			2020		2019
Service cost	$	3		$	4		$	—	$	1	$	4		$	3		$	1	$	—
Interest cost		7			7			2		2		6			7			2		2
Expected return on assets		(10	)		(12	)		—		—		(11	)		(10	)		—		—
Amortization of actuarial losses		3			3			—		1		1			3			—		—
Curtailment⁽¹⁾		6			—			3		—		—			6			—		3
Net periodic benefit cost	$	9		$	2		$	5	$	4	$	—		$	9		$	3	$	5
Six Months Ended June 30,
Service cost	$	7		$	8		$	1	$	2	$	7		$	7		$	2	$	1
Interest cost		15			15			4		4		12			15			4		4
Expected return on assets		(20	)		(24	)		—		—		(22	)		(20	)		—		—
Amortization of actuarial losses		7			5			—		1		3			7			—		—
Curtailment⁽¹⁾		6			—			3		—		—			6			—		3
Net periodic benefit cost	$	15		$	4		$	8	$	7	$	—		$	15		$	6	$	8

No significant contribution to the pension trust is expected for the remainder of ~~2019~~2020 based on current market conditions and assumptions, nor is a limitation on benefit payments expected to apply. DESC recovers current pension costs through either a rate rider that may be adjusted annually for retail electric operations or through cost of service rates for gas operations.

In March 2019, Dominion Energy announced a voluntary retirement program to employees, including employees of DESC, that meet certain age and service requirements. The voluntary retirement program will not compromise safety or DESC’s ability to comply with applicable laws and regulations. In the second quarter of 2019, upon the determinations made concerning the number of employees that elected to participate in the program, DESC recorded a charge of $62 million ($47 million after-tax), of which $50 million was included within other operations and maintenance expense, $3 million within other taxes and $9 million within other income (expense), net.

In the second quarter of 2019, DESC remeasured its pension and other postretirement benefit plans as a result of the voluntary retirement program. The remeasurement resulted in an increase in the pension benefit obligation of $16 million and an increase in the accumulated postretirement benefit obligation of $10 million. In addition, the remeasurement resulted in an increase in the fair value of pension plan assets of $27 million. The impact of the remeasurement on net periodic benefit cost was recognized prospectively from the remeasurement date. The remeasurement is expected to increase the net periodic benefit cost for 2019 by approximately $1 million, excluding the impacts of curtailments. The discount rate used for the remeasurement was 4.07% for the pension plan and 4.08% for the other postretirement benefit plan. All other assumptions used for the remeasurement were consistent with the measurement as of December 31, 2018.

As a result of issues generated in the ordinary course of business, DESC is involved in legal proceedings before various courts and is periodically subject to governmental examinations (including by regulatory authorities), inquiries and investigations. Certain legal proceedings and governmental examinations involve demands for unspecified amounts of damages, are in an initial procedural phase, involve uncertainty as to the outcome of pending appeals or motions, or involve significant factual issues that need to be resolved, such that it is not possible for DESC to estimate a range of possible loss. For such matters that DESC cannot estimate, a statement to this effect is made in the description of the matter. Other matters may have progressed sufficiently through the litigation or investigative processes such that DESC is able to estimate a range of possible loss. For legal proceedings and governmental examinations that DESC is able to reasonably estimate a range of possible losses, an estimated range of possible loss is provided, in excess of the accrued liability (if any) for such matters. Any accrued liability is recorded on a gross basis with a receivable also recorded for any probable insurance recoveries. Estimated ranges of loss are inclusive of legal fees and net of any anticipated insurance recoveries. Any estimated range is based on currently available information and involves elements of judgment and significant uncertainties. Any estimated range of possible loss may not represent DESC’s maximum possible loss exposure. The circumstances of such legal proceedings and governmental examinations will change from time to time and actual results may vary significantly from the current estimate. For current proceedings not specifically reported below, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material effect on DESC’s financial position, liquidity or results of operations.

DESC is subject to costs resulting from a number of federal, state and local laws and regulations designed to protect human health and the environment. These laws and regulations affect future planning and existing operations. They can result in increased capital, operating and other costs as a result of compliance, remediation, containment and monitoring obligations.

From a regulatory perspective, DESC and GENCO continually monitor and evaluate their current and projected emission levels and strive to comply with all state and federal regulations regarding those emissions. DESC and GENCO participate in the SO₂and NO_X emission allowance programs with respect to coal plant emissions and also have constructed additional pollution control equipment at their coal-fired electric generating plants. These actions are expected to address many of the rules and regulations discussed herein.

The CAA, as amended, is a comprehensive program utilizing a broad range of regulatory tools to protect and preserve the nation's air quality. At a minimum, states are required to establish regulatory programs to address all requirements of the CAA. However, states may choose to develop regulatory programs that are more restrictive. Many of DESC’s facilities are subject to the CAA’s permitting and other requirements.

In February 2019, the EPA published a proposed rule to reverse its previous finding that it is appropriate and necessary to regulate hazardous air pollutant emissions from coal- and oil-fired electric generating units. In May 2020, the EPA’s final rule became effective. The final rule is consistent with the EPA’s February 2019 proposal, and determines that it is not appropriate and necessary to regulate mercury and hazardous air pollutant emissions from coal- and oil-fired electric generating units. The final rule also states that the MATS rule remains in place and the emissions standards for affected coal- and oil-fired electric generating units will not change. DESC is complying with the applicable requirements of the rule and does not expect any impacts to its operations.

The EPA published final non-attainment designations for the October 2015 ozone standard in June 2018. States have until August 2021 to develop plans to address the new standard. Until the states have developed implementation plans for the standard, DESC is unable to predict whether or to what extent the new rules will ultimately require additional controls. The expenditures required to implement additional controls could have a material impact on DESC’s results of operations and cash flows.

In July 2019, the EPA published the final rule informally referred to as the ACE Rule, ~~which repeals and replaces~~as a replacement for the Clean Power Plan. The ACE Rule ~~only~~ applies to existing coal-fired ~~steam electric generating units greater than or equal to 25 MW.~~power plants. The final rule includes unit-specific performance standards based on the degree of emission reduction levels achievable from unit efficiency improvements to be determined by the permitting agency. The ACE Rule requires states to develop plans by July 2022 to implement these performance ~~standards, which~~standards. These state plans must be approved by the ~~EPA. DESC is currently evaluating the ACE Rule for potential impact at its coal fired units and expects any costs incurred to comply with such rule to be recoverable through rates.~~EPA by January 2024. While the impacts of this rule could be material to DESC’s results of operations, financial condition and/or cash flows, the existing regulatory framework in South Carolina provides rate recovery mechanisms that could substantially mitigate any such ~~impacts.~~impacts for DESC.

In ~~July 2011,~~August 2016, the EPA issued a draft rule proposing to reaffirm that a source’s obligation to obtain a PSD or Title V permit for GHGs is triggered only if such permitting requirements are first triggered by non-GHG, or conventional, pollutants that are regulated by the ~~CSAPR~~New Source Review program, and to ~~reduce~~set a significant emissions rate at 75,000 tons per year of SOCO₂ equivalent emissions under which a source would not be required to apply BACT for its GHG emissions. Until the EPA ultimately takes final action on this rulemaking, DESC cannot predict the impact to its results of operations, financial condition and/or cash flows.

In December 2018, the EPA proposed revised Standards of Performance for Greenhouse Gas Emissions from New, Modified, and NO_X ~~from power plants~~Reconstructed Stationary Sources. The proposed rule would amend the previous determination that the best system of emission reduction for newly constructed coal-fired steam generating units is no longer partial carbon capture and storage. Instead, the proposed revised best system of emission reduction for this source category is the most efficient demonstrated steam cycle (e.g., supercritical steam conditions for large units and subcritical steam conditions for small units) in combination with the best operating practices.

In August 2012, the EPA issued an NSPS impacting new and modified facilities in the ~~eastern half~~natural gas production and gathering sectors and made revisions to the NSPS for natural gas processing and transmission facilities. These rules establish equipment performance specifications and emissions standards for control of ~~the U.S. The CSAPR replaces the Clean Air Interstate Rule~~VOC emissions for natural gas production wells, tanks, pneumatic controllers and ~~requires a total of 28 states to reduce annual SO~~₂ ~~emissions and annual ozone season NO~~_X ~~emissions to assist in attaining the ozone and fine particle National Ambient Air Quality Standards. The rule establishes an emissions cap for SO~~₂~~and NO~~_X ~~and limits the trading for emission allowances by separating affected states into two groups with no trading between the groups. The State of South Carolina has chosen to remain~~compressors in the ~~CSAPR program, even though recent court rulings exempted~~upstream sector. In June 2016, the ~~state. This allows~~EPA issued another NSPS regulation, for the ~~state~~oil and natural gas sector, to ~~remain compliant with regional haze standards. Air quality control installations that DESC has already completed have positioned them~~regulate methane and VOC emissions from new and modified facilities in transmission and storage, gathering and boosting, production and processing facilities. All projects which commenced construction after September 2015 are required to comply with ~~the existing allowances set by the CSAPR. Any costs incurred to comply with CSAPR are expected to be recoverable through rates.~~

this regulation. In ~~February 2019,~~October 2018, the EPA published a proposed rule ~~to reverse its previous finding that it is appropriate~~reconsidering and ~~necessary to regulate toxic emissions from power plants. However, the emissions standards and other requirements~~amending portions of the ~~MATS~~2016 rule, ~~would remain in place as~~including but not limited to, the ~~EPA is not proposing to remove coal~~fugitive emissions requirements at well sites and ~~oil fired power plants from the list of sources that are regulated under MATS. Although litigation~~compressor stations. The amended portions of the ~~MATS~~2016 rule ~~and~~were effective immediately upon publication. Until the ~~outcome of the EPA’s rulemaking are still pending, the regulation remains in effect and~~proposed rule regarding reconsideration is final, DESC is ~~complying with~~implementing the ~~applicable requirements~~2016 regulation. DESC is still evaluating whether potential impacts on results of ~~the rule and does not expect any adverse impacts~~operations, financial condition and/or cash flows related to ~~its operations at~~ this ~~time due to plant retirements, conversions and enhancements.~~matter will be material.

The CWA, ~~provides for the imposition~~as amended, is a comprehensive program requiring a broad range of ~~effluent limitations that require treatment for wastewater discharges. Under~~regulatory tools including a permit program to authorize and regulate discharges to surface waters with strong enforcement mechanisms. DESC must comply with applicable aspects of the CWA ~~compliance with applicable limitations is achieved~~programs at its operating facilities.

In October 2014, the final regulations under state-issued NPDES permits such that, as a facility’s NPDES permit is renewed, any new effluent limitations would be incorporated. The ELG Rule was final in September 2015, after which state regulators are required to modify facility NPDES permits to match more restrictive standards, which would require facilities to retrofit with new wastewater treatment technologies. Compliance dates varied by type of wastewater, and some were based on a facility's five-year permit cycle and thus could range from 2018 to 2023. However, the ELG Rule is under reconsideration by the EPA and has been stayed administratively. The EPA has decided to conduct a new rulemaking that could result in revisions to certain flue gas desulfurization wastewater and bottom ash transport water requirements in the ELG Rule. Accordingly, in September 2017 the EPA finalized a rule that postpones compliance dates under the ELG Rule to a range from November 2020 to December 2023. The EPA indicates that the new rulemaking process may take up to three years to complete, such that any revisions to the ELG Rule likely would not be final until the summer of 2020. While DESC expects that wastewater treatment technology retrofits will be required at Williams and Wateree generating stations, any costs incurred to comply with the ELG Rule are expected to be recoverable through rates.

~~The CWA~~ Section 316(b) ~~Existing Facilities Rule became effective in October 2014. This rule establishes national requirements for~~of the ~~location, design, construction~~CWA that govern existing facilities and ~~capacity of cooling water intake structures~~new units at existing facilities that ~~reflect~~employ a cooling water intake structure and that have flow levels exceeding a minimum threshold became effective. The rule establishes a national standard for impingement based on seven compliance options, but forgoes the ~~best~~creation of a single technology

~~available~~ standard for ~~minimizing~~entrainment. Instead, the ~~adverse environmental impacts~~EPA has delegated entrainment technology decisions to state regulators. State regulators are to make case-by-case entrainment technology determinations after an examination of five mandatory facility-specific factors, including a social cost-benefit test, and six optional facility-specific factors. The rule governs all electric generating stations with water withdrawals above 2 MGD, with a heightened entrainment analysis for those facilities over 125 MGD. DESC has 5 facilities that are subject to the final regulations. DESC is also working with the EPA and state regulatory agencies to assess the applicability of Section 316(b) to 5 hydroelectric facilities. DESC anticipates that it may have to install impingement control technologies at certain of these stations that have once-through cooling systems. DESC is currently evaluating the need or potential for entrainment controls under the final rule as these decisions will be made on a case-by-case basis after a thorough review of detailed biological, technology, cost and ~~entrainment.~~ benefit studies. DESC is conducting studies and implementing plans as required by the rule to determine appropriate intake structure modifications at certain facilities to ensure compliance with this rule. ~~Any~~ While the impacts of this rule could be material to DESC’s results of operations, financial condition and/or cash flows, the existing regulatory framework in South Carolina provides rate recovery mechanisms that could substantially mitigate any such impacts for DESC.

In September 2015, the EPA released a final rule to revise the ELG Rule. The final rule establishes updated standards for wastewater discharges that apply primarily at coal and oil steam generating stations. Affected facilities are required to convert from wet to dry or closed cycle coal ash management, improve existing wastewater treatment systems and/or install new wastewater treatment technologies in order to meet the new discharge limits. In April 2017, the EPA granted two separate petitions for reconsideration of the final ELG Rule and stayed future compliance dates in the rule. Also in April 2017, the U.S. Court of Appeals for the Fifth Circuit granted the EPA’s request for a stay of the pending consolidated litigation challenging the rule while the EPA addresses the petitions for reconsideration. In September 2017, the EPA signed a rule to postpone the earliest compliance dates for certain waste streams regulations in the final ELG Rule from November 2018 to November 2020; however, the latest date for compliance for these regulations remains December 2023. While the impacts of this rule could be material to DESC’s results of operations, financial condition and/or cash flows, as DESC expects that wastewater treatment technology retrofits will be required at Williams and Wateree generating stations, the existing regulatory framework in South Carolina provides rate recovery mechanisms that could substantially mitigate any such impacts for DESC.

In December 2019, the EPA released proposed revisions to the ELG Rule that, if adopted, could extend the deadlines for compliance with certain standards at several facilities. While the impacts of this rule could be material to DESC’s results of operations, financial condition and/or cash flows, the existing regulatory frameworks in South Carolina provide rate recovery mechanisms that could substantially mitigate any such impacts for the regulated electric utilities.

In November 2019, a new CUA was established in the counties surrounding the Cope Generating Station (Western Capacity Use Area) under the South Carolina Groundwater Use and Reporting Regulation. Under the regulation any groundwater well in a CUA that withdraws above three million gallons per month must be permitted. The Cope Generating Station is located within this new Western Capacity Use Area. Cope has been using four deep groundwater wells for cooling water and other house loads since 1996. Prior to designation of the new Western Capacity Use Area, the wells at Cope Station were only required to be registered not permitted. As a result of this designation, Cope will need to restore the surface water equipment to operable status to reduce reliance on groundwater wells. This includes completion of 316(b) requirements, (including SCDHEC BACT determination and modification of the station national pollutant discharge elimination system permit) and extensive inspection, repair and/or replacement of the associated surface water withdrawal equipment which has been idle since 1996. While the impacts of this rule change are material to DESC’s results of operations, financial condition and/or cash flows, the existing regulatory framework in South Carolina provides rate recovery mechanisms that could substantially mitigate any such impacts for DESC.

The operations of DESC are subject to a variety of state and federal laws and regulations governing the management and disposal of solid and hazardous waste, and release of hazardous substances associated with current and/or historical operations. The CERCLA, as amended, and similar state laws, may impose joint, several and strict liability for cleanup on potentially responsible parties who owned, operated or arranged for disposal at facilities affected by a release of hazardous substances. In addition, many states have created programs to incentivize voluntary remediation of sites where historical releases of hazardous substances are identified and property owners or responsible parties decide to initiate cleanups.

From time to time, DESC may be identified as a potentially responsible party in connection with the alleged release of hazardous substances or wastes at a site. Under applicable federal and state laws, DESC could be responsible for costs associated with the investigation or remediation of impacted sites, or subject to contribution claims by other responsible parties for their costs incurred at such sites. DESC also may identify, evaluate and remediate other potentially impacted sites under voluntary state programs. Remediation costs may be subject to ~~comply with this rule are expected to be recoverable through rates.~~

~~The EPA's final rule for CCR became effective in the fourth quarter of 2015. This rule regulates CCR~~reimbursement under DESC’s insurance policies, rate recovery mechanisms, or both. Except as a non-hazardous waste under Subtitle D of the Resource Conservation and Recovery Act and imposes certain requirements on ash storage ponds and other CCR management facilities at certain of DESC's coal-fired generating facilities. DESC has already closed or has begun the process of closure of all of its ash storage ponds and has previously recognized AROs for such ash storage ponds under existing requirements.described below, DESC does not ~~expect the incremental compliance costs associated with this rule to be significant and expect to recover such costs in future rates.~~believe these matters will have a material effect on results of operations, financial condition and/or cash flows.

DESC ~~is responsible for four~~has 4 decommissioned MGP sites in South Carolina ~~which contain residues of by-product chemicals. These sites~~that are in various ~~stages~~states of investigation, remediation and monitoring under work plans approved by, or under review by, the SCDHEC ~~and~~or the EPA. DESC anticipates that ~~major remediation~~ activities at ~~all of~~ these sites will continue through 2025 at ~~least through 2022 and will~~an estimated cost ~~an additional~~of $10 million. In ~~February 2019, SCDHEC directed~~September 2018, DESC ~~to pursue a stakeholder-developed modified removal action~~submitted an updated remediation work plan for one site ~~(Congaree River). DESC is developing an engineering design for this plan,~~to SCDHEC, which ~~would require permits from the~~ ~~U.S. Army Corps of Engineers~~ ~~and others and further approvals before it could be implemented. If DESC receives the necessary permits and approvals for this plan, remediation cost for the Congaree River site~~if approved, would increase costs by $8approximately $11 million. DESC cannot predict if or when such permits or approvals will be received. Major remediation activities are accrued in other within deferred credits and other liabilities on the Consolidated Balance Sheets. DESC expects to recover ~~any cost~~costs arising from the remediation ~~of MGP~~work at all four sites through ~~rates. At~~rate recovery mechanisms and as of June 30, ~~2019,~~2020, deferred amounts, net of amounts previously recovered through rates and insurance settlements, totaled ~~$23~~$22 million and are included in regulatory assets.

In April 2015, the EPA enacted a final rule regulating CCR landfills, existing ash ponds that still receive and manage CCRs, and inactive ash ponds that do not receive, but still store, CCRs. DESC currently has inactive and existing CCR ponds and CCR landfills subject to the final rule at 3 different facilities. This rule created a legal obligation for DESC to retrofit or close all of its inactive and existing ash ponds over a certain period of time, as well as perform required monitoring, corrective action, and post-closure care activities as necessary.

In December 2016, legislation was enacted that creates a framework for EPA- approved state CCR permit programs. In August 2017, the EPA issued interim guidance outlining the framework for state CCR program approval. The EPA has enforcement authority until state programs are approved. The EPA and states with approved programs both will have authority to enforce CCR requirements under their respective rules and programs. In September 2017, the EPA agreed to reconsider portions of the CCR rule in response to two petitions for reconsideration. In March 2018, the EPA proposed certain changes to the CCR rule related to issues remanded as part of the pending litigation and other issues the EPA is reconsidering. Several of the proposed changes would allow states with approved CCR permit programs additional flexibility in implementing their programs. In July 2018, the EPA promulgated the first phase of changes to the CCR rule. Until all phases of the CCR rule are promulgated, DESC cannot forecast potential incremental impacts or costs related to existing coal ash sites in connection with future implementation of the 2016 CCR legislation and reconsideration of the CCR rule. In August 2018, the U.S. Court of Appeals for the D.C. Circuit issued its decision in the pending challenges of the CCR rule, vacating and remanding to the EPA three provisions of the rule. Until regulatory action is taken to incorporate the U.S. Court of Appeals for the D.C. Circuit’s decision, DESC is unable to make an estimate of the potential financial statement impacts associated with any future changes to the CCR rule in connection with the court’s remand.

A description of events and circumstances leading up to DESC's abandonment of the NND Project and subsequent regulatory, legislative, legal and investigative proceedings, as well as related impairments of NND Project and other costs are described in Note 1112 in DESC's Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019.

In accordance with the terms of the South Carolina Commission's SCANA Merger Approval Order, DESC adopted the Plan-B Levelized Customer Benefits Plan, effective February 2019, whereby the average bill for a DESC residential electric customer approximates that which resulted from the legislatively-mandated temporary reduction that had been put into effect by the South Carolina Commission in August 2018. DESC also recorded a significant impairment charge in the fourth quarter of 2018, which charge resulted from its conclusion that NND Project capital costs exceeding the amount established in the SCANA Merger Approval Order were probable of loss, regardless of whether the SCANA Combination was completed. In addition, in the first quarter of 2019, DESC recorded the following charges and liabilities which arose from or are related to provisions in the SCANA Merger Approval Order.

Further, except for rate adjustments for fuel and environmental costs, DSM costs, and other rates routinely adjusted on an annual or biannual basis, DESC will freeze retail electric base rates at current levels until January 1, 2021. As discussed in Note 2, in April 2020, the South Carolina Commission issued an order vacating the portion of the SCANA Merger Approval Order requiring that new retail electric rates be implemented by January 1, 2021.

The South Carolina Commission order also approved the removal of DESC's investment in certain transmission assets that have not been abandoned from BLRA capital costs. As of June 30, ~~2019,~~2020, such investment in these assets included ~~$323~~$345 million within utility plant, net and ~~$27~~$49 million within regulatory assets, which amount represents certain deferred operating costs. The South Carolina Commission approved deferral of these operating costs related to the investment until recovery of the transmission capital costs and associated deferred operating costs is addressed in a future rate proceeding. DESC believes these transmission capital and deferred operating costs are probable of recovery; however, if the South Carolina Commission were to disallow recovery of or a reasonable return on all or a portion of them, an impairment charge equal to the disallowed costs may be required.

Various parties filed petitions for rehearing or reconsideration of the SCANA Merger Approval Order. In January 2019, the South Carolina Commission issued an order (1) granting the request of various parties and finding that DESC was imprudent in its actions by not disclosing material information to the ORS and the South Carolina Commission with regard to costs incurred subsequent to March 2015 and (2) denying the petitions for rehearing or consideration as to other issues raised in the various petitions. The deadline to appeal the SCANA Merger Approval Order and the order on rehearing expired in April 2019, and no party has sought appeal.

The following describes certain legal proceedings involving DESC relating to events occurring before closing of the SCANA Combination. ~~Dominion Energy intends to vigorously contest the lawsuits, claims and assessments which have been filed or initiated against DESC.~~ No reference to, or disclosure of, any proceeding, item or matter described below shall be construed as an admission or indication that such proceeding, item or matter is material. For certain of these matters, and unless otherwise noted therein, DESC is unable to estimate a reasonable range of possible loss and the related financial statement impacts, but for any such matter there could be a material impact to its results of operations, financial condition and/or cash flows. For the matters for which DESC is able to reasonably estimate a probable loss, the Consolidated Balance Sheets at June 30, 2020 and December 31, 2019 include reserves of ~~$278~~$473 million and $492 million, respectively, and insurance receivables of $8 million and $6 million, respectively, included within ~~reserves for litigation and regulatory proceedings at June 30, 2019.~~

other receivables. During the three and six months ended June 30, 2019, the Consolidated Statements of Comprehensive Income (Loss) includes charges of $100 million ($75 million after-tax) and ~~$266~~$266 million ($200 million after-tax), respectively, included within impairment of assets and other charges.

In May 2018, a consolidated complaint against DESC, SCANA and the State of South Carolina was filed in the State Court of Common Pleas in Hampton County, South Carolina (the DESC Ratepayer Case). In September 2018, the court certified this case as a class action. The plaintiffs allege, among other things, that DESC was negligent and unjustly enriched, breached alleged fiduciary and contractual duties and committed fraud and misrepresentation in failing to properly manage the NND Project, and that DESC committed unfair trade practices and violated state anti-trust laws. The plaintiffs sought a declaratory judgment that DESC may not charge its customers for any past or continuing costs of the NND Project, sought to have SCANA and DESC’s assets frozen and all monies recovered from Toshiba and other sources be placed in a constructive trust for the benefit of ratepayers and sought specific performance of the alleged implied contract to construct the NND Project.

In December 2018, the State Court of Common Pleas in Hampton County entered an order granting preliminary approval of a class action settlement and a stay of pre-trial proceedings in the DESC Ratepayer Case. The settlement agreement, contingent upon the closing of the SCANA Combination, provided that SCANA and DESC would establish an escrow account and proceeds from the escrow account would be distributed to the class members, after payment of certain taxes, attorneys' fees and other expenses and administrative costs. The escrow account would include (1) up to $2.0 billion, net of a credit of up to $2.0 billion in future electric bill relief, which would inure to the benefit of the escrow account in favor of class members over a period of time established by the South Carolina Commission in its order related to matters before the South Carolina Commission related to the NND Project, (2) a cash payment of $115 million and (3) the transfer of certain DESC-owned real estate or sales proceeds from the sale of such properties, which counsel for the DESC Ratepayer Class estimate to have an aggregate value between $60 million and $85 million. At the closing of the SCANA Combination, SCANA and DESC funded the cash payment portion of the escrow account. The court held a fairness hearing on the settlement in May 2019. In June 2019, the court entered an order granting final approval of the settlement, which order became effective July 2019. In July 2019, DESC transferred $117 million representing the cash payment, plus accrued interest, to the plaintiffs. In addition, property with a net recorded value of $42 million ~~will be~~is in the process of being transferred to the plaintiffs ~~as soon as practicable~~in coordination with the court-appointed real estate trustee to satisfy the settlement ~~agreement.~~agreement, of which $21 million had been transferred as of June 30, 2020.

In September 2017, a purported class action was filed by Santee Cooper ratepayers against Santee Cooper, DESC, Palmetto Electric Cooperative, Inc. and Central Electric Power Cooperative, Inc. in the State Court of Common Pleas in Hampton County, South Carolina (the Santee Cooper Ratepayer Case). The allegations are substantially similar to those in the DESC Ratepayer Case. The plaintiffs seek a declaratory judgment that the defendants may not charge the purported class for reimbursement for past or future costs of the NND Project. In March 2018, the plaintiffs filed an amended complaint including as additional named defendants certain then current and former directors of Santee Cooper and SCANA. In June 2018, Santee Cooper filed a Notice of Petition for Original Jurisdiction with the Supreme Court of South Carolina which was denied. In December 2018, Santee Cooper filed its answer to the plaintiffs' fourth amended complaint and filed cross claims against DESC. In October 2019, Santee Cooper voluntarily consented to stay its cross claims against DESC pending the outcome of the trial of the underlying case. In November 2019, DESC removed the case to the U.S. District Court for the District of South Carolina. In December 2019, the plaintiffs and Santee Cooper filed a motion to remand the case to state court. In January 2020, the case was remanded to state court. In March 2020, the parties executed a settlement agreement relating to this matter as well as the Luquire Case and the Glibowski Case described below. The settlement agreement provides that Dominion Energy and Santee Cooper will establish a fund for the benefit of class members in the amount of $520 million, of which DESC’s portion is $320 million of shares of Dominion Energy common stock. Also in March 2020, the court granted preliminary approval for the settlement agreement. In July 2020, the court issued a final approval of the settlement agreement. The settlement will become effective upon the expiration of a 30-day appellate period. This case is pending.

In July 2019, a similar purported class action was filed by certain Santee Cooper ratepayers against DESC, SCANA, Dominion Energy and former directors and officers of SCANA in the State Court of Common Pleas in Orangeburg, South ~~Carolina.~~Carolina (the Luquire Case). In August 2019, DESC, SCANA and Dominion Energy were voluntarily dismissed from the case. The claims are similar to the Santee Cooper Ratepayer Case. In March 2020, the parties executed a settlement agreement as described above relating to this matter as well as the Santee Cooper Ratepayer Case and the Glibowski Case. This case will be dismissed upon the effective date of the Santee Cooper Ratepayer Case settlement. This case is pending.

In January 2018, a purported class action was filed, and subsequently amended, against SCANA, DESC and certain former executive officers in the U.S. District Court for the District of South ~~Carolina.~~Carolina (the Glibowski Case). The plaintiff alleges, among other things, that SCANA, DESC and

the individual defendants participated in an unlawful racketeering enterprise in violation of RICO and conspired to violate RICO by fraudulently inflating utility bills to generate unlawful proceeds. The DESC Ratepayer Class Action settlement described previously contemplates dismissal of claims by DESC ratepayers in this case against DESC, SCANA and their

officers. In August 2019, the individual defendants filed motions to dismiss. In March 2020, the parties executed a settlement agreement as described above relating to this matter as well as the Santee Cooper Ratepayer Case and the Luquire Case. This case will be dismissed upon the effective date of the Santee Cooper Ratepayer Case settlement. This case is pending.

In February 2018, a purported class action was filed against Dominion Energy and certain former directors of SCANA and DESC in the State Court of Common Pleas in Richland County, South Carolina (the Metzler Lawsuit). The plaintiff alleges, among other things, that defendants violated their fiduciary duties to shareholders by executing a merger agreement that would unfairly deprive plaintiffs of the true value of their SCANA stock, and that Dominion Energy aided and abetted these actions. Among other remedies, the plaintiff seeks to enjoin and/or rescind the merger. In February 2018, Dominion Energy removed the case to the U.S. District Court for the District of South Carolina and filed a Motion to Dismiss in March 2018. In August 2018, the case was remanded back to the State Court of Common Pleas in Richland County. Dominion Energy appealed the decision to remand to the U.S. Court of Appeals for the Fourth Circuit, where the appeal was consolidated with another lawsuit regarding the SCANA Merger Agreement to which DESC is not a party. In June 2019, the U.S. Court of Appeals for the Fourth Circuit reversed the order remanding the case to state court. ~~The case is pending in~~In September 2019, the U.S. District Court for the District of South ~~Carolina.~~Carolina granted the plaintiffs’ motion to consolidate the Metzler Lawsuit with another lawsuit regarding the SCANA Merger Agreement to which DESC is not a party. In October 2019, the plaintiffs filed an amended complaint against certain former directors and executive officers of SCANA and DESC, which stated substantially similar allegations to those in the initial lawsuits as well as an inseparable fraud claim. In November 2019, the defendants filed a motion to dismiss. In April 2020, the U.S. District Court for the District of South Carolina denied the motion to dismiss. In May 2020, SCANA filed a motion to intervene. This case is pending.

In August 2017, a case was filed in the U.S. District Court for the District of South Carolina on behalf of persons who were formerly employed at the NND Project. In July 2018, the court certified this case as a class action. In February 2019, certain ~~plantiffs who were not certified as part~~ of these plaintiffs filed an additional case, which case has been dismissed and the ~~class action~~plaintiffs have joined the case filed ~~a separate case. In those cases, the~~in August 2017. The plaintiffs allege, among other things, that SCANA, DESC, Fluor Corporation and Fluor Enterprises, Inc. violated the Worker Adjustment and Retraining Notification Act in connection with the decision to stop construction at the NND Project. The plaintiffs allege that the defendants failed to provide adequate advance written notice of their terminations of employment and are seeking damages, which are estimated to be as much as ~~$75~~$100 million for 100% of the NND Project.

In September 2018, a case was filed in the State Court of Common Pleas in Fairfield County, South Carolina by Fluor Enterprises, Inc. and Fluor Daniel Maintenance Services, Inc. against DESC and Santee Cooper. The plaintiffs make claims for indemnification, breach of contract and promissory estoppel arising from, among other things, the defendants' alleged failure and refusal to defend and indemnify the Fluor defendants in the aforementioned case. These cases are pending.

In November 2017, Fairfield County filed a complaint and a motion for temporary injunction against DESC in the State Court of Common Pleas in Fairfield County, South Carolina, making allegations of breach of contract, fraud, negligent misrepresentation, breach of fiduciary duty, breach of implied duty of good faith and fair dealing and unfair trade practices related to DESC’s termination of the FILOT agreement between DESC and Fairfield County related to the NND Project. The plaintiff sought a temporary and permanent injunction to prevent DESC from terminating the FILOT agreement. The plaintiff withdrew the motion for temporary injunction in December 2017. This case is pending.

In June 2018, DESC received a notice of proposed assessment of approximately $410 million, excluding interest, from the SCDOR following its audit of DESC’s sales and use tax returns for the periods September 1, 2008 through December 31, 2017. The proposed assessment, which includes 100% of the NND Project, is based on the SCDOR’s position that DESC’s sales and use tax exemption for the NND Project does not apply because the facility will not become operational. DESC has protested the proposed assessment, which remains pending.

In September and October 2017, SCANA was served with subpoenas issued by the U.S. Attorney’s Office for the District of South Carolina and the Staff of the SEC’s Division of Enforcement seeking documents related to the NND Project. In February 2020, the SEC filed a complaint against SCANA, two of its former executive officers and DESC in the U.S. District Court for the District of South Carolina alleging that the defendants violated federal securities laws by making false and misleading statements about the NND Project. In April 2020, SCANA and DESC reached an agreement in principle with the Staff of the SEC’s Division of Enforcement to settle, without admitting or denying the allegations in the complaint. The Staff of the SEC’s Division of Enforcement has not yet presented the proposed settlement to the SEC. The agreement in principle would, among other things, require SCANA to pay a civil monetary penalty totaling $25 million, and SCANA and DESC to pay disgorgement and prejudgment interest totaling $112.5 million,

which disgorgement and prejudgment interest amount will be deemed satisfied by the settlements in the SCANA Securities Class Action and the DESC Ratepayer Case. The proposed settlement is contingent on the review and approval of final documentation by SCANA, DESC and the Staff of the SEC’s Division of Enforcement and is subject to approval by the SEC and the U.S. District Court for the District of South Carolina. In June 2020, the U.S. Attorney’s Office for the District of South Carolina filed a motion to intervene and stay the SEC civil action, which the court granted. The stay is currently in effect but does not preclude the SEC’s Division of Enforcement from presenting the proposed settlement with SCANA and DESC to the SEC. This matter is pending.

In addition, the South Carolina Law Enforcement Division is conducting a criminal investigation into the handling of the NND Project by SCANA and DESC. ~~These matters are pending. SCANA and DESC are~~Dominion Energy is cooperating fully with the investigations by the U.S. Attorney’s Office and the South Carolina Law Enforcement Division, including responding to additional subpoenas and document requests. Dominion Energy has also entered into a cooperation agreement with the U.S. Attorney’s Office and the South Carolina Attorney General’s Office. The cooperation agreement provides that in consideration of its full cooperation with these investigations to the satisfaction of both agencies, neither such agency will criminally prosecute or bring any civil action against Dominion Energy or any of its current, previous, or future direct or indirect subsidiaries related to the NND Project. A former executive officer of SCANA entered a plea agreement with the U.S. Attorney’s Office and the South Carolina Attorney General’s Office in June 2020 and entered a guilty plea with the U.S. District Court for the District of South Carolina in July 2020. These matters are pending.

In December 2018, arbitration proceedings commenced between DESC and Cameco Corporation related to a supply agreement signed in May 2008. This agreement provides the terms and conditions under which DESC agreed to purchase uranium hexafluoride from Cameco Corporation over a period from 2010 to 2020. Cameco Corporation alleges that DESC violated this agreement by failing to

purchase the stated quantities of uranium hexafluoride for the 2017 and 2018 delivery years. DESC denies that it is in breach of the agreement and believes that it has reduced its purchase quantity within the terms of the agreement. This matter is pending.

In September 2019, a South Carolina state court jury awarded a judgment to the estate of Jose Larios in a wrongful death suit filed in June 2017 against DESC, of which DESC was apportioned $19 million. DESC holds general liability insurance coverage which is expected to provide payment for substantially all DESC’s liability in this matter. In October 2019, DESC filed a motion requesting a reduction in the judgment or, in the alternative, a new trial. In November 2019,DESC’s motion for a new trial was granted, setting aside the entire verdict amount. This matter is pending.

Westinghouse’s ~~reorganization plan~~Reorganization Plan became effective August 1, 2018. Initially, Westinghouse had projected that its ~~reorganization plan~~Reorganization Plan would pay in full or nearly in full its pre-petition trade creditors, including several of the Westinghouse Subcontractors which have alleged non-payment by the Consortium for amounts owed for work performed on the NND Project and have filed liens on related property in Fairfield County, South Carolina. DESC is contesting approximately $285 million of such filed liens. Most of these asserted liens are “pre-petition” claims that relate to work performed by Westinghouse Subcontractors before the Westinghouse bankruptcy, although some of them are “post-petition” claims arising from work performed after the Westinghouse bankruptcy. It is possible that the ~~reorganization plan~~Reorganization Plan will not provide for payment in full or nearly in full to its pre-petition trade creditors. The shortfall could be significant. In addition, payments under the Toshiba Settlement are subject to reduction if Westinghouse pays Westinghouse Subcontractors holding pre-petition liens directly. Under these circumstances, DESC and Santee Cooper, each in its pro rata share, would be required to make Citibank, N.A., which purchased the scheduled payments under the Toshiba Settlement, whole for reductions related to valid subcontractor and vendor pre-petition liens up to $60 million ($33 million for DESC's 55% share).

DESC and Santee Cooper ~~are~~were responsible for amounts owed to Westinghouse for valid work performed by Westinghouse Subcontractors on the NND Project after the Westinghouse bankruptcy filing (i.e., post-petition) until termination of the IAA (the IAA Period). In the Westinghouse bankruptcy proceeding, deadlines were established for creditors of Westinghouse to assert the amounts owed to such creditors prior to the Westinghouse bankruptcy filing and during the IAA Period. Many of the Westinghouse Subcontractors have filed such claims. In December 2019, DESC ~~does not believe that the~~and Santee Cooper entered into a confidential settlement agreement with W Wind Down Co LLC resolving claims ~~asserted related~~relating to the IAA Period will exceed the amounts previously funded for the currently asserted IAA-related claims, whether relating to claims already paid or those remaining to be paid. DESC intends to oppose any previously unasserted claim that is asserted against it, whether directly or indirectly by a claim through the IAA.

Further, some Westinghouse Subcontractors who have made claims against Westinghouse in the bankruptcy proceeding also filed against DESC and Santee Cooper in South Carolina state court for damages. The Westinghouse Subcontractor claims in South Carolina state court include common law claims for pre-petition work, IAA Period work, and work after the termination of the IAA. Many of these claimants have also asserted construction liens against the NND Project site. While DESC cannot be assured that it will not have any exposure on account of unpaid Westinghouse Subcontractor claims, which claims DESC is presently disputing, DESC believes it is unlikely that it will be required to make payments on account of such claims.

Under Price-Anderson, DESC (for itself and on behalf of Santee-Cooper) maintains agreements of indemnity with the U.S. Nuclear Regulatory Commission that, together with private insurance, cover third-party liability arising from any nuclear incident occurring at Summer. Price-Anderson provides funds up to ~~$14.0~~$13.8 billion for public liability claims that could arise from a single nuclear incident. Each nuclear plant is insured against this liability to a maximum of $450 million by American Nuclear Insurers with the remaining coverage provided by a mandatory program of deferred premiums that could be assessed, after a nuclear incident, against all owners of commercial nuclear reactors. Each reactor licensee is liable for up to $138 million per reactor owned for each nuclear incident occurring at any reactor in the U.S., provided that not more than $21 million of the liability per reactor would be assessed per year. DESC’s maximum assessment, based on its two-thirds ownership of Summer, would be $92 million per incident, but not more than $14 million per year. Both the maximum assessment per reactor and the maximum yearly assessment are adjusted for inflation at least every five years.

DESC currently maintains insurance policies (for itself and on behalf of Santee Cooper) with NEIL. The policies provide coverage to Summer for property damage and outage costs up to $2.75 billion resulting from an event of nuclear origin and up to $2.33 billion resulting from an event of a non-nuclear origin. The NEIL policies in aggregate, are subject to a maximum loss of $2.75 billion for any single loss occurrence. The NEIL policies permit retrospective assessments under certain conditions to cover insurer’s losses. Based on the current annual premium, DESC’s portion of the retrospective premium assessment would not exceed $24 million. DESC currently maintains an excess property insurance policy (for itself and on behalf of Santee Cooper) with EMANI. The policy provides coverage to Summer for property damage and outage costs up to $415 million resulting from an event of a non-nuclear origin. The EMANI policy permits retrospective assessments under certain conditions to cover insurer's losses. Based on the current annual premium, DESC's portion of the retrospective premium assessment would not exceed $2 million.

To the extent that insurable claims for property damage, decontamination, repair and replacement and other costs and expenses arising from an incident at Summer exceed the policy limits of insurance, or to the extent such insurance becomes unavailable in the future, and to the extent that DESC's rates would not recover the cost of any purchased replacement power, DESC will retain the risk of loss as a self-insurer. DESC has no reason to anticipate a serious nuclear or other incident. However, if such an incident were to occur, it likely would have a material impact on DESC's results of operations, cash flows and financial position.

~~At June 30, 2019, DESC had the following lease assets and liabilities recorded in the Consolidated Balance Sheets:~~

~~For the three and six months ended June 30, 2019, total lease cost consisted of the following:~~

For the six months ended June 30, 2019, cash paid for amounts included in the measurement of lease liabilities consisted of the following amounts, included in the Consolidated Statements of Cash Flows:

~~At June 30, 2019, the weighted average remaining lease term and weighted average discount rate for finance and operating leases were as follows:~~

~~Operating~~In December 2019, DESC realigned its segments ~~include Electric Operations and Gas Distribution and are organized primarily on~~which resulted in the ~~basis~~formation of ~~products and services sold.~~a single primary operating segment. The historical information presented herein has been recast to reflect the current segment presentation.

In connection with the SCANA Combination, effective January 2019, reportable segments were changed to include a Corporate and Other segment and to utilize comprehensive income (loss) as the measure of segment profitability. The Corporate and Other segment includes specific items attributable to ~~DESC's~~its operating ~~segments~~segment that are not included in profit measures evaluated by executive management in assessing the ~~segments'~~segment’s performance or in allocating resources. ~~Corresponding amounts~~

In the six months ended June 30, 2020, DESC reported after-tax net expense of $7 million for specific items in ~~prior periods have been recast~~the Corporate and Other segment, all of which was attributable to ~~conform to the current presentation.~~

its operating segment. In the six months ended June 30, 2019, DESC reported after-tax net expenses of $1.3 billion for specific items in the Corporate and Other segment, with $1.4 billion attributable to its operating ~~segments.~~segment.

The net expense for specific items attributable to DESC’s operating ~~segments~~segment in 2019 primarily related to the impact of the following items:

(millions)

External
Revenue

Comprehensive
Income (Loss)
Available
(Attributable) to
Common
Shareholder

Three Months Ended June 30, 2019

Electric Operations

$
620

$
104

Gas Distribution

78

(8
)
Corporate and Other

—

(166
)
Adjustments/Eliminations

—

(8
)
Consolidated Total

$
698

$
(78
)

Three Months Ended June 30, 2018

Electric Operations

$
553

$
30

Gas Distribution

79

(3
)
Corporate and Other

—

4

Adjustments/Eliminations

—

(5
)
Consolidated Total

$
632

$
26

Six Months Ended June 30, 2019

Electric Operations

$
1,147

$
152

Gas Distribution

225

14

Corporate and Other

(1,009
)

(1,339
)
Adjustments/Eliminations

—

(14
)
Consolidated Total

$
363

$
(1,187
)

Six Months Ended June 30, 2018

Electric Operations

$
1,100

$
130

Gas Distribution

234

29

Corporate and Other

—

—

Adjustments/Eliminations

—

(9
)
Consolidated Total

$
1,334

$
150

(millions)	External Revenue			Comprehensive Income (Loss) Available (Attributable) to Common Shareholder
Three Months Ended June 30, 2020
Dominion Energy South Carolina	$	624		$	77
Corporate and Other		—			(8	)
Consolidated Total	$	624		$	69

Three Months Ended June 30, 2019
Dominion Energy South Carolina	$	698		$	88
Corporate and Other		—			(166	)
Consolidated Total	$	698		$	(78	)

Six Months Ended June 30, 2020
Dominion Energy South Carolina	$	1,296		$	166
Corporate and Other		—			(9	)
Consolidated Total	$	1,296		$	157

Six Months Ended June 30, 2019
Dominion Energy South Carolina	$	1,372		$	152
Corporate and Other		(1,009	)		(1,339	)
Consolidated Total	$	363		$	(1,187	)

DESC owns 40% of Canadys Refined Coal, LLC, which is involved in the manufacturing and sale of refined coal to reduce emissions at certain of DESC's generating facilities. DESC accounts for this investment using the equity method. Purchases and sales of the related coal are recorded as other income (expense), net in the Consolidated Statements of Comprehensive Income (Loss).

DESC purchases natural gas and related pipeline capacity from ~~SCANA Energy Marketing, Inc.~~SEMI to serve its retail gas customers and to satisfy certain electric generation requirements. These purchases are included within gas purchased for resale or fuel used in electric generation, as applicable in the Consolidated Statements of Comprehensive Income (Loss).

DESS, on behalf of itself and its parent company, provides the following services to DESC, which are rendered at direct or allocated cost: information systems, telecommunications, customer support, marketing and sales, human resources, corporate compliance, purchasing, financial, risk management, public affairs, legal, investor relations, gas supply and capacity management, strategic planning, general administrative and retirement benefits. In addition, DESS processes and pays invoices for DESC and is reimbursed. Costs for these services include amounts capitalized. Amounts expensed are primarily recorded in other operations and maintenance - affiliated suppliers and other income (expense), net in the Consolidated Statements of Comprehensive Income (Loss).

	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,				Six Months Ended June 30,
(millions)	2019		2018		2019		2018		2020		2019		2020		2019
Purchases of coal from affiliate	$	34	$	45	$	62	$	77	$	—	$	34	$	—	$	62
Sales of coal to affiliate		34		45		62		77		—		34		—		62
Purchases of fuel used in electric generation from affiliate		10		29		43		60		—		10		—		43
Direct and allocated costs from services company affiliate⁽¹⁾		82		76		140		135
Direct and allocated costs from DESS⁽¹⁾										63		82		130		140
Operating Revenues - Electric from sales to affiliate		1		1		2		2		2		1		2		2
Operating Expenses - Other taxes from affiliate		1		1		3		3		1		1		4		3
Purchases of electricity from solar affiliates										4		3		6		4
Demand and transportation charges from DECG - Fuel used in electric generation										5		6		9		9
Demand and transportation charges from DECG - Gas purchased for resale										11		11		22		23

(millions)	June 30, 2019		December 31, 2018		June 30, 2020		December 31, 2019
Receivable from Canadys Refined Coal, LLC	$	10	$	7	$	—	$	2
Payable to Canadys Refined Coal, LLC		10		7		—		2
Payable to SCANA Energy Marketing, Inc.		—		14
Payable to DESS		63		38		59		76
Payable to Public Service Company of North Carolina, Incorporated						3		8
Payable to solar affiliates						2		—
Receivable from DECG						—		1
Payable to DECG						5		5

In connection with the SCANA Combination, purchases from certain entities owned by Dominion Energy became affiliated transactions. During the three and six months ended June 30, 2019, DESC purchased electricity generated by two such affiliates, Ridgeland Solar Farm I, LLC and Moffett Solar 1, LLC, totaling $3 million and $4 million, respectively, which is recorded as purchased power in the Consolidated Statements of Comprehensive Income (Loss). At June 30, 2019, DESC had accounts payable balances to these affiliates totaling $1 million. In addition, during the three and six months ended June 30, 2019, DESC incurred demand and transportation charges from Dominion Energy Carolina Gas Transmission, LLC totaling $17 million and $32 million, respectively, of which $6 million and $9 million, respectively, is recorded as fuel used in electric generation and $11 million and $23 million, respectively, is recorded as gas purchased for resale in the Consolidated Statements of Comprehensive Income (Loss). At June 30, 2019, DESC had an accounts payable balance due to this affiliate totaling $5 million.

	Three Months Ended June 30,						Six Months Ended June 30,						Three Months Ended June 30,						Six Months Ended June 30,
(millions)	2019			2018			2019			2018			2020			2019			2020			2019
Revenues from contracts with customers	$	2		$	2		$	3		$	3		$	—		$	2		$	1		$	3
Other income		2			4			6			130			4			2			7			6
Other expense		(15	)		(5	)		(25	)		(12	)		(3	)		(15	)		(5	)		(25	)
Allowance for equity funds used during construction		2			1			2			4			1			2			2			2
Other income (expense), net	$	(9	)	$	2		$	(14	)	$	125		$	2		$	(9	)	$	5		$	(14	)

~~Other income in 2018 includes gains from the settlement of interest rate derivatives of $115 million (see Note 7).~~ Non-service cost components of pension and other postretirement benefits are included in other ~~expense.~~income (expense).

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

MD&A provides management’s narrative analysis of its consolidated results of ~~operation.~~operations. MD&A should be read in conjunction with DESC's Consolidated Financial Statements. DESC meets the conditions to file under the reduced disclosure format, and therefore has omitted certain sections of MD&A.

This report contains statements concerning DESC’s expectations, plans, objectives, future financial performance and other statements that are not historical facts. These statements are “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995. In most cases, the reader can identify these forward-looking statements by such words as “anticipate,” “estimate,” “forecast,” “expect,” “believe,” “should,” “could,” “plan,” “may,” “continue,” “target” or other similar words.

DESC makes forward-looking statements with full knowledge that risks and uncertainties exist that may cause actual results to differ materially from predicted results. Factors that may cause actual results to differ are often presented with the forward-looking statements themselves. Additionally, other factors may cause actual results to differ materially from those indicated in any forward-looking statement. These factors include but are not limited to:

Additionally, other risks that could cause actual results to differ from predicted results are set forth in Part ~~II,~~I. Item 1A. Risk Factors in ~~this report.~~DESC’s Annual Report on Form 10-K for the year ended December 31, 2019, as updated in Part II. Item 1A. Risk Factors in its Quarterly Report on Form 10-Q for the quarter ended March 31, 2020.

DESC’s forward-looking statements are based on beliefs and assumptions using information available at the time the statements are made. DESC cautions the reader not to place undue reliance on its forward-looking statements because the assumptions, beliefs, expectations and projections about future events may, and often do, differ materially from actual results. DESC undertakes no obligation to update any forward-looking statement to reflect developments occurring after the statement is made.

	Second Quarter								Year-To-Date								Second Quarter							Year-To-Date
(millions)	2019			2018		$ Change			2019			2018		$ Change			2020		2019			$ Change		2020		2019			$ Change
Net income (loss)	$	(70	)	$	31	$	(101	)	$	(1,173	)	$	159	$	(1,332	)	$	67	$	(70	)	$	137	$	160	$	(1,173	)	$	1,333

Net income ~~decreased $101~~increased $137 million, primarily due to the absence of charges related to litigation and a voluntary retirement program. ~~These decreases were partially offset by the absence of a charge associated with South Carolina legislation enacted in the second quarter of 2018.~~

Net income ~~decreased~~increased $1.3 billion, primarily due to the absence of charges for refunds of amounts previously collected from retail electric customers for the NND Project, certain regulatory assets and utility plant for which DESC committed to forgo recovery, litigation and a voluntary retirement program. ~~These decreases were partially offset by the absence of a charge associated with South Carolina legislation enacted in the second quarter of 2018.~~

	Second Quarter								Year-To-Date								Second Quarter								Year-To-Date
(millions)	2019			2018		$ Change			2019			2018		$ Change			2020		2019			$ Change			2020		2019			$ Change
Operating revenues	$	698		$	632	$	66		$	363		$	1,334	$	(971	)	$	624	$	698		$	(74	)	$	1,296	$	363		$	933
Fuel used in electric generation		143			155		(12	)		280			315		(35	)		95		143			(48	)		199		280			(81	)
Purchased power		12			15		(3	)		20			67		(47	)		25		12			13			38		20			18
Gas purchased for resale		44			45		(1	)		121			121		—			34		44			(10	)		91		121			(30	)
Net revenue		499			417		82			(58	)		831		(889	)		470		499			(29	)		968		(58	)		1,026
Other operations and maintenance		195			164		31			339			310		29			143		195			(52	)		288		339			(51	)
Impairment of assets and other charges		100			—		100			371			4		367			—		100			(100	)		2		371			(369	)
Depreciation and amortization		115			81		34			217			161		56			118		115			3			236		217			19
Other taxes		72			65		7			141			129		12			65		72			(7	)		127		141			(14	)
Other income (expense), net		(9	)		2		(11	)		(14	)		125		(139	)		2		(9	)		11			5		(14	)		19
Interest charges		63			76		(13	)		136			152		(16	)		58		63			(5	)		116		136			(20	)
Income tax expense (benefit)		15			2		13			(103	)		41		(144	)		21		15			6			44		(103	)		147

Other operations and maintenance ~~increased 19%~~decreased 27%, primarily due to the absence of a charge related to a voluntary retirement program ($50 million) and a decrease in salaries, wages and benefits and administrative expenses ($4 million), partially offset by ~~lower legal costs ($9 million) and lower non-labor electric generation expenses~~an increase in allowance for credit risk on customer accounts related to COVID-19 ($5 million).

Impairment of assets and other charges ~~increased~~decreased $100 million, due to the absence of a charge related to litigation.

~~Depreciation and amortization~~ ~~increased 42%, primarily reflecting the amortization of NND Project costs.~~

Other taxes ~~increased 11%~~decreased 10%, ~~primarily~~ due to ~~higher~~a decrease in property taxes ~~associated with net plant additions~~ ($4 million) and the absence of a charge related to a voluntary retirement program ($3 million).

Other income (expense), net ~~decreased~~increased $11 million, primarily due to the absence of a charge related to a voluntary retirement program.

~~Interest charges~~Income tax expense ~~decreased 17%~~increased 40%, primarily due to ~~lower long-term debt principal balances as a result~~higher pre-tax income ($30 million) partially offset by the absence of ~~the debt tender offers completed in the first quarter of 2019.~~

~~Income tax expense~~ ~~increased $13 million, primarily due to~~ changes in unrecognized tax benefits ($~~26 million), partially offset by lower pre-tax income ($13~~23 million).

Net revenue ~~decreased by $889 million,~~increased $1.0 billion, primarily due to:

Other operations and maintenance ~~increased 9%~~decreased 15%, primarily due to the absence of a charge related to a voluntary retirement program ($50 million), lower legal and NND Project wind down costs ($8 million) and a decrease in salaries, wages and benefits and

administrative expenses ($5 million) partially offset by ~~lower non-labor electric generation expenses~~an increase in allowance for credit risk on customer accounts related to COVID-19 ($~~9 million) and lower legal costs ($8~~5 million).

Impairment of assets and other charges ~~increased $367 million,~~decreased 99%, primarily due to a$ reduction in charges associated with litigation ($266 ~~million charge related to litigation~~million) and a ~~$105 million charge~~decrease in charges for utility plant for which DESC committed to forgo ~~recovery.~~recovery ($103 million).

~~Depreciation and amortization~~Other taxes ~~increased 35%~~decreased 10%, primarily ~~reflecting~~due to a decrease in property taxes ($10 million) and the ~~amortization~~absence of ~~NND Project costs.~~a charge related to a voluntary retirement program ($3 million).

Other income (expense), net ~~decreased $139~~increased $19 million, primarily due to the absence of gains realized upon the settlement of interest rate derivative contracts in 2018 ($115 million) that were fully offset by downward adjustments to electric revenues pursuant to a previously received South Carolina Commission order related to fuel cost recovery and therefore had no effect on net income and a charge related to a voluntary retirement program ($9 million) and a decrease in donations ($4 million).

Interest charges decreased ~~11%~~15%, primarily due to lower long-term debt principal balances primarily as a result of the debt tender offers completed in 2019 ($15 million) and lower money pool interest ($5 million) partially offset by higher interest related to the ~~first quarter of 2019.~~intercompany credit agreement ($6 million).

Income tax expense ~~decreased $144~~increased $147 million, primarily due to ~~lower pre-tax~~the absence of a charge for certain income ~~($410 million), partially offset by a tax charge related to~~tax-related regulatory assets for which DESC committed to forgo recovery ($198 million) and ~~change~~the absence of changes in unrecognized tax benefits ($6663 million), partially offset by higher pretax income ($409 million).

Senior management of ~~June 30, 2019, management has evaluated, with the participation of the~~DESC, including DESC’s CEO and CFO, ~~(a)~~evaluated the effectiveness of ~~the design and operation of~~DESC’s disclosure controls and procedures ~~(as defined in Rules 13a-15(e) and 15d-15(e)~~as of the ~~Exchange Act) and (b) any change in internal control over financial reporting (as defined in Rules 13a-15(f) and 15d-15(f)~~end of the ~~Exchange Act).~~period covered by this report. Based on this evaluation ~~the~~process, DESC’s CEO and CFO have concluded that ~~as of June 30, 2019, these~~DESC’s disclosure controls and procedures are effective.

There were ~~effective. There has been~~ no ~~change in internal control over financial reporting~~changes that occurred during the last fiscal quarter ~~ended June 30, 2019~~ that ~~has~~have materially affected, or isare reasonably likely to materially affect, DESC’s internal control over financial reporting.

From time to time, DESC is alleged to be in violation or in default under orders, statutes, rules or regulations relating to the environment, compliance plans imposed upon or agreed to by DESC, or permits issued by various local, state and/or federal agencies for the construction or operation of facilities. Administrative proceedings may also be pending on these matters. In addition, DESC is involved in various legal proceedings from time to time, whether in the ordinary course of business or particularly following the abandonment of the NND Project.

See the following for discussions on various legal, environmental and other regulatory proceedings to which DESC is a party, which information is incorporated herein by reference:

DESC’s business is influenced by many factors that are difficult to predict, involve uncertainties that may materially affect actual results and are often beyond its control. A number of these risk factors have been identified in DESC’s Annual Report on Form 10-K for the year ended December 31, ~~2018,~~2019 and updated in its Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, which should be taken into consideration when reviewing the information contained in this report. DESC filed such annual report on a combined basis with SCANA. Accordingly, the information presented in such risk factors is presented on a combined basis and therefore some of the information may apply only to SCANA and not DESC. DESC makes no representation as to any such information. There have been no material changes with regard to the risk factors previously disclosed in DESC's Annual Report on Form 10-K for the year ended December 31, ~~2018.~~2019 and its Quarterly Report on Form 10-Q for the quarter ended March 31, 2020. For other factors that may cause actual results to differ materially from those indicated in any forward-looking statement or projection contained in this report, see Forward-Looking Statements in ~~Part I, Item 2.~~ MD~~&A.~~&A in this report.

~~Exhibits filed or furnished with this Quarterly Report on Form 10-Q are listed in the following Exhibit Index.~~

As permitted under Item 601(b) (4) (iii) of Regulation S-K, instruments defining the rights of holders of long-term debt of less than 10% of the total consolidated assets of DESC, for itself and its consolidated affiliates, have been omitted and DESC agrees to furnish a copy of such instruments to the SEC upon request.

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

~~South Carolina~~	~~57-0248695~~
~~State or Other Jurisdiction of Incorporation or Organization~~	I.R.S. Employer
Commission File Number	Exact name of registrant as specified in its charter	Identification ~~No.~~Number

001-3375	DOMINION ENERGY SOUTH CAROLINA, INC.	57-0248695

	south carolina
	(State or other jurisdiction of incorporation or organization)

	400 ~~Otarre Parkway, Cayce, South Carolina~~OTARRE PARKWAY
	CAYCE, South Carolina	29033
~~Address of Principal Executive Offices~~	(Address of principal executive offices)	(Zip ~~Code~~Code)

	(803) 217-9000
	(Registrants’ telephone number)

		Page
	Glossary of Terms	3

PART I. FINANCIAL INFORMATION

Item 1.	Financial Statements	5

Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	3130

Item 4.	Controls and Procedures	3433

PART II. OTHER INFORMATION

Item 1.	Legal Proceedings	3534

Item 1A.	Risk Factors	3534

Item 6.	Exhibits	3635

Abbreviation or Acronym		Definition
MGP		Manufactured gas plant
MW		~~Megawatt~~
NEIL		Nuclear Electric Insurance Limited
NO_X		~~Nitrogen oxide~~
~~NPDES~~		~~National Pollutant Discharge Elimination System~~
NND Project		V. C. Summer Units 2 and 3 nuclear development project under which ~~SCANA~~DESC and Santee Cooper undertook to construct two Westinghouse AP1000 Advanced Passive Safety nuclear units in Jenkinsville, South Carolina
~~ORS~~NO_x		~~South Carolina Office of Regulatory Staff~~Nitrogen oxide

~~Abbreviation or Acronym~~NSPS		~~Definition~~New Source Performance Standards
Order 1000		Order issued by FERC adopting requirements for electric transmission planning, cost allocation and development
Price-Anderson		Price-Anderson ~~Nuclear Industries Indemnity~~Amendments Act of 1988
PSD		Prevention of significant deterioration
Questar Gas		Questar Gas Company, a wholly-owned subsidiary of Dominion Energy
Reorganization Plan		Modified Second Amended Joint Chapter 11 Plan of Reorganization, filed by Westinghouse
RICO		Racketeer Influenced and Corrupt Organizations Act
Santee Cooper		South Carolina Public Service Authority
SCANA		The legal entity, SCANA Corporation, one or more of its consolidated subsidiaries (other than DESC) or the entirety of SCANA Corporation and its consolidated subsidiaries
SCANA Combination		Dominion Energy's acquisition of SCANA completed on January 1, 2019 pursuant to the terms of the SCANA Merger Agreement
SCANA Merger Agreement		Agreement and plan of merger entered on January 2, 2018 between Dominion Energy and SCANA
SCANA Merger Approval Order		Final order issued by the South Carolina Commission on December 21, 2018 setting forth its approval of the SCANA Combination
SCDHEC		South Carolina Department of Health and Environmental Control
SCDOR		South Carolina Department of Revenue
SEC		U.S. Securities and Exchange Commission
SEMI		SCANA Energy Marketing, LLC (formerly known as SCANA Energy Marketing, Inc.), a subsidiary of SCANA through December 2019, and effective December 2019, a subsidiary of Wrangler Retail Gas Holdings, LLC, a partnership between Dominion Energy and Interstate Gas Supply Inc.
SO₂		Sulfur dioxide
South Carolina Commission		Public Service Commission of South Carolina
Southern		The legal entity, The Southern Company, one or more of its consolidated subsidiaries, or the entirety of The Southern Company and its consolidated subsidiaries
Summer		V. C. Summer nuclear power station
Toshiba		Toshiba Corporation, parent company of Westinghouse
Toshiba Settlement		Settlement Agreement dated as of July 27, 2017, by and among Toshiba, DESC and Santee Cooper
VIE		Variable interest entity
Virginia Power		The legal entity, Virginia Electric and Power Company, a wholly-owned subsidiary of Dominion Energy, one or more of its consolidated subsidiaries or operating segment, or the entirety of Virginia Electric and Power Company and its consolidated subsidiaries
VOC		Volatile organic compounds
WECTEC		WECTEC Global Project Services, Inc. ~~(formerly known as Stone & Webster, Inc.)~~, a wholly-owned subsidiary of Westinghouse
Westinghouse		Westinghouse Electric Company LLC
Westinghouse Subcontractors		Subcontractors and suppliers to the Consortium

(millions)	June 30, 2019
Lease assets:
Operating lease assets⁽¹⁾	$	20
Finance lease assets⁽²⁾		28
Total lease assets	$	48
Lease liabilities:
Operating lease - current⁽³⁾	$	2
Operating lease - noncurrent⁽⁴⁾		16
Finance lease - current⁽⁵⁾		7
Finance lease - noncurrent⁽⁶⁾		22
Total lease liabilities	$	47


☒	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934


☐	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Large accelerated filer	☐		Accelerated filer	☐	Emerging growth company	☐
Non-accelerated filer	☒		Smaller reporting company	☐

(millions)	Increase (Decrease) in Derivatives Subject to Regulatory Treatment⁽¹⁾						Amount of Gain (Loss) Recognized in Income on Derivatives⁽²⁾
Three Months Ended June 30,	2019			2018		Location	2019		2018
Derivative type and location of gains (losses):
Interest rate contracts:						Interest charges	$	—	$	(1	)
						Other income		—		—
Total interest rate contracts	$	(2	)	$	—		$	—	$	(1	)
Six Months Ended June 30,
Derivative type and location of gains (losses):
Interest rate contracts:						Interest charges	$	—	$	(1	)
						Other income		—		115
Total interest rate contracts	$	(3	)	$	65		$	—	$	114

(millions)	Level 1		Level 2		Level 3		Total
At June 30, 2020
Liabilities
Interest rate	$	—	$	31	$	—	$	31
Total liabilities	$	—	$	31	$	—	$	31
At December 31, 2019
Liabilities
Interest rate	$	—	$	19	$	—	$	19
Total liabilities	$	—	$	19	$	—	$	19

(millions)	Amount
AROs at December 31, 2019	$	489
Liabilities settled		(2	)
Accretion expense		11
Revisions in estimated cash flows ⁽¹⁾		89
AROs at June 30, 2020	$	587

	~~Six Months Ended~~
~~(millions)~~	~~June 30, 2019~~
~~Operating cash flows from finance leases~~	$	—
~~Operating cash flows from operating leases~~		2
~~Financing cash flows from finance leases~~		4

	~~June 30, 2019~~
~~Weighted average remaining lease term - finance leases~~	~~5 years~~
~~Weighted average remaining lease term - operating leases~~	~~21 years~~
~~Weighted average discount rate - finance leases~~		~~2.97~~	%
~~Weighted average discount rate - operating leases~~		~~4.53~~	%

(millions)	Operating			Finance
2019	$	2		$	4
2020		2			8
2021		2			6
2022		1			5
2023		1			3
After 2023		22			5
Total undiscounted lease payments		30			31
Present value adjustment		(12	)		(2	)
Present value of lease liabilities	$	18		$	29

Exhibit No.		Description
3.1		Amended and Restated Articles of Incorporation, effective April 29, 2019 (Exhibit 3.1, Form 8-K filed April 29, 2019, File No. 1-3375).
3.2		Amended and Restated Bylaws, effective April 29, 2019 (Exhibit 3.2, Form 8-K filed April 29, 2019, File No. 1-3375).
~~31.1~~4.1		Dominion Energy South Carolina, Inc. agrees to furnish to the U.S. Securities and Exchange Commission upon request any instrument with respect to long-term debt as to which the total amount of securities authorized does not exceed 10% of its total consolidated assets.
31.a		Certification by Chief Executive Officer of Dominion Energy South Carolina, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
~~31.2~~31.b		Certification by Chief Financial Officer of Dominion Energy South Carolina, Inc. pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 (filed herewith).
~~32.1~~32.a		Certification to the Securities and Exchange Commission by Chief Executive Officer and Chief Financial Officer of Dominion Energy South Carolina, Inc. as required by Section 906 of the Sarbanes-Oxley Act of 2002 (furnished herewith).
101		The following financial statements from Dominion Energy South Carolina, Inc.’s Quarterly Report on Form 10-Q for the quarter ended June 30, ~~2019,~~2020, filed on August ~~2, 2019,~~5, 2020, formatted in iXBRL (Inline eXtensible Reporting Language): (i) Consolidated Balance Sheets, (ii) Consolidated Statements of Comprehensive Income (Loss), (iii) Consolidated Statements of Cash Flows, (iv) Consolidated Statements of Changes in Common Equity, and (v) the Notes to Consolidated Financial Statements.
104		Cover Page Interactive Data File (formatted in iXBRL (Inline eXtensible Reporting Language) and contained in Exhibit 101).

	DOMINION ENERGY SOUTH CAROLINA, INC.
		(Registrant)

	By:	/s/ Michele L. Cardiff
Date: August ~~2, 2019~~5, 2020		Michele L. Cardiff
		Vice President, Controller and Chief Accounting Officer