Rate and Other Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2022

Schedule of Regulatory Assets and Liabilities


At December 31,	2022		2021
(millions)
Regulatory assets:
NND Project costs(1)	$	138	$	138
Deferred employee benefit plan costs(2)		4		8
Other unrecovered plant(3)		17		16
DSM programs(4)		21		23
Cost of fuel and purchased gas under-collections(5)		508		126
Other		55		50
Regulatory assets - current		743		361
NND Project costs(1)		2,088		2,226
AROs(6)		381		311
Deferred employee benefit plan costs(2)		161		106
Interest rate hedges(7)		169		170
Other unrecovered plant(3)		58		57
DSM programs(4)		41		45
Environmental remediation costs(8)		37		30
Deferred storm damage costs(9)		43		38
Deferred transmission operating costs(10)		75		77
Derivatives(11)		105		125
Other(12)		131		138
Regulatory assets - noncurrent		3,289		3,323
Total regulatory assets	$	4,032	$	3,684
Regulatory liabilities:
Monetization of guaranty settlement(13)	$	67	$	67
Income taxes refundable through future rates(14)		34		42
Reserve for refunds to electric utility customers(15)		100		113
Derivatives(11)		43		20
Other		7		3
Regulatory liabilities - current		251		245
Monetization of guaranty settlement(13)		702		831
Income taxes refundable through future rates(14)		871		903
Asset removal costs(16)		596		570
Reserve for refunds to electric utility customers(15)		325		425
Derivatives(11)		276		198
Other		15		9
Regulatory liabilities - noncurrent		2,785		2,936
Total regulatory liabilities	$	3,036	$	3,181

(1)

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.

(2)

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.

(3)

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 following depreciation amounts that were designed to recover the retired units cost over their previous estimated remaining useful lives, which has been estimated to be through 2025. Based on current projections of remaining decommissioning costs, projected recovery is expected to extend through 2029. In addition, amounts include unrecovered costs of existing meters and equipment retired from service prior to being fully depreciated as part of the Advanced Metering Infrastructure project, which are being recovered through rates through 2028. This amount also includes certain inventory and preliminary survey and investigation charges being amortized over five years related to the transition or conversion from coal to gas fired generation at certain facilities. In addition, reflects an increase of approximately $7 million related to the abandonment of certain peaking gas generation facilities, such amounts having been reclassified from property, plant and equipment to noncurrent other unrecovered plant. Unamortized amounts are included in rate base and are earning a current return.

(4)

Represents deferred costs associated with electric demand reduction programs, and such deferred costs are currently being recovered over three years through an approved rate rider.

(5)

Represents amounts under- or over-collected from customers pursuant to the cost of fuel components approved by the South Carolina Commission.

(6)

Represents 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 105 years.

(7)

Represents the changes in fair value and payments made or received upon settlement of certain interest rate derivatives designated as cash flow hedges. The amounts recorded are expected to be amortized to interest expense over the lives of the underlying debt through 2065.

(8)

Reflects amounts 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 27 years. See Note 12 for additional information.

(9)

Represents storm restoration costs for which DESC expects to receive future recovery through customer rates over approximately 10 years pursuant to the settlement agreement approved in DESC’s retail electric base rate case. Unamortized amounts are included in rate base and are earning a current return.

(10)

Includes deferred depreciation and property taxes associated with certain transmission assets for which DESC expects recovery from customers through future rates over approximately 42 years pursuant to the settlement agreement approved in DESC’s retail electric base rate case. Unamortized amounts are included in rate base and earning a current return. See Note 12 for additional information.

(11)

Represents changes in the fair value of derivatives, excluding separately presented interest rate hedges, that following settlement are expected to be recovered from or refunded to customers.

(12)

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

(13)

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 liens, will be refunded to electric customers over a 20-year period ending in 2039.

(14)

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 Note 7 for additional information.

(15)

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 effective February 2019 in connection with the SCANA Merger Approval Order.

(16)

Represents estimated net collections through depreciation rates of amounts to be expended for the removal of assets in the future.