DOMINION ENERGY, INC
For the period ended Sep 30, 2026. Filed Oct 30, 2026.
View on SEC.govAbout this filing
A company's report for each of its first three quarters. The financial statements are not audited. It shows how the business has moved since the last annual report, and what management says changed.
Sep 30, 2026 · Filed Oct 30, 2026
D$68.60-1.5%Stored close · as of Nov 6, 2026
What changed in Management’s Discussion and Analysis?
Read the current filingPrevious report: 10-Q
Period ended 2026-06-30; filed 2026-07-31.
0001193125-26-327487
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of OperationsCurrent report: 10-Q
Period ended 2026-09-30; filed 2026-10-30.
0001193125-26-440697
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of OperationsThe baseline is this issuer’s latest earlier reporting period of the same form that was filed before the current report. A previous 10-Q is a different quarter, not a year-over-year comparison. Amendments are excluded.
Compared 254 previous paragraphs and 270 current paragraphs.
149 unchanged; 57 reworded; 58 added; 43 removed; 5 previous and 6 current paragraphs rearranged.
Tables are not compared: 16 previous and 16 current tables excluded. Dates, whitespace, punctuation and numbering changes are ignored; changes to financial figures remain significant.
A changed paragraph is not evidence that risk increased or decreased. An unchanged paragraph does not establish that risk stayed the same.
Added paragraphs (58)
Current report
Operating revenue increased 24%, primarily reflecting:
Current report
A $184 million increase associated with the 2025 Biennial Review at Virginia Power;
Current report
A $122 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days;
Current report
A $60 million increase in non-fuel base rates resulting from the settlement of the 2026 electric base rate case in South Carolina;
Current report
A $17 million increase in sales to electric utility retail customers associated with economic and other usage factors.
Current report
Electric fuel and other energy-related purchases increased 20%, primarily due to higher commodity costs for electric utilities ($363 million), partially offset by a decrease in the use of purchased renewable energy credits ($110 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain Virginia Power generation facilities subject to cost recovery through base rates ($60 million).
Current report
Purchased electric capacity increased $70 million, primarily due to an increase related to the net impact from the annual PJM capacity markets at Virginia Power ($97 million), partially offset by a decrease associated with supplemental capacity purchase agreements at Virginia Power ($22 million).
Current report
Other operations and maintenance increased 26%, primarily due to an increase in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income ($79 million), an increase in storm damage and restoration costs ($25 million), merger-related costs associated with the proposed NextEra Energy Merger ($23 million), renewable natural gas projects placed in service in late 2025 ($24 million) and an increase in outside services ($22 million).
Current report
Depreciation and amortization increased 19%, primarily due to various projects being placed into service ($67 million) and an increase in amortization associated with non-fuel riders ($24 million), which is offset in operating revenue and does not impact net income.
Current report
Other taxes increased 10%, primarily due to an increase in property taxes.
Current report
Impairment of assets and other charges decreased 85%, primarily due to the absence of a charge for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project.
Current report
Other income decreased 37%, primarily due to a decrease in net investment gains on nuclear decommissioning trust funds.
Current report
Operating revenue increased 22%, primarily reflecting:
Current report
A $466 million increase associated with the 2025 Biennial Review at Virginia Power;
Current report
A $71 million increase in non-fuel base rates resulting from the settlement of the 2026 electric base rate case in South Carolina;
Current report
A $52 million increase in sales to electric utility retail customers associated with growth;
Current report
A $30 million increase in sales to electric utility retail customers associated with economic and other usage factors; and
Current report
These increases were partially offset by:
Current report
A $26 million decrease from the impacts of the capital cost rider in South Carolina.
Current report
Purchased electric capacity increased $192 million, primarily due to an increase related to the net impact from the annual PJM capacity markets at Virginia Power ($162 million) and an increase due to clean energy rider costs ($20 million), which is offset in operating revenue and does not impact net income.
Current report
Other operations and maintenance increased 16%, primarily reflecting:
Current report
A $53 million increase in salaries, wages and benefits;
Current report
A $50 million increase in outside services;
Current report
$34 million in merger-related costs associated with the proposed NextEra Energy Merger; and
Current report
Depreciation and amortization increased 11%, primarily due to various projects being placed into service.
Current report
Operating revenue increased 27%, primarily reflecting:
Current report
A $348 million net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges;
Current report
A $258 million increase to recover the costs and an authorized return, as applicable, associated with non-fuel riders;
Current report
A $184 million increase associated with the 2025 Biennial Review;
Current report
A $75 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days;
Current report
A $14 million increase in sales to electric utility retail customers associated with growth; and
Current report
A $13 million increase in sales to electric utility retail customers associated with economic and other usage factors.
Current report
Electric fuel and other energy-related purchases increased 21%, primarily due to higher commodity costs for electric utilities ($329 million), partially offset by a decrease in the use of purchased renewable energy credits ($110 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain generation facilities subject to cost recovery through base rates ($60 million).
Current report
Purchased electric capacity increased $71 million, primarily due to an increase related to the net impact from the annual PJM capacity markets ($97 million), partially offset by a decrease associated with supplemental capacity purchase agreements ($22 million).
Current report
Depreciation and amortization increased 22%, primarily due to various projects being placed into service ($53 million) and an increase in amortization associated with non-fuel riders ($24 million), which is offset in operating revenue and does not impact net income.
Current report
Other taxes increased 12%, primarily due to an increase in property taxes.
Current report
Impairment of assets and other charges decreased 98%, primarily due to the absence of a charge for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project.
Current report
Other income decreased 21%, primarily due to a decrease in net investment gains on nuclear decommissioning trust funds.
Current report
Operating revenue increased 29%, primarily reflecting:
Current report
A $1.2 billion net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges;
Showing the first 40 of 58 passages. Open the source sections for the rest.
Removed paragraphs (43)
Previous report
Operating revenue increased 18%, primarily reflecting:
Previous report
A $142 million increase associated with the 2025 Biennial Review at Virginia Power;
Previous report
A $33 million increase in sales to electric utility retail customers associated with economic and other usage factors;
Previous report
A $15 million increase in sales to electric utility retail customers associated with growth.
Previous report
Purchased electric capacity increased $62 million, primarily due to returning to PJM’s capacity market in June 2025 ($23 million) and an increase related to the 2026 annual PJM capacity market ($20 million).
Previous report
Depreciation and amortization increased 6%, primarily due to various projects being placed into service ($46 million), partially offset by a decrease in amortization associated with non-fuel riders ($15 million), which is offset in operating revenue and does not impact net income.
Previous report
Other income increased 53%, primarily due to an increase in net investment gains on nuclear decommissioning trust funds ($205 million) and an increase in AFUDC associated with rate-regulated projects ($13 million).
Previous report
Operating revenue increased 20%, primarily reflecting:
Previous report
A $282 million increase associated with the 2025 Biennial Review at Virginia Power;
Previous report
A $31 million increase in sales to electric utility retail customers associated with growth;
Previous report
A $22 million increase attributable to sales at Millstone in the day-ahead energy market; and
Previous report
A $19 million increase attributable to a service contract with a government entity which commenced in late 2025.
Previous report
Electric fuel and other energy-related purchases increased 53%, primarily due to higher commodity costs for electric utilities ($879 million) and an increase in the use of purchased renewable energy credits ($125 million), which are offset in operating revenue and do not impact net income.
Previous report
Purchased electric capacity increased $122 million, primarily due to returning to PJM’s capacity market in June 2025 ($59 million), an increase related to the 2026 PJM capacity market ($20 million) and an increase due to the deferral of non-fuel rider costs ($17 million), which is offset in operating revenue and does not impact net income.
Previous report
Other operations and maintenance increased 11%, primarily reflecting:
Previous report
A $47 million increase in salaries, wages and benefits;
Previous report
A $24 million decrease in storm damage and restoration costs.
Previous report
Depreciation and amortization increased 7%, primarily due to various projects being placed into service ($97 million), partially offset by a decrease in amortization associated with non-fuel riders ($18 million), which is offset in operating revenue and does not impact net income.
Previous report
Income tax expense decreased 35%, primarily due to lower pre-tax income ($119 million), partially offset by higher taxes on earnings within qualified decommissioning trusts ($21 million) and the absence of a benefit associated with the remeasurement of an uncertain tax position ($18 million).
Previous report
Operating revenue increased 26%, primarily reflecting:
Previous report
A $291 million net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges;
Previous report
A $217 million increase to recover the costs and an authorized return, as applicable, associated with non-fuel riders;
Previous report
A $142 million increase associated with the 2025 Biennial Review;
Previous report
A $19 million increase in sales to electric utility retail customers associated with economic and other usage factors;
Previous report
A $12 million increase in sales to electric utility retail customers associated with growth; and
Previous report
An $8 million increase attributable to a service contract with a government entity which commenced in late 2025.
Previous report
Electric fuel and other energy-related purchases increased 47%, primarily due to higher commodity costs for electric utilities ($295 million) and an increase in the use of purchased renewable energy credits ($60 million), which are offset in operating revenue and do not impact net income.
Previous report
Purchased electric capacity increased $61 million, primarily due to returning to PJM’s capacity market in June 2025 ($23 million) and an increase related to the 2026 annual PJM capacity market ($20 million).
Previous report
Depreciation and amortization increased 5%, primarily due to various projects being placed into service ($32 million), partially offset by a decrease in amortization associated with non-fuel riders ($15 million), which is offset in operating revenue and does not impact net income.
Previous report
Impairment of assets and other charges increased $218 million, primarily due to an increase in charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($195 million) and the disallowance of certain strategic undergrounding costs ($23 million).
Previous report
Other income increased 59%, primarily due to an increase in net investment gains on nuclear decommissioning trust funds ($35 million) and an increase in AFUDC associated with rate-regulated projects ($14 million).
Previous report
Operating revenue increased 30%, primarily reflecting:
Previous report
A $814 million net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges;
Previous report
A $474 million increase to recover the costs and an authorized return, as applicable, associated with non-fuel riders;
Previous report
A $282 million increase associated with the 2025 Biennial Review;
Previous report
A $25 million increase in sales to electric utility retail customers associated with growth;
Previous report
A $19 million increase attributable to a service contract with a government entity which commenced in late 2025; and
Previous report
Electric fuel and other energy-related purchases increased 63%, primarily due to higher commodity costs for electric utilities ($823 million) and an increase in the use of purchased renewable energy credits ($125 million), which are offset in operating revenue and do not impact net income.
Previous report
Purchased electric capacity increased $119 million, primarily due to returning to PJM’s capacity market in June 2025 ($59 million), an increase related to the 2026 annual PJM capacity market ($20 million), an increase due to the deferral of non-fuel rider costs ($17 million), which is offset in operating revenue and does not impact net income, and an increase related to changes in other capacity purchase contracts ($12 million).
Previous report
Depreciation and amortization increased 6%, primarily due to various projects being placed into service ($59 million), partially offset by a decrease in amortization associated with non-fuel riders ($18 million), which is offset in operating revenue and does not impact net income.
Showing the first 40 of 43 passages. Open the source sections for the rest.
Reworded paragraphs (57)
Previous wording
Risks and uncertainties that may impact the ability of the parties to complete the proposed NextEra Energy Merger at all, or within the terms and time frames initially anticipated, including the ability to obtain the requisite approvals of Dominion Energy and NextEra Energy’s shareholders, applicable regulatory approvals and any associated terms and conditions of such approvals and any other events or changes in circumstances that could give rise to the termination of the NextEra Energy Merger Agreement by either party;
Current wording
Risks and uncertainties that may impact the ability of the parties to complete the proposed NextEra Energy Merger at all, or within the anticipated terms and time frames, including the ability to obtain applicable regulatory approvals and any associated terms and conditions of such approvals and any other events or changes in circumstances that could give rise to the termination of the NextEra Energy Merger Agreement by either party;
Previous wording
Net income attributable to Dominion Energy decreased 55%, primarily due to an impairment charge associated with nonregulated renewable natural gas facilities, increased unrealized losses on economic hedging activities and higher interest on long-term debt. These decreases were partially offset by a benefit related to the revision of AROs for Millstone Unit 1, an increase in net investment earnings on nuclear decommissioning trust funds, higher rider equity returns reflecting capital investments at Virginia Power and the impacts of the 2025 Biennial Review at Virginia Power.
Current wording
Net income attributable to Dominion Energy increased 15%, primarily due to higher rider equity returns reflecting capital investments at Virginia Power and the impacts of the 2025 Biennial Review at Virginia Power, partially offset by a decrease in net investment earnings on nuclear decommissioning trust funds.
Previous wording
Net income attributable to Dominion Energy decreased 33%, primarily due to impairment charges associated with nonregulated renewable natural gas facilities and certain nonregulated solar generation facilities, higher interest on long-term debt and increased unrealized losses on economic hedging activities. These decreases were partially offset by a benefit related to the revision of AROs for Millstone Unit 1, an increase in net investment earnings on nuclear decommissioning trust funds, higher rider equity returns reflecting capital investments at Virginia Power and the impacts of the 2025 Biennial Review at Virginia Power.
Current wording
Net income attributable to Dominion Energy decreased 13%, primarily due to impairment charges associated with nonregulated renewable natural gas facilities and certain nonregulated solar generation facilities, higher interest on long-term debt, increased unrealized losses on economic hedging activities and increased capacity expense. These decreases were partially offset by a benefit related to the revision of AROs for Millstone Unit 1, higher rider equity returns reflecting capital investments at Virginia Power and the impacts of the 2025 Biennial Review at Virginia Power.
Previous wording
A $312 million net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges at Virginia Power;
Current wording
A $382 million increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges at Virginia Power;
Previous wording
A $217 million increase to recover the costs and an authorized return, as applicable, associated with Virginia Power non-fuel riders;
Current wording
A $258 million increase to recover the costs and an authorized return, as applicable, associated with Virginia Power non-fuel riders;
Previous wording
Interest and related charges increased 13%, primarily due to net issuances of long-term debt ($189 million) and an increase in the outstanding balance on variable rate debt ($25 million), partially offset by net unrealized gains in 2026 compared to net unrealized losses in 2025 associated with freestanding derivatives ($58 million) and decreased interest expense associated with rider deferrals ($23 million), which is offset in operating revenue and does not impact net income.
Current wording
Interest and related charges increased 18%, primarily due to net issuances of long-term debt ($95 million) and increased interest expense associated with rider deferrals ($17 million), which is offset in operating revenue and does not impact net income, partially offset by net unrealized gains in 2026 compared to net unrealized losses in 2025 associated with freestanding derivatives ($22 million).
Previous wording
Noncontrolling interests decreased $65 million, due to a decrease in earnings from the CVOW Commercial Project, including the share of increased charges for costs not expected to be recovered from customers.
Current wording
Noncontrolling interests increased $92 million, due to an increase in earnings from the CVOW Commercial Project, including the absence of a share of a charge for costs not expected to be recovered from customers.
Previous wording
An $870 million net increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges at Virginia Power;
Current wording
A $1.3 billion increase in fuel-related revenue as a result of an increase in commodity costs associated with sales to electric utility retail customers, including revenue for the deferred fuel securitization and electric utility customers who elect to pay market based or other negotiated rates and related settlements of economic hedges at Virginia Power;
Previous wording
A $474 million increase to recover the costs and an authorized return, as applicable, associated with Virginia Power non-fuel riders;
Current wording
A $738 million increase to recover the costs and an authorized return, as applicable, associated with Virginia Power non-fuel riders;
Previous wording
A $32 million net increase in sales to electric utility retail customers, primarily due to an increase in heating degree days during the heating season ($42 million), partially offset by a decrease in cooling degree days during the cooling season ($10 million);
Current wording
A $154 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days during the cooling season ($112 million) and an increase in heating degree days during the heating season ($42 million);
Previous wording
$34 million in sales of renewable natural gas and related environmental credits;
Current wording
$48 million in sales of renewable natural gas and related environmental credits;
Previous wording
A $28 million increase in outside services;
Current wording
A $28 million increase attributable to a service contract with a government entity which commenced in late 2025.
Previous wording
A $102 million net decrease associated with market prices affecting Millstone, including economic hedging impacts of net realized and unrealized losses on freestanding derivatives ($110 million).
Current wording
A $159 million net decrease associated with market prices affecting Millstone, including economic hedging impacts of net realized and unrealized losses on freestanding derivatives ($201 million);
Previous wording
A $55 million decrease associated with severe weather events affecting Virginia Power.
Current wording
A $60 million decrease associated with severe weather events affecting Virginia Power; and
Previous wording
Electric fuel and other energy-related purchases increased 39%, primarily due to higher commodity costs for electric utilities ($316 million) and an increase in the use of purchased renewable energy credits ($60 million), which are offset in operating revenue and do not impact net income.
Current wording
Electric fuel and other energy-related purchases increased 39%, primarily due to higher commodity costs for electric utilities ($1.2 billion) and an increase in the use of purchased renewable energy credits ($15 million), which are offset in operating revenue and do not impact net income with the exception of the reduction in purchased renewable energy credits resulting from the utilization of such credits generated by certain Virginia Power generation facilities subject to cost recovery through base rates ($60 million).
Previous wording
A $21 million increase in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income; and
Current wording
A $100 million increase in certain Virginia Power expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income;
Previous wording
$57 million due to renewable natural gas projects placed in service in late 2025;
Current wording
$81 million due to renewable natural gas projects placed in service in late 2025;
Previous wording
An $18 million increase in outage costs primarily at Virginia Power.
Current wording
A $29 million increase in outage costs primarily at Virginia Power.
Previous wording
Impairment of assets and other charges increased $763 million, primarily due to a charge associated with nonregulated renewable natural gas facilities ($820 million), charges associated with certain nonregulated solar generation facilities ($78 million), an increase in net charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($33 million) and the disallowance of certain strategic undergrounding costs ($23 million), partially offset by a benefit related to the revision of AROs for Millstone Unit 1 ($195 million).
Current wording
Impairment of assets and other charges increased $652 million, primarily due to a charge associated with nonregulated renewable natural gas facilities ($820 million), charges associated with certain nonregulated solar generation facilities ($79 million) and the disallowance of certain strategic undergrounding costs ($23 million), partially offset by a benefit related to the revision of AROs for Millstone Unit 1 ($195 million) and a decrease in net charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($95 million).
Previous wording
Other income increased 51%, primarily due to an increase in net investment gains on nuclear decommissioning trust funds ($189 million), an increase in AFUDC associated with rate-regulated projects ($19 million) and an increase related to offshore wind installation vessel operations ($18 million), partially offset by a decrease in non-service components of pension and other postretirement employee benefit plan credits ($16 million).
Current wording
Other income increased 8%, primarily due to an increase in net investment gains on nuclear decommissioning trust funds ($32 million), an increase in AFUDC associated with rate-regulated projects ($27 million) and an increase related to offshore wind installation vessel operations ($18 million), partially offset by a decrease in non-service components of pension and other postretirement employee benefit plan credits ($25 million).
Previous wording
Interest and related charges increased 10%, primarily due to net issuances of long-term debt ($93 million) and an increase in the outstanding balance on variable rate debt ($18 million), partially offset by net unrealized gains in 2026 compared to net unrealized losses in 2025 associated with freestanding derivatives ($49 million).
Current wording
Interest and related charges increased 15%, primarily due to net issuances of long-term debt ($284 million) and an increase in interest on variable rate debt ($17 million), partially offset by net unrealized gains in 2026 compared to net unrealized losses in 2025 associated with freestanding derivatives ($80 million).
Previous wording
Income tax expense decreased 45%, primarily due to lower pre-tax income ($115 million), partially offset by higher taxes on earnings within qualified decommissioning trusts ($22 million).
Current wording
Income tax expense decreased 19%, primarily due to lower pre-tax income.
Previous wording
Noncontrolling interests increased 53%, due to an increase in earnings associated with the CVOW Commercial Project, which includes the share of increased charges for costs not expected to be recovered from customers.
Current wording
Noncontrolling interests increased $145 million, due to an increase in earnings associated with the CVOW Commercial Project, which includes the share of decreased charges for costs not expected to be recovered from customers.
Previous wording
Net income increased 12%, primarily due to higher rider equity returns reflecting capital investments and the impacts of the 2025 Biennial Review.
Current wording
Net income increased 32%, primarily due to higher rider equity returns reflecting capital investments and the impacts of the 2025 Biennial Review.
Previous wording
Net income increased 20%, primarily due to higher rider equity returns reflecting capital investments and the impacts of the 2025 Biennial Review.
Current wording
Net income increased 24%, primarily due to higher rider equity returns reflecting capital investments and the impacts of the 2025 Biennial Review, partially offset by higher interest on long-term debt and increased capacity expense.
Previous wording
Other operations and maintenance increased 11%, primarily due to an increase in salaries, wages and benefits and administrative costs ($65 million), an increase in outside services primarily attributable to a service contract with a government entity which commenced in late 2025 ($26 million), an increase in certain expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income ($21 million) and an increase in outage costs ($16 million), partially offset by a decrease in storm damage and restoration costs ($24 million).
Current wording
Other operations and maintenance increased 29%, primarily due to an increase in certain expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income ($79 million), an increase in salaries, wages and benefits and administrative costs ($51 million), an increase in storm damage and restoration costs ($24 million) and an increase in outside services primarily attributable to a service contract with a government entity which commenced in late 2025 ($10 million).
Previous wording
Interest and related charges increased 5%, primarily due to an increase in long-term debt borrowings ($67 million), partially offset by decreased interest expense associated with rider deferrals ($23 million), which is offset in operating revenue and does not impact net income.
Current wording
Interest and related charges increased 33%, primarily due to an increase in long-term debt borrowings ($50 million) and increased interest expense associated with rider deferrals ($17 million), which is offset in operating revenue and does not impact net income.
Previous wording
Noncontrolling interests decreased $65 million, due to a decrease in earnings from the CVOW Commercial Project, including the share of increased charges for costs not expected to be recovered from customers.
Current wording
Noncontrolling interests increased $92 million, due to an increase in earnings from the CVOW Commercial Project, including the absence of a share of a charge for costs not expected to be recovered from customers.
Previous wording
A $38 million net increase in sales to electric utility retail customers, primarily due to an increase in heating degree days during the heating season ($43 million), partially offset by a decrease in cooling degree days during the cooling season ($5 million);
Current wording
A $113 million increase in sales to electric utility retail customers, primarily due to an increase in cooling degree days during the cooling season ($70 million) and an increase in heating degree days during the heating season ($43 million);
Previous wording
A $55 million decrease associated with severe weather events.
Current wording
A $60 million decrease associated with severe weather events.
Previous wording
Other operations and maintenance increased 11%, primarily due to an increase in salaries, wages and benefits and administrative costs ($20 million) and an increase in outside services primarily attributable to a service contract with a government entity which commenced in late 2025 ($14 million), partially offset by a decrease in storm damage and restoration costs ($11 million).
Current wording
A $116 million increase in salaries, wages and benefits and administrative costs;
Previous wording
A $24 million increase in sales to electric utility retail customers associated with economic and other usage factors;
Current wording
A $24 million increase in outage costs;
Previous wording
A $10 million increase in sales to customers from non-jurisdictional solar generation facilities.
Current wording
A $10 million increase in bad debt expense.
Previous wording
Impairment of assets and other charges increased 60%, primarily due to an increase in net charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($33 million) and the disallowance of certain strategic undergrounding costs ($23 million).
Current wording
Impairment of assets and other charges decreased 30%, primarily due to a decrease in net charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($95 million), partially offset by the disallowance of certain strategic undergrounding costs ($23 million).
Previous wording
Income tax expense increased 34%, primarily due to higher pre-tax income.
Current wording
Income tax expense increased 46%, primarily due to higher pre-tax income.
Previous wording
Noncontrolling interests increased 53%, due to an increase in earnings associated with the CVOW Commercial Project, which includes the share of increased charges for costs not expected to be recovered from customers.
Current wording
Noncontrolling interests increased $145 million, due to an increase in earnings associated with the CVOW Commercial Project, which includes the share of decreased charges for costs not expected to be recovered from customers.
Previous wording
Includes an increase from renewable natural gas facilities of $6 million and $20 million for the quarter and year-to-date periods, respectively.
Current wording
Includes an increase from renewable natural gas facilities of $37 million and $57 million for the quarter and year-to-date periods, respectively.
Previous wording
Corporate and Other includes specific items attributable to Dominion Energy’s primary operating segments that are not included in profit measures evaluated by executive management in assessing the segments’ performance or in allocating resources. See Note 20 to the Consolidated Financial Statements in this report for discussion of these items in more detail. Corporate and Other also includes items attributable to the Corporate and Other segment. For the three months ended June 30, 2026, this primarily included $21 million after-tax benefit for derivative mark-to-market changes. For the six months ended June 30, 2026, this primarily included $24 million after-tax benefit for derivative mark-to-market changes. For the three months ended June 30, 2025, this primarily included $15 million after-tax loss for derivative mark-to-market changes. For the six months ended June 30, 2025, this primarily included $20 million after-tax loss for derivative mark-to-market changes.
Current wording
Corporate and Other includes specific items attributable to Dominion Energy’s primary operating segments that are not included in profit measures evaluated by executive management in assessing the segments’ performance or in allocating resources. See Note 20 to the Consolidated Financial Statements in this report for discussion of these items in more detail. Corporate and Other also includes items attributable to the Corporate and Other segment. For the three months ended September 30, 2026, this primarily included $25 million of after-tax charges for merger-related costs. For the nine months ended September 30, 2026, this primarily included $37 million of after-tax charges for merger-related costs and $36 million after-tax benefit for derivative mark-to-market changes. For the three months ended September 30, 2025, Dominion Energy reported an insignificant amount of specific items in the Corporate and Other segment. For the nine months ended September 30, 2025, this primarily included $23 million after-tax loss for derivative mark-to-market changes.
Previous wording
Includes cash outflows of $31 million and $39 million for energy efficiency programs in Virginia for the six months ended June 30, 2026 and 2025, respectively, and $14 million and $12 million for DSM programs in South Carolina for the six months ended June 30, 2026 and 2025, respectively.
Current wording
Includes cash outflows of $49 million and $55 million for energy efficiency programs in Virginia for the nine months ended September 30, 2026 and 2025, respectively, and $21 million and $19 million for DSM programs in South Carolina for the nine months ended September 30, 2026 and 2025, respectively.
Previous wording
Net cash provided by Dominion Energy’s operating activities increased $28 million, primarily due to higher operating cash flows from electric utility operations driven by riders and impacts from the 2025 Biennial Review ($754 million), partially offset by lower deferred fuel and purchased gas cost recoveries ($251 million), an increase in interest payments primarily driven by higher borrowings ($231 million) and lower settlements of interest rate swaps ($230 million).
Current wording
Net cash provided by Dominion Energy’s operating activities increased $314 million, primarily due to higher operating cash flows from electric utility operations driven by riders and impacts from the 2025 Biennial Review ($733 million) and lower net prepayments and deposits ($371 million), partially offset by an increase in interest payments primarily driven by higher borrowings ($430 million), a decrease from changes in working capital ($205 million) and lower settlements of interest rate swaps ($155 million).
Showing the first 40 of 57 pairs. Open the source sections for the rest.
Rearranged current paragraphs (6)
Current report — wording carried from elsewhere
A $21 million increase in sales to electric utility retail customers associated with growth; and
Current report — wording carried from elsewhere
A $28 million increase attributable to a service contract with a government entity which commenced in late 2025; and
Current report — wording carried from elsewhere
A $21 million increase in sales to electric utility retail customers associated with economic and other usage factors.
Current report — wording carried from elsewhere
A $100 million increase in certain expenditures which are primarily recovered through state- and FERC-regulated rates and do not impact net income;
Current report — wording carried from elsewhere
A $36 million increase in outside services primarily attributable to a service contract with a government entity which commenced in late 2025;
Current report — wording carried from elsewhere
The five largest counterparty exposures, combined, for this category represented less than 1% of the total net credit exposure.
Rearranged previous paragraphs (5)
Previous report — wording carried elsewhere
$18 million in sales of renewable natural gas and related environmental credits; and
Previous report — wording carried elsewhere
Other operations and maintenance increased 11%, primarily due to renewable natural gas projects placed in service in late 2025 ($27 million), an increase in salaries, wages and benefits ($25 million) and an increase in outside services ($16 million).
Previous report — wording carried elsewhere
Impairment of assets and other charges increased $844 million, primarily due to a charge associated with nonregulated renewable natural gas facilities ($820 million), an increase in charges for costs not expected to be recovered from customers on 100% of the CVOW Commercial Project ($195 million) and the disallowance of certain strategic undergrounding costs ($23 million), partially offset by a benefit related to the revision of AROs for Millstone Unit 1 ($195 million).
Previous report — wording carried elsewhere
A $167 million net decrease associated with market prices affecting Millstone, including economic hedging impacts of net realized and unrealized losses on freestanding derivatives ($202 million); and
Previous report — wording carried elsewhere
Union member or other applicable countries that were the subject of a U.S. Supreme Court’s ruling in late February 2026, and the estimated impact of new tariffs subsequently enacted in late February 2026 on equipment expected to be delivered from February 2026 through July 2026 that originates from Mexico, Canada, a European Union member or other applicable countries. The actual tariffs to be incurred are dependent upon the tariff requirements and rates, if any, at the time of delivery of the specific component.