How is the Company considering opportunities to add storage using the surplus interconnection process?

The Company’s business development team is carefully evaluating the opportunity. This potentially could allow generation, mainly storage resources, to be sited at existing sites where the capacity injection rights are not being fully utilized. This will be a site-by-site analysis to evaluate what land is available, what constraints in siting are present, like wetlands and cultural resources, and any county restrictions. Once the Company has that information, we can run economic analysis to determine if the potential cost reductions will offset the reduced benefits by siting storage behind another resource. We expect this to be a continuing analysis, and we will certainly take advantage of it on behalf of customers as the opportunity presents itself.

Will the Company publish the storage potential at generation sites from surplus interconnection? Will stakeholders be able to review the Company’s findings?

We anticipate this will be an on-going evaluation of both existing units in the Company’s fleet and the new units we plan to add in our clean energy filings and our ongoing development of resources to support the Company’s need. We do not anticipate this will result in a final report of any kind, as it is a continuing evaluation.

What specific changes prompted the expansion of the capacity import limit from 3300 MW to 5000 MW?

The 5000 MW came from our stakeholder survey results and is consistent with what we utilized last year.

What plans/vendors/permits have been considered for SMR deployments in the projection?

In the IRP we plan for generic resources. Consideration for the modeling of SMRs is based on information relative to that, not a site-specific location.

What assumptions are you making about the load growth from your large load customers, specifically federal sites like military installations that are considering hosting data centers? Do these projected loads materially affect your planned resource needs in the IRP?

We are required by the SCC to utilize the PJM Load Forecast in our IRP.

If a retirement was selected, would that resource appear as a negative value in the resources table, since megawatts would be removed?

Yes, they would be shown as negative megawatts since they would be a resource being taken away from the supply stack available to meet customer's needs. When we file our plan, there will be a specific column titled “retirements.” It will clearly note what number of megawatts were retired in a particular year.

How many years does this stakeholder modeling scenario cover? Would a 20-year time horizon go from 2026 to 2046?

For all plans, we will be using a 20-year planning horizon. It will show resource additions or retirements that occur between 2026 and 2045. This includes a full plan for 2026 and 2045, making that a 20-year horizon.

For the factors that influence the built limits for solar and storage, do all factors have equal weight, or do some of the factors pose more of a barrier to development?

The build limits in the stakeholder input case were based on the survey results.

Will other stakeholders be able to see the questions that were asked in the chat when watching the recording?

While they are not posted during the recorded presentation, we do respond to all questions on the Q/A section on the DEV IRP Stakeholder Website.

Will the company be modeling LNG in its IRP?

At this time, we are not proposing to include LNG in the 2025 IRP Update.

Please provide a map of transmission lines in Dominion Energy territory superimposing (a) current MW capacity of each line and (b) forecast data center load increases.

Dominion Energy has approximately 6,800 miles of transmission lines in Virginia, North Carolina, and West Virginia at voltages ranging from 69 kV to 500 kV. A map of those lines was published on page 23 of the Company’s 2024 IRP. Transmission planning occurs on the regional level pursuant to PJM’s Manual 14B: PJM Transmission Planning Process (https://www.pjm.com/-/media/DotCom/documents/manuals/m14b.pdf) and under the Federal Energy Regulatory Commission’s (“FERC”) jurisdiction, which requires clear functional separation between power generation and transmission planning to ensure fair and efficient operation of the electric grid.

How much of the load forecast increase from 2024 to 2025 is for data centers and how is the data center load split between the Dominion Load Serving Entity (LSE) and other LSEs? Where in VA is the data center load increasing? What process does Dominion use for load requests, and how does that eliminate double counting in the load requests?

The majority (approximately 85%) of the increase in the load forecast over the next 20 years is from data centers. The Company only forecasts its load, not other LSEs, for IRP purposes. Data center load increases are occurring in northern Virginia, the Stafford area, Richmond, and Southside VA. The Company uses a 3-contract structure (i.e., SELOA, CLOA, ESA) to process load requests with increasing financial commitments. While the Company does not forecast by contracts, this process does eliminate double counting in the load forecast. This approach takes into consideration that speculative projects will fall out when financial commitments are required. For more information on load forecasting methodologies, see the 2024 IRP Appendix 2A.

For load forecasts, why are data centers subtracted from the PJM forecast?

Data centers are subtracted from the PJM forecast in order to apply the DOM LSE to Zone ratio appropriately. Removing the data center load helps avoid double-counting and provides a clean baseline.

Does Dominion Energy have special rate agreements with data centers?

Cost allocation matters, including those regarding data centers, are not part of the IRP process. That is part of the rate case proceeding, which is currently on-going.

Please explain what criteria is utilized to include new load into the data center forecast? Please provide the list of the pending data center load requests.

The Company forecasts data center load based on over 12-years of metered load by customer. The Company forecasts its 7 largest or fastest growing customers and forecasts all remaining customers as a combined segment. The Company has 47 GW of potential projects in its queue. This is made up of connected projects, those under construction, and those in engineering. Project and customers specific information is confidential, and the Company does not forecast by project.

With the increase of data center load, how does it affect the demand for transmission, substations, and power generation investments.

The company expects to deploy more than $40 billion in capital over the next five years to support one of the highest projected growth rates of any utility and enable its “all-of-the-above” approach to resource adequacy, ensure reliable and increasingly clean energy supplies, and continue to maintain its assets. Slides 8 through 10 of the presentation discussed at the 2025 IRP Update Stakeholder Meeting regarding Modeling held on August 27th, including information regarding the load forecast. In addition, Section 2.1 and Appendix 2A of the 2024 IRP provide extensive information on the load forecast, load growth, and the data center contribution to that load growth, as well as extensive written and verbal testimony from the 2024 IRP proceeding which is available on the State Corporation Commission website.

How are the three levels of contracts used to produce the load forecast? Specifically, ESA, SELOA, and CLOA contracts. When data centers are not yet approved by localities, but SELOA's have been signed, are those included in the load forecast?

The company does not forecast by contract. Contracts are used to validate the forecast.

How is the combination of solar and storage considered?

The 2025 IRP Update will include solar/storage hybrid units as a selectable resource in some portfolios. However, in general, the Company prefers co-located solar and storage resources that allow the storage resources the ability to charge from the grid.

Please provide a list of existing power generation by geographic location and by amount of generation. Please explain how that relates to the Dominion Energy load forecast. What is the aggregate shortfall in power generation?

Please see Appendix 3B-1 of the 2024 IRP for a list of the Company's generating units. Please see Appendix 3C-5 of the 2024 IRP for the actual (2021-2023) and projected (2024-2039) Summer Capacity Position.

Please provide information on how cost impacts are modeled and presented in the Integrated Resource Plan.

Each IRP provides a net present value (NPV) value for every scenario modeled. In addition, select primary portfolios will include a customer bill impact.

Will PJM's emerging proposal for NCBL (Non-Capacity Backed Load) be addressed in the 2025 IRP Update?

Non-Capacity-Backed Load (NCBL) is a nascent proposal from PJM and not yet sufficiently developed for the Company to provide substantive comment at this time.

Can you confirm that LDES technology will be modeled in the IRP? And if so, how will that be represented in the model?

Select LDES technology will be available as a selectable resource in at least one secondary portfolio as part of the 2025 IRP Update.

Will you incorporate any of the elements of the SCC's 2024 IRP Final Order in the 2025 IRP update? Please provide an explanation of how you will comply with each of these requirements, both in the update and in the 2026 filing.

The Company intends to comply with all Commission orders. The 2024 IRP Final Order conditions will be addressed in future IRP filings.

Does Dominion Energy have enough cost and operational characteristics estimates for energy storage to use in IRP modeling?

Yes, there is enough information, particularly for 4-hour duration and lithium-ion technology. However, there is not sufficient data for long duration and non-lithium-ion technology.

How will you analyze and model IRP costs for different scenarios and options?

The Company presents an NPV, or net present value, of all costs of each resource added to meet the load forecast in the planning horizon.

Which load forecast will Dominion Energy use?

As required by the Virginia State Corporation Commission, Dominion Energy uses PJM’s most current load forecast for the DOM Zone.

How much of the Commission's order will be integrated in the 2025 IRP Update?

The Company intends to comply with all Commission orders. The 2024 IRP Final Order conditions will be addressed in future IRP filings.

Can we see all Stakeholder’s individual inputs?

We plan to share a summary of the survey results with stakeholders. In order for the survey results to be representative of the overall stakeholder group, we will try our best to combine or use the most requested updates into modeling the Stakeholder Input Case. This may include aggregating feedback received from multiple individuals from the same organization.

What is the timeline for next year's IRP?

Integrated Resource Plans are cyclical in nature. As soon as one IRP ends, the next begins. We are starting to plan ahead for 2026 but have no final plans at this time.

Will the sessions for the 2025 IRP Stakeholder Process be in the same format?

All 2025 IRP Update Stakeholder Meetings will be held virtually. We plan to give a presentation and/or present information at each meeting with the ability for Stakeholders to ask questions at any time during the meeting in the Q&A tab in the virtual meeting platform. At the end of the presentation, we will try to get to as many questions as possible during the allotted time. If we are not able to answer your question during the meeting, or if you think of something else after the meeting has concluded, we kindly ask you to submit comments or questions through the IRP Stakeholder website. We will continually update the Q&A tab of the website where you can view questions and answers we received so far.

Will any of the future meetings be in person?

Meetings for the 2025 IRP Update Stakeholder Process will be held virtually.

Why is there no listing of battery storage capacity (or limits) on the stakeholder Input case list?

Battery storage is listed as “Storage Build Limits” on the Stakeholder Input slide. If you have feedback on inputs you would like to see, we kindly ask you to submit the information through the IRP Stakeholder website.

Stakeholder Questions and Answers

Stakeholder Questions and Answers Answers to stakeholder questions regarding Dominion Energy’s Virginia and North Carolina Integrated Resource Plan (IRP) 2025 Update will be anonymized and added to the list below on an ongoing basis. If substantially similar questions are asked by more than one stakeholder, they will be combined into a single question/answer. Answers to questions may be updated as the stakeholder process progresses.

To submit a question, please use the feedback form here and check back soon for updates.

Stakeholder Input Review Meeting - September 30, 2025

How is the Company considering opportunities to add storage using the surplus interconnection process?
Will the Company publish the storage potential at generation sites from surplus interconnection? Will stakeholders be able to review the Company’s findings?
What specific changes prompted the expansion of the capacity import limit from 3300 MW to 5000 MW?
What plans/vendors/permits have been considered for SMR deployments in the projection?
What assumptions are you making about the load growth from your large load customers, specifically federal sites like military installations that are considering hosting data centers? Do these projected loads materially affect your planned resource needs in the IRP?
If a retirement was selected, would that resource appear as a negative value in the resources table, since megawatts would be removed?
How many years does this stakeholder modeling scenario cover? Would a 20-year time horizon go from 2026 to 2046?
For the factors that influence the built limits for solar and storage, do all factors have equal weight, or do some of the factors pose more of a barrier to development?
Will other stakeholders be able to see the questions that were asked in the chat when watching the recording?

Meeting on Modeling Inputs & Reliability - August 27, 2025

Will the company be modeling LNG in its IRP?
Please provide a map of transmission lines in Dominion Energy territory superimposing (a) current MW capacity of each line and (b) forecast data center load increases.
How much of the load forecast increase from 2024 to 2025 is for data centers and how is the data center load split between the Dominion Load Serving Entity (LSE) and other LSEs? Where in VA is the data center load increasing? What process does Dominion use for load requests, and how does that eliminate double counting in the load requests?
Does the DOM Zone forecast include data center load growth from coops such as NOVEC and REC?
For load forecasts, why are data centers subtracted from the PJM forecast?
Does Dominion Energy have special rate agreements with data centers?
Please explain what criteria is utilized to include new load into the data center forecast? Please provide the list of the pending data center load requests.
With the increase of data center load, how does it affect the demand for transmission, substations, and power generation investments.
How are the three levels of contracts used to produce the load forecast? Specifically, ESA, SELOA, and CLOA contracts. When data centers are not yet approved by localities, but SELOA's have been signed, are those included in the load forecast?
How is the combination of solar and storage considered?
Please provide a list of existing power generation by geographic location and by amount of generation. Please explain how that relates to the Dominion Energy load forecast. What is the aggregate shortfall in power generation?
Please provide information on how cost impacts are modeled and presented in the Integrated Resource Plan.
Will PJM's emerging proposal for NCBL (Non-Capacity Backed Load) be addressed in the 2025 IRP Update?
Can you confirm that LDES technology will be modeled in the IRP? And if so, how will that be represented in the model?
Will you incorporate any of the elements of the SCC's 2024 IRP Final Order in the 2025 IRP update? Please provide an explanation of how you will comply with each of these requirements, both in the update and in the 2026 filing.
Does Dominion Energy have enough cost and operational characteristics estimates for energy storage to use in IRP modeling?
How will you analyze and model IRP costs for different scenarios and options?

Kickoff Meeting - August 1, 2025

Which load forecast will Dominion Energy use?
How much of the Commission's order will be integrated in the 2025 IRP Update?
Can we see all Stakeholder’s individual inputs?
What is the timeline for next year's IRP?
Will the sessions for the 2025 IRP Stakeholder Process be in the same format?
Will any of the future meetings be in person?
Why is there no listing of battery storage capacity (or limits) on the stakeholder Input case list?