Dominion Energy Virginia residential VPP economics

Dominion Energy Virginia serves most of central, eastern and Northern Virginia. Like Duke Energy Carolinas, it is vertically integrated: it owns the power plants, the wires and the meter. Unlike Duke, it sits inside PJM, the regional grid operator for 13 states and Washington, D.C., so its service area is also a PJM pricing zone, the DOM Zone, and its capacity is bought and sold in PJM’s auctions.

Virginia’s lawmakers, not only its regulator, set the direction here. The Community Energy Act of 2025 told Dominion to file a VPP pilot of up to 450 MW, with at least 15 MW of residential batteries and a path for third-party aggregators, ending July 1, 2028 (Code of Virginia). Dominion runs the pilot through one distributed energy resource management system (DERMS), Generac’s Concerto.

Every deep dive on this site follows the same template, but each has one feature that changes how its economics read. For Dominion it is not a program; the programs are still fairly standard. It is the territory. Dominion combines, in one service area, nearly every condition that should make a utility want flexible customer resources at scale: fast load growth, scarce and expensive capacity, local grid constraints, a legal mandate and the software to dispatch it. That makes it a preview of where other fast-growing territories are heading.

The driver is data centers. Northern Virginia, centered on Loudoun County, is the largest data center market in the world (PJM Load Analysis Subcommittee). Dominion’s contracted data center capacity reached about 53.8 GW in July 2026, up from 16.5 GW three years earlier (Investing.com), and nine of the DOM Zone’s ten highest peak days on record came in 2026 (Dominion’s Q2 2026 call). The 2026 IRP update, filed October 15, 2026, plans 39,244 MW of new resources by 2046 (Energy News Beat).

Capacity is scarce across PJM, and the price shows it. The last three base residual auctions cleared at the price cap: about $120, $122 and $119 per kW-year for 2026/27 through 2028/29, and the 2028/29 auction fell about 6.8 GW short of its reliability target (Utility Dive). Without the cap, the 2028/29 price would have been about $202 (PJM). PJM expects about 32 GW of peak growth by 2030, more than 90% of it from data centers, with the DOM Zone the largest share (Clean Air Task Force).

The local grid is tight too. Dominion reports about 4 GW of data centers in Loudoun County alone, 178 post-contingency local load relief warnings so far in 2026, and an average warning length that grew almost five times from 2023 to 2025 (Dominion Energy). That is the kind of constraint a VPP can relieve in specific neighborhoods, not just at the system peak.

Dominion counts about 54 MW of customer resources already tied to the VPP, from existing demand response, and plans a path to about 466 MW by 2030 (Dominion filing). The SCC approved seven demand-side programs for an initial phase of about 18 months (SCC). Advanced Energy United argued that compensation is too low to attract batteries at scale (Advanced Energy United).

A home in every program would earn about $439 a year, almost all of it from Dominion. Battery events run 20–60 times in summer and 10–20 in winter, up to three hours each (Virginia Solar). Enrollment is one program per device: the pilot bars double enrollment (Dominion filing).

Batteries are the most valuable single asset in the pilot, but VPP growth at scale will depend on several assets working together at each home. Virginia’s current design keeps them apart. Rooftop solar is excluded from the VPP because it is already paid through net metering (WHRO), and a battery owner on net metering would not receive a second credit for energy exported during events, a point Advanced Energy United has criticized (Advanced Energy United). Under monthly net metering at the retail rate, a kWh stored from the roof is worth no more than a kWh exported, the same position as Puget Sound Energy and the Duke Bridge in our Duke Energy Carolinas deep dive. Stacking needs care, depending on M&V methodology.

On today’s terms the battery case rests on backup power, not the pilot. The point of the other rows is the gap: if Dominion paid a home battery what PJM pays for capacity, the payback would fall by more than half, and on the value study’s numbers it would fall below ten years. Where Virginia settles between those rows is the decision that will shape its VPP after 2028.

Six of the eight conditions are in place, which is rare. The two missing pieces are design choices rather than physics: paying resources closer to their capacity value, and letting solar, batteries, EVs and thermostats at the same address work as one resource. Dominion’s IRP still adds gas alongside storage, and its pilot cost is small, about 20¢ a month for a typical customer, so the question for 2028 is scale, not concept.

Related: the Duke Energy Carolinas residential deep dive for a vertically integrated utility outside PJM, the ComEd residential deep dive for another PJM zone, and the Dominion Energy Virginia C&I deep dive. To run other equipment, use the Residential VPP Calculator.