Google's 100-MW Virtual Power Plant in PJM Signals Rise of Distributed Capacity as Grid Tightens

Google's agreement to fund a 100-MW virtual power plant in PJM Interconnection, the largest regional electricity market in the United States, is being viewed by industry sources as a turning point for distributed capacity as a valuable grid resource amid tightening power supplies. The tech giant announced in June that it would pay residential, commercial and industrial customers across the PJM footprint to participate in a three-year virtual power plant operated by Voltus, the distributed energy resource aggregator.

The contract stands out because it holds Voltus responsible for Google's capacity obligation, a structure that reflects the hyperscaler's confidence in distributed resources and signals new market realities. Jon Wellinghoff, chief regulatory officer at Voltus and a former chairman of the Federal Energy Regulatory Commission, described the arrangement as a turning point that allows markets to treat distributed capacity like any other capacity resource. He noted that large loads such as data centers are now contracting with distributed capacity and DER providers for utility-scale bring-your-own-new-capacity arrangements.

The deal arrives as interconnection queues at PJM and other regional systems stretch years long while regulators weigh market reforms. Even with PJM's record-high capacity prices, demand for capacity continues to exceed supply, according to Mary Yang, an energy lawyer and chief operating officer at consulting firm 804 Advisory with extensive experience before PJM and FERC. She said current conditions require thinking about distributed capacity, which experts note is faster and easier to integrate than traditional capacity resources. That advantage has prompted utilities, states and hyperscalers to explore new business models aimed at scaling distributed capacity to regional market size.

While the power system still needs investment in transmission, centralized generation and storage to meet load growth and reduce electricity costs, operational flexibility from large loads, especially data centers, is increasingly seen as essential. Pier LaFarge, CEO of Sparkfund, which is working with Xcel Minnesota on the utility's Capacity*Connect distributed capacity pilot, said distributed capacity as a category of resource to meet system needs has arrived. Lon Huber, Xcel's senior vice president of integrated system planning and chief planning officer, said that done right, distributed capacity can unlock beneficial load growth that increases grid utilization and puts downward pressure on rates.

Google's 100-MW virtual power plant is modest compared with PJM's record peak load of 168.2 GW set on July 2, but distributed resources at large could meet as much as 20% of U.S. peak load needs by 2030, according to a 2025 Department of Energy study. A 2024 RMI report found that many utilities have rolled out their own virtual power plants in recent years to address resource adequacy, reliability, resilience, transmission and distribution infrastructure relief and affordability. In the PJM region, the average residential solar-plus-storage system reduces customer peak-period demand by about 6 kW while average consumption during critical peak periods is about 3 kW, according to Scott Vogt, a consultant and former vice president of strategy, energy policy and revenue initiatives at Commonwealth Edison. Vogt said solar-plus-storage owners reduce their own capacity costs and the high capacity costs of other customers in PJM's ComEd territory, adding that DER aggregators are reevaluating and restructuring their business models to make the value proposition easier for customers to understand.

Proposed changes to PJM's market structure could also affect the value of distributed capacity. FERC recently rejected most of the grid operator's large load interconnection plan, which would have placed a high risk of curtailment on customers that fail to bring new capacity. Meanwhile, some PJM states, including New Jersey and Pennsylvania, are considering how to compensate customers for demand-side value, though Yang noted that such efforts would require the right state programs and tariff structures and might need state or federal regulatory approval.

Questions surrounding hyperscaler-funded virtual power plant programs illustrate the need for greater regulatory clarity. In September, Pacific Gas & Electric announced a partnership with Google and Rewiring America to launch the Smart Home Assets for Reliability and Efficiency, or SHARE, program in the San Francisco Bay Area. The pilot will enroll more than 20,000 existing customer-owned distributed energy resources plus new battery-enabled heat pumps as a virtual power plant to relieve system congestion, with Google fully funding customer incentives, technology deployment and program delivery. Critics, including Jigar Shah, founding advisory chair of Deploy Action and former head of the U.S. Department of Energy's loan program, questioned why PG&E has not done more on its own to bring a virtual power plant online despite having more behind-the-meter batteries than any utility in the country. PG&E spokesperson Paul Doherty said responsibility lies with California regulators, who need to create a methodology for customer compensation, allow DER to compete in wholesale energy markets and set performance standards, adding that the SHARE program represents a faster path through external funding.

Distributed resource providers and aggregators have announced a series of notable deals in recent months. Sunrun, Everyday Electric and Tesla agreed to supply more than 16 GW of flexible energy capacity to utilities and hyperscalers. Schneider Electric, Octopus Energy US and Uplight finalized a partnership to expand Uplight's distributed resources portfolio to 20 GW over the next five years. Branch Energy announced $33 million in funding to expand from Texas into PJM's capacity market. Sunrun agreed to supply Voltus with energy capacity from thousands of residential storage and solar systems in PJM and MISO to support Voltus' AI hyperscaler agreements, and Voltus acquired battery project developer Brightfield. Earlier this month, Voltus announced it had raised $225 million in Series D financing with a target of 20 GW of distributed capacity by 2030.

Voltus CEO Dana Guernsey compared the new bring-your-own-new-capacity contracts to the power purchase agreements that revolutionized utility-scale solar and wind development by enabling financing from investors and technology companies with the largest balance sheets in the world. Guernsey said hyperscalers are also choosing load flexibility, distributed capacity and virtual power plant solutions in response to public backlash against data centers, returning value to customers and reducing bills for all electricity users. Tom Hunt, CEO of commercial and industrial-scale battery provider Pivot Energy, said the business model is evolving with the market and that the exact products and market mechanisms may not be certain for a decade. LaFarge of Sparkfund said regulators, utilities and other stakeholders are realizing that distributed capacity and other forms of load flexibility can and should be proactively developed to expand system utilization and preserve reliability and affordability, restoring customer trust and creating the social license needed to grow transmission and generation. He added that most hyperscalers now recognize that building off-grid is shockingly more expensive than contracting for distributed capacity.