Grid operators in the United States are facing an unprecedented dual challenge: rising electricity demand from data centers and frequent extreme weather events. These grid stresses are forcing a structural shift in the U.S. energy market, and decentralized generation capacity, aggregated under virtual power plants (VPPs), is starting to go mainstream.
As demand for electricity increases in the United States, the pace of grid infrastructure expansion is proving too slow and capital-intensive to meet this moment alone. Instead, a regulatory and technology shift is transforming millions of distributed energy resources (DERs) into utility-quality infrastructure.
VPPs are transitioning from small-scale pilot programs to important components in local energy systems. The scale of this transition is clear from the market data. Wood Mackenzie’s analysis shows that total U.S. energy capacity operating under VPPs was nearly 40 GW at the end of 2025, an increase of 21% year over year.
If this trajectory holds, the domestic market will reach approximately 100 GW of registered capacity by 2030. The U.S. Department of Energy (DOE) has targeted 80 GW to 160 GW of VPP capacity by the end of the decade to support grid reliability. Achieving these goals could offset the need for expensive new construction of peaking power plants and save energy systems an estimated $10 billion annually.
Distributed balancing
The financial justification for scaling up VPP infrastructure is that it reduces capital expenditure on generation capacity that would be idle for most of the year.
Historically, grid operators built or contracted centralized natural gas peaker plants to maintain reliability during the hours of highest demand. Research from organizations like Brattle Group shows that using coordinated residential solar, behind-the-meter battery storage and smart appliances is 40% to 60% cheaper than building new gas peaker or battery installations at scale, given resource adequacy.
Utilities must change the way they view customer assets to capture these economic benefits. Pooling thousands of 5 kW residential batteries together creates a reliable, dispatchable resource. When high temperatures strain the grid, an aggregator can immediately signal these systems to export power or limit demand, reducing peak loads in real time.
Jigar Shah, former director of the DOE Loan Programs Office, calls these networks the fastest tool states have at their disposal to stabilize rising electricity bills. By using existing hardware already paid for by consumers, network operators can avoid the billions in transmission and distribution upgrade costs that are typically passed on to ratepayers.
Funded Defaults
Finding participants for VPP activities has also become easier. Historically, customer adoption has been a major barrier, as individual homeowners had to understand complex contracts and manually enroll. As ownership standards shift from direct consumer cash purchases to third-party financed options, the way VPPs are organized is also changing.
“There has been a shift in the DER space recently, and consequently the VPP space, as tax incentives have changed and ownership standards have shifted from customer ownership to increasingly funded third-party ownership,” Kevin Joyce, head of VPP and energy retail at Tesla, told pv magazine. “That has changed the way VPPs are organized and has shifted things from a more opt-in model for consumers to one where the consumer gets a program by default and has a clear opportunity to opt out. It’s a very positive development from an implementation perspective, it increases enrollment significantly.”
DERs scale
Although technological barriers are largely declining, the United States still lags behind other countries in comprehensive DER policies. A recent report from the Pew Charitable Trusts highlights that there is untapped potential, despite an increase in policy adoption by 2025. To move the market beyond the pilot phases, Pew has set out several recommendations to better integrate these assets into the network (see table above).
How utilities plan their growth poses a challenge. Pew suggested that distribution planning should no longer be an internal activity performed by local utilities, but should instead be part of broader Integrated Resource Plan (IRP) cycles – long-term strategies used by utilities to plan for future demand. Requiring utilities to be more transparent around modeling and assessments would also mean states can ensure that distributed energy assets are used in a way that maintains affordability for consumers while meeting expected increases in demand, according to Pew.
Success stories
States that have adopted such planning frameworks are already seeing results. New York’s framework called Reforming the Energy Vision (REV) has laid out a path to shift utilities away from traditional revenue models based on building poles and wires. By allowing utilities to capture some of the net benefits from pursuing non-wireless alternatives (NWAs), regulators have created a financial incentive to prioritize DER investments.
California has moved beyond the pilot phase to prove that residential batteries can effectively replace fossil fuels. Data from the state’s Demand Side Grid Support (DSGS) program shows that distributed storage is increasingly filling the role once reserved for gas peaker installations. During extreme heat, these aggregated batteries have provided capacity equivalent to several large-scale gas facilities, saving the state hundreds of millions of dollars in potential emergency power purchases.
Outside the United States, the Australian Energy Market Operator (AEMO) offers a blueprint for optimization. With rooftop solar expected to account for almost 13% of the country’s total generation by 2025, Australian regulators now require distributed resources to be considered an optimized input for all investments in national electricity systems. These rules position distribution resources as central to the energy transition and not as peripheral effects.
Puerto Rico
In Puerto Rico, the viability of DER aggregation has been subject to rigorous real-world testing. The island’s electrical infrastructure is plagued by chronic reliability issues and structural capacity shortages that regularly lead to progressive load shedding. To mitigate these disruptions, an aggregation network comprising 70,000 registered residential battery systems was mobilized to provide automated emergency capacity. Joyce said that while these customers value their backup energy highly due to frequent outages, participation in DER aggregation remained stable, noting that “these Powerwalls providing capacity services to the Luma grid allowed them to avoid losing loads they would otherwise have.” The VPP network injected power back into the distribution system when central plants failed, creating a capacity buffer large enough to prevent systemic load shedding.
Coordinated distributed clusters successfully protected entire communities and kept power on for neighbors who did not have their own solar-plus-storage hardware.
Wholesale barriers
The long-term success of the domestic VPP market will depend on solving complex technical and market regulatory challenges. Federal Energy Regulatory Commission (FERC) Order 2222 is designed to allow DER aggregations to directly participate in regional wholesale markets, but implementation in regional transmission organizations (RTOs) remains incomplete.
Technology providers are also looking at new capacity pools, such as vehicle-to-grid (V2G) integrations. Current pilots in California and Texas are trying to tap into the mobile battery capacity of electric vehicles. If successful, these programs could turn millions of parked cars, buses and trucks into a massive, flexible resource for network stabilization.
“What we need to work on now is market access pathways, simplifying the policy frameworks to be able to deploy VPPs to create accredited capacity, and just making sure that the fundamental demand response and demand side programs that have been so successful in operating at scale are available virtually everywhere,” Joyce said.
Integrated grid
The transformation of America’s power grid is accelerating out of necessity. As expectations for load growth in the manufacturing and technology sectors increase, especially due to the expansion of data centers, building new transmission lines cannot be the only solution.
Developing a high-voltage transmission line across state lines routinely requires a decade or more of environmental studies, local permit approvals and right-of-way negotiations. As data center developers look to build much faster, regional network systems face a timing challenge that infrastructure buildout cannot solve.
“One of the bigger affordability challenges right now is related to freight growth and the need for additional capacity,” Joyce said. “VPPs can provide that additional capacity, both from the existing installed base that is underutilized from a grid services perspective, but also because new deployments can be deployed quickly.”
By using flexible resources at the edge of the electricity grid, distribution expenditure is immediately optimized. Joyce said up to half of traditional utility capital expenditures are directly related to local distribution infrastructure, a cost that directly drives up electricity rates for consumers. When utilities build large-scale substations or upgrade distribution lines solely to handle a few hours of extreme peak loads, these multi-million dollar capital investments are added directly to the base of utility rates. Taxpayers will bear the financial burden of these underutilized investments for decades.
Coordinated distributed resources provide a way to avoid these costly investments. By leveraging peak shaving through automated household batteries and smart thermostats, commercial networks can delay or eliminate the need for more local substations.
Decentralized networks are a proven, reliable and cost-effective alternative to conventional energy generation. This systemic integration represents the critical path to building an affordable, resilient U.S. electric grid.
The post The aggregation imperative first appeared on pv magazine Global.
