US accelerates shift towards virtual power plants to meet growing electricity demand

The United States faces a looming electricity gap as load grows sharply across industry and consumers alike, and solutions that avoid building vast new generation capacity are rising to the fore. Alongside transmission upgrades and new renewables, one of the most cost‑effective levers is reducing the energy we no longer need to produce: efficiency and behind‑the‑meter coordination that can be aggregated to act like generation.

A business model gaining traction in this space is “energy as a service,” in which a third party becomes the utility customer for a site, finances upgrades, and recovers its capital from a share of future savings. According to the lead report for this portfolio, one company pursuing that route takes on the utility account, modernises equipment and controls at multiple commercial sites, and is paid back over time from lower bills. For owners and operators of distributed facilities , retail chains, warehouses, light manufacturing , that approach offers immediate relief from operating costs while simultaneously reducing peak demand on the grid.

When many such upgraded sites are orchestrated with software, their combined load flexibility and storage can be dispatched in the same way a conventional power plant is. These virtual power plants (VPPs) knit together batteries, smart heating, ventilation and air conditioning (HVAC), refrigeration, EV chargers and other responsive assets so grid operators can shave peaks, defer generation or reduce reliance on fast‑starting fossil peakers. The U.S. Department of Energy describes VPPs as networks of distributed resources coordinated to provide cleaner, more affordable power, and industry analysis suggests VPPs are substantially more economical than traditional peaker plants during high‑demand hours. According to a Built In analysis, VPPs can be as much as 60% cheaper in those periods.

The urgency of deploying these solutions is underscored by recent federal and independent studies. The Department of Energy has reported a dramatic increase in data centre electricity demand: usage has roughly tripled in the past decade and is expected to double or triple again by 2028 as artificial‑intelligence workloads proliferate. The MIT Energy Initiative notes U.S. data centres already accounted for more than 4% of national electricity consumption in 2023 and could consume up to 9% by 2030; a single hyperscale facility can draw as much power as tens of thousands of homes. Separately, the American Public Power Association estimates combined growth from data centres and electric vehicles could add around 290 terawatt‑hours of demand by 2030.

Those escalating loads make avoided generation and flexible demand especially valuable. The Department of Energy has quantified the potential: expanding VPP capacity to between 80GW and 160GW by 2030 could cut roughly $10 billion each year from grid costs. Brattle Group modelling cited by industry commentators indicates VPP deployment could eliminate tens of billions in upfront utility capacity investments over a decade and save hundreds of millions annually in individual states.

Policy and market structures remain a gating factor. Federal rulemaking in 2020 directed regional grid operators to permit aggregated distributed energy resources to participate in wholesale markets, yet implementation across regions has been uneven. Where pilots exist, they show promise: Texas launched a programme in 2023 incentivising residential solar and battery installations that can export to the grid, and a private partnership involving major technology and generator firms is testing the use of smart thermostats and other devices to tap up to 1GW from homes. Nonetheless, some states and system operators continue to move slowly, citing technical complexity and regulatory barriers.

Meanwhile, federal funding for grid modernisation is evolving. The administration recently announced a new programme that will allocate $1.9 billion for grid upgrades with applications due in May 2026. That initiative replaces a previously planned tranche of funding under earlier GRIP rounds and represents a reduction relative to earlier commitments: the Grid Resilience and Innovation Partnerships authorised $10.5 billion across five years and disbursed most of its first rounds in 2023–24. Transmission and smart‑grid grants authorised under the Bipartisan Infrastructure Law add additional, but separate, investment tools.

For industrial decarbonisation professionals, these trends matter on three fronts. First, energy efficiency and retrofit financing can deliver immediate reductions in site energy intensity and operating expenses while generating flexible capacity that utilities value. Second, when efficiency, storage and controls are aggregated into VPPs, they become traded assets that can monetise avoided capacity and ancillary services , creating new revenue streams for asset owners and service providers. Third, the scale of demand growth from hyperscalers and electrifying industry means that relying solely on new centralised generation or transmission will be costly and slow; a portfolio that combines targeted grid investment with distributed flexibility is likely the most pragmatic path to keep rates stable and emissions falling.

Adopting these solutions at scale will require aligned incentives: tariff structures that reward load flexibility, market rules that admit aggregated resources, and capital vehicles that bridge the gap between retrofit cost and long‑term savings. Where those pieces fall into place, thousands of upgraded commercial sites, fleets of batteries and networks of smart controllers can function as a decentralised, dispatchable system , effectively converting the electricity saved into the equivalent of generation capacity and reducing the need to build fossil‑fired peakers.

The technology and economics are increasingly persuasive; the remaining barriers are institutional. For businesses and policymakers aiming to decarbonise industry without destabilising the grid or blowing up customer bills, scaling financeable, aggregated behind‑the‑meter solutions and integrating them into wholesale markets offers one of the clearest pathways available.