A virtual power plant (VPP) functions by coordinating small-scale energy resources—such as heat pumps, HVAC systems, and industrial equipment—to deliver power services comparable to traditional plants. The U.S. Department of Energy currently supports this shift to address rising costs and congestion. Wood Mackenzie estimates the country holds 40 GW of VPP capacity, a figure the government projects could quadruple to 160 GW by 2030, meeting nearly 20% of expected peak demand.

Vermont has emerged as a testing ground for this model. Green Mountain Power (GMP) utilizes a battery lease program that has become the state’s primary power source, with over 5,500 participants. After regulators removed enrollment caps in 2023, the utility set a goal to eliminate outages entirely by 2030. Meanwhile, other states are following suit: Virginia has authorized a 450-MW pilot, and Minnesota has committed to 200 MW. In California, Governor Gavin Newsom recently signed legislation to accelerate VPP adoption, overcoming pushback from major utilities.

Beyond reliability, the economic argument for VPPs is gaining traction. Ian Magruder of the Utilise Coalition notes that increasing grid utilization by just 10% could save consumers over $100 billion over the next decade. As artificial intelligence optimizes grid management, VPPs offer a faster deployment timeline—often under a year—compared to the multi-year construction cycles required for traditional gas or renewable projects. Policymakers now face the challenge of shifting utility incentives away from heavy infrastructure spending toward these more agile, distributed systems.