New Jersey Orders 150 MW of Behind-the-Meter Storage as VPP Program Takes Shape
The state Board of Public Utilities has cleared customer-sited batteries for a two-year technology-neutral program starting next year, testing whether aggregated residential assets can function as dispatchable capacity.
New Jersey's Board of Public Utilities has formally included customer-sited energy storage among the assets eligible for a two-year virtual power plant program, with electric distribution companies set to administer the initiative beginning in 2027, according to a straw proposal released on August 4 (2026-08-04). The program is described as technology-neutral, meaning batteries will compete alongside other distributed resources for dispatch slots.4
The program's design matters for anyone modeling PJM capacity supply over the next several years. Behind-the-meter storage, if aggregated at scale, could reduce peak demand obligations without new transmission or generation build, and New Jersey's move follows similar regulatory advances in Virginia and Illinois, according to Canary Media reporting from August 6 (2026-08-06).5,4
But the practical gap between regulatory ambition and enrolled megawatts is wide. A survey cited by Canary Media found that roughly 14% of respondents said they own a battery storage system, while actual market penetration sits below 1%. On heat pump water heaters, the same gap appeared: 25% of respondents claimed ownership against an industry-measured adoption rate of around 2%. The implication is that consumer self-reporting on clean energy assets is systematically unreliable, which complicates any regulator's baseline estimate of aggregable capacity.5
That enrollment challenge is separate from the physical storage math. The U.S. Department of Energy has estimated that tripling VPP capacity nationwide to between 80 and 160 gigawatts by 2030 could serve 10% to 20% of peak load and cut grid costs by nearly $10 billion annually, according to Canary Media. New Jersey's 150 MW target is a small slice of that ambition, but it functions as a proof-of-concept for distribution-company-administered aggregation in a dense, high-cost grid zone.5
The state's broader energy policy context adds pressure on the program to deliver. Gov. Mikie Sherrill signed legislation on July 7 (2026-07-07) requiring state regulatory review of supplemental transmission projects and mandating that utilities meet PJM Interconnection planning requirements, in what the state framed as an affordability push, according to Utility Dive. If transmission additions face new review hurdles, distributed resources like VPP-enrolled batteries become more attractive as a substitute, even if their capacity contribution is harder to guarantee.3
New Jersey also lifted its nuclear moratorium on April 8 (2026-04-08), becoming the sixth state in the last decade to do so, according to Canary Media. That decision changes the longer-term supply mix calculation but has no near-term operational relevance to a storage VPP beginning enrollment next year. The two moves point in the same direction — preserving or expanding firm capacity — but operate on very different timelines.1
For storage vendors, the program design details that remain unresolved are the ones that move order books. Technology-neutral language protects incumbents but also opens the door to thermal storage, smart water heaters, and EV chargers competing alongside lithium-ion batteries for the same dispatch revenue. Whether the distribution companies will offer long-term offtake structures or rely on spot dispatch payments will determine installer economics and, by extension, the pace of residential battery uptake in the state.4
The customer knowledge problem identified by Canary Media reporting is arguably the most underappreciated constraint. Aggregators need accurate asset inventories to bid capacity into PJM. If customers don't accurately know what they own, the registration process for a VPP program breaks down before dispatch logic is ever tested. New Jersey's straw proposal does not yet address how distribution companies will verify enrolled assets, and that verification methodology will set the ceiling on how much of the 150 MW target can realistically be committed.5,4
Virginia offers a partial data point. Elevate and ArcLight brought a utility-scale battery storage facility online in Virginia earlier this year, according to Power Magazine reporting from June 11 (2026-06-11), with the state's chief energy officer describing storage as a key component of grid resilience strategy. That project is utility-scale rather than behind-the-meter, but it reflects the same regional push to treat storage as dispatchable capacity rather than just a peak-shaving tool.2
The next signal to watch is the finalized program rules from New Jersey's distribution companies, particularly how they handle asset verification, dispatch compensation, and the treatment of batteries already enrolled in other demand response programs — stacking restrictions being the most common barrier that keeps residential storage out of aggregated markets.4