New Jersey moves from storage targets to customer-sited procurement
New Jersey regulators have taken a concrete step toward turning the state’s long-term energy storage goals into distributed capacity that can be called on during periods of grid stress. In a straw proposal published in August, the New Jersey Board of Public Utilities outlined a procurement for up to 150 megawatts of behind-the-meter energy storage capacity that would be spread across the service territories of the state’s four electric distribution companies.
The proposal is notable not because it is the state’s largest storage action, but because of where it sits in New Jersey’s broader strategy. The state has already procured large amounts of transmission-connected storage in an earlier phase of its Garden State Energy Storage Program. This new block shifts attention toward batteries installed at homes and small commercial sites, where storage can serve both as a customer resilience asset and as a grid resource during dispatch events.
If adopted in something close to its current form, the program would allow eligible customers served by Atlantic City Electric, Jersey Central Power & Light, Public Service Electric & Gas, and Rockland Electric to receive incentives for making stored electricity available when utilities call for discharge. The board said those distribution companies would administer the enrolled capacity within their territories.
A 10-year incentive tied to dispatch performance
Under the proposal, participating customers could receive up to $200 per kilowatt per year over a 10-year term. That payment structure is designed to support enrollment in relatively small battery systems while still recognizing that these assets already provide private value to the customer, particularly in the form of backup power and resilience.
That framing matters. Regulators are not treating residential and small commercial batteries as if they are blank-slate utility infrastructure that needs to be fully underwritten by ratepayer support. Instead, the proposal appears to assume that behind-the-meter storage delivers a dual benefit. Customers gain a personal resilience tool, while the grid gains a flexible resource that can discharge during moments of system stress.
The result is a program structure that aims to bridge two often competing policy goals: accelerating adoption of distributed storage without overpaying for capacity that may already make economic sense for some buyers. By setting a maximum annual incentive rather than an open-ended payment, the state is signaling that it wants a controlled first block that can be evaluated before larger commitments are made.
Part of a much larger storage mandate
The 150 MW procurement is only one piece of a bigger statutory framework. New Jersey is required to deploy 2 gigawatts of bulk and distributed energy storage capacity by 2030 through the Garden State Energy Storage Program. According to the proposal summary, the board is already halfway toward that target after procuring a combined 1 GW of transmission-connected storage in the program’s earlier first phase.
That context helps explain why this latest action matters even though its size is comparatively modest. Large, grid-connected battery projects can add capacity quickly, but they do not by themselves create a distributed flexibility network embedded in neighborhoods and business districts. Behind-the-meter storage can support a different operational model, one that relies on many smaller systems acting in aggregate during critical hours.
For policymakers, that model is increasingly attractive as load growth accelerates and utilities look for alternatives to conventional peaking resources or expensive grid upgrades. A distributed fleet of batteries does not replace every need for central infrastructure, but it can reduce stress at specific times and in specific places if it is enrolled and dispatched effectively.
From pilot logic to a virtual power plant market
The proposed procurement also connects directly to New Jersey’s developing vision for a virtual power plant, or VPP, framework. The board said residential and small commercial batteries would be eligible to participate in a temporary, technology-neutral VPP program that is expected to begin next year and operate for two years. After that, the state plans to transition to a market-based, open-access VPP tariff in 2029.
That timeline suggests the current storage block is not just an isolated incentive offering. It is also a practical way to seed a pool of dispatchable customer-owned assets before a more formal market structure is in place. In effect, the state appears to be using procurement design to prepare for a more durable VPP model.
This progression matters because VPP policy often stalls between aspiration and implementation. It is easy for regulators and utilities to describe a future in which customer devices respond to market signals and utility events. It is harder to build the enrollment base, compensation rules, utility interfaces, and stakeholder trust needed to make that system function in practice. New Jersey’s approach indicates an effort to connect those steps rather than treat them as separate policy tracks.
Political backing and the affordability question
The BPU tied the Aug. 17 proposal to Executive Order No. 2, signed by Governor Mikie Sherrill shortly after taking office on Jan. 20, 2026. That order directed the board to issue solicitations for new solar and storage capacity and to begin developing a virtual power plant program open to third-party energy suppliers.
By explicitly linking the procurement to the governor’s order, the board is framing distributed storage as part of a broader affordability and resilience agenda rather than a niche clean energy initiative. That distinction is politically important. Storage deployments are easier to defend when they are presented not only as decarbonization tools, but also as a way to manage rising demand, improve grid performance, and potentially reduce the cost of meeting peak conditions.
Still, the affordability case will depend on execution. Incentives that attract only a narrow slice of affluent early adopters may have limited system impact and invite criticism about cost allocation. A program that successfully aggregates meaningful capacity across varied customer classes would strengthen the argument that distributed storage can serve public system needs as well as private households.
What comes next
The board plans to host a virtual stakeholder meeting on Sept. 3 to gather feedback on the straw proposal. That step will likely surface questions about customer eligibility, performance requirements, dispatch rules, measurement standards, and how capacity should be allocated among the utilities.
Those details will shape whether the 150 MW target becomes a credible building block for the state’s VPP ambitions or remains a narrowly subscribed incentive program. For now, the proposal marks a clear directional shift: New Jersey is no longer only buying utility-scale storage at the transmission level. It is trying to recruit batteries in homes and small businesses into a structured grid support role.
That may prove to be one of the more consequential transitions in state energy policy. The next phase of storage deployment in the US is not just about adding megawatts. It is about deciding who owns flexible capacity, how it gets paid, and whether regulators can turn distributed devices into dependable infrastructure. New Jersey’s latest proposal is an early test of that model.
This article is based on reporting by Utility Dive. Read the original article.
Originally published on utilitydive.com
