Why New Jersey Is Turning Batteries Into a Grid Planning Tool

Published August 12, 2026

As electricity demand grows, utilities face a difficult planning question: how much new grid capacity is actually needed, and how quickly can it be built? New Jersey is exploring an approach that could give grid planners another option. The state is developing its first virtual power plant (VPP) program, which is expected to begin by July 2027 and coordinate distributed resources such as customer-sited batteries, electric vehicles, smart thermostats and other controllable devices. The program is being designed as a two-year transitional framework before moving toward an open-access, market-based VPP tariff from 2029.

The significance of this approach extends beyond virtual power plants. Batteries can potentially help manage the specific periods when electricity demand places the greatest pressure on the grid. Rather than treating every increase in peak demand as a requirement for immediate physical expansion, utilities can use flexible resources to change when electricity is consumed or supplied. This does not eliminate the need for transmission lines, substations or other infrastructure. Instead, it gives planners another tool for managing capacity, particularly where constraints occur during limited periods. New Jersey’s experience offers a useful case study in how batteries could become part of a broader strategy for managing grid capacity.

The Grid Challenge Is About When and Where Electricity Is Needed

Electricity demand is not constant throughout the day or year. A utility may have enough capacity to serve customers under normal conditions but encounter constraints during a relatively small number of high-demand periods. This distinction is becoming increasingly important as electricity consumption changes across the U.S.

Electrification of transportation and buildings can increase demand, while large new loads such as data centers can create significant requirements in specific locations. In New Jersey, regulators are simultaneously pursuing additional energy storage and developing programs that can make customer energy use more responsive to grid conditions. In March 2026, the New Jersey Board of Public Utilities approved incentives for 355 MW of large-scale battery storage and launched a solicitation for another 645 MW. The initiatives are part of a broader effort to move toward the state’s 2,000 MW energy storage goal for 2030.

This matters because grid planning is fundamentally a question of capacity. Infrastructure must be capable of handling periods when demand is at its highest, even if those conditions occur for only a limited number of hours. If a battery can reduce demand during those critical periods, the existing grid can potentially serve more customers without being operated at its maximum capacity.

The question for planners therefore becomes more specific: where are the constraints, when do they occur, and can flexible resources respond reliably enough to manage them?

How Batteries Can Become a Grid Planning Resource

A battery changes the timing of electricity consumption. It can charge when demand is lower and discharge when demand rises. At a commercial facility, for example, a battery could discharge during an afternoon peak, reducing the amount of electricity the facility draws from the grid.

At a larger scale, coordinated batteries can provide a similar service across multiple locations. New Jersey’s proposed VPP program would allow customer-sited energy storage to participate alongside other distributed energy resources. The state’s proposal is explicitly designed to coordinate thousands of devices through digital systems, with the goal of making small changes across many resources when demand increases.

Several characteristics make batteries relevant to grid planning:

Peak reduction: Batteries can discharge during periods of high demand, reducing the amount of electricity required from the grid.
Load shifting: Energy consumption can be moved from higher-demand periods to lower-demand periods.
Fast response: Batteries can respond quickly when a grid operator or aggregator calls on them.
Distributed capacity: Multiple smaller systems can provide flexibility across different locations.
Targeted support: Batteries located near constrained parts of the grid may have greater value than identical systems elsewhere.

The final point is particularly important. A 10 MW battery does not have the same value in every location. If a particular distribution circuit is congested, a battery connected elsewhere may do little to address that constraint. This means that the future value of storage will depend on more than installed megawatts. Location, timing, availability and operating strategy all matter.

New Jersey Is Moving From Individual Batteries to Coordinated Capacity

New Jersey’s emerging VPP framework illustrates how these individual assets could become part of a larger grid planning strategy. The proposed two-year transitional program would be administered by the state’s four electric distribution companies and use existing advanced metering, direct load control and demand response infrastructure. From 2029, the state envisions an open-access VPP structure that could allow broader participation by third-party aggregators.

The proposal also creates an opportunity for distributed batteries to participate in more than one market where rules allow. The BPU has indicated that batteries and other distributed resources could potentially stack distribution-level grid service payments with PJM Interconnection wholesale market payments.

For grid planning, aggregation is important because individual customer resources can be relatively small. PSE&G, for example, discussed a program involving an upfront incentive of approximately $5,000 for an 8 kW home battery, in exchange for allowing the utility to discharge the battery during peak-shaving events. The utility also said that several thousand small-scale batteries may already exist in New Jersey, creating a potential pool of existing resources that could eventually be enrolled in similar programs.

This creates a different way of thinking about capacity. Instead of viewing every battery as an isolated customer asset, utilities can potentially aggregate thousands of devices into a resource that responds to system conditions. The result is a more flexible grid where some capacity can come from coordinated customer assets rather than exclusively from centralized infrastructure.

Batteries Cannot Replace Every Grid Upgrade

The potential of batteries should be considered alongside their limitations. A battery can be highly effective when a grid constraint occurs during predictable peak periods, particularly when the constraint lasts for a limited number of hours. In these circumstances, a flexible resource may help reduce the immediate need for additional capacity.

However, batteries cannot solve every infrastructure problem. A transmission corridor that requires significantly greater physical capacity still requires physical investment. Similarly, if electricity demand continues increasing throughout the day and across multiple seasons, a short-duration battery may not provide sufficient capacity. Reliability planning also requires confidence that distributed resources will be available when needed.

There are practical challenges as well. Battery owners need to be willing to allow utilities or aggregators to control their assets. Frequent dispatches can affect battery operation, customer expectations and participation rates. At a July stakeholder meeting, Pepco Holdings discussed concerns about customer attrition in a Delaware bring-your-own-battery pilot. The program estimated annual performance payments of around $1,080 for participating customers, while the utility was also examining how frequently customers would tolerate battery dispatches.

These issues demonstrate why batteries should be viewed as a complement to infrastructure planning rather than a universal substitute. The most effective strategy will depend on the characteristics of each grid constraint, the availability of flexible resources and the economics of competing solutions.

What This Means for Commercial Energy Management

The development of programs such as New Jersey’s VPP initiative also changes the role of commercial buildings in the electricity system. A facility with battery storage, EV chargers, HVAC systems, solar generation or other flexible equipment may have the ability to change its electricity profile in response to prices or grid conditions.

However, flexibility begins with visibility. A facility needs to understand when its electricity demand peaks, what equipment drives those peaks, how much consumption can realistically be shifted and how changes in energy use affect operating costs. Without this information, installing a battery does not automatically create an optimized energy strategy.

For commercial facilities, this makes energy data increasingly valuable. Historical consumption patterns can identify recurring peaks. Real-time monitoring can show how operations affect demand. Utility rate data can indicate when electricity is most expensive. Together, these insights can help determine when a battery should charge or discharge and whether a facility has additional flexible loads that could be managed.

New Jersey’s approach points toward a broader change in grid planning. As electricity demand grows, some capacity may come from physical infrastructure while some can come from changing when electricity is consumed and stored. Batteries are therefore becoming more than storage assets. When strategically located, intelligently operated and coordinated across many facilities, they can become part of the grid’s capacity strategy. For commercial energy users, understanding their energy profile will be an increasingly important step toward capturing that value.