Directs BPU to establish virtual power plant program to reduce peak demand for electric energy.
S3399 would require the New Jersey Board of Public Utilities (BPU) to create a statewide virtual power plant program for electric public utilities. The bill defines a virtual power plant as an aggregation of distributed energy resources, such as solar, battery storage, electric vehicle chargers, smart thermostats, water heaters, and other controllable loads, that are coordinated to provide grid services. The stated goals are to reduce peak electricity demand, improve resource adequacy and reliability, and defer or avoid costly distribution and transmission upgrades.
The program must be designed to achieve a target of 500 megawatts of peak demand reduction by 2030. Within 12 months of enactment, the BPU must set minimum program requirements, including utility-specific targets, eligible technologies, technical and interoperability standards, customer compensation and performance rules, and requirements to include low- and moderate-income customers and overburdened communities. Electric utilities would then submit implementation plans for BPU review and approval, and they would have to file annual compliance reports. The bill also authorizes the BPU to set spending levels and rate of return parameters for utility participation, and it allows cost recovery only to the extent the program meets required metrics.
The bill would affect Title 48 utility law by adding a new regulatory framework for demand optimization and distributed energy resource aggregation. It would require utilities to coordinate with third-party distributed energy resource aggregators, but it expressly prohibits utilities from directly controlling customer devices or storage systems used in a virtual power plant. The measure also contemplates BPU rulemaking under the Administrative Procedure Act and could influence utility rates, grid planning, and wholesale market participation under PJM and FERC Order 2222.
Because there are no committee transcripts or recorded votes provided, the general sentiment can only be inferred from the bill text itself. The bill is strongly supportive of virtual power plants, emphasizing ratepayer savings, renewable integration, grid resilience, and environmental benefits. Its framing suggests a policy consensus in favor of demand-side grid management and clean energy deployment, though no formal legislative debate is available in the materials provided.
The main points of contention likely involve utility control, cost recovery, and implementation burden. The bill requires third-party aggregators—not utilities—to control customer resources, which may raise questions about market structure and operational responsibility. It also gives the BPU authority to reduce a utility’s allowed return on equity and disallow cost recovery if performance targets are missed, which could be controversial for utilities. Additional concerns may include whether the 500-megawatt target is feasible, how costs will be allocated to ratepayers, and whether the program can reliably deliver savings and benefits across different customer classes.
The bill would supplement Title 48 by directing the BPU to establish a new demand optimization and virtual power plant program for electric public utilities. It would require utility participation in a regulated framework for aggregating distributed energy resources, set performance and reporting obligations, and authorize the BPU to determine cost recovery, spending levels, and potentially a reduced rate of return on equity. It also would reinforce third-party aggregator participation in PJM wholesale markets consistent with FERC Order 2222 and could affect utility planning, customer enrollment, and grid modernization requirements.
No committee testimony or vote history was provided, so there is no recorded legislative sentiment to summarize from debate or roll calls. Based on the bill text, the measure is clearly favorable toward virtual power plants, distributed energy resources, and clean-energy-oriented grid management. The sponsor’s framing emphasizes cost savings, reliability, equity, and emissions reductions, indicating a positive policy posture toward the proposal.
The most likely areas of contention are the bill’s restrictions on utility control, its performance-based cost recovery provisions, and the practical feasibility of meeting the 500-megawatt peak reduction target by 2030. Utilities may object to being limited to an implementation role while third-party DER aggregators retain direct control over customer devices and storage. They may also resist the BPU’s authority to set spending caps, adjust return on equity, and disallow recovery of costs if program metrics are not met. Consumer advocates and policymakers could also scrutinize whether the program’s costs, benefits, and enrollment requirements are distributed fairly across all customers, including low- and moderate-income households and overburdened communities.