FERC Orders PJM to Open Demand Response to 24/7 Dispatch and Raises Capacity Accreditation from 69% to 92%
The Federal Energy Regulatory Commission directed PJM Interconnection on May 5 to dismantle the seasonal time windows that have governed demand response participation since the resource was first integrated into the capacity market. Beginning June 1, 2027, for the 2027/2028 delivery year, demand response resources in PJM will be required to be available 24 hours a day, 365 days a year, replacing the existing summer window of 10 a.m. to 10 p.m. and the winter window of 6 a.m. to 9 p.m.
Paired with the dispatch expansion is a structural revaluation of what a megawatt of demand response is worth on the capacity ledger. The Effective Load Carrying Capability rating, which determines how much of a resource’s nameplate counts toward capacity obligations, is projected to climb from 69 percent in the 2026/2027 delivery year to 92 percent in 2027/2028.
The accreditation math. ELCC is the haircut PJM applies to a resource based on how reliably it can serve load during the hours that drive system risk. A 69 percent rating on a one-megawatt resource means the operator gets paid for 690 kilowatts of capacity. At 92 percent, the same megawatt clears 920 kilowatts. The 23-point swing is the difference between a resource that the market treats as a part-time hedge and one that the market treats as functionally firm.
PJM’s most recent base residual auction cleared at $329.17 per megawatt-day for the 2026/2027 delivery year, the price ceiling under the current market rules. Applied to the ELCC delta, the per-megawatt-year revenue uplift on a fully accredited demand response resource is roughly $28,000 before any energy market or ancillary services revenue is layered on top. For a 2 MW commercial site running peak shaving on demand charges, the capacity stream alone moves from a rounding error to a meaningful contribution to project IRR.
The dispatch change. The 24/7 obligation is a harder lift than the accreditation change. Until now, demand response in PJM has been a summer afternoon and winter morning product. Curtailment Service Providers built portfolios around the assumption that customers would be asked to curtail load only during predictable high-demand windows. The new rule requires resources to be available at 3 a.m. on a Tuesday in October if PJM calls.
For traditional load-curtailment demand response, where a commercial customer agrees to reduce HVAC or production load on call, 24/7 availability is operationally awkward. Few facility managers are willing to commit to off-hours load reductions on short notice for the size of payment that demand response historically delivered.
For battery storage, the constraint flips. A 2 MW battery cycling on demand-charge avoidance during business hours sits idle from roughly 8 p.m. to 6 a.m. on most days. The 24/7 obligation that strains a load-curtailment portfolio is the natural operating envelope of a battery that already exists for another purpose.
The PJM capacity context. The May 5 order arrives in the middle of a capacity supply crisis that PJM has spent the last two auctions trying to manage. The 2025/2026 auction cleared at $269.92 per megawatt-day, an 833 percent increase over the prior year. The 2026/2027 auction hit the $329.17 price cap. PJM’s load forecast continues to rise on data center interconnection requests, with 67 GW of storage and 240 GW of generation in the reopened queue.
The Commission’s order is, in part, an attempt to add demand-side capacity faster than the supply-side queue can deliver new generation. Demand response is the only resource class that can be enrolled in months rather than years, and the ELCC rerating is a direct attempt to attract behind-the-meter capacity that has historically not been worth the enrollment paperwork.
The commercial procurement window. The structural shift that matters for commercial buildings is timing. Capacity accreditation reform is a 2027/2028 phenomenon, but the contracting cycle for that delivery year is happening now. Curtailment Service Providers in PJM are already building their portfolios for the 2027/2028 base residual auction. A commercial site that wants to capture the 92 percent ELCC rating needs to be enrolled, metered, and dispatchable through a CSP before the auction clears.
PJM territory covers 13 states and the District of Columbia, including the highest-demand-charge commercial markets in the eastern Interconnection: PSE&G in New Jersey, ConEd-adjacent territory under Orange and Rockland, BGE in Maryland, PECO in Pennsylvania, ComEd in Illinois, and Dominion in Virginia. The buildings whose underlying tariff structure already justifies on-site storage are concentrated in these utility footprints.
The stacking architecture. A commercial battery in PJM running on demand-charge avoidance now has three distinct revenue streams that do not conflict in time. Demand-charge reduction operates during the customer’s coincident peak windows, which are utility-specific but generally cluster in late afternoon. PJM capacity payments now require 24/7 availability but only call on resources during system stress events, which are rare and predictable. Energy market arbitrage operates on real-time prices that the operator can choose to chase or ignore.
The economic question for the next two years is whether the capacity uplift is large enough to compress payback periods on commercial systems that currently rely on demand-charge savings as the primary cash flow. At $28,000 per megawatt per year in incremental capacity revenue, a typical 2 MW commercial deployment picks up roughly $56,000 annually in stackable capacity payments on top of demand-charge savings that already pencil at six- to nine-year paybacks in PJM territory.
The risk side of the ledger. ELCC ratings are projections, not guarantees. The 92 percent figure is what PJM expects demand response to be worth at the 2027/2028 reliability requirement; the actual accredited value will be set by PJM’s Loss of Load Expectation studies closer to the auction. If the demand response participation surge that the Commission is trying to engineer actually materializes, ELCC will erode as the resource class becomes a larger share of capacity supply.
The structural change that will not erode is the 24/7 dispatch requirement. That is a one-way door. Once PJM rebuilds its portfolio around always-on demand response, the operational architecture of the resource class becomes a capability problem, not a window-management problem. The resources that can show up at 3 a.m. on a Tuesday will continue to clear; the ones that cannot will fall out.
The Commission’s order is, in effect, a regulatory selection event that favors batteries over load curtailment as the dominant form of behind-the-meter capacity in the largest electricity market in North America.
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