How Wholesale Capacity Markets Affect Your Electricity Bill (2026)

If you’ve ever looked at your electricity bill and wondered why the per-kilowatt-hour price seems disconnected from headlines about natural gas being cheap, the answer often traces back to a market most consumers have never heard of: the wholesale capacity market. Capacity markets pay generators to stand by — to guarantee they’ll be available during the highest-demand hours of the next several years — and those payments roll straight through to your retail rate. Understanding how capacity charges work explains a meaningful slice of your bill, especially in deregulated markets across PJM, ISO-NE, and NYISO.

What is a wholesale capacity market?

Capacity markets are auctions run by regional grid operators (called ISOs or RTOs) to procure enough generation resources to meet projected peak demand three years out, plus a reserve margin. Generators bid the dollar-per-megawatt-day price they need to remain available; the auction clears at the price required to satisfy total capacity demand. Resources that clear are obligated to perform when called on during reliability emergencies, and they’re paid the clearing price for every day of the delivery year — whether they actually run or not.

The biggest capacity auctions in the U.S. are PJM’s Base Residual Auction, ISO-New England’s Forward Capacity Auction, and NYISO’s Installed Capacity (ICAP) market. ERCOT in Texas, notably, does not run a capacity market — it uses an energy-only model with scarcity pricing. That structural difference is one of the main reasons Texas electricity bills have a fundamentally different cost stack than bills in PJM states like Pennsylvania, Ohio, or New Jersey.

How capacity costs show up on your bill

Capacity charges reach residential and small-business customers through two main paths. First, your local utility (the “wires” company) recovers its share of capacity costs through a separate delivery-side rider — often labeled “capacity recovery,” “RPM charge,” or simply rolled into the distribution component. Second, your competitive supplier embeds wholesale capacity costs into the energy supply rate it quotes you when you sign a fixed-price contract. In states like New Jersey and Maryland, capacity-related charges can account for 15-25 percent of the all-in supply rate during high-priced auction years.

Because capacity prices are set years in advance, your bill today partly reflects auction outcomes from 2023 or 2024 — not what’s happening on the grid this month. When PJM’s 2025/26 auction cleared at $269.92 per megawatt-day, customers in PJM territories began absorbing those costs in mid-2025, regardless of what wholesale energy prices were doing in real time.

Why capacity prices have been climbing

Three forces are pushing capacity prices higher across most U.S. markets:

• Coal and older gas retirements: As large baseload plants exit the market, the capacity supply curve tightens, lifting clearing prices.
• Slow new-build pace: Permitting, interconnection queue delays, and capital cost inflation mean new generation isn’t replacing retiring units fast enough.
• Demand growth from data centers and electrification: AI compute load, heat-pump adoption, and EV charging are pushing forecast peak demand up sharply in certain zones — northern Virginia in particular.

The PJM 2025/26 auction clearing price jumped roughly 10x compared to the prior year’s auction. ISO-NE and NYISO have seen smaller but still meaningful increases. For competitive supplier quotes, this means the “embedded capacity” portion of a 12-month fixed price can shift dramatically between contract cycles.

How to read capacity costs in your supplier quote

Most retail electricity suppliers don’t itemize capacity costs on the residential quote — you see a single bundled cents-per-kWh number. But the differences between competing quotes often come down to how each supplier hedged their capacity exposure and which auction zones their customers sit in. A few practical signals to watch:

• Compare quotes for the same delivery period. A 12-month plan starting in June will price differently than one starting in October because capacity delivery years run June-May.
• Ask suppliers whether the quoted rate is fully load-following or block-priced. Load-following plans typically pass capacity changes through; block plans lock in the supplier’s hedged position.
• Look at “all-in” rate structures versus “energy only”. Some suppliers split out a separate monthly “capacity adder” — this can look cheaper on a per-kWh basis but adds back the same dollars.

What this means for residential decision-making

For most residential customers, the capacity market doesn’t change whether you should shop for a supplier — it changes when. Locking in a multi-year fixed rate right before a high capacity auction clears can leave you with above-market pricing for years. Conversely, locking in just after auction results are published gives you a clearer picture of what suppliers are baking into their offers. If you live in PJM territory (Ohio, Pennsylvania, Maryland, New Jersey, Illinois ComEd, Virginia, DC), watching the Base Residual Auction calendar — typically run each summer — gives you a planning advantage.

One nuance worth flagging: capacity costs don’t apply equally across customer classes. Large commercial and industrial customers can sometimes opt into “capacity-light” hourly pricing, while residential customers are typically billed on a class-average basis. That means your share of capacity costs reflects your zone’s peak demand contribution, not your individual usage pattern — though demand-response and time-of-use programs are increasingly tying individual behavior to capacity-related charges.

Where capacity policy is heading

Capacity markets are under active reform. PJM has proposed changes to how it values reliability, how demand response participates, and how renewables with storage qualify as capacity resources. ISO-NE is exploring a “Day-Ahead Ancillary Services Initiative” that would shift some capacity functions toward energy and reserve markets. Texas is debating whether to introduce a Performance Credit Mechanism — a capacity-like construct designed to address reliability concerns after Winter Storm Uri.

The direction of travel matters because reforms typically aim to send sharper price signals during scarcity hours. For residential customers, that increases the value of time-of-use plans, smart-thermostat enrollment, and home battery storage that can shave peak consumption.

FAQ

Why are capacity charges higher in PJM than in Texas?

PJM runs a forward capacity auction that pays generators to remain available. ERCOT (Texas) does not run a capacity market — it uses an energy-only design with scarcity pricing instead. The cost recovery happens through different mechanisms; both end up in retail bills, but the structure and predictability differ.

Does shopping for a competitive supplier let me avoid capacity charges?

No. Capacity costs are a wholesale-market reality that every supplier must hedge or absorb. Shopping helps you compare how suppliers have priced that exposure, but no retail offer eliminates the underlying cost.

When are capacity prices set for the coming year?

It depends on the region. PJM’s Base Residual Auction is held each summer for delivery three years forward. ISO-NE runs its Forward Capacity Auction in February. NYISO runs auctions on a six-month cycle for the upcoming capability period.

Can I lower my own capacity charges?

For residential customers, direct reductions are limited because charges are allocated on a class-average basis. Indirect savings come from time-of-use plans, demand-response enrollment, smart thermostats, and home batteries that reduce your peak-hour contribution. Commercial customers have more direct levers, including hourly pricing and demand response.

How long are the impacts of one auction felt on my bill?

Most capacity auctions cover a one-year delivery period, but supplier hedges and utility rate riders often spread the cost across longer windows. Expect a high auction clearing price to influence your rates for at least 12 months, and sometimes longer if your supplier hedged forward.

Bottom line: the wholesale capacity market is one of the largest invisible drivers of your electricity bill, and it operates on a multi-year planning horizon that’s only loosely connected to today’s natural gas or electricity headlines. Knowing when your region’s capacity auction results clear — and how your supplier prices that exposure — gives you real leverage when shopping for a new plan.