How to Hedge Factory Power Costs Inside PJM

Industrial electricity rates PJM manufacturers pay rose sharply in 2026. EIA puts the July average industrial price at 10.95¢/kWh in Ohio and 11.04¢ in Pennsylvania. Capacity is the fastest-growing piece of the bill. PJM capacity prices are now set through May 2029, so the hedges that work are a lower capacity tag, a better-structured energy contract and curtailment sold as demand response.

What plants in Ohio and Pennsylvania pay now

According to EIA's Electric Power Monthly (Table 5.6.A), Ohio's average industrial price was 10.95¢/kWh in July 2026, up from 9.05¢ a year earlier. Pennsylvania's rose from 9.87¢ to 11.04¢. Increases elsewhere in the PJM footprint were smaller in some states and larger in others:

Source: EIA Electric Power Monthly, Table 5.6.A, average industrial price.

The wholesale components explain where the increase came from. PJM's Independent Market Monitor, Monitoring Analytics, reported on August 13, 2026 that total wholesale cost rose from $76.16/MWh in the first half of 2025 to $114.50/MWh in the first half of 2026, an increase of 50.3%. The parts moved at very different rates:

• Energy: $49.21 to $72.68/MWh (+47.7%)

• Capacity: $6.39 to $19.61/MWh (+207.1%)

• Transmission: $18.82 to $19.88/MWh (+5.6%)

Energy is still the biggest line item. Capacity has roughly tripled per MWh, and it is the line a plant manager has the most direct control over.

Why it happened

PJM buys capacity three years ahead in its Base Residual Auction (BRA). In the auction for the 2024/25 delivery year, the RTO-wide price was $28.92/MW-day. For 2025/26 it was $269.92, and Utility Dive reported that consumers were expected to pay $14.7 billion for capacity that year, up from $2.2 billion. Some zones paid well above the RTO price: $466.35/MW-day in BGE (Maryland) and $444.26 in Dominion.

Every auction since has cleared at the FERC-approved cap:

• 2026/27: $329.17/MW-day, results released July 22, 2025 (PJM)

• 2027/28: $333.44/MW-day, auction held December 2025

• 2028/29: $325.00/MW-day, results released July 14, 2026 (PJM)

Data centers are a real factor, mostly through the capacity market. The IMM estimates that counting data center load in the capacity market raised first-half 2026 total wholesale cost by $11.11/MWh, or 9.7%, from $103.40 to $114.50. Through July, Utility Dive reported from the monitor's figures that data center load made up 9% ($10.48/MWh) of wholesale costs, and that data center load growth added $29.4 billion to capacity market revenues over the last four auctions. The monitor's office has recommended keeping forecast data center demand out of the capacity market and requiring data centers to bring their own new generation.

The energy price rose for other reasons. The real-time load-weighted average LMP went from $51.75 to $72.54/MWh, up 40.2%. The IMM attributes 45.3% of that increase to the transmission constraint penalty factor component and 34.9% to fuel and consumables. Market power accounted for 8.8% and emissions for 5.1%. Calling the whole increase a data center story gets the cause wrong, and it leads to the wrong hedge.

The capacity price is known. Your exposure to it is not.

All three capacity prices that run through May 2029 are now set: $329.17, $333.44 and $325.00 per MW-day. PJM said the 2028/29 cap was 2.5% below the year before. A plant can't hedge a price that is already fixed. What it can still change is the number of megawatts that price is multiplied by, and how its energy purchases are structured.

Supply is still tight. The 2028/29 auction procured 138,318 MW UCAP, plus 10,864 MW from FRR regions. It came in 6,831 MW short of the reliability requirement, the first time the whole RTO has missed the requirement in consecutive auctions. Total auction value was $16.4 billion. "These auction results show that demand for electricity continues to grow faster than electricity supply," PJM CEO David Mills said. PJM said it would ask FERC for approval to hold a special Reliability Backstop procurement in September 2026 to cover the shortfall. Prices after 2028/29 have not been set, and this article doesn't forecast them.

Enel North America has translated the 2028/29 cap into commercial and industrial terms. By Enel's figures, it equals $118,625/MW-year. Enel expects retail capacity charges to average about $110,000/MW-year, which it says comes to about 2.5¢/kWh at a typical 50% load factor and is "more than five times higher" than 2024/25, about 0.5¢/kWh.

Lever 1: Contract term and structure

This section is editorial analysis, not sourced fact.

Start by splitting the invoice into three parts: energy, capacity and transmission. Many retail contracts pass capacity and transmission through at cost. Others fold them into a fixed all-in price. With capacity prices set through May 2029, a fixed all-in price no longer protects the buyer from capacity-price risk, because that risk is gone. What it mostly locks in is the energy price, plus whatever premium the supplier charges for carrying uncertainty about your tag.

That has practical consequences:

• If you plan to cut your tag, a capacity pass-through lets you keep the savings. A fixed price built on last year's tag gives some of that value to the supplier.

• Energy is where term and structure matter. Energy was the largest wholesale component in H1 2026 at $72.68/MWh, and its drivers (congestion and fuel) are still moving. Fixed blocks, index pricing or a mix should be decided on energy exposure alone.

• Compare offers line by line. Ask each supplier to quote energy separately from capacity and transmission, so you can see where each one's premium is.

Expect fewer offers that beat the default rate. In its May 20, 2026 notice, the Pennsylvania PUC said "current wholesale market trends have resulted in fewer supplier offers below the utility rate than in prior years." The residential Price to Compare changes on June 1 ranged from +1.5% at PPL to +11.88% at Penelec, with West Penn at +10.3%. Those are residential default rates, not industrial prices. They are useful as a sign of the market's direction.

Lever 2: Peak-load management (your capacity tag)

Your capacity charge is your peak load contribution (PLC) multiplied by the capacity price. As quoted on BGE's supplier page from PJM rules: "PJM will identify the five highest weather normalized PJM system coincident load hours that occurred on different days over the period from June 1 through September 30." The PLC is based on the customer's load in those five hours (5CP), scaled to zonal load. The method above is BGE's. Ask your own utility how it calculates the tag.

Timing matters. AEP Ohio sends new PLC (capacity) and NSPL (transmission) tags to retail suppliers each December. PLC values run June 1 through May 31. NSPL values run on a calendar year. So summer 2026 load set the tag billed from June 2027 through May 2028, the year priced at $333.44. Summer 2027 will set the tag for 2028/29 at $325.00. The NSPL transmission tag is separate and on a different calendar, so check how it is set before assuming one curtailment plan covers both.

The value of cutting the tag. Take a hypothetical plant with a 5 MW PLC. Cutting 1.5 MW during the 5CP hours saves about 1.5 × $333.44 × 365 ≈ $182,600 in 2027/28. Spread over the plant's annual consumption at a 60% load factor, that is about 0.69¢/kWh.

Load-shedding steps on the floor are familiar ones. Run batch processes, ovens and heat-treat cycles in the morning or overnight on likely peak afternoons. Stage compressed-air and chiller loads so they don't peak together. Pre-cool, and build work-in-process ahead. PJM's 5CP hours fall on hot summer afternoons, but the plant won't know which five hours counted until afterward. Most plants act on peak alerts and accept some false alarms. Price those false alarms honestly: lost output on a missed shipment can outweigh a share of the capacity savings. ManufacturingMag's downtime cost calculator separates lost contribution from recovery costs, which is the comparison to make before committing a line to curtailment.

Lever 3: Demand response

Lowering your tag cuts your own bill. Demand response sells your flexibility to the grid. There are two broad types:

• Load management (capacity DR): you commit curtailable MW as a capacity resource and are paid for it. If PJM calls and you don't deliver, you pay penalties.

• Economic DR: you choose to reduce load when energy prices are high, and you are paid for the reduction, with no standing capacity obligation.

The program is large and is being used. PJM's Summer 2026 outlook projected an expected peak of about 156,400 MW, against about 180,200 MW of generation and about 7,800 MW of contracted demand response. PJM called on non-emergency DR six times in summer 2025. Michael Bryson, PJM's SVP of Operations, cited "continued load growth driven by data centers outpacing new generation." Demand response made up about 5% of the 2028/29 cleared capacity mix.

The main risk is committing more curtailment than you can deliver. A plant that enrolls 2 MW but can only shed 1.2 MW on a high-production day pays penalties that can wipe out the payment. Enel says new DR penalty structures and audit rules take effect in 2028/29. Any curtailment provider's terms should be read with that in mind. Base your commitment on the load you can reliably shed during peak season, not on nameplate capacity.

Lever 4: On-site generation and storage

Running behind-the-meter generation or discharging a battery during likely 5CP hours lowers the load the utility measures, and so lowers the tag. A battery sized to cover the peak-alert afternoons is the cleanest way to get the 1.5 MW reduction in the example above without cutting output. Get site-specific quotes; this article doesn't assume equipment costs.

Backup diesel is a separate question. Emergency-certified engines can't simply be enrolled as demand response. EPA's RICE NESHAP technical documents page lists guidance dated April 15, 2016 on the vacatur of RICE NESHAP and NSPS provisions for emergency engines, along with the D.C. Circuit mandate for the vacatur dated May 4, 2016. Bring in your air-permit team before any generator is included in a peak-shaving or DR plan.

Worked example: one 5 MW tag across four auctions

Illustrative only. This is ManufacturingMag's arithmetic on verified RTO clearing prices for a hypothetical plant with a 5 MW PLC at a 60% load factor (26,280 MWh/yr). It leaves out utility scaling and capacity-loss factors, zonal price differences and retail margins, so actual bills will differ.

For context, the IMM's H1 2026 wholesale energy component was $72.68/MWh (about 7.27¢/kWh) and transmission was $19.88/MWh (about 1.99¢/kWh). Both are wholesale averages, not retail rates. At the 2024/25 price, capacity cost was a rounding error next to energy. Now it is roughly a third the size of energy, and tag management alone can move it by about 0.7¢/kWh.

Plant manager checklist

• Find your tags. Pull your current PLC and NSPL from your supplier invoice or utility data, and note which summer set each one.

• Map peak-hour load by line. Use interval data from last summer's likely 5CP afternoons to see which lines, compressors and HVAC loads were running.

• Price a curtailment plan. For each load you could shed, weigh lost contribution and recovery cost (use the downtime cost calculator) against about $121,700 per MW-year of capacity value at the 2027/28 price.

• Decide on DR enrollment. Commit only the MW you can deliver on your busiest peak day.

• Then set the contract. Choose energy term and structure on energy risk, and make sure the capacity line passes through so your tag savings show up on the bill.

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• More Sustainability coverage

Sources

• PJM Inside Lines: 2028/29 Base Residual Auction results

• PJM Inside Lines: 2026/27 Base Residual Auction results

• Utility Dive: PJM capacity prices hit record highs (July 31, 2024)

• Monitoring Analytics: Market Monitor H1 2026 release (Aug 13, 2026)

• Utility Dive: Data center load made up 9% of PJM wholesale costs (Aug 27, 2026)

• EIA Electric Power Monthly, Table 5.6.A

• Pennsylvania PUC: June 1, 2026 price changes

• Enel North America: PJM 2028/2029 capacity auction results

• BGE Supplier: Peak Load Contribution overview

• AEP Ohio: CRES calculation processes

• PJM Inside Lines: Summer Outlook 2026

• EPA: Technical documents, RICE NESHAP