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The Federal Energy Regulatory Commission (FERC) has approved the first batch of capacity market reforms for ISO New England, according to ISO Newswire. These changes will shift auctions to a "prompt" timeline beginning in 2028 and modify how power plants can exit the market.

TL;DR: Starting in 2028, New England's capacity market will operate on a faster timeline that could improve electricity supply planning and potentially affect rates. While these are wholesale market changes, they may influence the competitive electricity rates available to consumers in Maine, New Hampshire, Massachusetts, and Rhode Island over time.

Last updated: 2026-04-01

What Are Capacity Markets and Why Do They Matter?

Capacity markets ensure there's enough electricity generation available to meet peak demand, even during the hottest summer days or coldest winter nights. Unlike energy markets that pay for actual electricity produced, capacity markets pay power plants simply to be available when needed.

ISO New England operates the capacity market for the entire region, including Maine, New Hampshire, Massachusetts, and Rhode Island. Power plants bid to provide capacity three years in advance, creating a forward market that signals whether new generation is needed.

These wholesale market mechanisms ultimately influence the rates that competitive suppliers can offer consumers. When capacity costs rise, electricity rates typically follow. When the market operates more efficiently, those savings can flow through to consumer rates.

The 2028 Changes Explained

The approved reforms introduce two major changes to how New England's capacity market operates:

Prompt Capacity Auctions

Starting in 2028, capacity auctions will shift from the current three-year forward timeline to a "prompt" schedule. This means auctions will occur closer to the actual delivery period, giving market participants better information about real-time conditions.

The current system requires power plants to commit to providing capacity three years in advance, often based on uncertain forecasts. The new prompt timeline allows for more accurate planning based on actual market conditions and resource availability.

Modified Exit Procedures

The reforms also change how power plants can retire or exit the capacity market. Under the new rules, generators will have different procedures for notifying ISO-NE about planned retirements, potentially affecting long-term supply planning.

These exit rule changes aim to provide better visibility into which power plants might retire, helping ISO-NE plan for replacement capacity or transmission upgrades.

Impact on New England Electricity Rates

While capacity market changes happen at the wholesale level, they can influence the competitive electricity rates available to consumers across New England's deregulated markets.

Rate Implications by State

Massachusetts: With current basic service rates around 15.4 cents per kWh for National Grid customers and 15.6 cents per kWh for Eversource customers, any wholesale market efficiency improvements could help competitive suppliers offer better rates relative to these benchmarks.

Rhode Island: Rhode Island Energy customers currently pay about 14.8 cents per kWh for last resort service. More efficient capacity markets could support competitive pricing in this smaller market.

New Hampshire: Eversource customers face default service rates of 11.3 cents per kWh, while Liberty Utilities charges 13.7 cents per kWh. Capacity market improvements may help competitive suppliers better compete with these relatively lower default rates.

Maine: Central Maine Power's standard offer sits at 12.7 cents per kWh, with Versant Power at 13.0 cents per kWh. Enhanced market efficiency could benefit the competitive options available to Maine consumers.

Why the Timing Matters

The 2028 implementation timeline gives market participants two years to prepare for the new auction format. This transition period is crucial as New England faces several energy challenges:

Winter Reliability Concerns: New England's electricity system faces stress during cold snaps when natural gas is diverted to heating. The prompt auction timeline could better account for these seasonal reliability needs.

Resource Transitions: As older power plants retire and renewable resources grow, the capacity market needs to adapt quickly. Prompt auctions provide more flexibility to manage this transition.

Grid Modernization: The region is investing heavily in transmission upgrades and energy storage. More responsive capacity markets can better integrate these new technologies.

What This Means for Energy Consumers

For residential and business electricity customers in New England's deregulated markets, these capacity market reforms represent a step toward more efficient wholesale pricing. While you won't see immediate changes to your electricity bill, the reforms could influence competitive supplier rates over time.

Near-term (2026-2027): Current capacity market rules remain in effect. Focus on comparing available competitive rates against your utility's default service rate.

Medium-term (2028-2030): As prompt auctions begin, monitor whether competitive suppliers can offer better rates due to improved wholesale market efficiency.

Long-term (2030+): Enhanced capacity market operations may contribute to more stable and competitive electricity pricing across the region.

Current Rate Comparison Opportunities

While waiting for these wholesale market improvements, New England consumers can already take advantage of competitive electricity markets:

• Massachusetts consumers can compare competitive rates against basic service rates ranging from 13.7 to 16.2 cents per kWh depending on their utility
• Rhode Island residents can evaluate options against the 14.8 cents per kWh last resort service rate
• New Hampshire customers have opportunities to beat default service rates of 11.3 to 13.7 cents per kWh
• Maine consumers can seek competitive alternatives to standard offer rates of 12.7 to 13.0 cents per kWh

Regulatory Oversight and Consumer Protection

The Maine Public Utilities Commission, New Hampshire PUC, Massachusetts DPU, and Rhode Island PUC maintain oversight of retail electricity markets in their respective states. These regulators ensure that wholesale market changes like the capacity reforms don't negatively impact consumer protections.

FERC's approval of these reforms follows extensive stakeholder input and analysis. The commission determined that the prompt auction timeline and modified exit procedures will enhance market efficiency while maintaining reliability standards.

How to Stay Informed About Rate Changes

Capacity market reforms happen gradually, but electricity rates can change more frequently based on various market factors. Here's how to stay on top of rate changes:

Monitor Default Service Rate Updates: Each utility publishes new default service rates on a scheduled basis - typically every six months in Massachusetts and at different intervals in other states.

Compare Competitive Options Regularly: The relationship between default service rates and competitive offers changes as market conditions evolve. What looks expensive today might become competitive tomorrow.

Understand Your Current Plan: Review your electricity supply contract to know when it expires and what rate you'll pay if you don't take action before renewal.

Next Steps for Consumers

While the 2028 capacity market reforms represent positive long-term changes for New England's electricity system, consumers don't need to wait to potentially save on their electricity bills.

Comparing plans on Gatby is always free, and you can see current competitive rates available in your area. The platform helps New England consumers navigate the differences between utility default service and competitive supplier options.

Gatby's automated platform monitors rate changes and contract renewals, ensuring you don't miss opportunities to save as market conditions evolve. With capacity market improvements coming in 2028, having automated energy management becomes even more valuable for capturing the benefits of a more efficient wholesale market.

Whether you're in Massachusetts dealing with basic service rate changes, or in Maine evaluating standard offer alternatives, staying engaged with your electricity options helps you benefit from both current competitive rates and future market improvements.

Written by Hash Manesia, Energy Market Analyst at Gatby. Hash Manesia covers deregulated electricity markets across Texas and the Northeast, helping consumers navigate plan selection, rate comparison, and energy policy changes.

Reviewed by the Gatby Editorial Team on 2026-04-01

Frequently Asked Questions

When will the New England capacity market changes take effect?

The FERC-approved capacity market reforms will begin implementation in 2028. The shift to prompt auctions and new exit procedures will be phased in over the 2028-2030 timeframe. Current capacity market rules remain in effect through 2027, so there are no immediate changes to wholesale electricity markets or consumer rates.

Will these capacity market changes directly affect my electricity bill?

The capacity market reforms happen at the wholesale level and won't directly change your electricity bill. However, they may influence the competitive rates that suppliers can offer over time. More efficient wholesale markets can lead to better competitive pricing, but your immediate rate depends on your current electricity supply contract and local utility default service rates.

How do capacity markets differ from regular electricity markets?

Regular electricity markets pay power plants for actual electricity they produce hour by hour. Capacity markets pay power plants just to be available when needed, even if they never actually run. This ensures there's enough generation capacity to meet peak demand during extreme weather. Both markets influence the total cost of electricity that flows through to consumer rates.

Should I wait until 2028 to switch electricity suppliers?

No, you shouldn't wait for the 2028 capacity market changes to evaluate competitive electricity options. These reforms may improve wholesale market efficiency over time, but competitive rates are available now that could save money compared to utility default service rates. Current Massachusetts basic service rates range from 13.7 to 16.2 cents per kWh, while other New England states have their own default service benchmarks you can compare against immediately.

Which New England states will be affected by these capacity market changes?

All New England states participating in ISO-NE's capacity market will be affected, including Maine, New Hampshire, Massachusetts, Rhode Island, Connecticut, and Vermont. However, only Maine, New Hampshire, Massachusetts, and Rhode Island have fully deregulated retail electricity markets where consumers can choose competitive suppliers. The capacity market changes may influence wholesale costs across the entire region regardless of retail market structure.

How can I track whether these changes improve my electricity rate options?

Monitor your utility's default service rate changes and compare them regularly against competitive supplier offers. Default service rates typically change every six months in Massachusetts and on different schedules in other states. Automated energy management platforms can help track these changes and identify savings opportunities as wholesale market efficiency improvements from the capacity reforms potentially flow through to competitive rates over the 2028-2030 timeframe.