Four-hour battery storage outpaces gas peaker economics for 2026

Solmar Insights

Four-hour battery energy storage is now significantly less expensive than new-build gas peaker plants across global markets, including the United States, according to a new analysis from Wood Mackenzie. For projects with commercial operation dates in 2026, battery storage can be 65% to 75% cheaper than open-cycle gas turbines, a shift driven by surging turbine prices and increased volatility in natural gas fuel costs.

Gas turbine economics deteriorate

The economics of gas peaker plants have shifted dramatically due to a near tripling in gas turbine equipment prices since 2019. Wood Mackenzie projects turbine prices to reach $600 per kilowatt by late 2027, as global manufacturing backlogs mount for major suppliers such as GE Vernova, Siemens Energy, and Mitsubishi. These manufacturers collectively face demand queues ranging from 35 GW to as much as 116 GW, reflecting the challenge of balancing increased grid reliability needs while capital costs rise sharply.

This surge in capital expenditure coincides with escalating volatility in fuel markets, making gas peaking projects particularly exposed to operational expense risks. The report notes that backlogs and manufacturing bottlenecks are hindering new thermal buildouts at a time when grid operators are seeking flexible, dispatchable capacity to shore up system reliability.

Battery storage surpasses peaking plants on cost

Wood Mackenzie’s analysis found that the levelized cost of electricity (LCOE) for four-hour battery storage is now lower than that of new gas peakers not only in the United States but also in other global markets. In North America, the cost advantage is pronounced, with batteries estimated to be 65% to 75% less expensive than open-cycle gas turbines for 2026 project start dates, with figures varying based on state-level carbon pricing policies.

This cost differential is widening as manufacturing scale continues to drive down battery prices. The trend is reinforced by high demand from sectors such as data centers, which are increasingly viewed as major long-term drivers for renewable and storage investment to meet growing electricity requirements with lower-carbon power procurement strategies.

Data centers influence grid investment signals

Accelerating digital infrastructure investment, especially the proliferation of hyperscale data centers, is creating additional pressure on North American power markets and shaping future generation portfolios. The analysis notes that North America is likely to face a “supply deficit cycle” for gas-fired generation into the late 2030s, as surging data center load growth restricts available thermal capacity and keeps capital costs elevated for conventional resources.

The growing power requirements of AI, cloud, and colocation facilities are reinforcing the case for developers and institutional investors to prioritize both renewables and storage in generation expansion planning. As backup and fast-ramping solutions, battery projects are poised to displace gas peakers as the go-to asset for meeting incremental and peak load while enabling grid decarbonization targets.

Global trends in storage and renewables LCOE

The Wood Mackenzie report highlights dramatic cost improvements for utility-scale renewable and storage projects internationally. In 43 of 48 modeled markets, single-axis tracker solar installations are now the lowest-cost new-build resource, with onshore wind leading in five. Some of the world’s most competitive power markets, such as Saudi Arabia and the United Arab Emirates, are expected to see utility solar LCOE drop below $20 per megawatt-hour by 2033.

For battery storage, particularly in the Middle East and Africa, four-hour system LCOE is forecast to decline by 33% to $80 per megawatt-hour by 2035. The report positions China as the global price leader, with its battery storage costs roughly 55% lower than the average for the rest of Asia Pacific markets. These developments signal a growing opportunity for utilities and investors to accelerate the replacement of gas peakers outside North America as well.

Market impact for developers and institutional buyers

The decisive shift in cost parity between batteries and gas combustion peakers will reverberate through capacity markets and fixed resource adequacy procurement. Higher capital requirements and backlogs for new gas infrastructure are likely to tilt procurement away from thermal new-builds, favoring battery and renewable paired assets in both merchant and contracted arrangements. This trend is particularly relevant for market participants in ERCOT, CAISO, and PJM, where interconnection queues and data center off-take arrangements are shaping asset finance and deployment schedules.

For investors and infrastructure buyers, assessing the relative cost and availability of equipment is now inseparable from evaluating market revenue streams, with buyers more likely to secure battery equipment procurement and developer partnerships well in advance of peak demand years. Asset delivery risk, especially in thermal supply chains, is becoming a central factor affecting acquisition timing, pricing, and competitive positioning.

Reporting via the original publisher