AEP Locks Up 13 GW of Gas Turbines Through 2031 as Generation Leads Its $78 Billion Growth Plan
America's largest transmission operator is betting heavily on gas capacity as turbine scarcity tightens and data centre load growth accelerates across its 11-state footprint.
American Electric Power added 3 GW of gas turbine capacity in the second quarter of 2026, bringing its total secured supply deployable by 2031 to roughly 13 GW, CEO Bill Fehrman told analysts on Thursday (2026-07-30) during the company's quarterly earnings call. The move is deliberate and competitive: Fehrman called turbines "a scarce resource" that will "become increasingly more valuable" and said AEP would "continue to be aggressive" in locking up positions with key suppliers.6
The scale of AEP's turbine acquisition reflects how fundamentally load growth is reshaping capital priorities at major US utilities. The company serves 5.6 million customers across 11 states and operates the nation's largest transmission network at 40,000 line miles. Its $78 billion, five-year capital plan running from 2026 through 2030 is already weighted toward generation, and Fehrman told analysts that new generation investments will play "a pretty central role" in driving long-term growth when the next iteration of the plan is unveiled this fall.6,1
Beyond the 13 GW secured for deployment by 2031, AEP has optioned a further 10 GW of turbines through 2035. AEP's CFO Trevor Mihalik noted that the timing of those options aligns with AEP's aging fleet, positioning the company to replace retiring coal plants and older gas units in its vertically integrated utilities. The resource plan underlying that build-out calls for 15.3 GW of gas, 6.4 GW of solar, 5.1 GW of wind, and 500 MW of storage. Pending requests for proposals across the utilities total 7.8 GW.6
The supply-side context makes AEP's early positioning look canny. The IEA reported that US companies placed orders for roughly 20 GW of gas turbine generation capacity in the first quarter of 2026 alone. The manufacturer's CEO flagged that a 30% production capacity increase "is not enough to meet growing demand." With 40% of new global orders originating in the United States, utilities that did not move early face a genuine wait.3
Bank of America analysts put numbers to the broader shortfall: the US will need more than 230 GW of new generating capacity over the next five years, but regulated utilities are on track to add only about 93 GW of accredited supply, leaving a gap of more than 100 GW. BofA also warned that planned additions likely overstate available supply because intermittent resources contribute less accredited capacity during peak demand than their nameplate ratings suggest. Where utilities fall short, BofA expects more data centre developers to pursue behind-the-meter generation, effectively routing around the regulated grid.5
The Tennessee Valley Authority's preliminary 2026 integrated resource plan, released on Monday (2026-06-22), illustrated how quickly conditions are moving. TVA said load growth in its footprint was already outpacing its reference case forecast and identified incremental capacity needs of between 7 GW and 26 GW of natural gas through the end of its planning horizon. TVA's higher-growth scenario explicitly accounts for a higher gas price environment driven by substantial economic activity — a scenario that increasingly looks like the base case rather than an upside.2
The spending environment is being reinforced at the policy level. The IEA, as cited by the Financial Times, projected US companies will spend roughly $50 billion on coal and gas generation in 2026 — the first time in decades that US spending on those fuels would exceed China's, with the gap at $3 billion. That figure captures the pace of US utilities' pivot back toward thermal generation after years of renewables-led capital allocation.3
AEP's Texas subsidiary has already tapped federal financing to support infrastructure expansion, reaching financial close on a loan of up to $3.26 billion from the Trump administration's Energy Dominance Financing Program in early July (2026-07-09). In October 2025, AEP Transmission separately secured a $1.6 billion loan guarantee from the DOE's Loan Programs Office. The availability of federal credit has given AEP a funding runway that smaller or less-capitalised utilities may struggle to match.4,1
On the engineering side, AEP contracted Worley in late May (2026-05-27) for engineering, detailed design, and procurement support on stages 3 and 4 of the 450 MW Northeastern U5/6 simple-cycle gas turbine project in Oklahoma, at the Public Service Company of Oklahoma's Northeastern Generation Facility. That project is one visible piece of a much larger construction pipeline.1
Fehrman's comments on PJM, the grid operator covering much of AEP's eastern footprint, were cautiously upbeat. He said the "pace and intensity of productive conversations with PJM has significantly increased," with positive engagement from PJM, FERC, and other stakeholders. He offered no specific timeline or interconnection figures. The gap between AEP's turbine acquisition programme and its ability to move generation through PJM's interconnection queue remains the most concrete execution risk embedded in the company's build-out plans.6