AEP Expects 24 GW of New Load by 2030, Mostly Data Centers

American Electric Power, one of the largest U.S. utilities, says a huge wave of new demand is coming. In July 2025, AEP said it expects to interconnect 24 GW of new load by 2030, up from its earlier forecast of 20 GW.

For context, AEP's weather-normalized peak demand was 37.6 GW. Most of the new load is data centers.

Here is where AEP's new demand is coming from, how the utility plans to bridge the gap, and what it means for the grid and for solar owners.

How Much New Demand Does AEP Expect?

AEP expects to connect 24 GW of new load by 2030, up about 15% from its previous 20 GW forecast, with 18 GW of that coming from data centers, according to Utility Dive. Its weather-normalized peak demand was 37.6 GW, up 12% from a year earlier.

If all 24 GW showed up at peak, it would equal roughly 65% of AEP's current peak load. That's about the output of two dozen large nuclear reactors.

AEP also said its utilities had received inquiries for possible new load totaling 190 GW. Not all of that will materialize, but it shows how much demand is chasing available power.

Where Is AEP's New Load Coming From?

Most of AEP's new load is data centers, with a large block of cryptocurrency mining in Texas. CEO William Fehrman told analysts: "Texas is clearly becoming the crypto center for us."

The breakdown by region, according to Utility Dive:

• ●ERCOT (Texas). 13 GW, including about 5 GW of crypto operations and 2 GW of data centers.
• ●PJM. 9 GW, including about 3.7 GW of data centers in Ohio and 3.1 GW in Indiana Michigan Power's territory.
• ●Southwest Power Pool. 2.5 GW.

Both Texas and PJM are already under strain. We've covered how PJM is struggling to meet demand from AI, and how Texas has paused some data center interconnections.

How Is AEP Bridging the Gap?

AEP is turning to on-site fuel cells as a near-term bridge, with a Bloom Energy contract for 100 MW and an option to expand to 1 GW. In Ohio, regulators approved two contracts totaling about 98 MW of fuel cells, according to Utility Dive.

Fuel cells can be installed at customer sites faster than new power plants or transmission lines. But 100 MW, or even 1 GW, is small next to 24 GW of new demand.

It's a smart stopgap, not a solution. The bulk of the new load will still need new generation, new transmission, and new substations.

24 GW of new load is coming. The question is whether the grid can be built fast enough to serve it.

How Are State Policies Shaping the Response?

Ohio and Texas are taking opposite approaches to how utilities can serve large new loads. That will shape how quickly and how cheaply the new demand gets met.

According to Utility Dive:

• ●Ohio. House Bill 15, effective August 14, 2025, repealed provisions that let utilities offer customer-sited generation like fuel cells, while grandfathering existing contracts.
• ●Texas. House Bill 5247 allows eligible utilities to use a "unified tracker mechanism" to recover certain costs faster, encouraging investment.

These choices matter. Faster cost recovery can speed up grid building, but it also moves costs onto customer bills sooner.

Why Is Load Growth Like This a Grid Problem?

When demand grows faster than generation and transmission, prices rise and reliability gets harder to maintain. Utilities have to build substations, lines, and generation, and much of that equipment has long lead times.

Transformers and switchgear are among the biggest bottlenecks. Data center expansion depends heavily on imported electrical equipment, and shortages can delay projects by years.

There are faster tools, too. Data centers can act as grid assets by flexing their load during peak hours. Distributed solar and storage can add capacity close to where it's needed without waiting on major transmission builds.

What Should Grid Planners Prioritize?

The fastest path to meeting new load combines rapid distributed solutions like storage and on-site generation with longer-term investments in transmission and new generation.

Options that can move quickly:

• ●Battery storage. Shifts power into peak hours and supports local grids.
• ●Distributed solar. Adds generation close to load without major new transmission.
• ●Demand flexibility. Large loads that can reduce use when the grid is stressed.
• ●Existing assets at full output. Solar and other resources already connected, running at their best.

Which approach utilities and regulators lean into will shape bills for years.

Cost allocation matters just as much as speed. If utilities build large amounts of new infrastructure for data centers, regulators have to decide how much of that cost stays with the data centers and how much spreads to every other customer.

What Does This Mean for Solar Owners?

As utilities scramble to serve new load, every kilowatt-hour from existing solar becomes more valuable. Systems already connected to the grid don't need a place in an interconnection queue or a new substation.

But many older commercial systems are underperforming because of aging inverters or degraded panels. Repowering an aging PV system can restore that output using the connection you already have.

Start With a Ballpark Estimate

Demand is rising faster than new supply in much of the country. Find out what your existing solar project may be worth before deciding whether to repair, repower, or sell.

Source: Utility Dive, "AEP expects to add 24 GW of load by 2030, mainly from data centers"