Gas Power Is Moving Back Into the U.S. Grid as AI Data Centers Drive Demand

Natural gas is making a comeback in U.S. power planning. Not because renewables disappeared. Not because solar and batteries stopped growing. The reason is simpler: electricity demand is rising fast, and data centers want power that runs all day and all night.

For years, the backlog of power projects waiting to connect to the U.S. grid was dominated by renewables and battery storage. Solar, wind, and storage projects were flooding interconnection queues across the country. Gas looked like it was losing ground.

Now the picture is changing.

Grid operators in several regions are seeing a jump in proposed natural gas plants. The biggest driver is the AI data center boom. These facilities use huge amounts of electricity and need stable power. That has pushed utilities, developers, and grid operators to look again at gas-fired generation, which can run whenever fuel is available.

This is not a full reversal of the clean energy transition. Solar and storage are still expected to add more total capacity over time. But gas is no longer sitting quietly in the back of the line.

It is back in the conversation.

Why Gas Is Rising Again

The basic problem is load growth.

Data centers built for artificial intelligence need massive amounts of electricity. They are not small office buildings. They are industrial-scale power users. They run servers, cooling systems, networking equipment, and backup systems around the clock.

That makes them different from normal commercial demand.

A solar farm can produce cheap power during the day. Wind can produce strong output when conditions are right. Batteries can help fill short gaps. But data centers often want constant power, not power that changes with weather or time of day.

That is where natural gas comes in.

Oliver Kerr, managing director at Aurora Energy Research, said gas is seeing a “major resurgence” in interconnection queues across the country. He pointed to expected load growth, especially from data centers, as one major cause. He also noted that federal policy support is playing a role.

Rystad Energy analyst Reid Ramdathsingh made the point more bluntly. He said many grid operators are realizing they need more thermal capacity on the grid to meet rising demand.

Translation: the grid needs power it can call on when needed.

Texas Shows the Shift Clearly

Texas is one of the clearest examples.

For the last six months, natural gas generation in the Electric Reliability Council of Texas interconnection queue has surpassed wind. That is the first time gas has overtaken wind in the queue since January 2016.

The numbers show how fast the shift has been.

Gas projects in ERCOT’s queue rose from about 12,500 megawatts in March 2023 to nearly 64,000 megawatts as of last month. That is more than a 400% increase. Wind projects also grew, but much more slowly, rising from 25,700 megawatts to about 48,000 megawatts over the same period.

Solar and battery projects still dominate the Texas queue overall. Together, they account for about 75% of the 458,000 megawatts waiting to connect. But gas moving ahead of wind is still a major signal.

The reason is not hard to understand.

Data centers are pouring into Texas.

ERCOT data shows around 360,000 megawatts of prospective demand tied to data center projects. That number alone would be more than four times the grid’s record peak demand of 85,500 megawatts, set in August 2023. Not all of those projects will get built. But if even a meaningful share becomes real, Texas will need a lot more power.

ERCOT CEO Pablo Vegas told state lawmakers that if anything close to that level of demand materializes, the grid will clearly need more gas generation to stay balanced and reliable.

That is the point.

The grid cannot run on hopes. It needs firm capacity.

Policy Is Helping Gas Too

Texas is also using policy to support gas.

The Texas Energy Fund, passed by the Legislature in 2023, offers low-interest loans to developers of dispatchable power. That means power plants that can ramp up and down as grid demand changes. Gas-fired plants fit that category.

About 9,000 megawatts of projects in the ERCOT queue are receiving loans from the fund. ERCOT described many of those as near-term gas projects expected to come online.

Other grid operators are also changing their rules in ways that help gas.

PJM, the largest grid operator in the U.S. and home to Virginia’s “data center alley,” moved from a first-come, first-served interconnection model to a first-ready, first-served system. That change has shifted the queue toward projects that are more ready and often more dispatchable. PJM said in April that gas now leads its newly reformed queue, a major change from four years earlier, when renewables and storage made up 95% of the backlog.

The Midcontinent Independent System Operator has also created a fast-track process. In its latest cycle, the 8 gigawatts of generation resources consisted of battery storage and fossil fuels, with gas making up about 71% of the estimated capacity.

Fast-track systems do not openly say “gas only.” But when they reward projects that can produce on demand, gas benefits.

Wind Is Slowing Down in Texas

Gas is rising partly because wind is facing more resistance.

Texas was once the symbol of the U.S. wind boom. A decade ago, wind power was growing fast and drawing heavy investment. But now wind has fallen behind every other major generation source in ERCOT’s queue.

There are several reasons.

First, the best sites have already been developed. West Texas and coastal regions with strong wind, available land, and transmission access are no longer wide open. As Joseph Rand of Lawrence Berkeley National Laboratory put it, much of the “low-hanging fruit” has already been picked.

Second, transmission congestion has become a problem. Wind generators in crowded regions can be forced to curtail output because the lines cannot move all the electricity to customers. That cuts into profits.

Third, solar has become cheaper. Lawrence Berkeley data cited in the Texas Tribune report showed solar costs dropping from around $160 per megawatt-hour in 2010 to around $70 in 2024. That makes solar, especially solar paired with batteries, a stronger business case in many places.

Fourth, policy uncertainty is making investors nervous. Federal actions and permitting reviews can slow wind projects, including reviews tied to aviation rules for structures over 200 feet tall.

Gas is rising while wind is dealing with all of that.

Gas Has Its Own Problems

The gas comeback is not simple.

The biggest problem is equipment.

New gas plants need turbines, and the turbine supply chain is tight. Wood Mackenzie estimates that many new gas resources may not come online until 2030 or 2031 because of turbine shortages.

Texas developers are already looking for workarounds. Some are repurposing turbines originally designed for aircraft or cruise ships. In El Paso, the city utility is planning a gas plant using 813 small gas generators to produce 366 megawatts for a Meta data center.

That sounds extreme, but it shows how urgent the demand is.

University of Texas grid researcher Joshua Rhodes said the financial loss of not getting a data center running quickly can be measured in billions of dollars. That kind of money pushes companies toward unusual solutions.

Not Every Project Will Be Built

Interconnection queues are not construction lists. They are waiting lists.

Many projects never get built.

In ERCOT, Lawrence Berkeley National Laboratory data shows only about 22% of projects in the queue actually reach completion. That is still the highest completion rate of any grid in the country.

So the surge in gas proposals does not mean every plant will be built. But it does show what developers think the market wants.

And some gas projects are becoming more serious. Aurora Energy reported that over the past year, new-build gas-fired capacity with signed interconnection agreements grew by 13 gigawatts. Signed agreements usually mean a higher chance of a project getting built.

Renewables Still Lead the Long-Term Buildout

Gas is coming back, but renewables are not leaving.

Wood Mackenzie estimates that new gas resources in the U.S. will add 72 gigawatts of capacity between 2026 and 2030. Over that same period, storage, solar, and onshore wind are expected to add 268 gigawatts combined.

That is the bigger picture.

Gas is gaining because reliability is becoming more urgent. Renewables are still gaining because they are cheap, scalable, and fast to deploy in many regions.

The grid is not choosing one thing. It is trying to survive a demand shock.

The Bottom Line

Natural gas is moving back into U.S. power planning because data centers are changing the math.

AI needs electricity. Data centers need steady power. Grid operators need resources they can dispatch when demand rises. Gas fits that need, even as solar and batteries continue to dominate many queues.

The key facts are clear:

• Gas projects are rising in U.S. interconnection queues.
• AI data centers are a major driver.
• Gas has overtaken wind in Texas’ queue for the first time since 2016.
• ERCOT gas proposals grew from 12,500 MW in 2023 to nearly 64,000 MW.
• Solar and batteries still dominate the Texas queue overall.
• Gas projects face turbine shortages and long delivery timelines.
• Renewables are still expected to add far more capacity than gas through 2030.

This is not a clean energy collapse.

It is a reliability scramble.

The grid is being asked to power a new wave of AI infrastructure faster than planners expected. Gas is getting another shot because it can promise firm power. The question is whether that promise arrives fast enough, cheap enough, and without locking the grid into another long cycle of fossil fuel dependence.