“Data centers will account for nearly half of electricity demand growth in the US between now and 2030,” the International Energy Agency said in April 2025, highlighting a seismic shift in the US energy scene. Underpinning this change is a clash of policy, market drivers, and technological upheaval all set against the stage of political brinksmanship surrounding clean energy incentives and a record boom in both artificial intelligence (AI) infrastructure and liquefied natural gas (LNG) exports.
The ongoing Congressional debate on the repeal of federal clean energy incentives and tax credits for renewables and battery storage brought about by the House GOP’s ambitious reconciliation bill has triggered alarm bells in the entire energy industry. As the Chesapeake Climate Action Network Action Fund’s Quentin Scott said, The fossil fuel industry is smiling all the way to the bank with the passage of the so-called ‘One Big Beautiful Bill’; meanwhile, the American people will pay higher prices for dirtier and less reliable energy (the bill could cut growth in clean energy jobs and raise household energy bills by $32 billion over the next decade). Even some of the House Republicans who supported the bill have since called on the Senate to make the most drastic reductions less sharp, saying that “this approach jeopardizes ongoing development, discourages long-term investment, and could significantly delay or cancel energy infrastructure projects across the country” (House Republicans warn of disruption to energy projects).
The stakes are unusually high. The U.S. grid, which has been used to steady-state growth for so long, is now confronted with a historic peak of demand. The Department of Energy’s 2024 report projects that data center load growth has tripled in the last ten years and will double or triple again by 2028, with data centers potentially accounting for between 6.7% and 12% of all U.S. electricity by 2028 (DOE report on data center energy use). Goldman Sachs Research projects that global power demand from data centers will increase 50% by 2027 and as much as 165% by 2030 compared to 2023, with the U.S. accounting for the largest share of this growth (AI to drive 165% increase in data center power demand by 2030).
AI’s appetite for electricity is only one side of the equation. The U.S. is also experiencing an LNG export boom. Based on the Energy Information Administration, U.S. LNG export capacity will grow by nearly 50% by 2028, with new terminals such as Plaquemines LNG and Golden Pass LNG entering into production (U.S. LNG export capacity). Consequently, Bank of America and EIA projections both expect Henry Hub natural gas spot prices to almost double between 2024 and 2026, led by skyrocketing LNG exports and shrinking domestic supply (U.S. gas prices may double due to LNG exports). By 2028, LNG exports will account for more than 20% of U.S. natural gas output, exerting further upward pressure on prices for domestic users and power producers.
The combination of these trends—increasing demand from AI and data centers, increasing LNG exports, and threatened reductions in clean energy incentives—has produced a perfect storm for electricity prices. Senate Energy and Natural Resources Committee ranking member Martin Heinrich cautioned during the POLITICO Energy Summit, “We’re in a constrained supply environment and an increased demand environment. People’s electricity bills all over the country are going to go up.” He said, “If you’re not building renewables and storage over the next five years, you’re only artificially increasing the cost of electricity everywhere.”
The engineering and market realities that underlie such warnings are grim. The lead time for new dispatchable capacity—natural gas or nuclear—can be three to five years or longer, complicated by supply chain constraints, delays in permits, and shortages of labor (McKinsey on new power plant lead times). Combined-cycle gas turbines, for instance, now have up to five-year lead times, and major transmission project permitting can last more than a decade. The SunZia Transmission Project, quoted as an example, took 17 years to get past permitting.
Utilities and grid operators are racing to catch up. The North American Electric Reliability Corporation forecasts 78 GW of winter peak demand growth over the next decade, with some regions such as Texas (ERCOT) and the Mid-Atlantic (PJM) facing double-digit percentage increases in peak load (Strategic Perspectives on U.S. Electric Demand Growth). Yet, grid expansion and new generation are not keeping pace. The danger, as the Center for Strategic and International Studies points out, is underbuilding rather than overbuilding causing reliability deficiencies, delayed economic growth, and increased costs to consumers.
In the meantime, the energy industry’s resiliency is being put to the test by changing policy cues. The sudden phasing out of clean energy tax credits risks to halt or cancel scores of renewable and storage projects, working against the very technologies that would be able to insulate the grid from volatility and increasing costs of fossil fuels. According to ICF, “Utilities and other electric grid stakeholders will be constrained in their ability to meet the demand growth in some regions due to limited capacity to connect new generation to the grid or deliver more electricity to customers” (ICF on grid constraints).
A few utilities and technology firms are testing out new business models such as colocation of data centers with on-site generation and innovative rate models that transfer transmission costs from residential to commercial customers (Deloitte on data center power strategies). But the scope of the challenge is overwhelming: estimates suggest U.S. utilities could require $36 billion to $60 billion in grid investment by 2030 simply to meet demand from data centers alone.
The boom in LNG exports presents a further complication. With U.S. exports on the rise, prices for gas domestically are more closely tied to world markets. The Department of Energy’s recent estimate determined that a 32.6 Bcf/d increase in LNG exports would increase U.S. wholesale gas prices by 31%, with independent studies indicating the impact could be higher (DOE and RFF on LNG export price impacts). Rates of methane leakage, which are the source of controversy during climate arguments, add to the environmental mathematics of increased gas exportation.
With the U.S. working its way through this new era of energy consumption, the interplay of political policy, market incentives, and technology innovation will influence not just electricity prices, but the country’s industrial competitiveness and climate path as well. The future will depend on skillful policy balancing, stepped-up investment in grid infrastructure, and a practical approach to reconciling reliability, affordability, and sustainability in an evolving energy system.
