How Liquid Natural Gas Export Boom Might Impact the US

With U.S. overseas sales forecast to double by 2030, some ask, ‘Will high-dollar offshore demand lower domestic supply and raise local electricity bills?’

Sempra and ConocoPhillips announce strategic partnership for Port Arthur LNG on Texas Gulf Coast. Courtesy of Sempra

Surging global demand for natural gas and the build-out of three new Gulf of America export terminals will spur a 20 percent boost in 2025 and a 15 percent increase in 2026 in domestic liquid natural gas (LNG) production, the Energy Information Administration projects in its March 2025 Short-Term Energy Outlook.

“We expect U.S. LNG exports to continue growing, driven by the start-up of three new facilities” that will expand the nation’s export capacity by 50 percent when fully operational this year,” the administration said in an April 3 analysis of the outlook.

The updated analysis was needed after preliminary data from the London Stock Exchange Group (LSEG) indicated U.S. producers exported a record monthly amount of liquefied natural gas in March, more than 70 percent to Europe, surpassing their December 2023 record.

That indicates a natural gas market growing faster than previous Energy Information Administration, LSEG, and S&P Global forecasts anticipated, although significant increases in U.S. liquid natural gas exports in 2025 were universally anticipated.

With Plaquemines LNG Phase 1 starting operations in December 2024 and functioning at 140 percent capacity in March, Corpus Christi LNG’s Stage 3 producing its first LNG in February, and Golden Pass LNG expected to come online soon, last month’s sharp surge still surprised some analysts.

“Its impact penetrates deep into the heartland where gas is produced and transported, and supports supply chain and manufacturing communities in the Northeast, Midwest, and Southeast,” S&P Global stated in its December 2024 report titled “US Industry at a Crossroads: A US LNG Impact Study.”

LNG exports from the United States have increased every year since starting from scratch in 2016 to becoming the world’s largest exporter by 2023, the Energy Information Administration reported.

President Donald Trump’s lifting of the Biden administration’s LNG export permit pause cleared the way to complete the three underway liquefaction plant and export terminal projects.

Trump’s “drill baby drill” policy seeks to boost fossil fuel production, especially natural gas, to lower domestic electricity costs and pay down the nation’s nearly $37 trillion debt with exported LNG. The United States is the world’s largest producer and exporter of natural gas.

“With more favorable conditions under the new administration, U.S. LNG exports are forecast to double by 2030, with projects currently under construction accounting for approximately 60 percent of that projected growth,” S&P Global said in its study, which was co-sponsored by the U.S. Chamber of Commerce.

The study projects that the U.S. LNG industry will contribute $1.3 trillion to the nation’s economy by 2040, with 90 percent of every dollar spent in domestic supply chains, creating an annual average of 500,000 jobs, including nearly 40 percent in “non-producing states.”

There are now eight large U.S. LNG export plants in Texas and Louisiana. Six other Gulf LNG plants could be proposed within two years, Reuters reported. A state-sponsored export terminal at the end of an 800-mile pipeline in Alaska and a revived project in Oregon are vying to become the first U.S. LNG ports on the West Coast.

Shell stated in its LNG 2005 outlook that worldwide demand will increase by about 60 percent by 2040. S&P Global stated that U.S. producers could supply more than a quarter of that global demand.

Some, including the Energy Information Administration, warn domestic power consumers may pay a price in the form of higher electric bills if too much natural gas is shipped away as LNG.

Consumers Pay the Price?

According to the Energy Information Administration’s March short-term outlook, annual LNG demand exceeds supply in both 2025 and 2026, leading to lower natural gas inventories and increasing prices in both years.

In fact, the administration projects the “Henry Hub natural gas spot price”—the market price-setter—will double by March 2026 with nearly all growth destined for high-dollar export.

“Varying levels of LNG exports translate directly” onto domestic natural gas prices, the outlook explains. With lower LNG exports, less natural gas is used for liquefaction and more is retained in underground storage, resulting in lower natural gas prices.

“Conversely,” it reads, “more LNG exports would result in lower volumes in underground storage and likely higher natural gas prices.”

FXEmpire analyst Christopher Lewis says in an April 3 technical analysis that building out export capacity and filling it up could tighten domestic natural gas supply over time, but it won’t likely affect prices anytime soon with spring ahead.

“The cycle this time of year is typically very poor[for natural gas prices],” he said. “After all, I’m doing this analysis here with the window open. So, obviously, heating demand in America is starting to shrink. If that’s going to be the case, that has a major effect on natural gas.”

S&P cited two obstacles in growing a domestic natural gas market that can affordably meet quadrupling demand for electricity while also generating billions in LNG export revenues—state and federal regulatory and litigative challenges, and pipeline “constraints.”

Trump has issued several deregulation executive actions, and there is bipartisan support in the GOP-held Congress for federal permitting reform, particularly related to the Clean Water Act and National Environmental Policy Act.

Eliminating “regulatory, legal, and environmental barriers” could save more than 100,000 jobs and retain $250 billion annually in economic activity that will otherwise go elsewhere, S&P Global’s study states.

The pipeline constraints are more regional—Permian producers in Texas are seeking outlets to the sea for export; Marcellus/Utica producers in Pennsylvania are seeking ways out of state policy straitjackets and to markets—especially the power-hungry Northeast.

According to the Energy Information Administration’s Natural Gas Pipeline Projects tracker, much of the activity related to pipelines is occurring in Texas, where the emphasis is on LNG export; and in Appalachia, which includes Pennsylvania, West Virginia, Ohio, and Kentucky, where producers are seeking to expand their share of the domestic national market.

In 2024, Texas operators completed the Matterhorn Express Pipeline to move more Permian Basin gas to Gulf export terminals. Under Trump’s National Energy Emergency Declaration, eight Texas pipeline projects are eligible for rocket-docket regulatory reviews, including the 365-mile Blackcomb, 563-mile Apex, and 550-mile-long Bahia pipelines.

There’s no similar financial or political enthusiasm for pipeline projects currently in New York and New England, where consumers on average pay 40 percent more—according to ISO New England, which oversees power system operations in the region—for electricity because of a lack of pipeline links to nearby Pennsylvania.

S&P Global stated that there are enough “low-cost gas reserves” in the Marcellus and Utica formations in New York, Pennsylvania, West Virginia, and Ohio “to meet nationwide demand for more than 17 years.”

However, because they “are being developed at a suboptimal rate,” consumers in Boston, Chicago, and New York City “could pay 160 percent higher than the national gas market in peak months” beginning this summer, it stated.