U.S. Natural Gas Production Hits New Records as Demand Surges

Dry natural gas is gas with little water and few heavier hydrocarbons, such as ethane or propane. It is mostly methane and is suitable for pipelines, power generation, and liquefied natural gas production. The article uses dry-gas output as its main measure of U.S. production.

A record high means producers are extracting more marketable gas than ever before. U.S. dry-gas production reached 107.64 billion cubic feet per day in 2025. It is forecast to rise to 112.2 billion cubic feet per day in 2026 and 116.13 billion in 2027.

This growth reflects more associated gas from Permian oil production and increased output from the Haynesville basin. It also shows that producers are responding to stronger demand from American data centers, industrial users, power generation, and overseas LNG buyers.

U.S. dry natural gas production is forecast to grow substantially over two years. Output was 107.64 billion cubic feet per day in 2025. The EIA expects 112.2 billion in 2026 and 116.13 billion in 2027, an overall increase of 8.49 billion cubic feet per day.

The export side is expanding too. U.S. LNG exports averaged 17.4 billion cubic feet per day during the first six months of the year. That was 23% higher than during the same period in 2025, reaching the fastest shipment pace since American LNG exports began a decade ago.

The increases are connected. New liquefaction capacity allows more gas to leave the country as LNG, while producers add supply to meet overseas demand. Domestic power demand, especially from data centers, adds another reason to keep production growing through 2027.

Data centers consume large amounts of electricity, and the article links their rapid expansion to the AI boom. U.S. operators have turned to additional gas-fired generation to support that demand. More electricity use therefore creates another market for natural gas inside the country.

Overseas demand is rising at the same time. Expanding liquefaction capacity lets U.S. terminals export more LNG. Global buyers are also seeking spot cargoes because Qatar’s gas is unavailable due to the Iran war, according to the article. American LNG can help fill that gap.

These pressures create a demand-pull market. Producers are raising output because domestic power users and foreign LNG buyers want more gas. U.S. LNG exports averaged 17.4 billion cubic feet per day in the first half of the year, up 23% from 2025.

The Permian basin matters because oil production there also brings associated natural gas to the surface. As Permian operators produce more oil, additional gas becomes available. That gas can strengthen overall U.S. supply without requiring every new molecule to come from a gas-only drilling project.

The Haynesville basin has a different advantage. The article identifies it as close to LNG export terminals and major domestic industrial gas users. Producers can therefore place its output near large customers, supporting both exports and American manufacturing or power demand.

These basins serve complementary roles. Permian growth adds associated supply, while Haynesville operators are actively boosting gas production near key markets. Together, they help explain the EIA’s forecast for record U.S. output in 2026 and again in 2027.

Henry Hub is the main U.S. natural gas pricing point. When producers add supply faster than consumers and exporters absorb it, more gas remains available in the domestic market. That surplus generally pressures prices lower, assuming other market conditions do not offset it.

The article gives a clear example. U.S. production is expected to keep rising, even while LNG exports increase. The EIA forecasts average Henry Hub prices of $3.16 per million British thermal units in 2027, down 9% from 2026.

The reason is the balance between supply and demand. Higher LNG shipments remove gas from the domestic market, but projected production growth is larger. More associated gas from the Permian and stronger Haynesville output are expected to more than offset export demand, leaving additional supply available in the United States.

EQT and Range Resources are merging because gas markets have shifted from producer-push to demand-pull. Customers now need more supply for power generation, data centers, industrial use, and LNG exports. The transaction would create what the companies describe as America’s leading natural gas company.

EQT will buy Range in an all-stock transaction. The combined company would have a pro-forma enterprise value above $50 billion. Range’s Appalachian assets would add inventory and liquids diversification, while EQT would gain greater scale in a major gas-producing region.

A larger producer can coordinate supply, transportation, and customer relationships more effectively. Wood Mackenzie’s Lydia Walker said the deal should strengthen EQT’s position as a supplier for Appalachian power generation and data-center growth. The companies also point to improved market access, enhanced cash flow, and greater resilience through commodity cycles.

The supply chain begins when producers drill wells and bring raw gas to the surface. Processing facilities remove water, impurities, and heavier hydrocarbons, producing pipeline-quality dry gas. Gathering systems then move gas from wells to larger transmission pipelines. This general chain is not detailed step by step in the article.

Transmission pipelines carry gas to power plants, factories, storage facilities, and export terminals. Power plants burn it to generate electricity, including the additional gas-fired generation serving data centers and AI-related demand. Industrial users also consume gas directly for their operations.

At an LNG terminal, gas is cooled into a liquid, allowing it to be loaded onto ships and sold overseas. The article connects this final stage to rising liquefaction capacity and record U.S. LNG exports. Production from the Permian and Haynesville must reach these markets through gathering, processing, and transportation networks.