EIA Forecasts US Natural Gas Production to Hit Record 122.5 Bcf/d in 2026

A common assumption in energy markets is that record-breaking natural gas production requires high natural gas prices to incentivize drilling. The reality unfolding across the United States in 2026 contradicts that logic entirely. Despite a bearish domestic market and Henry Hub spot prices hovering near historic, inflation-adjusted lows, the U.S. Energy Information Administration (EIA) forecasts that American marketed natural gas production will hit an unprecedented 122.5 billion cubic feet per day (Bcf/d) this year.[3][7]

This surge surpasses the previous record of 118.5 Bcf/d set in 2025, driven not by a sudden appetite for gas exploration, but by the mechanics of crude oil extraction and the geological realities of aging shale reservoirs. The August 2026 Short-Term Energy Outlook confirms that the United States is extending its 17-year run as the world's largest natural gas producer. During the first half of 2026, marketed production already averaged 121.3 Bcf/d, representing a 4 percent increase over the same period last year.[4][5]

The engine behind this record output is the Permian Basin, spanning Texas and New Mexico, which the EIA expects to average 29.2 Bcf/d in 2026—a 6 percent year-over-year increase. In this region, natural gas is primarily an "associated" byproduct of crude oil extraction.

Because West Texas Intermediate (WTI) crude prices averaged $84 per barrel through July, well above the $63 to $69 breakeven costs reported by operators, oil-directed drilling remains highly profitable. When producers drill for oil, the gas comes up with it, flooding the market regardless of whether domestic buyers need it.[4][6]

Furthermore, a shifting geological dynamic is amplifying this associated gas output. As Permian reservoirs mature and internal pressure declines, the gas-to-oil ratio (GOR) steadily increases. Natural gas flows more easily at lower pressures than crude oil, meaning that each new barrel of oil extracted brings a progressively larger volume of natural gas to the surface alongside it. This structural shift ensures that Permian gas production will continue to climb as long as oil prices justify maintaining current rig counts.[5][6]

While the Permian supplies the byproduct, the Haynesville Shale in Louisiana and East Texas is providing targeted growth. Production in the Haynesville rose 7 percent in the first half of the year, and the EIA projects a 9 percent expansion for the full year. Unlike the Permian, Haynesville operators drill specifically for natural gas, navigating depths of up to 13,500 feet. The economics of these expensive, deep wells are sustained by their immediate proximity to the Gulf Coast's expanding liquefied natural gas (LNG) export terminals and dense petrochemical corridors.[3][5]

This dual-basin expansion is triggering a massive midstream infrastructure buildout to prevent regional bottlenecks. Texas currently originates two-thirds of the 44.9 Bcf/d of new U.S. pipeline capacity planned for 2026 and 2027, with nearly 70 percent of those projects already under construction. Pipelines such as the WhiteWater-led Blackcomb and Energy Transfer's Hugh Brinson are racing to connect stranded Permian gas to South Texas hubs and export facilities, ensuring that the sheer volume of associated gas does not overwhelm local gathering systems.[5]

The downstream consequence of this production boom is a heavily insulated domestic market. The EIA projects that Lower 48 working gas inventories will reach 3,985 Bcf by the end of October, sitting 5 percent above the five-year average. This robust storage cushion has prompted the agency to lower its 2026 Henry Hub spot price forecast to $3.44 per million British thermal units (MMBtu), down from earlier estimates. For domestic utilities and industrial consumers, this translates to sustained price stability heading into the winter heating season.[2][3][7]

Internationally, the record U.S. output is critical for balancing a tight global market. While domestic prices remain subdued, European and Asian markets continue to trade at a significant premium, driven by geopolitical tensions and recovering demand. U.S. LNG exports are forecast to average 16.5 Bcf/d in the third quarter of 2026, with new capacity like Mexico's Energia Costa Azul terminal actively drawing on Permian supplies.

As maintenance at major facilities like Freeport LNG concludes in late August, the U.S. is positioned to seamlessly route its record production surplus to international buyers, cementing its role as the primary stabilizing force in global gas trade.[2]