Henry Hub Holds Near $2.89 as Rising Output and Pacific Surpluses Weigh on Front-Month Gas
Rising L48 production, Pacific storage surpluses, and falling California demand are keeping NYMEX front-month gas below $3, the level producers need to justify new drilling.
NYMEX Henry Hub front-month gas was last quoted at $2.89 per million British thermal units on Sunday (2026-08-30), with markets closed for the weekend, as EBW Analytics Group said milder weather was undermining near-term fundamentals in a note cited by Rigzone in mid-July (2026). The price sits just below the $3 threshold that many producers consider necessary to justify new capital commitment.5
Lower 48 marketed gas production averaged 117.2 billion cubic feet per day in the first quarter of 2026, a 4% increase on the same period in 2025, EIA data show. The agency forecasts a further 3% gain for the full year, driven by the Permian Basin, expected at 29.2 Bcf/d in 2026, up 6% year-on-year, and by a Haynesville revival projected at 6% growth this year and 8% in 2027. Supply is not slowing down.1
The pressure is sharpest in California. Monthly average spot prices there hit record lows across the first five months of 2026, EIA reported, matching conditions last seen during the 2024 nationwide low-price market. Pacific-region storage was 30.9%, or 69 billion cubic feet, above the five-year average in the week ended May 22 (2026), a surplus that had persisted since the first week of December 2025. California consumed just 4.8 Bcf/d in 2025, a record low, down 7% from 2024, and near-term demand signals from that region point lower, not higher.2
That regional demand erosion shapes the national benchmark. Henry Hub is a localized price signal driven by supply, demand, and infrastructure conditions in southern Louisiana, Wood Mackenzie noted in July (2026-07-08). When consuming-region demand weakens and storage builds, the signal transmits through the pipeline system to the Hub. Infrastructure that might otherwise tighten regional spreads has instead widened the gaps between production centres and end-users.3
The global picture offers a stark contrast. Following the February 28 (2026) closure of the Strait of Hormuz, ICE Endex TTF front-month gas climbed to $14.80 per million BTU, EIA reported on April 28 (2026-04-28), while Henry Hub moved in almost entirely the opposite direction. Asian JKM LNG stood at $23.17/MMBtu per Sunday's (2026-08-30) reference, an eight-to-one premium over the domestic U.S. benchmark that in theory should pull American LNG to export terminals and tighten supply at the source. Terminal capacity constraints and long-term offtake contracts limit how much of that arbitrage actually transmits back to Henry Hub.4
Wood Mackenzie issued a structural warning in early July (2026-07-08): the era of near-zero marginal cost U.S. gas production is ending. The consultancy estimated that the share of supply delivered at effectively no marginal cost would fall below 20% within a decade, down from the majority share that has kept Henry Hub subdued for years. With supply less responsive to price signals, prices "will need to go higher and stay higher to bring new molecules to market," the firm said. But that is a multi-year structural shift. It does not prevent $2.89 front-month gas this weekend.3
The EIA moved in the same directional territory with its July short-term energy outlook, raising Henry Hub price forecasts for both 2026 and 2027, though the revised projections were not fully detailed in available summaries. The upgrade sits uneasily against an immediate supply-demand balance that remains loose.5
Permian infrastructure constraints — which the EIA said have been limiting near-term basin output — are expected to ease in the second half of 2026, at which point the agency projects 10% basin production growth in 2027. More gas from a basin already running at 29.2 Bcf/d would test whether downstream pipeline capacity can absorb the volumes without pushing basis differentials wider and keeping Hub prices anchored.1
Pacific storage at a 30.9% surplus and California demand at a multi-decade low represent a heavy injection-season overhang. How quickly the Permian bottlenecks clear, and whether new Haynesville volumes materialise before seasonal withdrawal demand builds in earnest, will set the trajectory for what Henry Hub can realistically achieve before winter arrives.2,1