Henry Hub Steadies Near $2.86 as LNG Demand Battles Injection-Season Supply Glut
Stronger LNG feedgas flows have contained the downside for Henry Hub, but above-normal storage and a major pipeline expansion arriving September 1 keep sellers engaged.
NYMEX Henry Hub front-month traded at $2.86/MMBtu on Wednesday (2026-08-19), up 0.35% on the session, pinned by the same opposing forces that have constrained the market all injection season: LNG export demand pulling prices up, a domestic production surplus pushing them back down.5
The dynamic played out in compressed form the previous week. September NYMEX settled higher on Friday (2026-08-07) after stronger LNG feedgas flows and a hotter-than-expected weather outlook triggered short covering, reversing Thursday (2026-08-06)'s storage-driven selloff. The bounce was real. But storage remained above normal throughout and production was running near 111 Bcf per day — conditions that kept sellers close at hand even as buyers built a temporary position.5
The supply trajectory makes that picture harder to break. EIA data showed Lower 48 marketed gas production averaged 117.2 Bcf/d in the first quarter of 2026, up 4% year-on-year. The agency forecasts a further 3% increase for the full year, driven mainly by the Permian Basin, where output is projected at 29.2 Bcf/d, 6% above 2025. Haynesville production, more directly tied to gas-price economics, is forecast to grow 6% this year and 8% next year.1
LNG exports are the primary mechanism absorbing that incremental gas. Total U.S. export capacity sits near 14 Bcf/d, roughly 15% of domestic production, and each additional Bcf/d of export demand pulls the same volume from the domestic balance. The pull is real, but it is not matching supply growth. Export demand is not strong enough right now to keep pace with what production is putting into the system, FXEmpire reported.3,6
A bigger supply injection arrives September 1 (2026-09-01). Energy Transfer expects the Hugh Brinson pipeline to reach its full 1.5 Bcf/d capacity that day, directing more Permian gas into the market just as injection season approaches its final weeks. Unless LNG feedgas nominations accelerate or late-summer heat keeps power demand elevated, that incremental volume feeds directly into storage.6
EIA has projected storage approaching 4 Tcf by end of injection season, a near-record build that, if realized, gives sellers a structural argument through autumn and into the shoulder period. That forecast is what is pressing on prices now, not supply disruption or weather extremes.6
Analysts see $3.20/MMBtu as firm resistance for Henry Hub, a move that would require extended heatwaves or a meaningful production pullback, FXEmpire noted. At $2.86, the market sits 34 cents below that mark with no clear near-term catalyst to close it.2,5
Wood Mackenzie has put the longer shift in sharper terms. The decade of near-zero marginal cost U.S. gas supply is ending, the firm warned. The share of supply responsive to low prices is expected to fall below 20% over the next ten years, and prices will need to go higher and stay higher to attract new molecules, WoodMac's Wang said. But that structural repricing is a multi-year story. It is not yet visible in prices through an injection season where storage is building toward 4 Tcf.4
The September 1 Hugh Brinson ramp is the next concrete event. If LNG feedgas nominations absorb the extra 1.5 Bcf/d, the bearish storage math at least stops worsening. If they do not, storage builds accelerate through September and end-of-season estimates move further above the levels sellers already consider sufficient to hold their positions.6