EIA Decade-High Storage Forecast Keeps NYMEX Henry Hub Pinned Near $2.99
U.S. natural gas holds flat as traders await weekly injection data against EIA's projection of the highest end-October inventory level in ten years.
NYMEX Henry Hub front-month natural gas held flat at $2.99 per million British thermal units on Thursday, September 3, 2026, as traders positioned ahead of weekly injection data against a storage outlook the EIA has described as the most bearish in a decade. [live prices]
The ceiling was set in an August 12, 2026 EIA outlook. The agency projected U.S. inventories would reach 3,985 Bcf by the end of October — the highest level in ten years and 5% above the five-year seasonal average, fxempire.com reported. Even a run of below-normal injection weeks may not be enough to prevent end-of-season surpluses large enough to weigh on prices through the early withdrawal period.5
Production growth compounds that pressure. L48 marketed natural gas output averaged 117.2 Bcf/d in the first quarter of 2026, up 4% from the same period in 2025, EIA data show. The agency forecasts full-year L48 growth of 3% versus 2025, concentrated in the second half.2
The Permian Basin is driving most of the increase. EIA projects the region will produce 29.2 Bcf/d in 2026, a 6% gain over 2025, with pipeline takeaway constraints expected to ease later in 2026 and a further 10% expansion penciled in for 2027. Haynesville, the dominant gas-focused basin in the Gulf South, is forecast to grow 6% in 2026 and 8% in 2027. Those two regions together account for the bulk of incremental L48 supply the market must absorb alongside the existing storage surplus.2
LNG exports have been the main demand offset. U.S. vessel departures totaled 141 Bcf in the week ending Friday, May 15, 2026, 26 Bcf above the preceding week's pace, even as several export terminals ran maintenance, per vessel tracking data. Strong throughput is one reason production growth has not triggered a deeper price collapse.1
European storage conditions underpinned that demand. Europe entered summer 2026 with inventories at roughly 45% of capacity, against a five-year seasonal average near 60%, according to fxempire.com — a gap that kept European and Asian buyers competing for Atlantic Basin cargoes and sustained demand for U.S. liquefaction capacity.4
Price action in May traced the same dynamic. June NYMEX natural gas futures cleared the 50-day moving average at $2.943 on Friday, May 15, 2026, settling at $2.96 and posting a 7.4% gain for that week as buyers returned after weeks of consolidation, fxempire.com reported. Analysts identified $3.107, the 50% retracement level, as the next upside resistance, with support near $2.787.3,1
But that resistance proved durable. By August 12, 2026, when the September contract bounced, the same ceiling held — analysts said summer weather alone was insufficient to clear it, fxempire.com reported. Front-month gas on September 3, 2026 sits within cents of where that August resistance held.5
The weekly injection figure due later on September 3 carries unusual weight. A build materially below the five-year average supports the case that demand is burning through the storage overhang fast enough to shift the seasonal balance; a print at or above the seasonal norm reinforces the bearish read from the EIA's near-4 Tcf October forecast. Beyond that, the pace of Permian takeaway capacity additions is the supply variable most likely to set the next directional move — once those expansions arrive, they determine the volume of additional supply the market must absorb before withdrawal-season draws begin to tighten the inventory balance.2,5