Key Highlights

  • US natural gas futures fell 1.50% to 3.1718 US dollars per MMBtu, yet remain 9.37% higher over one month.
  • Federal data showed inventories rising by 85 Bcf in the week to October 2, above the 79 Bcf consensus.
  • Hurricane Isaias shut in about 59% of offshore Gulf output, a small share of national marketed supply.
  • LNG feedgas averaged 17.1 bcfd so far in October, down from 18.0 bcfd recorded in September.

A Storm With Limited Reach

US natural gas futures traded near 3.17 US dollars per million British thermal units, down 1.50% on the day but up 9.37% across the past month. The retreat followed a two-week high in the prior session, when Hurricane Isaias forced producers to shut in roughly 1.3 billion cubic feet per day of offshore Gulf output, about 59% of the region's total.

The scale of that loss looks larger than its consequence. Offshore wells accounted for only around 2% of US marketed gas production in 2025, so the national supply picture barely shifted. The bulk of output comes from onshore basins, which helps explain why the price spike proved short-lived. Weather-driven outages tend to attract short-term buying before the underlying balance reasserts itself.

Storage and Export Demand Pull in Different Directions

Domestic fundamentals offered little support. The latest federal storage report showed inventories rising by 85 billion cubic feet in the week ending October 2, against market expectations of 79 billion, a result consistent with ample supply. Higher stocks reduce the urgency of near-term buying.

Export demand, usually a source of support, softened for operational reasons. LNG feedgas to major US export terminals averaged 17.1 billion cubic feet per day so far in October, compared with 18.0 billion in September. A delayed restart of a liquefaction train at Freeport LNG and planned maintenance at Cove Point account for most of the decline.

Overseas appetite has not faded. Buyers in Europe and Asia continue to seek US cargoes, partly because Middle East supply carries persistent risk. That gap between strong foreign demand and constrained terminal throughput is the central tension: gas that cannot be liquefied stays in the domestic market and weighs on prices.

Balanced Risks Into Winter

Upside risks centre on demand and logistics. A faster restart at Freeport LNG, the end of maintenance at Cove Point or an early cold spell could lift feedgas and withdrawals, tightening a market that currently looks comfortable. Disruption to Middle Eastern LNG supply may also raise reliance on American exporters.

Downside risks are equally present. Further storage builds above forecasts would deepen the sense of surplus, and any extended delay in export capacity returning could leave more gas trapped at home. Storm damage to offshore infrastructure, while limited so far, remains a source of short-lived volatility in either direction.

The next weekly storage reports and terminal throughput data may offer the clearest read on which set of forces is gaining ground.

Conclusion

US natural gas is trading on the interplay of storage, export capacity and weather rather than on any single shock. The Gulf hurricane tested sentiment but touched only a small fraction of national supply, while a larger-than-forecast storage build and lower LNG feedgas have kept prices contained. Strong overseas demand could reassert itself once terminal constraints ease. Until then, conditions describe a market that reacts quickly to operational news and remains sensitive to weekly inventory data and terminal operating schedules.