October natural gas futures on the New York Mercantile Exchange settled lower on Tuesday, closing down 1.06% to end the session at NGV26. Prices eased after U.S. weather forecasts shifted toward cooler conditions, which traders said could temper electricity demand for air conditioning—one of the key drivers of natural gas burn.
Losses were restrained, however, by support from a stronger European gas market. Concerns that the closure of the Strait of Hormuz could persist longer than previously expected helped lift European natural gas prices, keeping a bid under sentiment for the global fuel complex.
Key takeaways
- Price move: October natural gas futures fell 1.06% on Tuesday.
- Catalyst: Cooler U.S. weather forecasts reduced expectations for near-term power-sector gas demand.
- Offsetting support: European gas rallied on fears related to the Strait of Hormuz, helping limit downside.
- Supply/demand signals: Data showed production and LNG exports supported demand, while broader inventory outlooks remain an overhang.
- Implication: The market is trading the near-term weather impulse while investors weigh longer-term storage and seasonal demand risk.
What drove the move
Tuesday’s pullback reflected a change in the weather outlook. According to forecaster Vaisala, temperatures are expected to fall below normal in the Northeast at the beginning of this weekend. Cooler conditions typically reduce the need for power generation associated with air conditioning, lowering incremental natural gas demand from electricity providers.
Even with that bearish near-term demand signal, trading losses were contained by cross-market support. The report noted that fears over a potentially prolonged closure of the Strait of Hormuz pushed European natural gas prices to a 3.5-year high. Europe relies on the strait for roughly 10% of its natural gas supplies from Qatar, and that physical supply risk helped bolster prices across the Atlantic.
Market reaction: balancing weather pressure with energy flows
On the U.S. supply side, data from BNEF showed lower-48 dry gas production at 114.0 bcf/day, up 5.5% year over year. Demand indicators were also supportive: BNEF estimated lower-48 state gas demand at 79.7 bcf/day, up 14.7% year over year.
LNG export activity further supported the complex. Estimated net flows to U.S. LNG export terminals were 19.5 bcf/day, up 12.0% week over week, according to BNEF. That combination—rising production, stronger domestic demand, and improving LNG throughput—helped prevent deeper declines despite the weather-related pullback.
On the electricity side, the Edison Electric Institute reported last Wednesday that U.S. (lower-48) electricity output in the week ended August 22 increased 6.1% year over year to 100,895 GWh. The broader trend was also higher: output over the 52 weeks ending August 22 rose 2.2% year over year to 4,365,212 GWh. Higher power generation can sustain gas burn, even when near-term weather softens incremental demand.
Bearish undertones investors are watching
Despite the day’s decline being modest, several forward-looking factors remain a headwind. The U.S. Energy Information Administration projected on August 11 that U.S. natural gas storage could rise to 3,985 bcf by the end of October. The report characterized this as the highest level in 10 years and about 5% above the five-year average—conditions that typically pressure prompt prices by signaling ample inventory coverage heading into seasonal transitions.
In addition, the EIA raised its 2027 estimate for U.S. dry natural gas production to 116.0 bcf/day, up from 115.3 bcf/day projected in July. Higher forward production expectations can weigh on prices if markets interpret them as reducing the likelihood of tightness later in the cycle.
Looking further ahead, the article also pointed to speculation that a powerful El Niño weather pattern could bring warmer-than-normal temperatures to the Northern Hemisphere this fall and winter. Warmer conditions would typically reduce heating demand, adding a medium-term bearish layer to the outlook.
Inventory and rig data: mixed signals for the near term
Recent inventory data provided some support but did not eliminate supply concerns. The weekly EIA report released last Thursday showed U.S. natural gas inventories rose by 15 bcf for the week ended August 21—right in line with expectations but below the five-year weekly average increase of 33 bcf. As of August 21, inventories were down 1.0% year over year and 5.5% above their five-year seasonal average, indicating stocks remain adequate.
Storage conditions abroad also mattered for sentiment. As of August 30, gas storage in Europe was 65% full compared with the five-year seasonal average of 82% full for that time of year. That relative tightness in Europe can continue to support global pricing, particularly if geopolitical risks disrupt supply routes.
On the production ramp, Baker Hughes reported last Friday that the number of active U.S. natural gas drilling rigs rose by 5 to 132 rigs in the week ended August 28, a 5-month high. The total remains just below the 3-year high of 134 rigs set in February 2026, reinforcing the possibility of continued output pressure over time if drilling activity translates into production gains.
Bigger picture
The Tuesday decline in October natural gas futures underscored how quickly the market reacts to weather expectations, even when broader demand and export flows remain firm. Investors also appear to be trading the interaction between U.S. seasonal outlooks—shaped by storage projections and potential El Niño impacts—and global supply risk, which has been elevated by Middle East shipping concerns affecting European pricing.
Looking ahead, traders will likely focus on upcoming weather updates and the next set of inventory and production-related data releases. Attention should also remain on further guidance from the EIA and on signals about how LNG export demand and drilling activity evolve as the market moves toward the end-of-season storage window.
