September natural gas futures on the New York Mercantile Exchange settled lower on Monday, dropping 1.57% to close down 0.043. The decline was tied to a cooler shift in U.S. weather forecasts that could soften power-sector demand for gas, while multiple supply indicators pointed to an ample inventory backdrop.
Key takeaways
- Price move: September natural gas futures fell 1.57% to close down 0.043.
- Catalyst: Weather outlook turned cooler, reducing expected demand for electricity generation tied to air conditioning.
- Supply backdrop: Forecasts and reported data continue to signal robust U.S. inventories and steady production.
- Demand uncertainty: Ongoing speculation about a developing El Niño pattern raises questions about heating demand later this year.
- What it implies: With storage and supply metrics still supportive, upside for prices may require a more durable demand surprise.
What drove the move
Traders pointed to shifting U.S. weather expectations as the near-term driver. According to Commodity Weather Group, the outlook moved cooler, with average to below-average temperatures expected across the eastern U.S. from August 22–31. Cooler conditions typically reduce the need for power generation associated with summer cooling loads, which can translate into lower natural gas burn for electricity.
Alongside the weather signal, supply indicators added bearish pressure. The U.S. Energy Information Administration, in its latest projections, indicated that U.S. natural gas storage is expected to rise to 3,985 bcf by the end of October—described as the highest level in 10 years and about 5% above the five-year average. The same data set showed inventories currently running 6.7% above the five-year seasonal average, pointing to continued tightness being absent from the storage picture.
Moody supply dynamics also played a role. Energy Transfer previously announced that the Hugh Brinson pipeline would be able to operate at full transportation capacity of 1.5 bcf/day by September 1. The company’s move was framed as enabling more gas to flow from the Permian Basin to Henry Hub in Erath, Louisiana, which would support domestic supply availability at the benchmark.
In the medium-term, bearish sentiment persisted due to speculation around El Niño. Traders have been weighing the possibility that a stronger-than-normal El Niño could bring warmer conditions to much of the Northern Hemisphere during fall and winter, potentially dampening heating-driven natural gas demand.
Market reaction and demand vs. supply signals
While the forecast shift pressured prices on the day, the market’s broader framework remains anchored to the balance between production, consumption, and exports.
Data cited by BNEF showed lower-48 dry gas production at 114.1 bcf/day on Monday, up 4.1% year over year. Lower-48 gas demand was reported at 82.5 bcf/day, up 5.1% year over year. Estimated LNG net flows to U.S. export terminals were 18.9 bcf/day, up 2.3% week over week, suggesting exports remained a constructive outlet for supply.
Electricity generation data also provided a counterweight for demand expectations. According to the Edison Electric Institute, U.S. (lower-48) electricity output in the week ended August 8 rose 7.0% year over year to 99,864 GWh. Over the 52 weeks ending August 8, output increased 2.3% year over year to 4,357,109 GWh. Even so, Monday’s weather-driven demand signal outweighed the positive generation print in the near term.
Inventory trends reinforced that view. The most recent bearish weekly EIA update—reported for the week ended August 7—showed natural gas inventories increased by 36 bcf, above the market expectation of 31 bcf and above the five-year average of 33 bcf. As of August 7, inventories were down 1.0% year over year but still 6.7% above the five-year seasonal average. In addition, Europe’s gas storage level was cited at 61% full as of August 15, compared with a 78% seasonal reference point, highlighting tighter conditions abroad even as the U.S. remains comfortably supplied.
Production activity and the forward view
Upstream activity was also in focus. Baker Hughes reported that the number of active U.S. natural gas drilling rigs rose by 4 to 128 in the week ended August 14, modestly below the 3-year high of 134 rigs set in February 2026. Increased rig activity typically supports longer-run supply potential, which can weigh on prices when near-term demand signals soften.
What analysts will watch next
For natural gas, the next catalyst will likely be whether weather models continue to trend cooler—or reverse—because those updates directly affect power-sector consumption. On the fundamentals side, market participants are likely to monitor upcoming EIA storage reports, additional LNG flow data, and further signs of whether domestic production and rig counts hold steady or accelerate. Investors will also be watching developments in seasonal forecasting tied to El Niño expectations, which could shape the demand outlook for heating months ahead.
