September natural gas futures on the Nymex finished Wednesday higher, closing up by 0.037, or 1.34%. Prices rose as weather forecasts pointed to persistently warmer conditions across key U.S. demand regions, offsetting concerns about ample storage and potential supply headwinds.
Key takeaways
- Price move: September natural gas futures settled up 1.34% on Wednesday.
- Catalyst: Updates to temperature forecasts kept heating demand expectations supported in the near term.
- Supply overhang remains: The latest outlook for U.S. storage suggests levels could remain elevated into the next inventory build.
- Market focus ahead: Investors are positioning for Thursday’s weekly EIA storage report and are also tracking broader demand signals, including power burn and LNG exports.
What drove the move
Weather was the primary near-term tailwind for natural gas prices. According to Vaisala forecasts, temperatures were expected to remain hotter-than-average for the Midwest and South from Aug. 17 to Aug. 21, with the West expected to be above normal from Aug. 22 to Aug. 26. Warmer conditions in these windows can influence the timing of heating and electricity demand, supporting the commodity when cooler weather would otherwise be expected to reduce demand.
Despite the weather support, other fundamental inputs pointed to a still-solid supply backdrop. Data highlighted by the article noted that the U.S. Energy Information Administration projected on Tuesday that natural gas storage would rise to 3,985 billion cubic feet at the end of October—described as the highest level in 10 years and 5% above the five-year average. The same report framework indicated inventories are currently above their five-year seasonal average, a signal that the market still has to balance weather-driven demand fluctuations against relatively comfortable inventory levels.
Supply and demand signals investors weighed
The day’s narrative also included carryover factors tied to infrastructure and production. The report referenced Energy Transfer’s announcement that the Hugh Brinson pipeline would be able to operate at full transportation capacity of 1.5 billion cubic feet per day by Sept. 1, enabling more gas flows from the Permian Basin to Henry Hub in Louisiana. That development was characterized as supportive of domestic supplies, which can cap upside if demand does not absorb the incremental volumes.
On the demand side, the article cited BNEF figures for Wednesday showing lower-48 dry gas production at 112.7 billion cubic feet per day, up 3.2% year over year. It also cited lower-48 gas demand of 82.2 billion cubic feet per day, down 3.1% year over year, and estimated net flows to U.S. LNG export terminals at 18.3 billion cubic feet per day, down 1.4% week over week. Together, these figures underscore a market where production remains robust while demand growth appears uneven, depending on the segment.
Another offset came from power demand. The report pointed to an Edison Electric Institute update indicating U.S. electricity output for the week ended Aug. 8 rose 7.0% year over year to 99,864 gigawatt hours. It also cited year-over-year gains in electricity generation over the 52 weeks ending Aug. 1, which can help support natural gas burn in power markets—an important driver when weather expectations affect air-conditioning and heating needs.
Still, the article flagged a longer-range risk to demand tied to El Niño expectations. It noted market speculation that a strong El Niño system could bring warmer-than-normal temperatures to the Northern Hemisphere during fall and winter, potentially reducing heating demand. While that factor is more relevant to later-season balances, it can shape how traders price the futures curve.
Inventory outlook and the next EIA catalyst
Attention remains centered on weekly storage data from the EIA. The article said the consensus is for Thursday’s weekly report to show an increase of 31 billion cubic feet for the week ended Aug. 7, slightly below the five-year average increase of 33 billion cubic feet. That expectation matters because storage builds relative to seasonal norms help determine whether the market believes supply is tightening or staying comfortable.
Recent history looks mixed for bulls. The prior weekly EIA report, published last Thursday, was described as bearish because inventories for the week ended July 31 rose by 33 billion cubic feet—above expectations of a 30 billion cubic feet increase and above the five-year weekly average increase of 23 billion cubic feet. As of July 31, the article cited inventories down 0.4% year over year but 6.7% above the five-year seasonal average, indicating the market continues to carry an adequate supply buffer.
International storage conditions also appeared in the discussion. The article noted that gas storage in Europe was 59% full as of Aug. 9, compared with a 76% five-year seasonal average for the same time of year. While not directly driving Wednesday’s move, European storage levels are often referenced by traders when assessing broader seasonal gas balances.
Baker Hughes data cited in the report offered another factor on the supply side: active U.S. natural gas drilling rigs fell by 3 to 124 rigs for the week ended Aug. 7, modestly below a February 2026 three-year high of 134 rigs. Rig counts can influence future production expectations, though the immediate effect typically depends on how quickly drilling translates into output.
Bigger picture
Wednesday’s rise in natural gas futures reflects a weather-led bid that temporarily outweighed concerns about inventories and supply. With the EIA storage report due Thursday and the market still balancing robust supply signals against shifting temperature expectations, the near-term direction is likely to hinge on whether the weekly inventory build matches expectations and whether power-sector demand remains strong enough to absorb supply.
What to watch next: The weekly EIA natural gas storage report due Thursday is the key near-term driver. Traders will also monitor updates to temperature forecasts beyond mid-August, along with ongoing data on power generation, LNG export flows, and any further developments that affect U.S. pipeline capacity and gas supply to Henry Hub.
