US natural gas futures posted a sharp rebound on Monday, with the September Nymex contract (NGU26) settling up 0.132, or 4.96%, as a warmer weather forecast lifted expectations for higher power demand. Analysts pointed to shifting outlooks for hotter conditions across the central and southern United States, which could increase electricity generation needs during peak cooling season.
Support also came from spillover strength in Europe’s natural gas market, where prices surged to a two-week high amid uncertainty around the reopening of the Strait of Hormuz. Investors, however, are balancing near-term weather-driven optimism against recent storage and supply indicators that have kept a lid on prices.
Key takeaways
- Price move: September natural gas futures (NGU26) closed up 0.132 (+4.96%) on Monday.
- Catalyst: Weather forecasts shifted toward much hotter conditions in the central and southern US.
- Another driver: A sharp rise in European natural gas prices offered carryover support to US benchmarks.
- Implication for investors: Near-term demand expectations are improving, but recent storage strength and supply forecasts limit upside.
What drove the move
According to the Commodity Weather Group, forecast models moved toward significantly hotter weather in the coming weeks, with the most pronounced changes in the central and southern regions of the US. Traders linked the update to a potential step-up in electricity demand from air conditioning, typically boosting gas burn during warmer spells. The expectation of higher power-sector consumption helped extend sentiment into Monday’s settlement.
In parallel, European natural gas strength added a second layer of support. Data cited in Monday’s market commentary showed European prices jumping 11% to a two-week high, tied to uncertainty related to the reopening of the Strait of Hormuz. With European supplies perceived as tight, that price action was interpreted as improving the attractiveness of US gas exports and reinforcing demand for US supply.
Supply backdrop and previous bearish signals
The rally arrives after a bearish turn late last week. Natural gas prices fell to a 3.5-month nearest-futures low on Thursday following a larger-than-expected weekly storage increase. According to the report referenced in the article, inventories rose and ended the period 6.7% above the five-year seasonal average, signaling robust supply conditions.
There was also a negative supply carryover highlighted by market coverage from Tuesday, after Energy Transfer said the Hugh Brinson pipeline is expected to operate at full transportation capacity of 1.5 bcf/day by September 1. That improvement was described as enabling more gas flows from the Permian Basin into the Henry Hub benchmark area in Louisiana, which can weigh on prices when supply expectations rise.
Looking ahead into the fall and winter season, speculation around a strong El Niño system was flagged as a potential medium-term headwind. Warmer-than-normal temperatures would tend to reduce heating demand, weakening one of the key late-year demand supports for natural gas.
How fundamental data shaped the debate
Market participants referenced several activity and demand metrics from BNEF. US (lower-48) dry gas production was reported at 113.1 bcf/day, up 2.9% year over year. Demand in the lower-48 was cited at 84.1 bcf/day, up 9.2% year over year. Estimated LNG net flows to US export terminals were listed at 18.7 bcf/day, up 6.9% week over week.
Even with those demand and export figures, supply expectations remain central to how traders frame the move. According to the article, on July 7 the US Energy Information Administration raised its forecast for 2026 lower-48 dry natural gas production to 111.2 bcf/day, up from a June estimate of 111.0 bcf/day. Higher projected production typically pressures prices over time by increasing the expected availability of gas.
On the power side, the Edison Electric Institute reported that US electricity output increased. The article cited that electricity generation in the week ended August 1 rose 0.9% year over year to 100,254 GWh, and output in the 52 weeks ended August 1 rose 2.1% year over year to 4,350,538 GWh. That backdrop provides some support for the demand narrative, though Monday’s weather catalyst remained the most immediate driver.
In addition, the article highlighted the bearish tone of last Thursday’s weekly EIA report, which showed a storage build of 33 bcf for the week ended July 31, above expectations of 30 bcf and above the five-year average increase of 23 bcf. It also noted that inventories were down 0.4% year over year but still 6.7% above the five-year seasonal average.
European storage levels were also cited as relatively fuller than the seasonal norm. As of August 4, Europe’s storage was 58% full versus a five-year seasonal average of 74% for this time of year—an additional factor that can influence how quickly demand shocks translate into tighter supply pricing.
Drilling and the next signals to watch
Baker Hughes data referenced in the coverage indicated the number of active US natural gas drilling rigs fell by 3 to 124 rigs in the week ended August 7. The level was described as modestly below a three-year high of 134 rigs reached in February 2026. Rig activity can affect the forward supply outlook, though weather and storage data typically dominate near-term price action.
For investors, the immediate focus is whether hotter weather holds up in subsequent forecast updates and whether power-sector gas burn continues to track rising demand. Next checkpoints will likely include continued weekly storage readings from the EIA and additional supply indicators such as production trends and drilling activity, alongside any new guidance from agencies regarding seasonal demand expectations.
