Natural gas futures gain 1.5% as heat may cut storage surplus

US natural gas futures climbed 1.5% to $2.809 per million British thermal units Tuesday as overnight forecasts added heat to the weather outlook, a pattern that could trim the storage surplus to 160-170 Bcf from 195 Bcf.

"National demand will be high to very high the next 10 days as an impressively strong ridge of high pressure sets up across much of the southern two-thirds of the US, focused from Texas to the Southeast and where highs of 90s and 100s will be widespread," NatGasWeather.com said in a note.

The weather pattern suggests near-to-smaller-than-usual inventory builds that could reduce the storage surplus to 160-170 Bcf from the current 195 Bcf, the forecaster added. Working gas in storage stood at 3,117 Bcf as of July 31, 6.7% above the five-year average of 2,922 Bcf, after a 33 Bcf injection that beat the 28-31 Bcf consensus and compared with a 13 Bcf build a year earlier.

The rally tests whether summer heat can finally outrun record production. Lower 48 dry gas output averaged a record 111.2 Bcf/d in August, and the EIA's August Short-Term Energy Outlook, released Tuesday, will show whether the agency's $3.70 full-year Henry Hub forecast survives a front month trading 34% below it.

The weather-driven bounce comes against a storage backdrop that has capped every rally this summer. The surplus widened from 183 Bcf across three weeks of peak cooling demand, and the July 31 injection ended two consecutive bullish prints that had begun to establish a narrative of summer demand outrunning supply. A strong ridge across the southern two-thirds of the country, with widespread highs in the 90s and 100s Fahrenheit from Texas to the Southeast, should sustain power-generation demand for at least 10 days. NatGasWeather.com projects builds that could narrow the surplus by 25-35 Bcf — the first meaningful compression of the season.

Record output caps the rally

The structural constraint is supply. Lower 48 dry gas production averaged a record 111.2 Bcf/d in August, up from 110.7 Bcf/d in July, with the Permian leading growth as associated gas from oil-directed drilling responds to WTI crude at $83.33 rather than to gas prices. The EIA's balance framework has supply growing 1.1 Bcf/d in 2026 against demand growth of 0.6 Bcf/d, a 0.5 Bcf/d surplus that roughly matches the size of the storage build.

LNG feedgas at 17.9 Bcf/d, a one-month high, is the only bullish variable working. Golden Pass nominations rose 0.3 Bcf/d to 0.558 Bcf/d on early-cycle data with a single train operating, and each additional train converts directly into Henry Hub demand. But export capacity is plant-limited, so the $20.80 per MMBtu European TTF price — 7.5 times Henry Hub — does not transmit into US prices until new capacity commissions.

The EIA's $3.70 forecast faces its first test

The August Short-Term Energy Outlook, released Tuesday, is the most consequential scheduled event. The July edition placed the 2026 Henry Hub average near $3.70 and the fourth quarter at $3.57, against a front month at $2.809 — a 29% gap to the fourth-quarter figure. The July forecast predates the entire July storage build sequence, the record production figures, and the break below $2.70, so today's revision either closes the gap or confirms the front month was right.

The October target of 3,966 Bcf is the deciding number. Reaching it requires 849 Bcf of injections across roughly 13 weeks, an average of 65 Bcf per week against recent builds of 28-43 Bcf. September and October builds routinely run 60-90 Bcf per week once power burn falls, so the target is achievable — and an October figure above 4,000 Bcf would justify cutting the fourth-quarter projection toward $3.20.

The winter precedent shows how quickly storage expectations can reprice the curve. During the January 2026 episode, the February NYMEX contract rose $1.76 in a single report week, from $3.120 to $4.875 per MMBtu, as the 12-month strip climbed 65 cents to $3.970. A market that repriced 56% in one week on storage expectations can do so again, though entering winter with 3,966 Bcf makes that less likely than entering with 3,600 Bcf.

The trade is the $2.70-$2.90 box. A close above $2.90 with a supportive storage print opens $3.00 and $3.20; a break below $2.62 opens the April lows and targets $2.50. The medium-term structure is bearish through the injection season and constructive into 2027, when demand growth of 2.5 Bcf/d against supply growth of 0.9 Bcf/d produces a 1.6 Bcf/d deficit that removes roughly 584 Bcf from storage. Thursday's report for the week ending August 7 is the next test of whether the heat can finally compress the surplus.

This article is for informational purposes only and does not constitute investment advice.