U.S. natural gas futures settled higher on July 29, 2026, snapping a four-session losing streak as the August front-month contract expired on the New York Mercantile Exchange. Prices were steady in early trading before settling up on the session, according to WSJ.

The expiration-day gain caps a volatile stretch for the prompt contract — the nearest-month futures contract that traders watch most closely. On July 16, front-month gas fell 6.6 cents, or 2.3%, to settle at $2.888 per million British thermal units (Reuters). Earlier in the summer, futures gave up early gains to settle down 1.5% at $2.871/MMBtu on June 12, extending a pullback from a test of the $3 level (WSJ). The June 10 session had seen prices rise roughly 1% on forecasts for hotter-than-normal weather and stronger demand (Reuters.

Working natural gas in storage stood at 3,084 Bcf (billion cubic feet) as of Friday, July 24, 2026, a net increase of 28 Bcf from the prior week, per EIA estimates (EIA). The preceding week's inventory build of 32 Bcf had landed at the low end of expectations (WSJ). Storage injections running at or below the low end of survey ranges tighten the cushion heading into the withdrawal season — the period when demand outpaces production and the country draws down stored gas — even with production climbing.

On the supply side, U.S. dry natural gas production increased year over year for the 14th consecutive month in May 2026, according to EIA's Natural Gas Monthly (EIA). Sustained production growth has been a structural cap on prices even as weather-driven demand spikes and LNG export pull create episodic upside. Earlier this year, the EIA's Natural Gas Weekly Update attributed price strength mostly to anticipated changes in 2026 storage balances, with reported prices exceeding $4.00/MMBtu at that time (EIA). Prompt prices have since retreated well below that threshold, settling in the high-$2 range through July.

The EIA's Short-Term Energy Outlook provides the structural backdrop. The agency forecasts total U.S. natural gas consumption rising 2% in 2026 and another 4% in 2027, reaching 38.1 Bcf/d (EIA). From 2025 to 2027, total consumption is projected to increase by 3.1 Bcf/d (3%), with the electric power sector accounting for 2.3 Bcf/d (7%) of that growth. Power-sector demand has been the marginal driver of incremental consumption, reflecting continued coal-to-gas switching and rising cooling load. The STEO also forecasts natural gas prices averaging close to $3.70/MMBtu over the forecast horizon (EIA).

The broader context here is a genuine tension between what the futures market is pricing and what the government's forecast assumes. Prompt prices in the $2.80s sit well below the EIA's forecast average near $3.70, implying either the market is pricing in a substantial supply overhang that the STEO underweights, or the forecast itself embeds demand assumptions the prompt curve is skeptical of. The 14-month production streak lends credence to the supply-side case, but low-end injection prints suggest the storage surplus may be narrowing faster than the production trajectory alone would imply.

Roll dynamics add another layer. The August contract's expiration on July 29 removes the prompt-month weather premium embedded in the summer strip, shifting focus to the September contract and the shoulder-season lull before heating demand reasserts itself. The four-session losing streak preceding the expiration-day gain indicates positioning was already leaning defensive into the roll, and the snap higher likely reflects short-covering — traders buying back contracts they had bet against — rather than a fundamental demand shift.

The storage data due in the coming sessions will be the next clean read on whether the below-consensus injection pattern persists or reverts toward the five-year average. With storage at 3,084 Bcf and the injection season entering its final weeks, each weekly print carries outsized weight for winter strip pricing.