Natural gas futures closed at $2.70 per million British thermal units on Tuesday, rising 0.46% after a 2% decline the previous day pushed prices to their lowest point since early August. The small gain does not offset the broader decline: front-month gas has fallen 2.5% this week, 5.5% this month, and 2.3% compared to last year.
The market hovers near its 52-week low of $2.54, trading just 6.3% above that level and 51.9% below the annual peak of $5.62. Every attempt to rally in August has stalled within a 20-cent range, leaving the contract trapped in a tight band.
Record production keeps pressure on prices
Output in the Lower 48 states hit a new high of 111.6 billion cubic feet per day in August, exceeding July’s previous record of 110.7 Bcf/d. The Energy Information Administration had forecast full-year production at 109 Bcf/d, but August’s figures already exceed that estimate by 2.6 Bcf/d. Each month this year has set a new benchmark.
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This supply increase clashes with weaker-than-expected demand. Weather forecasts now predict milder temperatures across much of the U.S. in the coming weeks, reducing reliance on gas-fired power generation. Storage levels stand nearly 200 Bcf above the five-year average, and injections have consistently surpassed expectations.
Associated gas from oil drilling adds another layer of complexity. With West Texas Intermediate crude near $84, Permian producers keep drilling regardless of gas prices, introducing more supply that cannot be easily reduced. At $2.70, dry gas economics are worsening, but the delay between rig cuts and production declines means the market will not feel the impact until next year.
The EIA’s January forecast assumed supply growth would outpace demand growth by 0.5 Bcf/d across 2026, with demand rising less than 1% at plus 0.6 Bcf/d against supply increasing nearly 1% at plus 1.1 Bcf/d. The realized supply overshoot is larger than that model contemplated.
Storage and market trends
Storage sits nearly 200 Bcf above the five-year average. The August focus is shifting from the 2026 cooling season toward the 2026/2027 peak heating season, where demand and prices structurally reach their annual highs. That transition is the only bullish argument currently available.
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The long-term outlook changes in 2027. The EIA expects demand growth to outpace supply by 1.6 Bcf/d, driven by new LNG export capacity. That shift would reverse the current surplus and push prices higher, but for now, the market remains focused on the immediate oversupply.
The difference with oil is clear. Brent crude traded near $91 on Tuesday, supported by geopolitical tensions in the Middle East. Gas, protected by its domestic supply chain, lacks a similar premium. Retail traders hold overwhelmingly long positions—80.8%—even as the market continues to decline.
The only remaining argument for a price increase is the seasonal shift toward winter demand. With storage already ample and production at record levels, that transition may not be enough to break the trend.
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