NextFin News - U.S. natural gas futures retreated on Tuesday as a sharp reduction in feed-gas deliveries to major liquefied natural gas (LNG) export terminals outweighed concerns over domestic production levels. The decline highlights the market's heightened sensitivity to export infrastructure, which has become the primary engine for American gas demand even as the domestic power sector enters a shoulder season of moderate temperatures.
On the New York Mercantile Exchange, the front-month gas contract for July delivery slipped approximately 1% to trade near $2.58 per million British thermal units (MMBtu) during Tuesday morning sessions. The downward pressure was primarily attributed to data from financial group LSEG showing that average gas flows to the nine largest U.S. LNG export plants fell to 17.3 billion cubic feet per day (bcfd) so far in May and early June. This represents a significant pullback from the monthly record of 18.8 bcfd established in April, as several facilities entered scheduled spring maintenance cycles.
The maintenance-driven lull in exports has temporarily trapped more supply within the domestic market, complicating the storage outlook. According to LSEG data, while average gas output in the U.S. Lower 48 states has moderated to 109.1 bcfd—down from the December record of 110.6 bcfd—the reduction in production has not been sufficient to offset the drop in export demand. This imbalance is reflected in the narrowing premium of July futures over June contracts, which recently hit a 13-month low of roughly 14 cents per MMBtu, signaling a lack of immediate supply tightness.
Market participants are closely monitoring the Waha hub in West Texas, where prices have remained under severe pressure due to pipeline constraints in the Permian Basin. Waha prices have averaged a negative $2.22 per MMBtu so far in 2026, a stark contrast to the positive $1.15 average seen in 2025. This regional glut continues to act as a localized anchor on the broader national price structure, despite efforts by producers to curtail drilling activity in response to the low-price environment.
A more cautious perspective is offered by analysts at the U.S. Energy Information Administration (EIA), who maintain a relatively constructive outlook for the second half of the year. In its latest Short-Term Energy Outlook, the EIA projected that Henry Hub prices would average approximately $3.50 per MMBtu for the full year of 2026. This forecast assumes that the current maintenance-related dip in LNG flows is transitory and that export capacity will rebound as new projects, such as the Golden Pass LNG terminal, move closer to operational status later this year.
The immediate path for prices remains tethered to weather patterns and the pace of storage injections. Current storage levels sit roughly 6.6% above the five-year average, providing a comfortable cushion against potential summer heatwaves. Unless a sustained period of above-normal temperatures triggers a surge in power-sector demand, the market appears likely to remain range-bound until the full return of export capacity restores the link between U.S. production and global demand centers.
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