Key Highlights

  • U.S. Natural Gas front-month futures settled at $3.336 per mmBtu on June 4, a 16-week closing high, rising approximately 5% on the session.
  • The EIA reported a storage injection of 95 bcf for the week ended May 29, below the consensus forecast of 101 bcf and last year's comparable build of 119 bcf.
  • Domestic dry gas output fell to a preliminary four-month low of 107.4 bcfd, with declines concentrated in Texas and Arkansas.
  • Above-normal temperatures are forecast across the contiguous U.S. through at least June 19, lifting power-sector gas consumption projections.
  • LNG export feedgas flows declined to 16.3 bcfd in June from 17.1 bcfd in May due to scheduled maintenance at several terminals.

A Tighter Balance Than the Market Expected

U.S. natural gas futures at $3.336 per million British thermal units on Thursday, their highest since February 6, as three reinforcing factors arrived simultaneously: a storage injection that fell short of forecasts, a sharper-than-expected decline in domestic production, and a weather outlook that extended the cooling season's pull on power-sector consumption further into June than previously anticipated.

Storage Build Disappoints, but the Surplus Persists

The EIA reported that energy firms injected 95 bcf into storage for the week ended May 29, below the 101 bcf analyst consensus and well short of the 119 bcf built in the comparable week last year. Total working gas now stands at approximately 2,578 bcf, around 5.7% above the five-year seasonal average.

The market is not in a structural Deficit. However, the pace at which the surplus is being rebuilt has slowed. The prior week's injection of 92 bcf also fell below seasonal norms. Two consecutive undershoots do not constitute a trend, but they indicate the Supply buffer is accumulating less quickly than the calendar would suggest, gradually narrowing the ceiling that has capped prices for much of the year.

Output Hits a Four-Month Low

Analysts estimated average Lower 48 dry gas output at 108.5 bcfd for June to date, down from 109.7 bcfd in May and well below the December 2025 record of 110.6 bcfd. On a daily basis, production fell by approximately 3.1 bcfd over six days to a preliminary four-month low of 107.4 bcfd, with declines concentrated in Texas and Arkansas.

The proximate cause appears operational rather than structural, likely reflecting maintenance-related curtailments. Nevertheless, a production dip that coincides with accelerating Demand does more price work than one that arrives during a shoulder-season lull.

Heat Lifts Power Demand Outlook

Meteorological models project temperatures will remain above the seasonal norm through at least June 19. Total U.S. gas demand is forecast to rise from approximately 98.4 bcfd this week to 100.5 bcfd next week, driven largely by the power sector, where consumption is projected to climb from 34.6 bcfd to 36.6 bcfd. LSEG's GFS model projects 188 cooling degree days over the coming two weeks, sharply above both the prior-year reading and the ten-year norm of 138.

Natural gas accounts for roughly 37% to 40% of U.S. weekly power generation, making it the marginal fuel whose cost moves most directly with seasonal temperature swings.

LNG Flows and the Global Premium

Average feedgas flows to the nine major U.S. LNG export terminals fell to 16.3 bcfd in June from 17.1 bcfd in May, reflecting scheduled maintenance at the ExxonMobil and QatarEnergy Golden Pass Facility and Freeport LNG's Texas plant. That compares with the April record of 18.8 bcfd. The effect is temporary; once outages conclude, feedgas demand is expected to recover toward record levels.

European and Asian benchmarks offer additional context. The TTF front-month contract traded near $16.58 per mmBtu and the Japan-Korea Marker at approximately $18.82 per mmBtu. Henry Hub's current range of $3.27 to $3.34 per mmBtu represents roughly a one-fifth discount to European spot prices, a spread that underpins the commercial logic of U.S. LNG export growth and provides a medium-term floor for domestic prices.

Conclusion

The nearly 5% single-session rally is best understood as a market repricing of a near-term balance that arrived tighter than consensus expected. The storage shortfall, the output dip, and the weather-driven Demand Pull are all transient. None alters the fundamental condition in which U.S. gas storage remains more than 5% above its five-year average.

What the move signals is that the price ceiling has become more porous. A continuation of below-average storage builds through June, combined with sustained above-normal temperatures, could push prices toward the $3.50 range before the summer injection season concludes. Whether this week marks a genuine inflection or a temporary repricing will become clearer across the next two to three EIA weekly reports.