US Natural Gas futures surged over 4% to $3.2315 per MMBtu after the EIA reported a smaller-than-expected 92 bcf storage build. With output easing and the inventory surplus narrowing to 6.2% above the five-year average, the Supply-Demand balance is gradually tightening ahead of peak summer demand.

Key Highlights

  • US natural gas futures rose more than 4% to $3.2315 per MMBtu, reaching levels not seen in roughly 11 weeks.
  • The EIA reported a storage injection of 92 bcf for the week ended May 22, below analyst forecasts of 95 bcf and the 104 bcf recorded a year earlier.
  • Total inventories stand at 2.483 trillion cubic feet, 6.2% above the five-year seasonal average, with the surplus narrowing week on week.
  • US dry gas production in the Lower 48 states eased in May
  • LNG export flows declined to 17.1 bcfd in May from a record 18.8 bcfd in April due to seasonal maintenance at major plants.

US natural gas futures climbed more than 4% on May 28, touching $3.2315 per MMBtu, as a below-forecast storage build reinforced a tightening supply picture heading into the summer demand season. The move extends a broader recovery that has lifted the front-month contract to its highest close in approximately 11 weeks.

EIA Storage Data Underpins the Rally

The US Energy Information Administration reported that utilities injected 92 billion cubic feet of gas into storage during the week ended May 22. The figure came in below analyst forecasts of 95 bcf and was materially lower than the 104 bcf recorded during the same period a year ago. It also trailed the five-year seasonal average injection of 97 bcf for the period.

Total inventories rose to 2.483 trillion cubic feet, approximately 0.9% above year-ago levels. The surplus relative to the five-year average narrowed to 6.2%, or roughly 144 bcf, from 6.6% the prior week. While the overhang remains, the directional compression is providing a structural underpinning for prices.

Output Softens as Summer Demand Builds

On the supply side, average dry gas production across the Lower 48 states eased to 109.4 bcfd in May, down from 109.8 bcfd in April and well below the monthly record of 110.6 bcfd set in December 2025. The modest pullback, combined with above-normal cooling demand as temperatures rise, is gradually eroding the inventory buffer that had kept prices in check through much of the spring.

Cooling degree days for the current two-week forecast period stand at 138, above the prior-year reading of 113 and the 10-year norm of 120, pointing to elevated power-sector demand for gas in the weeks ahead. Power generation from natural gas accounted for 39% of total US electricity output in the week ended May 29, up from 37% the prior week, reinforcing near-term demand visibility.

LNG Export Flows Ease on Maintenance

Flows to the nine major US LNG export terminals averaged 17.1 bcfd in May, down from the record 18.8 bcfd recorded in April. Freeport LNG's Texas plant was among the facilities undergoing scheduled spring maintenance, contributing to the monthly decline in feedgas flows. Cheniere Energy (NYSE: LNG), operator of the Sabine Pass and Corpus Christi terminals and the largest US LNG exporter, has also historically clustered maintenance activity in the May-June window, further weighing on aggregate export volumes.

Despite the temporary pullback, LNG export feedgas demand remains structurally elevated relative to the five-year average of 12.9 bcfd. Capacity additions from newer entrants reinforce the Long-term Growth trajectory. The Golden Pass LNG terminal, a joint venture between ExxonMobil (NYSE: XOM) and QatarEnergy, shipped its inaugural cargo in April 2026 and is currently ramping toward full commercial output across its three trains. Venture Global (NYSE: VG) continues expanding throughput at its Plaquemines Facility in Louisiana, while NextDecade (Nasdaq: NEXT) is advancing construction of its Rio Grande LNG terminal in Texas, with first LNG production targeted for the first half of 2027.

Global benchmarks reflect this tightness. The Title Transfer Facility in Europe was quoted at $16.47 per MMBtu and the Japan-Korea Marker at $18.24 per MMBtu, both significantly above the Henry Hub Spot Price, sustaining the economic incentive for US LNG exports once maintenance concludes.

Weather and Near-Term Demand Outlook

Meteorological forecasts point to broadly normal conditions through mid-June, limiting the upside from weather-driven demand spikes in the immediate term. Supply and demand projections indicate total US gas demand, including exports, at approximately 100.0 bcfd this week before easing to around 98.7 bcfd the following week. These figures remain above the five-year average of 94.8 bcfd for the period, suggesting underlying demand conditions are firmer than seasonal norms alone would imply.

Conclusion

The convergence of a below-forecast storage injection, moderating production, and sustained LNG export demand has shifted the near-term price narrative for US natural gas. The inventory surplus, while still present at 6.2% above the five-year average, is compressing. If production remains soft and summer cooling demand meets or exceeds current forecasts, the structural case for further price support strengthens. The key variables to monitor are LNG plant restart timelines, output trends across the Lower 48, and any deviation in temperature patterns through June.