U.S. natural gas futures have experienced notable gains recently, climbing above $3.20 per million British thermal units (MMBtu), levels not seen since February. This increase followed the release of government data indicating a smaller-than-expected build in natural gas storage for the week ending May 22. According to the U.S. Energy Information Administration (EIA), utilities added 92 billion cubic feet (Bcf) of gas to storage, which was below market forecasts of 95 to 96 Bcf and also less than the 104 Bcf injection recorded during the same period last year.
Total natural gas inventories reached 2.483 trillion cubic feet, representing a 0.9% increase compared to the previous year and standing 6.2% above the five-year seasonal average. However, the surplus over this average has narrowed slightly from 149 Bcf to 144 Bcf in the latest report. Meanwhile, U.S. gas production in the Lower 48 states declined marginally from 109.8 billion cubic feet per day (bcfd) in April to 109.4 bcfd in May, while flows to major liquefied natural gas (LNG) export facilities also fell due to scheduled maintenance.
Market analysts have noted that these supply factors, combined with weather forecasts predicting mostly normal conditions through mid-June, contributed to steady natural gas prices. After an initial surge following the EIA report, July natural gas futures settled into a sideways trading pattern as traders sought new catalysts to drive further price movements.
The demand outlook for natural gas remains influenced by power generation needs, especially during the summer cooling season. The EIA’s Short-Term Energy Outlook projects that natural gas consumption by the U.S. electric power sector will hold steady at around 43.7 Bcf per day during the summer months of June through September, matching last summer’s levels but exceeding the five-year average by approximately 4%. This stability is attributed largely to increased electricity generation from renewable sources offsetting what would otherwise be higher natural gas use.
Looking ahead, however, the EIA forecasts a rise in natural gas demand for power generation in 2027, with consumption expected to reach a record high of 46.1 Bcf per day—a 6% increase over this summer’s forecast and surpassing previous records set in 2024. This growth is driven by expanding electricity sales in commercial and industrial sectors, particularly in regions like Texas and the Mid-Atlantic where new data centers and manufacturing facilities require significant energy for operations and cooling.
The Electric Reliability Council of Texas (ERCOT) is anticipated to respond to rising demand by increasing generation from both natural gas and solar power sources by roughly 22% between summers of 2025 and 2027. Similarly, the PJM Interconnection grid covering much of the Mid-Atlantic has steadily increased its use of natural gas for electricity generation over the past decade as it shifts away from coal.
Overall, the U.S. power sector is undergoing a transition towards cleaner energy mixes, with renewables expected to provide about 25% of electricity generation by 2027 compared to 21% in 2025. This shift helps moderate natural gas demand growth despite rising electricity consumption across commercial and industrial users.
In summary, recent EIA data points to tighter-than-expected natural gas storage builds amid slightly declining production and maintenance-related export reductions. These factors have supported recent price gains while summer demand remains steady with an eye toward significant growth in coming years due to increased power sector requirements.
