US natural gas markets are experiencing a structural transformation that is pulling Henry Hub prices higher even as shoulder season demand remains subdued. The NGI Weekly Henry Hub index settled at $2.86/MMBtu for the week ending May 15 — a gain of 12.5 cents week-on-week — while the June futures contract broke above the psychologically significant $3.00 threshold in Monday trading. June futures expire May 27, and market participants are watching the expiry dynamics closely for signals about summer pricing.
The LNG demand revolution. The single most important structural change in the US natural gas market over the past five years has been the exponential growth of LNG exports. NGI's LNG Export Flow Tracker shows deliveries to Lower 48 liquefaction plants averaged 18.1 Bcf/d in April 2026, compared with just 11.1 Bcf/d in April 2021 — a 63% increase that has fundamentally altered the supply-demand balance.
This 7 Bcf/d of incremental structural demand has progressively absorbed what was once surplus production capacity. The traditional metrics that traders use to gauge market tightness — most notably the surplus or deficit relative to the five-year average storage level — may be underestimating the tightening effect. As NGI's analysts note, the "year/year deficit" measure could be gaining in relative importance because the market structure has changed so materially. A storage position that appears comfortable against a five-year average that includes years with far lower LNG demand may in fact be tighter than it looks.
Feedgas flows and maintenance. LNG feedgas deliveries averaged 16.3 Bcf/d last week, down 0.3 Bcf/d as spring maintenance continues at several Gulf Coast liquefaction facilities. This seasonal maintenance is a normal part of the annual cycle, but the scale of outages matters more now because the base level of demand is so much higher. Any unplanned maintenance extension during the summer cooling season could have outsized price impacts.
FACT: The 18.1 Bcf/d of April LNG feedgas demand represents approximately 17% of total Lower 48 dry gas production of 108.4 Bcf/d. Five years ago, LNG absorbed less than 11% of production. The export market has shifted from a marginal demand source to a core structural component of the US gas balance.
Weather and seasonality. The prompt month's rise above $3.00 is notable given that it has occurred during the shoulder season — the period between heating and cooling demand when weather-driven consumption is at its annual low. This suggests that the market's underlying tightness is structural rather than seasonal. A developing El Niño weather pattern is emerging as a potentially bullish factor, with rising risks for stronger LNG demand competition this summer as Asia heats up.
The EIA lowered its 2026 Henry Hub spot price forecast to $3.50/MMBtu in the May STEO (a 4.4% reduction from prior), but this still implies significant upside from current spot levels near $2.86. The futures curve supports this view: Henry Hub futures average $3.26/MMBtu for contracts through end-2026, with the December 2026 contract trading above $4.00. The backwardation in the near term and contango further out reflects near-term supply sufficiency but tightening balances through the injection season and into winter.
What changed. The US natural gas market has historically been defined by abundant supply, limited export capacity, and chronic oversupply that capped prices. That paradigm is shifting. As LNG export capacity expands — with new trains at Plaquemines, Corpus Christi Stage 3, and other facilities ramping up — the structural floor for Henry Hub prices is rising. The market is transitioning from one in which storage surpluses are the norm to one in which storage must be actively managed to meet both domestic and export demand through the full seasonal cycle.
The structural tightening of the US gas market via LNG demand has implications for hedging strategy and contract structure. Buyers should expect the $2.50–$3.00 range to become a firmer price floor than in prior years, with seasonal upside to $3.50–$4.00 during summer and winter peaks. The EIA's 2026 forecast of $3.50/MMBtu provides a reasonable central estimate for annual procurement planning. Monitor LNG feedgas flows daily during spring maintenance season — unplanned outages that extend into June could create buying opportunities, while faster-than-expected restart could tighten the market ahead of summer.