Here's the paradox at the center of the U.S. natural gas market right now: prices are rising, demand is growing, and the grid is leaning harder on gas-fired generation than ever — yet the geopolitical shock that was supposed to detonate global LNG prices has largely failed to materialize in the U.S. domestic market. Understanding why tells you everything about where baseload stability is headed this summer and beyond.
The Numbers Are Moving, But Not Panicking
Henry Hub spot prices averaged $2.94 per MMBtu in May, up 6.2% from April, with the July futures contract settling at $3.41 per MMBtu as of June 10. That's a real move — prompt-month prices crossed back above $3 for the first time since late March — but it's a weather-driven demand story, not a supply crisis. Meteorologists are forecasting warmer-than-normal temperatures through late June, which means gas-fired power plants are running hard to keep air conditioners on. About 40% of U.S. power generation comes from gas-fired plants, so when summer heat arrives, Henry Hub follows.
The supply picture is actually more comfortable than the price move suggests. Average gas output in the Lower 48 has fallen to 108.8 bcfd so far in June, down from 109.7 bcfd in May and a record 110.6 bcfd in December 2025 — but the EIA's latest Short-Term Energy Outlook projects that rising Permian associated gas output will keep storage inventories above the five-year average, with end-of-October inventories expected to exceed the five-year maximum. The EIA now projects Henry Hub to average $3.60 per MMBtu for full-year 2026 — up slightly from January forecasts but still $1.12 per MMBtu lower than the January 2026 projection for 2027. The market is not pricing in catastrophe.
Why the Iran Conflict Didn't Break U.S. Gas Prices
This is the part that should recalibrate how you think about natural gas geopolitics. When U.S. and Israeli military operations against Iran commenced in late February 2026, the immediate fear was Strait of Hormuz closure — a waterway through which approximately 20% of the world's LNG, primarily from Qatar, transits to global markets. Iran reportedly struck Qatari LNG infrastructure in retaliation. By any prior logic, that should have sent Henry Hub vertical.
It didn't. U.S. natural gas prices have stayed relatively flat compared to crude oil, which trended sharply upward after the conflict began. The reason is structural: natural gas remains a regional commodity. Only about 23% of U.S. natural gas is exported, compared to nearly 30% of U.S. crude oil. The global gas market simply isn't integrated enough for a Hormuz disruption to transmit cleanly into American baseload pricing the way it does for oil.
That's a feature, not a bug — for now. But it also means the U.S. grid's gas dependency is insulated from global shocks only as long as domestic production stays robust and LNG export infrastructure stays constrained. The moment either of those conditions changes, the firewall disappears.
The LNG Maintenance Wrinkle and What It Signals
There's a quieter constraint operating right now that deserves attention. Average gas flows to the nine major U.S. LNG export plants have fallen from 17.1 bcfd in May to 16.5 bcfd so far in June, due to ongoing spring maintenance at several facilities including the ExxonMobil/QatarEnergy Golden Pass facility and Freeport LNG's Texas plant — down from a monthly feedgas record of 18.8 bcfd in April. That reduced export pull is actually keeping more gas in the domestic market, softening what would otherwise be tighter summer supply conditions.
The IEA's Global LNG Capacity Tracker puts this in civilizational context: between 2025 and 2030, around 345 bcm/year of new LNG export capacity is set to come online from projects already under construction as of 2025 — the largest wave of capacity additions ever recorded. When that capacity comes online and maintenance windows close, the export pull on domestic supply will intensify. The comfortable inventory buffer the EIA is projecting for late 2026 may look very different by 2028.
The Baseload Stability Equation
Here's what this means for grid operators right now: the summer of 2026 is manageable. Gas is available, storage is healthy, and prices — while rising — are not at crisis levels. But the structural tension is building. FERC just approved PJM's expedited interconnection track for large generating projects of at least 250 MW that can come online within three years, a direct acknowledgment that gas-dependent baseload is not keeping pace with data center and AI demand growth. The fast-track process accepts up to 10 projects annually through end of 2027 — a useful patch, not a structural fix.
The electricity maximalist case for gas has always been transitional: burn it hard while we build the nuclear and storage capacity that makes it unnecessary. That case still holds. But the window between "gas is the reliable bridge" and "gas exports are tightening the domestic market" is shorter than the EIA's comfortable 2026 projections suggest. Watch the feedgas flow numbers when Golden Pass and Freeport return from maintenance. That's when the real
