Henry Hub natural gas is trading at $3.28/MMBtu on June 29, a modest 1.9% decline on the session as the market digests an overwhelmingly well-supplied fundamental picture. Prompt-month futures have climbed back above $3 since mid-May as summer cooling demand begins to lift power burn, but the market remains far from the $7.72/MMBtu average seen in January 2026 during the peak of the winter heating season.
The storage picture tells the story clearly. Working gas in storage stood at 2,835 Bcf as of June 19, representing a 76 Bcf weekly injection. That is 152 Bcf above the five-year average and marks a consistent pattern: the surplus versus the five-year has held steady at approximately 150 Bcf for three consecutive weeks. Total working gas remains within the five-year historical range but on the comfortable side of it. The EIA expects injections during the April-October season to be above average, with inventories ending October 31 at 7% above the five-year average.
Production is the key variable driving the comfortable supply picture. Lower 48 marketed gas production averaged 117.2 Bcf/d in Q1 2026, up 4% year-on-year. The EIA projects full-year 2026 production at 118.9 Bcf/d, up 3% from 2025, with growth driven primarily by the Permian Basin. The Permian alone is expected to produce 29.2 Bcf/d in 2026, 6% above 2025 levels. Associated gas from oil-directed drilling continues to increase supply even as dry-gas drilling activity has moderated.
Demand is growing but not fast enough to absorb the supply increase. U.S. natural gas consumption is projected at 91.24 Bcf/d for 2026, essentially flat compared to 2025. The power sector, which accounts for approximately 40% of gas demand, is expected to see its share of electricity generation ease from 40% to 39% as renewables continue to gain share. Summer cooling demand is projected to increase 2.3% versus last year, averaging 76.7 Bcf/d for June-August, driven by warmer-than-normal temperature forecasts. But this is modest relative to the supply growth.
LNG exports are the structural growth story. U.S. LNG exports are projected to average 17.0 Bcf/d in 2026 and 18.2 Bcf/d in 2027, up from 15.1 Bcf/d in 2025. April 2026 saw approximately 0.9 Bcf/d of incremental export capacity come online. The expansion is driven by new Gulf Coast liquefaction capacity and by global demand for U.S. gas as an alternative to disrupted Middle East supply. However, LNG feedgas demand has dipped seasonally in spring due to planned maintenance at liquefaction facilities, temporarily easing demand pressure during the early injection season.
The American Gas Association describes storage as healthy and injections as strong. Henry Hub spot prices were generally below $3 from mid-March through early May, only recovering above $3 in mid-May as summer cooling demand began to materialize. On an inflation-adjusted basis, prompt-month prices are below both 2025 levels and the five-year median. The EIA lowered its 2026 Henry Hub forecast in both the May and June STEO updates, reflecting the persistent supply strength.
EIA's price outlook tells a story of capped upside. The agency forecasts Henry Hub averaging $2.83/MMBtu in Q2 2026, $3.34/MMBtu in H2 2026, and $3.50/MMBtu for full-year 2026. The 2027 forecast of $3.18/MMBtu is actually lower than 2026, as continued production growth and storage rebuilding weigh on prices. The price curve retains the same general shape from earlier forecasts but has been translated vertically downward by more than $1/MMBtu for 2027.
Bull case: A sustained summer heat wave drives power burn to record levels, drawing storage injections significantly below the five-year average. Combined with faster LNG export ramp-up and any supply disruptions in the Permian, inventories could enter winter at or below average, supporting a price rally to $4.00+. Bear case: Mild summer weather, continued strong associated gas production, and a quick resolution of LNG maintenance schedules keep injections on track. End-October storage finishes 10% or more above the five-year average, setting up a weak winter price environment. Base case: Storage finishes the injection season at the EIA's forecast of 7% above average. Henry Hub trades $3.00-3.75 for the balance of 2026.
Henry Hub at $3.28/MMBtu reflects a market that is well-supplied but not oversupplied. The 152 Bcf storage surplus versus the five-year average is comfortable but not extreme, representing about five days of consumption. For natural gas buyers managing industrial or power-generation fuel costs, the current environment favors a cautious hedging approach. The EIA's end-of-season storage forecast implies limited upside risk to $4.00, but the downside is also capped by LNG demand growth and the physical reality that storage is not yet excessive. Cover 40-50% of winter 2026-27 requirements at current forward prices, which are in the $3.30-3.50 range for the January-March strip. Leave the balance unhedged to capture any weather-driven sell-off. The most important variable to watch is the weekly storage injection relative to the five-year average. If injections run consistently above 100 Bcf/week through July-August, the surplus will widen and prices will drift toward $3.00. If injections slow below 70 Bcf/week, the market will reprice higher.