US dry gas production remains stubbornly flat at approximately 101.8 Bcf/d in June, up just 0.2% year-over-year despite Henry Hub prices averaging above $3.00/mmBtu for most of 2026. The supply response to higher prices has been far more muted than historical patterns would suggest, reflecting structural changes in the producer landscape.
The natural gas-directed rig count has fallen to 92, down 15% from 2025 levels and near the lowest since the COVID-era lows of 2020. Producers have been disciplined in their capital allocation, prioritizing shareholder returns over growth. Many gas-focused E&P companies have publicly stated they need sustained prices above $3.50/mmBtu before they will add rigs.
Associated gas from oil-directed wells in the Permian Basin provides an increasing share of total US gas supply. Associated gas output is running at approximately 32 Bcf/d, up 3% year-over-year. This gas is effectively a by-product of oil drilling decisions — it continues to flow regardless of gas prices, providing a floor under total supply that cheapens the marginal cost of gas production.
The Appalachian Basin (Marcellus and Utica shales) is the swing region for gas supply. Appalachia produces approximately 35 Bcf/d, accounting for roughly 34% of total US dry gas output. The region's rig count has stabilized at 28 rigs, but EQT Corporation and other major Appalachian producers have not signaled any intention to materially increase activity.
On the demand side, liquefied natural gas (LNG) exports continue to grow. Feedgas deliveries to US LNG terminals averaged 13.2 Bcf/d in June, up 2% year-over-year. The Plaquemines LNG terminal in Louisiana is ramping toward full capacity, and Corpus Christi Stage 3 is expected to reach its full 5 Bcf/d nameplate capacity by Q4 2026. LNG feedgas demand is projected to reach 14-15 Bcf/d by early 2027.
The net effect is a market that can tighten relatively quickly if weather creates demand spikes, but where sustained price rallies above $3.50 are self-limiting. At $3.50+, producers add rigs, and associated gas from the Permian continues growing. The structural supply story is one of constraint, not scarcity.
Flat production + growing LNG exports = a market that will tighten over time but is not yet tight. The key variable is Permian associated gas — you can't separate it from oil drilling decisions. For natural gas buyers: the $3.00-$3.50 range is the new equilibrium band. Below $3.00 is attractive for forward contracting. Above $3.50, producers respond. Use the band boundaries for procurement decisions.