Henry Hub next-day physical averaged $3.146/MMBtu in June, up 7.1% MoM, with improving cooling-demand expectations offsetting above-average storage and strong U.S. production. Regional basis did the real work: the GCX Expansion eased Permian constraints and pulled Waha basis tighter by $3.29/MMBtu, while Northeast ranges narrowed as late-spring weather cleared, with cooling signals only showing up on the last trading day. Blackcomb (Q3) is set to add further Permian takeaway, which would typically support Waha strengthening. The WTI selloff is the offsetting risk: sustained oil weakness would eventually pressure oil-directed drilling economics, which is what drives Permian associated-gas growth.
Price Action
Henry Hub recovered from an early-month low and strengthened steadily through the second half of June. Next-day physical reached an intramonth high of $3.370 on Jun 29, the highest close since mid-February, before settling at $3.317 on Jun 30. The rally was supported by improving cooling-demand expectations, though above-average storage inventories and strong U.S. natural gas production continued to limit further upside.
- Henry Hub averaged $3.146/MMBtu in June, up 7.1% month on month and 4.3% year on year, finishing at $3.317/MMBtu on Jun 30 after peaking at $3.370 on Jun 29.
- The monthly trading range narrowed to $0.447/MMBtu, roughly half May's range, reflecting a steadier market.
- The market strengthened through the second half of June as weather forecasts became more supportive.
- Working gas inventories stood at 2,835 Bcf as of June 19, 152 Bcf above the five-year average, with weekly injections remaining at or above seasonal norms.
Cross-Market Dynamics
- U.S. LNG export economics remained supportive of Henry Hub throughout June, even as European gas prices eased. The TTF-Henry Hub spread narrowed modestly but stayed wide enough to keep the transatlantic arb comfortably open, and Marine LNG Houston continued to trade at a large premium to HH. What matters for the U.S. balance is not the exact spread level but that LNG feedgas demand held near record territory around ~19 Bcf/d through the month, providing a structural floor under Henry Hub that has grown into a durable feature of the U.S. gas complex rather than a cyclical one.
- Crude oil moved in the opposite direction, with WTI Midland falling sharply while Henry Hub strengthened — a classic crude-gas divergence, this time reflecting oil-specific weakness rather than any change in the gas fundamentals. The implication is more interesting than the divergence itself. Permian gas is largely associated gas that comes out of the ground alongside crude drilling; sustained lower oil prices would eventually pressure oil-directed drilling economics and slow associated-gas production growth. If that plays out, it works against the structural Waha basis compression thesis that Blackcomb and the broader wave of new Permian takeaway is built on.
Cross-Regional Dynamics
- Regional basis markets, rather than Henry Hub, provided the clearest market signals during June.
- Waha-Henry Hub basis strengthened from -$6.226/MMBtu in May to -$2.934/MMBtu in June following the commissioning of the GCX Expansion.
- The timing suggests infrastructure changes, rather than weather, were the primary driver of Waha basis strengthening.
- HSC basis remained broadly stable, indicating Gulf Coast supply and demand remained well balanced despite higher Permian deliveries.
- Northeast basis volatility eased notably from May, with both Algonquin Citygate and Transco Zone 6 NY flipping positive on Jun 30 (+$0.667 and +$0.207 respectively), an early cooling-demand signal at month-end.
- Overall, June highlighted two distinct themes: structural improvement in Permian pricing, and material easing of Northeast basis volatility with an early cooling-demand signal appearing on the final trading day.
Price Volatility
Volatility eased across Henry Hub during June, while regional basis markets continued to reflect changing infrastructure and seasonal fundamentals.
Henry Hub's coefficient of variation fell to 3.79%, its lowest level in six months, consistent with a narrower trading range. Waha basis volatility increased as prices adjusted to the structural impact of the GCX compression additions rather than disorderly trading. Because Northeast basis averages remained close to zero and both Algonquin and Transco Zone 6 NY crossed from negative to positive within the month, intra-month trading ranges provide a more meaningful measure of volatility than the coefficient of variation for those hubs.
*Near-zero-mean artifact: when basis averages near zero, CV becomes mathematically large even with modest absolute volatility.
Something to Watch
Blackcomb Pipeline (Expected Q3 2026)
- Observation: Blackcomb is expected to add 2.5 Bcf/d of natural gas takeaway capacity from the Permian Basin to the Gulf Coast when it enters service in Q3 2026.
- Why it matters: The GCX Expansion, delivered through compression additions on the existing 500-mile line, demonstrated how brownfield egress additions can quickly reshape regional pricing. Blackcomb is a different profile: a 365-mile greenfield pipeline whose 2.5 Bcf/d nameplate is already fully contracted with firm transportation agreements from Devon Energy, Diamondback Energy, Marathon Petroleum and Targa Resources. Provided commissioning holds, it would deliver a larger, single-shot capacity add and support further Waha-Henry Hub basis strengthening.
- What to monitor: Updates on the commissioning timeline (365 miles of new pipe carries schedule risk) and the pace of the Waha-Henry Hub basis response around start-up. Because firm agreements already cover the full 2.5 Bcf/d nameplate, flows should ramp toward maximum quickly, so the more meaningful reads will be basis behaviour and whether the incremental takeaway is absorbed by continued Permian associated-gas production growth.
Storage Through the Injection Season
- Observation: Working gas inventories stood at 2,835 Bcf, 152 Bcf above the five-year average, with injections continuing at or above seasonal norms.
- Why it matters: If the storage surplus remains elevated through the remainder of the injection season, it is likely to continue limiting upside. A narrowing surplus would indicate a tighter market heading into winter.
- What to monitor: The weekly EIA Natural Gas Storage Report will remain the key measure of market balance. Particular attention should be paid to whether injections continue to outpace the five-year average or whether the storage surplus begins to narrow.
Summer Cooling Demand
- Observation: Henry Hub reached $3.370 on Jun 29, its highest close since mid-February, and settled at $3.317 on Jun 30 as expectations for stronger cooling demand improved.
- Why it matters: Weather is expected to remain the primary short-term driver of Henry Hub prices. Sustained above-normal temperatures would increase gas-fired power demand, while milder weather would likely support stronger storage injections and keep prices range-bound.
- What to monitor: U.S. medium-range weather forecasts for signs of sustained heat. Weekly power burn data and EIA storage reports will indicate whether stronger demand is beginning to tighten the supply-demand balance.
June marked a shift from weather-driven volatility to infrastructure-driven regional pricing. While Henry Hub responded to improving cooling demand expectations, the clearest market signals came from regional basis markets, where new pipeline capacity and changing seasonal fundamentals reshaped price relationships across North America. How storage evolves, whether summer heat persists, and the progress of additional Permian takeaway projects will determine whether regional strength translates into broader gains during the second half of the year.
Note: All figures, prices and market activity referenced in this report are based on the period 1 to 30 June 2026.
