Natural Gas Price Forecast: What to Expect in Q2 2026

With shifting supply dynamics and evolving LNG export policies, natural gas markets face uncertainty. Our analysts share their outlook for enterprise buyers planning Q2 procurement.

Energy markets reward those who are prepared.

Natural gas is the backbone of commercial heating, industrial processing, and power generation across North America. For businesses budgeting energy costs in Q2 2026, the question isn't simply what prices are today — it's where they're headed and what that means for your procurement position.

Henry Hub front-month futures are currently trading in the $3.20-$3.60/MMBtu range — elevated relative to Q2 2025 but well below late-2025 peaks. Here's what's driving that range and what B2B buyers should do about it.

Natural gas prices are inherently sensitive to daily weather patterns, storage data, and geopolitical shifts. This analysis reflects conditions as of publication and should inform — not replace — real-time monitoring through your energy advisor.

Four Forces Shaping Q2

• LNG export demand: U.S. liquefied natural gas exports continue setting records. New Gulf Coast capacity commissioned in 2025–26 has connected domestic gas prices to global LNG markets more directly than at any point in history. Strong European and Asian demand keeps export facilities near full utilization — placing sustained upward pressure on domestic prices.
• Power sector demand: Rapid AI data center expansion and broad industrial electrification are driving electricity sector gas demand to multi-year highs. When renewable generation falls short, gas-fired plants fill the gap — creating demand spikes that feed directly into spot pricing.
• Storage deficit: U.S. gas storage ended the 2025-26 heating season below the five-year average, leaving a thinner cushion heading into the injection season. A slow storage build would keep prices elevated through June. Above-normal spring temperatures — which NOAA currently leans toward — would provide relief.
• Production growth: Continued Permian and Appalachian output growth is the primary factor capping price upside. More supply chasing similar demand limits how far prices can rise — but producer capital discipline means growth is measured, not unlimited.

Regional Outlook

Henry Hub (Gulf Coast)

Expect $2.80-$3.70/MMBtu through Q2. The wide range reflects genuine uncertainty — budget for both ends.

Northeast (Algonquin / Transco Zone 6)

Structural pipeline constraints keep regional basis $0.50-$2.00+ above Henry Hub during demand spikes. Northeast buyers should build conservative basis assumptions rather than relying on spot availability during peak windows.

Midwest (Chicago Citygate)

Tracks closely to Henry Hub with modest $0.10-$0.30/MMBtu positive basis. The most stable regional market heading into Q2.

Western U.S. (SoCal / Sumas)

Structural basis volatility driven by import pipeline constraints and high electricity sector demand. Western buyers should expect persistent premiums above the national benchmark.

How to Position Your Business

Your right move depends on your current contract situation. Fixed-rate buyers locked in earlier in 2026 are likely well-positioned — the question is whether to extend. Variable-rate buyers carry full Q2 price exposure and should evaluate a partial fixed/variable blend to reduce downside. Spot buyers may find current levels a reasonable entry point for 6–12 months of forward coverage ahead of any late-spring demand surprises.

The businesses that manage energy cost risk most effectively aren't the ones that always buy at the lowest price — they're the ones that build systematic procurement frameworks that remove decision-making from the volatility.