The market context
Industrial natural gas buyers have lived through two complete market regimes in under 24 months. The 2024 calendar year delivered the lowest inflation-adjusted Henry Hub average in history. Twelve months later, the first weeks of 2026 delivered the sharpest single-month spike in years. Budgets built on recent history were invalidated at both ends.
Disciplined procurement is not a reaction to volatility. It is the posture that lets industrial buyers protect margin through both regimes, without needing to predict which one they are entering.
Henry Hub spot price history
Monthly average data from the EIA DHHNGSP series, 2024 through early 2026. The table below shows the scale of the trough-to-spike move industrial buyers absorbed.
| Year | Jan | Feb | Mar | Apr | May | Jun | Jul | Aug | Sep | Oct | Nov | Dec | Ann. Avg |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 2024 | 3.18 | 1.72 | 1.49 | 1.60 | 2.12 | 2.54 | 2.07 | 1.99 | 2.28 | 2.20 | 2.12 | 3.01 | $2.21 |
| 2025 | 4.13 | 4.19 | 4.12 | 3.42 | 3.12 | 3.02 | 3.20 | 2.91 | 2.97 | 3.19 | 3.79 | 4.26 | $3.52 |
| 2026 | 7.72 | 3.62 | 3.04 | - | - | - | - | - | - | - | - | - | ~$4.31 (fcst) |
All prices in nominal USD/MMBtu. Source: U.S. EIA, DHHNGSP Series. 2026 annual forecast per EIA Short-Term Energy Outlook, April 2026. January 2024 daily high reached $13.49/MMBtu on a cold snap; intraday extremes are not reflected in monthly averages.
What the data tells industrial buyers
- The trough-to-spike range is extreme. From March 2024's record low of $1.49/MMBtu to January 2026's monthly average of $7.72, a +418% move in under 24 months.
- The 2024 calm was an anomaly. The 2024 annual average of $2.21 was the lowest in inflation-adjusted history, a 68% collapse from 2022. Buyers who anchored budgets to 2024 spot were unprepared for 2025.
- The 2025 rebound was sharp and sustained. All 12 months of 2025 averaged above $2.91. Q1 2025 averaged $4.15, driven by polar vortex withdrawals - the fourth-largest weekly storage draw on record.
- Volatility peaked at 102%. 30-day historical volatility hit 102% on February 3, 2025, the highest since March 2023.
- 2026 opened with the sharpest spike in years. Henry Hub surged from $3.04 to $8.21/MMBtu intraday the week of January 19-23, 2026, a +170% weekly move driven by Winter Storm Fern.
- LNG export pressure is structural. EIA forecasts prices rising to $4.31/MMBtu (2026) and $4.38 (2027) on sustained LNG and data center demand growth.
A one-year disciplined average hedge costs only $0.02/MMBtu more than unhedged over a decade. Minimal insurance for major risk reduction.
Disciplined procurement: action checklist
- Audit your contract exposure. Determine what percentage of volume is on daily spot versus index versus fixed. Most industrial users are more exposed than they realize. 60% on spot is common.
- Separate basis from commodity. Regional basis can diverge $4.00+/MMBtu from Henry Hub in a single week. Address NYMEX and regional basis as distinct risks.
- Start layering hedges 12 to 24 months out. Disciplined averaging is cheap insurance over a decade.
- Use the collar structure where appropriate. A costless collar (buy call ceiling, sell put floor) defines a price band at zero net premium. It preserves downside participation while capping extreme exposure.
- Model load versus procurement volume. Over-purchasing and under-purchasing both carry cost. Accurate load forecasting eliminates budget surprises at both tails of the price curve.
- Review strategy seasonally. LNG exports, storage levels, polar vortex probability, and data center load growth all shift procurement optionality each quarter.
Procurement structures for industrial users
No single structure fits every buyer. The right mix depends on volume, regional pipeline exposure, budget tolerance, and the buyer's view on where forward prices sit versus historical averages.
Fixed-Price Contract
Lock 100% of projected volume for 6 to 36 months. Full budget certainty. Optimal when forward prices are below the 3-year historical average. Locking at 2024 lows would have saved 40 to 59% versus 2025 actuals.
Index + Fixed Blend
Fix the basis component. Let NYMEX float first-of-month. Addresses the most common hidden cost driver. One Midwest manufacturer reduced 40%+ delivered-price swings by fixing basis alone.
Layered / Dollar-Cost Average
Spread procurement across 12 to 24 months in tranches, analogous to dollar-cost averaging in portfolio management. Smooths realized price across the forward curve. Preferred for large-volume buyers with predictable load.
Costless Collar
Buy a price-ceiling call and sell a price-floor put at matched premiums. Net zero upfront cost. Defines a protected band (e.g. $3.50-$5.50/MMBtu). Particularly effective against January 2026-style tail-risk events.
NYMEX + Basis Split
Treat NYMEX and regional basis as separate instruments. Fix basis when pipeline spreads are favorable; hedge NYMEX independently. Critical for Midwest and Rust Belt facilities on constrained pipelines with elevated basis.
Storage + Load Forecast
Buyers with storage access can inject at 2024-style lows ($1.49-$2.21/MMBtu) and withdraw at winter peaks. Accurate load forecasting prevents over-purchasing and eliminates budget surprises at price extremes.
Structure risk comparison
| Structure | Budget Risk | Market Upside | Complexity | Best When |
|---|---|---|---|---|
| Fully Indexed (Spot) | High | Full | Low | Prices in secular decline; very high storage surplus |
| Fixed Price (Full) | Eliminated | None | Low | Prices at or below 3-year avg; flat or backwardated curve |
| Fixed Basis / Float HH | Moderate | Partial | Medium | Pipeline-constrained regions; basis premium is rising |
| Layered / Blended | Reduced | Partial | Medium | Volatile or uncertain market outlook; large-volume buyers |
| Costless Collar | Capped | Retained | High | High volatility; elevated tail risk (polar vortex probability) |
The Executive Energy point of view
Disciplined procurement is not a forecast. It is a set of structures that protect margin across regimes, and a rhythm of review that keeps those structures aligned with the market as conditions shift. We build that discipline into every client engagement, from initial benchmark through quarterly supply oversight.
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Request a Benchmark Back to HomePrimary Data Sources
U.S. Energy Information Administration - Henry Hub Natural Gas Spot Price (DHHNGSP Series, release April 15, 2026); EIA "Spot Henry Hub natural gas prices hit a historic low in 2024" (January 2025); EIA "Natural gas price volatility fell over the first half of 2025" (July 2025); EIA "In 2025, U.S. natural gas spot prices increased from 2024's record low" (April 2026); EIA "U.S. natural gas production to reach record highs in 2026 and 2027" (April 16, 2026); EIA Short-Term Energy Outlook, April 2026. General Index "January 2026 U.S. Natural Gas Prices: Volatility, Regional Dislocation" (January 22, 2026). World Kinect Energy Services (December 2025, March 2026). Vicinity Energy Market Update (February 2025). American Gas Association Market Indicators (April 2024). PCI Energy Solutions (2022). Stanwich Energy Advisors (2023). Dallas Federal Reserve Energy Survey (2025).
All prices nominal USD/MMBtu unless noted. Monthly averages per EIA official release. Intraday and daily extremes sourced separately. Procurement strategy content is educational and does not constitute financial advice. Market conditions as of April 2026.