Storage Report Details
| Metric | Value | Context |
|---|---|---|
| Net Change | -54 Bcf | Above market expectations |
| Working Gas | 1,829 Bcf | Within 5-year historical range |
| vs 5-Year Avg | +14 Bcf | 0.8% above (1,815 Bcf avg) |
| vs Year Ago | +90 Bcf | Healthier than 2025 position |
| Henry Hub Spot | $3.82/MMBtu | Up from $3.13 two weeks ago |
| April Futures | $3.91/MMBtu | NYMEX front-month |
Why the 54 Bcf Draw Matters
A 54 Bcf withdrawal in late March is significant. The winter withdrawal season typically ends in mid-to-late March, and late-season draws of this magnitude signal that residual heating demand — particularly in the Northeast and Midwest — remains elevated. For context, the same week last year saw a draw of only 29 Bcf.
The draw pushed Henry Hub spot prices up nearly 22% from the $3.13/MMBtu level recorded just two weeks earlier. April futures at $3.91 suggest the market expects continued tightness through the seasonal transition.
Injection Season Outlook
The market is transitioning into injection season under a mixed outlook:
- Production: Lower 48 dry gas production remains robust at 109–110 Bcf/d, providing a well-supplied production base.
- Demand drivers: Power sector gas demand is structurally higher due to AI data center expansion. LNG export demand from Sabine Pass, Cameron, and Freeport terminals continues to pull 13–14 Bcf/d from the domestic market.
- Bull case: If injection rates track below the 5-year average pace, the storage deficit could widen by summer, supporting prices above $4.00/MMBtu heading into the 2026/27 heating season.
- Bear case: If mild spring weather accelerates injections, the current 14 Bcf surplus over the 5-year average could grow rapidly, capping prices in the $3.50–3.75 range.
Impact on Electricity Prices
Natural gas sets the marginal clearing price in most US wholesale electricity markets. The 22% rally from $3.13 to $3.82/MMBtu translates directly to higher power costs:
- ISO-NE: Most exposed. New England imports LNG at global prices during peak demand. The DASI cost overrun ($921M) compounds this exposure.
- ERCOT: Texas gas-fired generation represents 45% of the fuel mix. Higher gas costs flow through to wholesale prices within days.
- PJM: Gas-on-the-margin hours have increased from 32% to 41% since 2023. The $329/MW-day capacity price adds structural cost pressure on top of fuel costs.
Commercial Procurement Action Items
- Gas buyers: The $3.82 spot price is 8% below the EIA’s revised March STEO forecast of $3.80 (annual average), but 31% above the February futures trough of $2.90. Consider locking 50–70% of summer requirements at current levels.
- Electricity buyers: Gas volatility will ripple through power markets. Fixed-price contracts locked before injection season typically capture lower risk premiums.
- Monitor next report: The next EIA storage report (week ending March 27) releases April 2, 2026. The first net injection of the season would signal the seasonal floor.
Source: EIA Weekly Natural Gas Storage Report, released March 26, 2026; Henry Hub spot and futures via CME/NYMEX.