Bigger Natural Gas Storage Build Ahead, but Gap to Last Year Continues to Close

Why It Matters

The tighter inventory balance and maintenance‑driven bottlenecks could lift natural‑gas prices and affect earnings for producers and downstream users ahead of the summer heating season.

Key Takeaways

• NGI projects 86 Bcf injection week ending May 8, near 5‑year average
• Surplus to last year shrinks to 52 Bcf, down from 75 Bcf
• Henry Hub price rose 11.5 cents to $2.735/MMBtu
• Production ticked up to 108.4 Bcf/d; rig count modestly increased
• Pipeline maintenance may cut east‑west capacity by up to 545,000 MMBtu/d

Pulse Analysis

The latest EIA weekly storage report shows an 86 billion‑cubic‑foot (Bcf) injection for the week ending May 8, according to Natural Gas Intelligence (NGI). While this figure trails the 109 Bcf injected a year earlier, it aligns closely with the five‑year average of 84 Bcf and represents a 23 Bcf week‑over‑week increase. The higher injection narrows the annual surplus to 52 Bcf, down from 75 Bcf, signaling a modest rebalancing of the U.S. gas market as inventories climb toward seasonal norms. The tighter inventory outlook also supports higher forward curves into the peak demand months.

Demand across the Lower 48 weakened, with NGI’s LNG Export Flow Tracker reporting feed‑gas deliveries of 16.6 Bcf/d, a drop of 1.1 Bcf/d from the prior week. Wood Mackenzie data show residential, commercial, industrial and power‑generation consumption each fell between 0.1 and 1.0 Bcf/d, reflecting milder weather and slower industrial activity. On the supply side, production edged higher to 108.4 Bcf/d, and Baker Hughes noted a modest rise in the rig count, while the Primary Vision frac‑spread tally climbed five to 179, the highest weekly total since November 2021. These demand and supply shifts are likely to influence next‑quarter earnings for major gas producers.

Regional price spreads reacted to the storage build and upcoming pipeline work. Henry Hub climbed 11.5 cents to $2.735/MMBtu, while the West Texas/South‑East New Mexico average slipped 23 cents to –$3.915. Conversely, the Rocky Mountains and California benchmarks rose 20 cents and 34 cents respectively, underscoring localized supply constraints. Maintenance on the Rockies Express, Texas Eastern, Southern Natural and Southeast Supply Header pipelines is slated for May 12‑13, potentially shaving up to 545,000 MMBtu/d of east‑west capacity. Analysts expect these short‑term bottlenecks to keep price differentials elevated ahead of the summer heating season. Market participants will watch the maintenance schedule closely, as any delays could further tighten regional supplies.