Natural Gas EIA Weekly Natural Gas Storage

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Latest report October 2, 2026

Natural Gas EIA Storage — October 2, 2026

EIA Weekly Natural Gas Storage Analysis: 2026-10-02

Executive Summary

Total Lower 48 working natural gas in underground storage expanded by 85 Bcf for the week ending October 2, 2026, bringing aggregate inventories to 3,500 Bcf. Stocks stand 68 Bcf (+2.0%) above the five-year average, while remaining 130 Bcf (-3.6%) lower than the corresponding period last year. Regional injections were balanced across key consuming and producing basins, keeping the national inventory trajectory on a comfortable path heading into the final month of the injection season.

Storage Snapshot

  • Total Lower 48 Inventories: 3,500 Bcf
  • Weekly Net Change / Implied Flow: +85 Bcf (vs. 3,415 Bcf prior week)
  • Year-Ago Comparison: -130 Bcf (-3.6% vs. 3,630 Bcf)
  • Five-Year Average Comparison: +68 Bcf (+2.0% vs. 3,432 Bcf)

Regional Breakdown: - East: Built +22 Bcf to 862 Bcf (+0.7% vs. year-ago, +3.7% vs. 5-year average). - Midwest: Built +26 Bcf to 1,010 Bcf (+1.3% vs. year-ago, +2.3% vs. 5-year average). - South Central: Built +28 Bcf to 1,076 Bcf (-10.3% vs. year-ago, -2.3% vs. 5-year average). - Salt: +14 Bcf to 227 Bcf (-23.1% vs. year-ago, -14.0% vs. 5-year average). - Nonsalt: +15 Bcf to 849 Bcf (-6.1% vs. year-ago, +1.4% vs. 5-year average). - Mountain: Built +5 Bcf to 253 Bcf (-7.7% vs. year-ago, +5.9% vs. 5-year average). - Pacific: Built +4 Bcf to 299 Bcf (-1.6% vs. year-ago, +9.1% vs. 5-year average).

Injections were led by the South Central (+28 Bcf) and Midwest (+26 Bcf) regions. Despite the steady weekly build, the South Central remains the only macro region running below its five-year norm, driven primarily by salt cavern storage, which sits 14.0% below historical averages.

Implications

The +85 Bcf injection reflects typical early-autumn fundamentals, where mild shoulder-season weather suppresses residential and commercial consumption as well as cooling-related power burn.

With Lower 48 inventories crossing the 3.5 Tcf mark and maintaining a 2.0% surplus over the five-year average, the current trajectory is fundamentally range-bound to slightly soft for front-month NG futures. However, the sustained deficit in South Central salt facilities (-14.0% vs. the 5-year average) offers an offsetting regional tightness. Because salt caverns provide the primary peak-shaving and quick-cycle balancing capacity for Gulf Coast LNG feedgas swings, this lingering deficit limits downstream flexibility and prevents broad price erosion. No revision or reclassification flags were reported in this release.

Risks and Context

  • Shoulder Season Trajectory: With roughly four weeks remaining in the nominal injection season, inventory additions over the remainder of October will dictate whether end-of-October working gas reaches or exceeds 3.8 Tcf.
  • Weather and Early-Winter Sensitivity: Late-October heating degree day (HDD) outcomes will directly impact injection magnitudes in the East and Midwest. Additionally, because fast-cycling salt storage remains constrained relative to historical norms, any unseasonably cold early-November weather combined with uninterrupted LNG feedgas demand could trigger swift early-season drawdowns in the South Central region.

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