Natural Gas Prices Ease as Western Heat Moderates, Storage Build Expected

Natural gas futures retreated last week despite the kind of demand surge that typically props up prices. September contracts closed Friday at $3.222 per million British thermal units, down nearly two and a half percent from the prior week's settlement. The decline came after prices had tested multi-month highs early in the week, only to lose momentum as the week progressed and traders absorbed conflicting signals about what comes next.

The week's volatility reflected a market caught between two competing forces. Cash prices for natural gas actually moved higher, driven by the relentless heat blanketing the western United States. Across California, Texas, and much of the Lower 48, homes and businesses pushed air conditioning systems to their limits as temperatures soared. Power plants and utilities scrambled to meet the surge in cooling demand, and both natural gas and electricity prices climbed to their highest levels in months. The intensity was real enough that forecasters would later describe June as tracking toward the top five hottest on record.

But the bullish fundamentals—the kind of demand that normally lifts prices—got dampened by other developments. Early in the week, news that a flow restriction on Enbridge's Texas Eastern Transmission pipeline would persist through the end of summer had briefly supported prices. That support evaporated as the week wore on. Weather models shifted cooler for the days ahead, suggesting that the intense demand for cooling would ease. A storm system moving through the Gulf of Mexico threatened to further reduce demand. And then came the inventory report.

On Thursday, the Energy Information Administration released its weekly storage data, and the numbers created confusion that sent some traders to the sidelines. The agency reported that domestic natural gas supplies rose by 16 billion cubic feet for the week ending June 11. But the headline masked a complication: the EIA had reclassified some gas stocks from working inventory—the volume actually available for market use—to base gas, which sits in reserve. When adjusted for this reclassification, the implied build to working gas stocks was 67 billion cubic feet. That figure came in a few ticks below what analysts had expected, but the reclassification itself was unusual enough to unsettle traders and weigh on prices into the close.

The storage picture, taken as a whole, tells a story of tightness. Total stocks now stand at 2.427 trillion cubic feet, down 453 billion cubic feet from the same week a year earlier and 126 billion cubic feet below the five-year average. Analysts had been bracing for a lighter-than-usual injection this week anyway. NGI's model predicted a 74 billion cubic foot build; the five-year average for this period is 87 billion cubic feet. Last year at this time, the EIA recorded an 86 billion cubic foot injection.

Looking ahead, forecasters expect the week to bring a modest storage build of around 72 billion cubic feet, still below the historical average. The American and European weather models agree that temperatures from Tuesday through Friday will be "not quite hot enough" to sustain the elevated demand of the past two weeks. National cooling needs should ease as weather systems move across the northern and east-central United States. But the Southwest will remain substantially hot, and California's ongoing drought continues to constrain hydropower generation, keeping upward pressure on natural gas demand. Bespoke Weather Services noted that despite the moderating trend, June is still on pace to rank among the five hottest months in the historical record, a reminder that the heat driving this market remains extraordinary by any measure.