Natural gas price: futures hold $3 ahead of EIA storage report

Front-month U.S. natural gas closed Wednesday at $3.066 per million British thermal units, up about 1% on the day. Traders are positioning for Thursday's weekly storage report from the Energy Information Administration, and the bet is plain: a ninth consecutive below-average injection that keeps draining the inventory surplus.

The streak is the whole story, and it is getting long. Each of the last eight EIA reports has printed a smaller-than-normal build, according to NatGasWeather.com, and analysts expect the run to extend to nine weeks when Thursday's numbers land. Last week's injection was 64 billion cubic feet. That is a respectable number in absolute terms. It sits well short of the 80 Bcf five-year average for that week, though. Small misses, repeated eight times, are how surpluses disappear.

The surplus erosion has been relentless.

Working gas stood at 3,415 Bcf on September 25 — 79 Bcf, or 2.4%, above the five-year average of 3,336 Bcf, yet 138 Bcf, or 3.9%, below the same point last year. Early estimates put this week's build at 79 Bcf for the week ended October 2, against 77 Bcf a year ago and a 96 Bcf norm; confirmed, the surplus narrows to roughly 62 Bcf, under 2% above normal. The prior week's 64 Bcf build had already marked the seventh straight below-average print before the streak extended again.

Supply is quietly helping the bulls. Lower 48 production has slipped to about 112.2 billion cubic feet per day in early October from the record 113.3 Bcf/d averaged across August and September, with autumn pipeline maintenance accounting for part of the dip. Gas flows to U.S. LNG export terminals have eased to 17.0 Bcf/d from 17.9 in September as plants schedule seasonal maintenance — gas that would have left the country is staying home and padding storage, which makes the shrinking surplus more telling, not less. Salt-dome storage in the South Central region even drew down 4 Bcf in late September, a withdrawal during injection season that points to Gulf Coast demand absorbing gas faster than it arrives.

Note the paradox: gas that would have been exported is staying home — and the surplus is shrinking anyway.

The skeptics have their own ammunition. BOK Financial notes that quant funds have drifted more to the short side — fuel for a squeeze, but only if demand cooperates — and cautions that without a real fundamental shift, the path of least resistance remains lower. The weather outlook stays mild through mid-October, limiting both cooling and heating demand, and the November contract is clinging just above its 50-day moving average near $3.03 after Friday's intraday plunge to $2.912.

A week that opened with a 6%-plus slide and finished back above $3 is a market that has now refused lower prices twice.

Why it matters

The end-of-season storage math no longer adds up the way the bears need it to. Official forecasts project inventories of 3,969 Bcf on October 31 — 5% above the five-year average and 44 Bcf short of the record set in October 2016. But reaching 3,969 Bcf from 3,415 Bcf requires 554 Bcf of injections over five weeks, or 111 Bcf a week, while recent builds have run 44, 53 and 64 Bcf and the next is pegged at 79. At an 80-to-90 Bcf pace through October, storage lands near 3,800 to 3,850 Bcf: comfortable, and well short of a record. That quietly deflates one of the market's main bearish talking points.

Then there is the global price disconnect. European gas at the Dutch TTF hub trades near the equivalent of $24 per mmBtu, and Asian spot LNG at $25.74, against Henry Hub at $3.03. The $21-plus spread cannot pull U.S. prices higher because liquefaction plants are running at full capacity — there is no spare room to export more. New trains at Plaquemines in Louisiana, Corpus Christi's third stage in Texas, and Golden Pass add 0.5 to 0.7 Bcf/d of demand each as they ramp, and that demand growth arrives just as the heating season starts.