Associated gas production from the nation’s key oil basins is growing, and analysts expect the gassy trend to continue.

There is approximately 36 Bcf/d of associated wet gas output coming from four major U.S. shale basins – the Permian Basin, the Eagle Ford Shale, the Niobrara Basin and the Bakken – according to data from Bernstein and the Energy Information Administration (EIA).

That’s from an average 8.1 MMbbl/d in crude oil production coming from those four plays.

Associated gas production from these oil-rich regions has grown between 5% and 8% per year since 2017 and is expected to continue rising.

In the Permian, the gas-oil ratio (GOR) has grown around 4% per year since 2017, according to Bernstein’s analysis.

Even if crude oil production were to remain flat, associated gas output from the Permian, the Eagle Ford, the Niobrara and the Bakken are forecast to grow by between 1 Bcf/d and 1.5 Bcf/d, according to Bernstein’s analysis.

Shale Basin Gas Oil Ratio Data
The gas-oil ratio from four top U.S. oil basins – the Permian, the Eagle Ford, the Niobrara and the Bakken – is expected to rise in the coming years, even with flat crude oil output. (Source: EIA, Bernstein analysis)

Based on Bernstein’s crude production growth forecast of 1.8 MMbbl/d from 2022 through 2027, associated gas output could grow even faster at the current GOR.

Shale Basin Oil Output Gains
At the current gas-oil ratio, additional crude production will accelerate associated gas production in the four major shale oil basins. (Source: EIA, Bernstein analysis)

Natural gas production from the Permian Basin, the nation’s premier liquids play, is forecast to reach a record 22.51 Bcf/d in May, according to the EIA’s latest Drilling Productivity Report published on April 17.

Wet gas output from the Eagle Ford, the Niobrara and the Bakken is also expected to grow month over month, according to EIA data.

Growth in Lower 48 gas production is being led by the Haynesville Shale in Louisiana and East Texas, where output is expected to reach 16.82 Bcf/d in May.

Gas output is rising and U.S. oil wells are getting gassier as the industry faces a period of low prices.

Henry Hub natural gas prices are expected to average $2.94/MMBtu in 2023, down over 50% from an average of $6.42/MMBtu last year, EIA reported on April 11.

Crude production from oil basins is also expected to grow month over month. Crude oil output from the Permian is forecasted to grow by 13,000 bbl/d to reach 5.69 MMbbl/d in May.

Oil output growth will be led by the Bakken, which is slated to add 17,000 bbl/d to reach nearly 1.18 MMbbl/d next month.

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Gas glut, inventory issues

Oil producers around U.S. shale plays, but particularly in the mighty Permian Basin, are searching for liquids-weighted inventory to extend their drilling runways.

Much of the core inventory in the Permian’s Midland and Delaware basins has been picked through, and private E&Ps are amassing acreage in the more fringe areas of the play.

Midland Basin Wells GOR Data
Wells in the Midland Basin get gassier faster – at 9% per year – and reach 50%-gas five years after drilling. (Source: Bernstein, Enverus)
Delaware Basin Wells GOR Data
Wells drilled in the Delaware Basin get gassier slower than in the Midland – at 4% per year. (Source: Bernstein, Enverus)

Analysts say that it’s becoming increasingly competitive for publics to find and acquire core Permian inventory.

Earlier this month, Ovintiv Inc. agreed to scoop up three EnCap-backed privates in the Northern Midland Basin for $4.275 billion.

Matador Resources Co. closed a $1.6 billion bolt-on acquisition in the Delaware Basin last week.

Exxon Mobil has reportedly held preliminary discussions on potential M&A with Permian pure-player Pioneer – a deal with the potential to reshape the Permian.

“Inventory depth is probably not quite what everyone’s expected, and folks are scrambling to shore it up with acquisitions,” said Dan Pickering, chief investment officer at Pickering Energy Partners, at the World Oilman’s Mineral & Royalty Conference on April 11.

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