What EIA Changed About The Permian Read
EIA's August 19 analysis adds drilling design to the existing associated-gas picture. New horizontal completions have stayed near 6,000 per year since 2022, but average lateral length increased from 6,149 feet in 2015 to 10,867 feet in 2025. Over the same decade, EIA reports total Permian hydrocarbon production rose 284%, from 2.9 million to 11.2 million barrels of oil equivalent per day.
The new well-length facts complement EIA's June 18 gas-oil-ratio analysis. EIA says marketed natural gas production in the Permian rose from 17.2 Bcf/d in 2021 to 27.6 Bcf/d in 2025. Crude oil output also grew, from 4.7 million b/d to 6.6 million b/d, but the gas increase was faster. That is why Permian associated gas remains one of the main supply-side counterweights to LNG-driven demand growth.
| Signal | EIA Source Fact | Buyer Read |
|---|---|---|
| Super-laterals emerged | EIA says wells longer than 15,000 feet accounted for 15% of new Permian horizontal completions in 2025. | Longer wells help explain how basin output can grow without a matching increase in annual well counts. |
| Average lateral length rose 77% | EIA reports average new-well lateral length increased from 6,149 feet in 2015 to 10,867 feet in 2025. | Productivity and drilling design belong in the supply model alongside rig counts, oil prices, and takeaway capacity. |
| Gas production outpaced oil | EIA says Permian marketed natural gas rose from 17.2 Bcf/d in 2021 to 27.6 Bcf/d in 2025. | Associated gas remains a major supply-side input for Henry Hub and Gulf Coast risk models. |
| Oil still drives the basin | EIA says Permian crude oil production rose from 4.7 million b/d in 2021 to 6.6 million b/d in 2025. | Gas supply can keep growing even when the commercial buyer is watching natural gas, not crude. |
| The gas-oil ratio increased | EIA says the Permian gas-oil ratio averaged nearly 4,200 cubic feet per barrel in 2025, up 16% from 2021. | A maturing basin can produce more gas per barrel of oil, changing supply without requiring a separate gas-drilling boom. |
| Higher GOR added material gas | EIA estimates 2025 Permian output would have been 23.8 Bcf/d if the 2021 GOR had held, 14% less than actual output. | That 3.8 Bcf/d difference is large enough to matter in national supply-balance conversations. |
Longer Wells Are A Productivity Signal, Not A Price Forecast
EIA says short-reach wells under 5,000 feet fell from 43% of completions in 2015 to 4% in 2025. Mid-length wells between 5,000 and 15,000 feet represented 81% of 2025 completions, while super-laterals longer than 15,000 feet represented 15%. Longer laterals expose more reservoir rock per well and can raise output while containing the number of new completions.
That efficiency signal matters to a supply-balance model, but it does not prove how much gas will reach Henry Hub, Waha, an LNG terminal, or a commercial meter. Oil prices, completion timing, gas processing, pipeline takeaway, maintenance, weather, and export demand still determine how upstream capability becomes market supply.
Why The Gas-Oil Ratio Matters
The gas-oil ratio measures cubic feet of natural gas produced per barrel of crude oil. EIA says the Permian ratio averaged nearly 4,200 cubic feet per barrel in 2025, 16% higher than in 2021. EIA also says that if the 2021 ratio had held, 2025 Permian gas production would have been 23.8 Bcf/d instead of 27.6 Bcf/d.
That estimated 3.8 Bcf/d difference is the practical buyer signal. It does not guarantee low natural gas prices, but it helps explain why U.S. gas supply can keep expanding even when buyers are focused on LNG export growth and power-sector gas demand.
Supply-Balance Input
Rising Permian GOR can add gas supply without requiring a separate dry-gas growth story.
Not A Delivered-Rate Quote
Regional basis, transportation, storage, LNG feedgas, weather, and retail contract terms still decide buyer cost.
Commercial Buyer Actions
- Use Permian productivity as a supply-side scenario input: pair well length and gas-oil ratio with the August STEO, weekly storage, LNG feedgas, and weather rather than treating either as a standalone bearish call.
- Separate Henry Hub from basis: more Permian supply can help national balance, while regional hubs and delivered zones can still disconnect.
- Watch Gulf Coast demand: LNG exports and industrial load can absorb incremental gas even when upstream supply grows.
- Keep procurement claims modest: this page is source-backed market context, not a supplier offer or guaranteed savings estimate.
What Not To Infer
- Do not assume Permian associated gas guarantees lower Henry Hub prices.
- Do not assume Waha or Permian basis is available to a buyer in another region without transportation and contract analysis.
- Do not treat a production-growth fact as a delivered utility-bill forecast.
- Do not use this page as a substitute for account-specific natural-gas procurement review.
Sources: U.S. Energy Information Administration Today in Energy, August 19 and June 18, 2026; EIA Short-Term Energy Outlook, August and June 2026; Enverus lateral-length data as cited by EIA. Retrieved August 21, 2026.