US natural gas producers: basins, operators, and pricing

Where U.S. natural gas comes from

EIA reports U.S. dry natural gas production of about 36.35 trillion cubic feet in 2022. In that year, five states accounted for most output: Texas at 24.6 percent, Pennsylvania at 21.8 percent, Louisiana at 9.9 percent, West Virginia at 7.4 percent, and Oklahoma at 6.7 percent. EIA's projections identify shale and tight resources as the largest sources of U.S. natural gas production through 2050. Production statistics by state and month are published in EIA's natural gas data series.

Those shares point to two quite different kinds of producer. In Appalachia, covering Pennsylvania, West Virginia, and Ohio, many wells are drilled primarily for natural gas. In Texas, Oklahoma, and other oil-weighted basins, a large share of gas is associated gas produced alongside crude oil. A producer's dependence on gas prices, and its response to them, depends heavily on which of those groups it belongs to.

Gas-weighted and oil-weighted producers

EQT develops natural gas resources in the Appalachian Basin, principally across Pennsylvania, West Virginia, and Ohio, with large-scale horizontal development in the Marcellus and Utica formations, and it presents midstream and commercial services that connect production with gathering and downstream transportation. For a gas-weighted producer of that kind, pipeline capacity and regional gas pricing are central to value.

Oil-weighted and diversified producers also produce substantial gas. Devon Energy develops oil, natural gas, and NGLs across U.S. onshore basins including the Delaware, Marcellus, Rockies, Anadarko, and Eagle Ford regions. EOG Resources explores for and produces crude oil, NGLs, and natural gas across U.S. resource plays including the Delaware Basin, Eagle Ford, Dorado, Utica, Williston, and Powder River areas, and manages gathering, processing, and marketing activities adjacent to the wellhead. ConocoPhillips produces crude oil, bitumen, natural gas, NGLs, and LNG-linked resources across several regions, with transportation and marketing activities connecting production to regional and global markets.

The product mix matters because associated gas volumes respond to oil drilling decisions rather than to gas prices alone. A gas price decline may slow drilling in a gas-weighted basin while associated gas from oil basins keeps flowing. Analysts should separate gas-directed from associated volumes when forecasting supply or comparing producers.

Takeaway, basis, and realized prices

A producer's realized price is not the headline benchmark. Gas sold in a producing region trades at a basis to the benchmark hub that reflects pipeline capacity, local demand, and storage. When takeaway is constrained, regional prices can trade at a steep discount; when new pipelines or demand sources arrive, the discount can narrow. Firm transportation contracts, marketing arrangements, and processing terms all sit between the wellhead and the realized price.

Midstream companies shape those outcomes. Williams gathers, processes, stores, and transports natural gas, with its Transco system linking supply areas to customers along the Eastern Seaboard and Gulf Coast. Kinder Morgan's natural gas business covers transmission, gathering, processing, storage, and LNG-terminal interests. Export demand adds another outlet: EIA reports U.S. LNG exports averaged 11.90 billion cubic feet per day in 2023, which ties Gulf Coast gas demand to global markets.

Demand and storage shape the market producers sell into

Producers sell into a market balanced by storage. EIA notes that most U.S. underground gas storage sits in depleted oil and gas fields close to consuming regions, with salt caverns and aquifers making up the rest. Storage is filled during lower-demand months and drawn down in winter, so the level of inventories relative to normal is one of the most watched indicators in the gas market. A producer's near-term price outlook therefore depends not only on its own output but on weather, power-sector demand, industrial use, exports, and how full storage is heading into each season.

That seasonality affects operating decisions. Some producers curtail or defer turning wells to sales when regional prices are weak, and some hold firm transportation to reach higher-priced markets. Comparing producers without accounting for those choices can make a disciplined operator look like a weak one in a single quarter.

Forecasting and valuing gas production

Gas production forecasts combine decline-curve or type-curve analysis with development schedules, downtime, and infrastructure constraints. Valuation then pairs those volumes with a price deck, basis differentials, processing and transportation costs, royalties, taxes, and capital. BTU Graph's upstream forecasting and valuation guide covers that workflow and the reserves-economics systems used for it, such as ComboCurve, PHDwin, ARIES, and Enverus PRISM.

Keep the price inputs explicit and dated. A defensible model names the benchmark hub, the basis assumption, the unit, and the date of the scenario. Oil Price API, which publishes BTU Graph, supplies natural gas benchmark series as structured data for that staging layer; the forecasting and economics systems remain responsible for volumes, costs, and valuation logic.

How to use this producer map

Start with EIA's state and national data to frame the supply picture, then use the company profiles below to see each producer's basins, product mix, and adjacent midstream activities with dated evidence. Compare producers on gas weighting, basin, takeaway position, and marketing approach rather than on volume alone.

Companies are listed alphabetically and drawn from BTU Graph's public-evidence profiles. Inclusion is not an endorsement or a ranking, and this page is not a complete list of U.S. natural gas producers. Production volumes, reserves, and asset portfolios change through drilling, acquisitions, and divestitures; confirm current figures in each company's latest filings and EIA's most recent data before relying on them.