Most natural gas in the United States comes from shale rock formations deep underground, extracted through horizontal drilling and hydraulic fracturing. The largest producing regions are concentrated in a handful of states: Texas, Pennsylvania, Louisiana, West Virginia, and Oklahoma account for the bulk of output. Total U.S. production currently averages around 120 billion cubic feet per day, making the country the world’s largest natural gas producer.
How Natural Gas Forms Underground
Natural gas is mostly methane, created over millions of years as heat and pressure broke down the remains of ancient marine organisms buried in layers of sedimentary rock. Some of that gas migrated upward and collected in porous rock formations capped by impermeable layers above, forming conventional reservoirs that have been tapped for over a century. But the majority of today’s U.S. production comes from unconventional sources, particularly shale formations where the gas remained trapped in the dense rock where it originally formed.
Shale gas stayed commercially out of reach until the combination of horizontal drilling and hydraulic fracturing made it possible to crack open these tight rock layers and release the gas. A single well can be drilled vertically for a mile or more, then turned sideways to run horizontally through a thin shale layer for another mile or two, dramatically increasing the surface area that produces gas. This technology transformed the U.S. energy landscape starting in the mid-2000s and is now responsible for the vast majority of new gas wells drilled in the country.
The Major Producing Regions
U.S. natural gas production is dominated by a few prolific basins, each with its own geology and characteristics.
The Appalachian Basin, centered on the Marcellus and Utica shale formations beneath Pennsylvania, West Virginia, and Ohio, is the single largest gas-producing region in the country. These are dedicated gas wells, meaning the primary product is natural gas rather than oil. Pennsylvania alone rivals Texas in total gas output.
The Permian Basin in western Texas and southeastern New Mexico is a massive oil-producing region, but it also generates enormous volumes of natural gas as a byproduct of oil drilling. This “associated” gas hit 12.5 billion cubic feet per day in 2024, an 8% increase over the prior year, accounting for 47% of total Permian gas production. The Haynesville shale, straddling the Texas-Louisiana border, is another major dedicated gas play that ramps up quickly when prices rise because its wells are close to Gulf Coast export terminals.
Beyond those three powerhouses, the Bakken formation in North Dakota produced about 2.3 billion cubic feet per day of associated gas in 2024, and the Eagle Ford shale in south Texas contributed another 1.8 billion cubic feet per day. The Anadarko Basin in Oklahoma and the Niobrara formation in Colorado and Wyoming round out the major producing areas.
Associated Gas vs. Dedicated Gas Wells
Not all natural gas comes from wells drilled specifically for gas. About 37% of U.S. natural gas production is “associated” gas, meaning it comes up alongside crude oil during oil drilling. The remaining 63% is “non-associated” gas from wells targeting gas as the primary product.
This distinction matters because associated gas production rises and falls with oil prices and oil drilling activity, not gas prices. When oil companies ramp up drilling in places like the Permian Basin, gas floods the market whether demand exists or not. Associated gas production grew nearly 8% in 2023 alone, averaging 17.1 billion cubic feet per day. That surge of supply can push gas prices down even when dedicated gas producers are cutting back. It also means that a significant share of America’s gas supply is effectively a side effect of oil production decisions.
From the Wellhead to Your Home
Raw natural gas straight out of the ground isn’t ready for your furnace or stove. It contains water vapor, hydrogen sulfide, carbon dioxide, nitrogen, helium, and heavier hydrocarbons like ethane, propane, butane, and pentane. Pipeline companies set strict quality standards for what enters the transmission system, so the gas must be processed first.
At processing plants near production areas, these impurities and extra hydrocarbons are stripped out. The hydrogen sulfide and carbon dioxide (collectively called “acid gases”) get removed because they’re corrosive and toxic. The heavier hydrocarbons are separated and sold as natural gas liquids, which become feedstock for plastics, heating fuel (propane), and gasoline blending components. What remains is “pipeline quality” dry natural gas, almost pure methane, which enters the interstate pipeline network under high pressure.
How the U.S. Stores Its Supply
Natural gas demand swings dramatically with the seasons. Heating needs spike in winter, but production stays relatively steady year-round. Underground storage bridges that gap. The U.S. uses three types of underground storage facilities: depleted oil and gas reservoirs, natural aquifers, and salt caverns.
Depleted reservoirs are the most common type, often located near major population centers where the gas will eventually be consumed. They hold large volumes and work well for seasonal storage, filling up during the lower-demand summer months and drawing down in winter. Aquifer storage is used mainly in the Midwest, where natural underground water-bearing rock formations have been converted to hold gas. Salt caverns, found along the Gulf Coast, store less total volume but can inject and withdraw gas extremely quickly, making them useful for short-term supply swings and price spikes rather than long seasonal cycles.
Where Production Is Headed
U.S. natural gas production is projected to keep climbing. The EIA forecasts marketed production will average 120.8 billion cubic feet per day in 2026, a 2% increase, then reach a record 122.3 billion cubic feet per day in 2027. Prices are expected to rise alongside production, from $3.52 per million BTU in 2025 to $4.31 in 2026, driven largely by growing demand from liquefied natural gas export terminals along the Gulf Coast and increasing electricity generation from gas-fired power plants.
The growth will continue to come overwhelmingly from shale formations, with the Permian Basin’s associated gas and the Appalachian and Haynesville dedicated gas plays doing the heavy lifting. Conventional vertical gas wells, the kind that dominated for most of the 20th century, now represent a small and shrinking share of new production.