October 31, 2026 - Coal continues to play a significant role in the U.S. electricity system, supported by extensive domestic reserves, established infrastructure and growing demand for reliable generating capacity.

According to the U.S. Energy Information Administration (EIA), coal supplied approximately 17% of utility-scale electricity generation in 2025, ranking third behind natural gas at about 41% and nuclear power at roughly 18%. Although coal’s share has declined over the past two decades, hundreds of generating facilities remain in operation, and several utilities are extending plant operating lives to meet regional power needs.

A Changing Electricity Market

Coal’s role has evolved as utilities respond to changing fuel prices, environmental requirements and electricity demand.

Increased domestic natural gas production, supported by advances in horizontal drilling and hydraulic fracturing, made gas-fired generation increasingly competitive during the 2000s and 2010s. Modern combined-cycle plants also convert fuel into electricity more efficiently than conventional coal-fired facilities. Natural gas became the leading source of U.S. electricity generation in 2016.

Wind and solar development has added further competition in some regions. Meanwhile, environmental regulations have required investments in equipment to control sulfur dioxide, nitrogen oxides, particulate matter and other emissions. Utilities weigh those investments alongside maintenance costs, fuel availability and the reliability needs of their customers when deciding how long to operate existing coal units.

Coal combustion also produces carbon dioxide. Natural gas generally produces less carbon dioxide for an equivalent amount of energy, although methane emissions during production and transportation affect its overall environmental impact.

These considerations have reshaped the generation mix while leaving coal an important resource in many regional electricity systems.

A Substantial Domestic Resource

The United States produces the overwhelming majority of the coal it consumes, drawing on reserves across three principal producing regions.

EIA figures show U.S. coal production totaled approximately 512.5 million short tons in 2024, down 11.3% from 2023. Wyoming remained the leading producer, accounting for about 37% of national output. West Virginia ranked second, followed by Pennsylvania, Illinois and Montana. Together, those five states supplied roughly 73% of U.S. production.

The Western region produced approximately 271 million short tons in 2024, representing more than half of national output. The Powder River Basin in Wyoming and Montana contains extensive deposits served by large surface operations, including the Black Thunder and North Antelope Rochelle mines.

Appalachia produced about 158 million short tons. West Virginia led the region, where underground mining remains especially important. Pennsylvania, eastern Kentucky and neighboring states also contribute to regional production.

The Interior region, including Illinois, Indiana, western Kentucky and portions of the central and southern United States, produced approximately 83 million short tons.

Differences in geology, mining methods, transportation access and operating costs shape each region’s markets. Western surface mines expanded substantially during the late 20th century, benefiting from large deposits, comparatively low extraction costs and demand for lower-sulfur coal. Appalachian and Interior operations continue to support electricity generation, industrial customers and local economies.

Major Plants Continue Serving Regional Grids

Coal-fired generation is concentrated in the Ohio and Tennessee river valleys, the Upper Midwest, the Great Plains and parts of the Southeast. An independent inventory using EIA records identified approximately 205 active coal plants in 2026, with combined generating capacity of about 180,400 megawatts.

Georgia’s Plant Bowen, near Cartersville, is among the country’s largest operating coal-fired stations. Its four units entered commercial service between 1971 and 1975 and provide approximately 3,160 megawatts of capacity.

Georgia Power’s 2025 resource planning called for extended operation and additional environmental-control investments at Bowen. Approved planning assumptions include operating its first two units through at least 2035, reflecting growing electricity demand.

Other major stations include Gibson in Indiana, Monroe in Michigan and John E. Amos in West Virginia. Their operating schedules and retirement plans depend on utility planning, regulatory requirements and regional electricity needs.

Texas also maintains substantial coal-fired generation, including Martin Lake. In North Dakota, lignite plants operate near their supplying mines, limiting fuel transportation distances. Wyoming and other Western states continue using coal alongside expanding wind and solar resources.

The location of these plants reflects more than proximity to mines. Customer demand, rail and river transportation networks, and access to other generating resources also influence where coal is used.

Utilities Reassess Retirement Timelines

Rising electricity demand and the timing of replacement projects are prompting utilities to reconsider some planned coal retirements.

According to EIA, approximately 2.6 gigawatts of coal-fired capacity retired in 2025, the lowest annual total since 2010. Several utilities have postponed closures to preserve generating capacity while additional resources are developed.

Plant Bowen illustrates that shift. Continued operation is part of Georgia Power’s approach to meeting increased demand. Elsewhere, utilities are evaluating similar decisions where replacement generation is not yet available.

Coal plants still face competition and ongoing maintenance and environmental investment requirements. Their outlook, however, varies by facility and region. Some units will retire, while others are expected to operate beyond earlier schedules.

With domestic fuel supplies, established generating assets and an experienced workforce, coal remains a significant part of America’s electricity system as utilities balance affordability, reliability and a changing energy mix.