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| Coal Creek Station | |
|---|---|
| Name | Coal Creek Station |
| Location | Underwood, North Dakota, United States |
| Coordinates | 47°21′N 101°27′W |
| Owner | Great River Energy (formerly) |
| Operator | Great River Energy |
| Status | Decommissioned (units ceased 2022–2023) |
| Primary fuel | Lignite |
| Units | 2 × 605 MW (gross) |
| Commissioned | 1979–1980 |
| Decommissioned | 2022–2023 (units) |
Coal Creek Station
Coal Creek Station is a large lignite-fired electricity generating facility located near Underwood in McLean County, North Dakota. Built in the late 1970s and operated for decades, the plant was a major asset in regional power supply, regional transmission and coal mining linkages, and a focal point for debates over carbon capture, air pollution controls, and utility economics. The station interfaced with interstate transmission systems and federal regulatory frameworks while drawing labor, fuel, and policy attention from local, state, and national actors.
Construction of the plant began after approvals in the 1970s, amid energy policy developments following the 1973 oil crisis, the Energy Policy and Conservation Act of 1975, and regional planning by utility cooperatives such as Great River Energy and predecessor public power entities. Commissioning occurred in 1979–1980, contemporaneous with projects like the Kearny Generating Station and large base-load builds on the Mississippi River System. The station’s development involved engineering firms, financing from institutions such as the Rural Utilities Service and investor coal purchasers, and coordination with the Southeast North Dakota Development Corporation. Over decades the plant intersected with federal regulation from the Environmental Protection Agency and regional market shifts influenced by the North American Electric Reliability Corporation and Midcontinent Independent System Operator (MISO). Discussions on retrofits and carbon management in the 2000s linked Coal Creek to initiatives like the Department of Energy’s carbon demonstration programs and to research at the National Renewable Energy Laboratory and Lawrence Berkeley National Laboratory.
The facility comprised two pulverized coal-fired steam electric units with once-through cooling systems, generating gross output around 1,210 MW, and auxiliary systems for coal handling, ash disposal, and flue gas treatment. Plant layout included large boilers and steam turbines supplied by major equipment vendors that have supplied projects such as Babcock & Wilcox and General Electric installations at the Pawtucket Power Station. Fuel was supplied from nearby lignite mines tied to enterprises like the Freedom Mine and regional coal producers that also serve mines in the Powder River Basin and Bakken Formation logistics corridors. Onsite infrastructure included switchyards connecting to high-voltage lines operated by Basin Electric Power Cooperative, Xcel Energy, and regional balancing authorities like MISO and North American Electric Reliability Corporation standards. Environmental control equipment evolved to include scrubbers, low-NOx burners, electrostatic precipitators, and ash handling similar to systems at plants such as TXU Power facilities and Plant Scherer.
During peak years the station ran as a baseload resource providing energy and ancillary services, contributing to regional capacity markets, spinning reserves, and voltage support across transmission networks that link to Minnesota Power and Montana-Dakota Utilities. Unit dispatch varied with seasonal demand influenced by the North Dakota grid, natural gas price signals from hubs like Henry Hub, and renewable integration from Grand Ridge Wind Farm and CapX2020 transmission projects. Plant performance metrics including heat rate, capacity factor, forced outage rate, and thermal efficiency were tracked by operators and reported to entities such as the Energy Information Administration and Federal Energy Regulatory Commission. Workforce and labor relations involved unions and trade groups active in the energy sector comparable to United Mine Workers of America interactions with coal operations elsewhere.
Coal Creek’s emissions profile included carbon dioxide, sulfur dioxide, nitrogen oxides, particulate matter, mercury, and trace metals—issues regulated under statutes like the Clean Air Act and subject to EPA rulemakings such as the Cross-State Air Pollution Rule and Mercury and Air Toxics Standards. Mitigation measures considered or implemented mirrored technologies piloted at sites supported by the Department of Energy’s clean coal initiatives and pilot carbon capture projects at facilities like Boundary Dam Power Station and Petra Nova. The plant’s ash ponds and landfill practices raised concerns similar to incidents at Kingston Fossil Plant and regulatory scrutiny by state agencies such as the North Dakota Department of Environmental Quality. Regional water use implicated river systems and cooling intake impacts analogous to debates around Lake Sakakawea and Missouri River resources. Community health and environmental advocacy organizations, including national groups like the Sierra Club and local conservation groups, engaged on monitoring and policy.
Owned and operated by Great River Energy and tied to cooperative utility models similar to Basin Electric Power Cooperative and Minnkota Power Cooperative, the plant’s economics were shaped by coal procurement contracts, mine royalties, capital expenditures for emissions controls, and comparisons with natural gas-fired combined cycle plants from firms like Calpine and Exelon. Market forces—commodity prices, carbon pricing proposals debated in the United States Congress, and state-level energy policy in North Dakota—affected dispatch decisions. Financing, potential sale, or repowering discussions involved industry players and investors comparable to transactions seen with NRG Energy and Vistra Energy assets. Tariff structures administered by the Federal Energy Regulatory Commission and participation in ancillary service markets by MISO influenced revenue streams.
Coal Creek was subject to controversies over emissions, permit disputes, and economic viability amid changing market conditions that mirrored conflicts at plants such as Kennecott Utah Copper and Mountaineer Power Plant. Regulatory enforcement actions and community litigation invoked agencies like the EPA and state courts. Operational incidents included equipment failures, unplanned outages, and ash management events reminiscent of the Tennessee Valley Authority’s operational challenges. Debates over public subsidies, potential federal support for carbon capture, and differences between cooperative members echoed controversies involving Western Area Power Administration and other publicly oriented utilities.
Faced with economic pressures as natural gas and renewable generation expanded, the units were retired in phases in the early 2020s, with cessation of commercial operation aligning with retirements at coal plants nationwide. Stakeholders explored options such as site remediation, redevelopment for grid-scale batteries like projects by Tesla, repowering with gas turbines similar to conversions at Monticello Steam Electric Station, industrial reuse, or carbon capture utilization and storage initiatives referencing demonstrations at Sleipner and proposals akin to the Northeastern Carbon Capture Project. State and local authorities, tribal governments, and economic development agencies engaged in transition planning comparable to efforts in regions impacted by closures at Centralia Coal Mine and the Appalachian coalfields.
Category:Coal-fired power stations in North Dakota Category:Energy infrastructure completed in 1980