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954 MW Lignite operating in Mercer, ND
954 MW
Nameplate Capacity
2
Generators
units
Conventional Steam Coal
Technology
1984
Operating Since
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| Field | EIA | GEM | Wikidata |
|---|---|---|---|
| Operator | Basin Electric Power Coop | — | — |
| Owner(s) | Basin Electric Power Coop | — | — |
| Status | Operating | — | — |
Antelope Valley Station is a coal-fired power plant in the United States in North Dakota. One of the reasons it is significant is because of alleged environmental damage from local coal mining and pollution from the plant.
Read more on WikipediaThe Antelope Valley Station is a 954 MW coal-fired power plant located in Mercer County, North Dakota. It began operating in 1984 and is owned and operated by Basin Electric Power Cooperative. The plant utilizes conventional steam coal technology and its primary fuel source is lignite (LIG). Antelope Valley Station is the largest of four power plants in North Dakota and ranks second out of eight similar plants nationally.
The plant consists of two generators and operates within the Southwest Power Pool (SPP) balancing authority, falling under the Midcontinent Reliability Organization (MRO) NERC region. In its latest year of reported generation, the plant produced 5,992,022 MWh, achieving a capacity factor of 71.7%. Financial data indicates an installed cost of $1,141.33 per kW, as reported to FERC.
Generated from EIA, GEM, and public data sources
ISO/RTO
SPP
Market
ISO/RTO Member
NERC Region
MRO — Midwest Reliability Organization
Balancing Authority
Southwest Power Pool (SWPP)
Grid Voltage
345.0 kV
Regulatory Status
RE — Regulated
Entity Type
Cooperative
Sector
Electric Utility
Monthly net generation as reported to EIA-923 — useful for historical context. Confidence varies sharply by fuel type; the band above and the “About this data” button explain the caveats specific to this plant and how InfraSure’s in-house model handles them.
541.8K MWh
Latest Month
6.0M MWh
Annual Generation
71.7%
Capacity Factor
Forward-looking generation outlook with probabilistic ranges across weather, demand, and policy scenarios. Powered by InfraSure's generation modeling stack.
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CO₂ Intensity
2390 lb/MWh
NOx
1 lb/MWh
SO₂
5 lb/MWh
CH₄
0.272 lb/MWh
N₂O
0.040 lb/MWh
Capacity Factor
59.0%
Annual Net Gen
4935 GWh
CO₂eq
2408 lb/MWh
Subregion
MRO West
Steam turbine · basin electric power cooperative (pudl determined) · Data from 2019–2024
$1,170/kW
Installed Cost
$5/kW
Annual CapEx
$39.5/MWh
Operating Cost
Annual Capital & Operating Expenses
Cumulative Installed Cost
Per-Unit Cost Trends
Forward revenue, DSCR bands, and refinancing risk projected under price, demand, and policy scenarios. Powered by InfraSure's asset cashflow stack.
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Point of Interconnection
Nearest Substation
Antelope Valley Substation · 345 kV
Substation Distance
< 10 km
Operator
Basin Electric Power Cooperative
Coord Source
OSM spatial
Market Position
ISO/RTO Market
SPP
LMP Node
WAUEANTELOPUNANTELO_1_UNIT_RA
Pricing Hub
SPPNORTH_HUB
Node Source
EIA-860 direct report
No wholesale contracts disclosed in FERC EQR for this plant.
FERC EQR captures bilateral wholesale energy + capacity contracts ≥$1M/yr filed quarterly by jurisdictional sellers — covers renewable PPAs, thermal energy sales agreements, capacity contracts, and tolling agreements alike. Many plants don't appear: regulated-utility output flows to ratepayers via cost-of-service rather than bilateral contracts; small projects fall below the filing threshold; tax-equity-financed renewables route offtake to investors not utilities; merchant plants sell into ISO clearing markets without bilateral contracts. News-extracted buyer facts (below) may surface contracts disclosed only through announcements.
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