Thermal Plants Owned and Operated by PacifiCorp
Blundell Plant
Maximum Nameplate Rating: 26 MW
Location: Beaver County, Utah, 23 miles southwest of Milford.
Fuel: Geothermal steam from adjacent well field.
Plant Description: One unit; commercial operation in 1984. Geothermal fluid from well is flashed; steam portion goes through the turbine; condensate and excess brine are reinjected into wells.
Plant Location Description: Blundell Plant is located in a remote area of geothermal activity. The plant emits hydrogen sulfide vapors. The plant is located in an air attainment area.
Carbon Plant
Maximum Nameplate Rating: 189 MW
Location: Carbon County, Utah, 5 miles north of Helper.
Fuel: Bituminous Coal, 11,800 BTU/lb, 9.0% ash, 0.5% sulfur (0.81 lb SO2/MMBTU)
Plant Description: Two units; commercial operation in
1954 and 1957; each unit has a tangentially-fired boiler with electrostatic precipitator, mechanical draft cooling towers with NPDES (national pollutant discharge elimination system) discharge to Price River.
Plant Location Description: Carbon Plant is located in a canyon along U.S. Highway 6, next to the Price River. Originally designed as a mine mouth plant, fuel is now received by truck from Carbon and Emery County mines. The plant is located in an air attainment area.
Centralia Plant
Maximum Nameplate Rating: 1460 MW
Location: Lewis County, Washington, 5 miles north of Centralia.
Fuel: Sub-bituminous coal, 8000 BTU/lb, 14.4% ash, 0.65% sulfur (1.6 lb SO2/MMBTU).
Plant Description: Two units; commercial operation in 1972 and 1973; each unit has a tangentially-fired divided-wall boiler with two electrostatic precipitators, mechanical draft cooling towers with NPDES discharge through a series of ponds to Big Hanaford Creek.
Plant Location Description: Centralia Plant is located in Hanaford Valley adjacent to the Centralia Coal Mine. Originally designed as a mine mouth plant, supplemental lower sulfur coal is also received by rail from Rocky Mountain states. The plant is located in an air attainment area.
Dave Johnston Plant
Maximum Nameplate Rating: 817 MW
Location: Converse County, Wyoming, 4 miles east of Glenrock.
Fuel: Sub-bituminous coal, 7800 BTU/lb, 8.9% ash, 0.4% sulfur (1.0 lb SO2/MMBTU).
Plant Description: Four units; commercial operation in 1959, 1960, 1964, and 1972. Units 1, 2 and 3 have wall-fired boilers with electrostatic precipitators, once-through condenser cooling with mechanical draft cooling towers that operate during summer with NPDES discharge into the North Platte River. Unit 4 has a tangentially-fired boiler and a wet venturi scrubber for particulate and SO2 control, mechanical cooling towers for condenser cooling, and NPDES discharge from ash ponds.
Plant Location Description: Dave Johnston Plant is located along I-25 beside the North Platte River. Originally designed as a captive mine plant, supplemental lower sulfur coal is also received by rail from mines in the Powder River Basin of Wyoming. The plant is located in an air attainment area.
Gadsby Plant
Maximum Nameplate Rating: 252 MW; Unit 3 in operation, Units 1 and 2 out of service.
Location: 1407 W. N. Temple, Salt Lake City, Utah, in Salt Lake County.
Fuel: Natural gas.
Plant Description: Three units; commercial operation in 1951, 1952, and 1955. Units 1, 2 have wall-fired boilers with mechanical draft cooling towers. Unit 3 has a tangentially-fired boiler with mechanical draft cooling tower. The plant has an NPDES discharge permit into the Jordan River. Electrostatic precipitators are installed on units 2 and 3, but are not used for gas operation.
Plant Location Description: Gadsby Plant is located west of downtown Salt Lake City, beside the Jordan River. The plant is located in an air non-attainment area for PM-10. Utah's state implementation plan (SIP) requires that Gadsby Plant burn natural gas and limits the tons-per-year emissions of PM-10, SO2 and NOx.
Hunter Plant
Maximum Nameplate Rating: 1210 MW
Location: Emery County, Utah, 2 miles south of Castle Dale.
Fuel: Bituminous coal, 11,500 BTU/lb, 12.7% ash, 0.48% sulfur (0.8 lb SO2/MMBTU).
Plant Description: Three units; commercial operation in 1978, 1980, and 1983. Units 1 and 2 are tangentially-fired boilers with electrostatic precipitators and wet lime flue gas desulfurization (FGD) systems operating at 0.15 lb SO2/MMBTU. Unit 3 is a wall-fired boiler with low-NOx burners, a baghouse for particulate control and a wet lime FGD system operating at 0.12 lb SO2/MMBTU. Each unit has mechanical draft cooling towers and the plant is zero-discharge for waste water.
Plant Location Description: Hunter Plant is located in a broad valley. Coal is received by truck from nearby dedicated coal mines. The plant is located in an air attainment area. Units 1 and 2 must comply with Subpart D of the New Source Performance Standards (NSPS). Unit 3 complies with Subpart Da of the NSPS.
Huntington Plant
Maximum Nameplate Rating: 893 MW
Location: Emery County, Utah, 7 miles west of Huntington.
Fuel: Bituminous coal, 11,500 BTU/lb, 12.7% ash, 0.42% sulfur (0.7 lb SO2/MMBTU).
Plant Description: Three units; commercial operation in 1977 and 1974. The units have tangentially-fired boilers with electrostatic precipitators. Unit 1 has a wet lime FGD system operating at 0.15 lb SO2/MMBTU. Each unit has mechanical draft cooling towers and the plant is zero-discharge for waste water.
Plant Location Description: Huntington Plant is located in a canyon beside Huntington Creek. Coal is received from an adjacent coal mine. The plant is located in an air attainment area.
Unit 1 must comply with Subpart D of the New Source Performance Standards (NSPS).
Jim Bridger Plant
Maximum Nameplate Rating: 2242 MW
Location: Sweetwater County, Wyoming, 35 miles east of Rock Springs.
Fuel: Sub-bituminous coal, 9600 BTU/lb, 10% ash, 0.6% sulfur (1.32 lb SO2/MMBTU)
Plant Description: Four units; commercial operation in 1974, 1975, 1976, and 1979. Each unit has a tangentially-fired boiler, electrostatic precipitator, and wet sodium FGD system operating at 0.3 lb SO2/MMBTU (0.2 for Unit 4). Each unit has mechanical draft cooling towers and the plant is zero-discharge for waste water.
Plant Location Description: Jim Bridger Plant is located in Deadman Wash. Coal is received by conveyor from a dedicated coal mine, and supplemental coal is received by truck from nearby mines and by rail from other Wyoming coal mines. The plant is located in an air attainment area, however exceedances of the ambient particulate standard have occurred in Deadman Wash due to coal handling activities at the power plant and coal mines. Unit 4 must comply with Subpart D of the New Source Performance Standards (NSPS).
Naughton Plant
Maximum Nameplate Rating: 707 MW
Location: Lincoln County, Wyoming, 5 miles south of Kemmerer.
Fuel: Sub-bituminous coal, 9800 BTU/lb, 5% ash, 0.7% sulfur (1.4 lb SO2/MMBTU).
Plant Description: Three units; commercial operation in 1963, 1968, and 1971. Each unit has a tangentially-fired boiler and electrostatic precipitator for particulate control. Unit 3 has a wet sodium FGD system operating at 0.5 lb SO2/MMBTU. Each unit has mechanical draft cooling towers. Water is discharged under an NPDES permit to Hams Fork River.
Plant Location Description: Naughton Plant is located in a valley, coal is received by conveyor from a dedicated coal mine. The plant is located in an air attainment area, however Units 1 and 2 are under a compliance schedule to reduce SO2 emissions through coal blending and natural gas co-firing.
Wyodak Plant
Maximum Nameplate Rating: 362 MW
Location: Campbell County, Wyoming, 4 miles east of Gillette.
Fuel: Sub-bituminous coal, 7900 BTU/lb, 8% ash, 0.68% sulfur (1.7 lb SO2/MMBTU)
Plant Description: One unit; commercial operation in 1978. The unit has a wall-fired boiler, electrostatic precipitator for particulate control, and a dry lime spray dryer FGD system operating at 0.5 lb SO2/MMBTU. The unit has an air cooled condenser and no waste water is discharged from the plant.
Plant Location Description: Wyodak Plant is located in a valley near I-90. A small coal plant is operated adjacent to Wyodak by Black Hills Power & Light; coal is received by conveyor from a dedicated coal mine. The plant is located in an air attainment area.
Thermal Plants Owned But Not Operated by PacifiCorp
Cholla 4
PacifiCorp owns Unit 4 of the four unit Cholla Plant
Maximum Nameplate Rating: 414 MW
Location: Near Joseph City in Navajo County, Arizona.
Fuel: Sub-bituminous coal, 9840 BTU/lb, 13.9% ash, 0.46% sulfur (0.9 lb SO2/MMBTU).
Plant Description: Began commercial operation in 1978. The unit has a tangentially-fired boiler, electrostatic precipitator for particulate control, and a wet limestone FGD system operating at 0.8 lb SO2/MMBTU. The unit has mechanical cooling towers and no waste water is discharged from the unit.
Plant Location Description: The plant is located near I-40; coal is shipped from New Mexico. The plant is located in an air attainment area.
Colstrip Plant
PacifiCorp owns 10% of Units 3 and 4 of the four-unit Colstrip Plant.
Maximum Nameplate Rating: 1729 MW (100% of Units 3 and 4).
Location: Near Colstrip, in Rosebud County, Colorado.
Fuel: Sub-bituminous coal, 8600 BTU/lb, 9.4% ash, 0.65% sulfur (1.5 lb SO2/MMBTU)
Plant Description: Units 3 and 4 began commercial operation in 1984 and 1986. The units have tangentially-fired boilers and wet venturi lime scrubbers for particulate control, and FGD systems operating at 0.1 lb SO2/MMBTU. The units have mechanical cooling towers and no waste water is discharged from the plant.
Plant Location Description: The plant is located near a coal mine.
Craig Plant
PacifiCorp owns 19.3% of Units 1 and 2 of the three-unit Craig Plant.
Maximum Nameplate Rating: 892 MW (100% of Units 1 and 2).
Location: Near Craig, in Moffat County, Colorado.
Fuel: Sub-bituminous coal, 10040 BTU/lb, 6.8% ash, 0.38% sulfur (0.75 lb SO2/MMBTU).
Plant Description: Units 1 and 2 began commercial operation in 1980. The units have wall-fired boilers with low-NOx burners, electrostatic precipitators for particulate control, and wet limestone FGD systems operating at 0.4 lb SO2/MMBTU. The units have mechanical cooling towers and no waste water is discharged from the plant.
Plant Location Description: The plant is located in the Yampa River valley; coal is received from a nearby mine. The plant is located in an attainment area.
Hayden Plant
PacifiCorp owns 17.5% of Units 1 and 2 of the three-unit Craig Plant.
Maximum Nameplate Rating: 365 MW (100% of
Units 1 and 2).
Location: Near Hayden, in Routt County, Colorado.
Fuel: Sub-bituminous coal, 10700 BTU/lb, 9.9% ash, 0.44% sulfur (0.8 lb SO2/MMBTU).
Plant Description: Units 1 and 2 began commercial operation in 1965 and 1976. Unit 1 has a wall-fired boiler and electrostatic precipitators for particulate control. Unit 2 has a tangentially-fired boiler and an electrostatic precipitator. The units have mechanical cooling towers.
Plant Location Description: The plant is located in the Yampa River valley; coal is received from a nearby mine. The plant is located in an attainment area.
Figure E-1:
Principal Power Facilities, Western United States(1)
Table A-1: Federal System Hydroelectric Projects
September 30, 1992
Project |
Initial Year of Service |
Number of Units |
Name-plate Rating (MW) |
Instantaneous Generating Capacity(2) (peak MW) |
Firm Energy (aMW) |
U.S. Bureau of Reclamation Hydroelectric Projects |
Grand Coulee |
1941 |
30 |
6,450.0 |
6,684 |
1,865 |
Hungry Horse |
1952 |
4 |
392.0 |
428 |
107 |
Palisades |
1957 |
4 |
142.2 |
164 |
61 |
Anderson Ranch |
1950 |
2 |
27.0 |
30 |
11 |
Minidoka |
1909 |
7 |
13.4 |
16 |
9 |
Roza |
1958 |
1 |
11.3 |
13 |
4 |
Black Canyon |
1925 |
2 |
8.0 |
10 |
7 |
Chandler |
1956 |
2 |
12.0 |
13 |
7 |
Total Bureau of Reclamation Projects |
52 |
7,055.9 |
7,358 |
2,071 |
U.S. Army Corps of Engineers Hydroelectric Projects |
Chief Joseph |
1955 |
27 |
2,069.0 |
2,614 |
1,114 |
John Day |
1968 |
16 |
2,160.0 |
2,484 |
872 |
The Dalles |
1957 |
22 |
1,780.0 |
2,074 |
697 |
Bonneville |
1938 |
18 |
1,050.0 |
1,186 |
537 |
McNary |
1953 |
14 |
980.0 |
1,127 |
630 |
Lower Granite |
1975 |
6 |
810.0 |
932 |
188 |
Lower Monumental |
1969 |
6 |
810.0 |
930 |
191 |
Little Goose |
1970 |
6 |
810.0 |
932 |
185 |
Ice Harbor |
1961 |
6 |
603.0 |
693 |
187 |
Libby |
1975 |
5 |
525.0 |
600 |
197 |
Dworshak |
1974 |
3 |
400.0 |
460 |
144 |
Lookout Point |
1954 |
3 |
120.0 |
138 |
24 |
Detroit |
1953 |
2 |
100.0 |
115 |
34 |
Green Peter |
1967 |
2 |
80.0 |
92 |
22 |
Lost Creek |
1975 |
2 |
49.0 |
56 |
23 |
Albeni Falls |
1955 |
3 |
42.6 |
49 |
26 |
Hills Creek |
1962 |
2 |
30.0 |
35 |
14 |
Cougar |
1964 |
2 |
25.0 |
29 |
12 |
Foster |
1968 |
2 |
20.0 |
23 |
10 |
Big Cliff |
1954 |
1 |
18.0 |
21 |
11 |
Dexter |
1955 |
1 |
15.0 |
17 |
8 |
Total Corps of Engineers Projects |
149 |
12,496.6 |
14,607 |
5,126 | |
Total Bureau of Reclamation and Corps of Engineers Projects |
201 |
19,552.5 |
21,965 |
7,197 |
SOURCE: Bonneville Power Adminstration, Pacific Northwest Loads and Resources Study, December 1992
Table A-2: Non-Federally Owned BPA Resources and Contracts
Project |
Type |
Operator |
Date in Service |
OY 1993-94 Capacity (peak MW) |
OY 1993-94 Firm Energy (aMW) |
Existing Non-Federally Owned BPA Resources |
Trojan (30%) |
Nuclear |
PGE |
1976 |
331 |
214 |
WNP-2 |
Nuclear |
WPPSS |
1984 |
1,100(3) |
7051 |
Boardman |
Coal |
PGE |
1992(4) |
50 |
29 |
Packwood Lake |
Hydro |
WPPSS |
1964 |
30 |
6 |
Idaho Falls |
Hydro |
City of Idaho Falls |
1982 |
18 |
18 |
Cowlitz Falls |
Hydro |
Lewis County PUD |
1994 |
0(5) |
103 |
Total Non-Federally Owned BPA Resources |
1,529 |
982 |
Firm Contracts |
Canadian Entitlement |
186 |
62 | |||
Restoration, Columbia River Treaty w/Canada |
0 |
-26 | |||
Southwest Capacity/Energy Exchange |
0 |
9 | |||
Montana Power Capacity/Energy Exchange |
0 |
29 | |||
PP&L (Wyoming) Import for Southern Idaho Load |
189 |
94 | |||
Basin Electric Cooperative Purchase |
120 |
105 | |||
Powerex (TransAlta) Purchase |
125 |
100 | |||
WNP-3 Exchange Settlement Agreements |
0 |
113 | |||
Total BPA Firm Contracted Resources |
620 |
486 |
SOURCE: Bonneville Power Adminstration, Pacific Northwest Loads and Resources Study, December 1992
Table A-3 summarizes the Federal system firm energy resources and contracts available to meet Federal firm loads for OY 1993-94. Federal system firm energy resources are comprised as follows: 83 percent from hydroelectric power, 11 percent from two nuclear power plants, 6 percent from BPA's firm contracts, and less than 1 percent from BPA's share of the Boardman coal-fired facility.
Table A-1: Federal System(6) Firm Resources for OY 1993-94(7)
Project Type |
Generating Peak Capacity (MW) |
Generating Peaking Capacity % of Total |
Firm Energy (aMW) |
Firm Energy % of Total |
Hydro |
21,440 |
91 |
7,233 |
83 |
Nuclear |
1,431 |
6 |
920 |
11 |
Coal |
50 |
0 |
28 |
0 |
Firm Contracts |
620 |
3 |
487 |
6 |
Total Federal Resources |
23,541 |
100 |
8,668 |
100 |
Table A-1: Federal System(8) Firm Resources for OY 1993-94(9)
Project Type |
Generating Peak Capacity (MW) |
Generating Peaking Capacity % of Total |
Firm Energy (aMW) |
Firm Energy % of Total |
Hydro |
21,440 |
91 |
7,233 |
83 |
Nuclear |
1,431 |
6 |
920 |
11 |
Coal |
50 |
0 |
28 |
0 |
Firm Contracts |
620 |
3 |
487 |
6 |
Total Federal Resources |
23,541 |
100 |
8,668 |
100 |
(1) Adapted from Western Area Power Administration, 1992, Principal Power Facilities of the Western United States (map).
(2)Maximum generation under optimum conditions. Does not reflect reduction to the peaking capacity of the hydro system due to the drafting of reservoirs and other project constraints.
(3)Efficiency improvements will increase WNP-2 maximum capacity to 1,155 megawatts and maximum capability to 751 average megawatts when completed in OY 1996. WNP-2 expected energy output prior to the efficiency improvements was 715 aMW; however, in OY 1993-94, an extended maintenance schedule reduced WNP-2 generation to 705 aMW.
(4)Seasonally acquired by BPA from PNGC for September through April, OY 1992-93 through 1994-95.
(5)Acquired by BPA on January 28, 1991 and will become operational April 1, 1994. Full energy capability is 22 average megawatts and maximum capacity is 70 megawatts starting OY 1994-95.
(6)Includes Federally and non-Federally owned projects
(7)Operating Year (OY) is the 12-month period August 1 through July 31. For example, OY 1993-94 is August 1, 1993 through July 31, 1994.
(8)Includes Federally and non-Federally owned projects
(9)Operating Year (OY) is the 12-month period August 1 through July 31. For example, OY 1993-94 is August 1, 1993 through July 31, 1994.