EPA-908/4-78-002
8
1977 Power Plan!
Summary
March 1978
Inited States
Protection
. Colorado 8O295
-------
EPA-908/4-78-002
REGION 8
1977 POWER PLANT SUMMARY
MARCH 1978
Prepared By
Gary E. Parker
George Boulter
U.S. EPA, REGION VIII
OFFICE OF ENERGY ACTIVITIES
DENVER, COLORADO 80295
-------
DISCLAIMER
This report has been reviewed by the EPA, Region VIII, Office of
Energy, and approved for publication. Approval does not signify
that the contents necessarily reflect the views and policies of the
U.S. Environmental Protection Agency, nor does mention of trade
names or commercial products constitute endorsement or recommendation
for use.
DOCUMENT AVAILABILITY
This document is available to the public through the National
Technical Information Service, Springfield, Virginia 22161.
n
-------
INTRODUCTION
This publication represents the second year a regional summary of
existing and proposed electrical generation facilities has been prepared.
The information and format as presented in the previous publication has
been expanded to include plant specific information.
The new format used to identify the types of electrical generation
is that established by the Western Systems Coordinating Council (WSCC)
in their publication titled "Reliability and Adequacy of Electric Service"
April 1, 1977 reply to Federal Power Commission (FPC) Order 383-4 Docket
R-362.
Information for this publication was obtained from:
1. Western Systems Coordinating Council Reply to Federal
Power Commission Docket R-362 "Reliability and Adequacy
of Electric Service" April 1, 1977.
2. Mid-Continent Area Reliability Coordination Agreement,
Reply to Federal Power Commission Docket R-362, April 1,
1977.
3. Individual utility reports to the Federal Power Commission
FPC, Form 67 for 1974 and 1976.
4. Personal communication with various State and local
officials.
This document identifies the existing as of December 31, 1976 and
proposed through December 31, 1986 electrical generation facilities for
the EPA Region VIII states of Colorado, Montana, North Dakota, South
Dakota, Utah and Wyoming. Information on the operating utility, plant
name, number of units, location, size and fuel are provided.
From the information presented in this publication it can be seen that
the total net generating capacity for the EPA Region VIII is projected to
almost double during the ten year period from December 31, 1976 through
December 31, 1986. These projected capacity additions are principally
steam generation, most of which will be coal fired.
It is hoped that this publication will be used to identify areas
where future electric power generation is likely to occur and thus identify
those areas where near term and sound environmental planning may be needed.
111
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PUBLICATION USE
Section I Generating Capacity Summaries provides graphical summaries of
the existing and proposed net electrical generating capacities for the ten (10)
year period from December 31, 1976 through December 31, 1986. This information
is displayed for the six state EPA Region VIII as a whole, Figure 1, as well
as on an individual state-by-state basis, Figures 2 and 3. The information
is presented in terms of two general types of generation; steam generation and
other generation. Steam generation includes those types of generation that
are dependent upon the production of steam to power the turbine generator.
This general category includes categories: (1) Steam Turbine - Non Nuclear;
(2) Steam - HTGR Nuclear and (5) Combined Cycle as identified in Section III
GENERATING FACILITIES. The other general category then includes categories
(3) Internal Combustion; (4) Combustion Turbine; (6) Conventional Hydro; and
(7) Pumped Storage. Based upon the above two general categories, net generating
capacities as of December 31, 1976 and projected for December 31, 1986 are shown
graphically in Figure 1, 2 and 3. In all instances the size of the circles are
proportional to the net generating capacities.
Section II Projected Capacity Additions is the basic information used to
develop the figures shown in Section I. The net generating additions projected
through December 31, 1986 are presented both numerically, Tables 1 through 7,
and graphically, Figures 4 through 10.
Section III Generating Facilities provides a state-by-state breakdown of
individual existing and projected power generating facilities through December 31,
1986. Information is provided on the operating utility, as keyed to the system
identification codes in Table 8; the plant name, number of units, and location,
the size of the units; the primary and alternate type of fuels, also keyed to
Table 8; the projected on-line date; the participants in the facility if
appropriate; and a code number. The information as presented under the heading
of "Net Generating Capacity (MW)" represents the net generating capacity of the
successive units as identified under the units heading. For example under A.
Colorado la Steam Turbine - Non Nuclear, the George Birdsall plant is shown to
have three units. It is then shown under "net Generating Capacity (MW)", that
the first unit has a net capacity of 17 MW as does the second unit, while the
third unit has a net capacity of 23 MW. In some instances individual unit
sizes were not available and the net generating capacity of all units is
shown as total.
The code number corresponds to the plant locations as shown on Figures 11
and 12. The code numbers indicate the state by initial(s), if the facility
is steam electric or other by including the symbol 0 for other, and the
numerical sequence in the tables. For the steam electric category the code
number also corresponds to the plant specific information in Section IV Plant
Specific Information.
The generating facilities as identified in this publication are divided
into seven categories and further subdivided into existing and projected
subcategories. The seven categories are: 1 a & b Steam Turbine - Non Nuclear,
2 a & b Steam - HTGR Nuclear; 3 a & b Internal Combustion, 4 a & b Combustion
Turbine, 5 a & b Combined Cycle, 6 a & b Conventional Hydro, and 7 a & b
Pumped Storage. The letter a identifies existing units while b is used to
identify proposed units.
iv
-------
Section IV Plant Specific Information of this publication provides
plant specific information for plants identified under category la Existing Steam
Turbine - Non Nuclear, and in some instances information for plants under
category Ib, Proposed Steam Turbine - Non Nuclear. The information has been
extracted from FPC Form 67 for data years 1974 and 1976 and Environmental
Assessments and Impact Statements when available. The information presented in
this section provides operating characteristics on some of the environmentally
significant functions of the individual facilities.
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TABLE OF CONTENTS
Introduction iii
Pub!ication Use iv
Table of Contents vi
Ie GENERATING CAPACITY SUMMARIES 1
Region VIII Ten Year Projection (Figure 1) 2
State Capacities 1976 (Figure 2) 3
State Capacities 1986 (Figure 3) 4
II. PROJECTED CAPACITY ADDITIONS 6
Region VIII Graphical (Fiqure 4) 7
Region VIII Numerical (Table!) 8
Colorado Graphical (Figures) 9
Colorado Numerical (Table 2) 10
Montana Graphical (Figure 6) ill
Montana Numerical (Table 3) 12
North Dakota Graphical (Figure 7) 13
North Dakota Numerical (Table 4) 14
South Dakota Graphical (Figures) 15
South Dakota Numerical (Table 5) 16
Utah Graphical (Figure 9) 17
Utah Numerical (Table 6) 18
Wyoming Graphical (Figure 10) 19
Wyoming Numerical (Table 7) 20
-------
III. GENERATING FACILITIES 22
Steam Electric Systems Location (Figure 11) 23
Other Electric Systems Location (Figure 12) 24
System Identification Key (Table 8) 25
A. Colorado Facilities
1. Steam Turbine - Non Nuclear
a. Existing 26
b. Proposed 27;
2. Steam - HTGR Nuclear
a. Existing 27
b. Proposed 27
3. Internal Combustion
a. Existing 28
b. Proposed 28
4. Combustion Turbine
a. Existing 28
b. Proposed 29
5. Combined Cycle
a. Existing 29
b. Proposed 29
6. Conventional Hydro
a. Existing 29
b. Proposed 30
7. Pumped Storage
a. Existing 31
b. Proposed 31
B. Montana Facilities
1. Steam Turbine - Non Nuclear
a. Existing 32
b. Proposed 32
2. Steam - HTGR Nuclear
a. Existing 32
b. Proposed 32
3. Internal Combustion
a. Existing 33
b. Proposed 33
4. Combustion Turbine „
a. Existing JJ
b. Proposed 33
vi i
-------
B. Montana Facilities (con't)
5. Combined Cycle
a. Existing 33
b. Proposed 33
6. Conventional Hydro
a. Existing 34
b. Proposed 35
7. Pumped Storage
a. Existing 35
b. Proposed 35
C. North Dakota Facilities
1. Steam Turbine - Non Nuclear
a. Existing 36
b. Proposed 36
2. Steam - HTGR Nuclear
a. Existing 37
b. Proposed 37
3. Internal Combustion
a. Existing 37
b. Proposed 37
4. Combustion Turbine
a. Existing 37
b. Proposed 38
5. Combined Cycle
a. Existing 38
b. Proposed 38
6. Conventional Hydro
a. Existing 3°
b. Proposed 38
7. Pumped Storage
a. Existing 38
b. Proposed *°
-------
D. South Dakota Facilities
1. Steam Turbine - Non Nuclear
a. Existing 39
b. Proposed 39
2. Steam - HTGR Nuclear
a. Existing..... 40
b. Proposed 40
3. Internal Combustion
a. Existing 40
b. Proposed 41
4. Combustion Turbine
a. Existing 41
b. Proposed 41
5. Combined Cycle
a. Existing 42
b. Proposed 42
6. Conventional Hydro
a. Existing 42
b. Proposed 43
7. Pumped Storage
a. Existing 43
b. Proposed 43
E. Utah Facilities
1. Steam Turbine - Non Nuclear
a. Existing 43
b. Proposed 44
2. Steam - HTGR Nuclear
a. Existing 44
b. Proposed 44
3. Internal Combustion
a. Existing 45
b. Proposed 45
4. Combustion Turbine
a. Existing 45
b. Proposed 45
5. Combined Cycle
a. Existing 45
b. Proposed 45
ix
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E. Utah Facilities (Continued)
6. Conventional Hydro
a. Existing 46
b. Proposed 46
7. Pumped Storage
a. Existing 46
b. Proposed 46
F. Wyoming Facilities
1. Steam Turbine - Non Nuclear
a. Existing 47
b. Proposed 47
2. Steam - HTGR Nuclear
a. Existing 48
b. Proposed 48
3. Internal Combustion
a. Existing 48
b. Proposed 48
4. Combustion Turbine
a. Existing 48
b. Proposed 49
5. Combined Cycle
a. Existing 49
b. Proposed 49
6. Conventional Hydro
a. Existing 49
b. Proposed 50
7. Pimped Storage
a. Existing 50
b. Proposed 50
IV. PLANT SPECIFIC INFORMATION 52
Plant Equipment (Table 9) 53
C, Colorado
Cl, George Birdsal 1 55
C2, Martin Drake 58
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IV. Plant Specific Information (Continued)
C3, City of Lamar Unit #6 62
C4, Bullock (no information)
C5, Durango (no information)
C6, Hayden 65
C7, Nucla 68
C8, Oliver (no information)
C9, Alamosa (no infromation)
CIO, Arapahoe 71
Cll, Cameo 74
C12, Cherokee 77
CIS, Comanche 8°
C14, Valmont 83
C15, Zuni 87
CIS, W. R. Clark 90
C17, Pueblo 93
CIS, Rocky Ford (no information)
C19, Trinidad (no information)
C20, Wai sen Plant (no information)
C21, Ray D. Nixon (no information)
C22, Craig 96
M, Montana
Ml, Glendive (no information)
M2, Lewis and Clark 99
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M, Montana (continued)
M3, Frank Bird 102
M4, Colstrip (no information)
M5, J. E. Corette 105
ND, North Dakota
ND1, Leland Olds 108
ND2, Wm. J. Meal Ill
ND3, Dakota (no information)
ND4, R. M. Heskett 114
ND5, Knife River (no information)
ND6, Williston (no information)
ND7, Franklin P. Wood (no information)
ND8, Milton R. Young 117
ND9, Stanton 120
ND10, Antelope Valley (no information)
ND11, Coal Creek 123
ND12, Coyote 126
SD» South Dakota
SD1, Ben French (no information)
SD2, Kirk 129
SD 3, Mobridge (no information)
SD4, Lawrence 132
SD5, Pathfinder 135
SD6, Aberdeen (no information)
SD7, Mitchell (no information)
SD8, Big Stone 138
xi i
-------
U. Utah
Ul, Carbon (no information)
U2, Cal Poc Ute Co. (no information)
U3, Gadsby (no information)
U4, Hale (no information)
U5, Huntington
K, Wyoming
Wl, Neil Simpson 144
W2, Osage 147
W3, Dave Johnson 150
W4, Jim Bridger 153
W5, Trona (no information)
W6, Naughton 156
W7, Laramie River 159
xm
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LIST OF FIGURES
Figure Title Page
1 Region VIII Ten Year Projection 2
2 State Capacities 1976 3
3 State Capacities 1986 4
4 Region VIII Graphical 7
5 Colorado Graphical 9
6 Montana Graphical 11
7 North Dakota Graphical 13
8 South Dakota Graphical 15
9 Utah Graphical 17
10 Wyoming Graphical 19
11 Steam Electric Facilities (Location) 22
12 Other Electric Facilities (Location) 23
xiv
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LIST OF TABLES
Tab!e Title Page
1 Region VIII Numerical 8
2 Colorado Numerical 10
3 Montana Numerical 12
4 North Dakota Numerical 14
5 South Dakota Numerical 16
6 Utah Numerical 18
7 Wyoming Numerical 20
xv
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SECTION I
GENERATING CAPACITY SUMMARIES
Figures 1, 2 and 3 show the existing, as of December 31, 1976, and
projected, through December 31, 1986, net electrical generating capacity
for the EPA Region VIII and the individual states in the Region. The
sizes of the circles in the figures are proportional to the specified
net generating capacity thus allowing a quick and general visual comparison
of the existing and projected conditions and changes. The circles are
divided into segments representing the net generating capacity produced
by steam; categories 1, 2 and 5 under Section III GENERATING FACILITIES;
and by other methods such as hydro, internal combustion, etc.
Figure 1 shows the total net generating capacity is projected to
approximately double from December 31, 1976 through December 31, 1986.
Generation by steam facilities accounts for 62 percent of the total net
capacity in 1976 and will make up approximately 76 percent of the total
net capacity in 1986. The net steam generating capacity will increase
about 2.4 times over the ten year period while other net generating capacity
will increase only about 1.2 times over the same period.
Figures 2 and 3 show the existing and projected net generating capacities
for the individual EPA Region VIII states of Colorado, Montana, North Dakota,
South Dakota, Utah and Wyoming. Figure 2 shows Colorado had the largest
net generating capacity of the six states as of December 31, 1976. Colorado
was followed in order of decreasing net generating capacity by Montana,
Wyoming, SOuth Dakota, North Dakota and Utah. Figure 3 shows Colorado as also
having the largest projected net generating capacity as of December 31, 1986.
The sequence of decreasing net generating capacity for the states following
Colorado is projected to change to Wyoming, Montana, North Dakota, Utah,
South Dakota. Utah is projected to have the greatest increase, approximately
3.7 times, in net generating capacity while South Dakota shows the least
increase, approximately 1.1 times, over the ten year period. Colorado is
projected to experience the largest absolute net generating capacity increase
of 4352 megawatts.
-------
u ,
I .
REGION VIII
NET GENERATING
CAPACITY
-------
u
-
NET GENERATING CAPACITY
AS OF DECEMBER 31, 1976
-------
•
c
o>
NET GENERATING CAPACITY
AS OF DECEMBER 31, 1986
-------
BLANK PAGE
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II. PROJECTED CAPACITY ADDITIONS
Projected additions in net electrical generating capacity are
shown in both graphical and numeric form for the 10 year period from
December 31, 1976 through December 31, 1986. The incremental values are
divided into two categories of steam and other. The steam additions
include the processes identified in categories 1, 2, and 5 in Section
Ill.i.e Steam Turbine - non nuclear, Steam-HTGR Nuclear and Combined Cycle.
The Other Additions are those identified in categories 3, 4, 6 and 7, i.e.,
internal Combustion, Combustion Turbine, Conventional Hydro and Pumped
Storage,
-------
32.0_
-
-
-
-
REGION VIII
28.0_
Steam
24.0_
20.0 _
16.0 _
12.0-
4.0_
76 77 78 79 80 81 82 83 84 85 86
YEAR
FIGURE 4
7
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Table 1
REGION VIII NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
1977
STEAM
ADDITIONS
(MW's)
725/700
STEAM
CUMULATIVE
(MW's)
10270.8/10186.3
10995.8/10886.3
OTHER
ADDITIONS
(MW's)
472/506
OTHER
CUMULATIVE
(MW's)
6293.5/6268.7
6765.5/6774.7
TOTAL
ADDITIONS
(MW's)
TOTAL
CUMULATIVE
(MW's)
1197/1206
16564.3/16455
17761.3/17661
1978
1184.2/1183.7
12180/12070
180.1/204.1
6945.6/6978.8
1364.3/1387.8
19125.6/19048.8
1979
1726/1726
13906/13796
187.6/235.4
7133.2/7214.2
1913.6/1961.4
21039.2/21010.2
1980
2696/2694
16602/16490
20/26
7153.2/7240.2
2716/2720
23755.2/23730.2
1981
2223.5/2323.5
18825.5/18813.5
-188/-288
6965.2/6952.2
2035.5/2035.5
25790.7/25765.7
1982
380/380
19205.5/19193.5
0/0
6965.2/6952.2
380/380
26170.7/26145.7
1983
1210/1210
20415.5/20403.5
630/414
7595.2/7366.2
1840/1624
28010.7/27769.7
1984
1746/1746
22161.5/22149.5
90/90
7685.2/7456.2
1836/1836
29846.7/29605.7
1985
427/425.4
22588.5/22574.9
-2.4/-2.B
7682.8/7453.6
424.6/422.8
30271.3/30028.5
1986
1750/1750
24338.5/24324.9
0/0
7682.8/7453.6
1750/1750
32021.3/31778.5
-------
9.0-
8.5-
8.0-
7.5-
7.0-
6.5-
o.o-
COLOR
75 76 77 78
79 80
YEAR
Figure 5
9
82 83 84 85 86
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TABLE 2
COLORADO NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
lQ7fi
1 I y / u
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
STEAM
ADDITIONS
(MW's)
^S^^fe^SfeS^fessssss^s^SfS
^^^^^^^^^^^^w^y^^ sSE«J
300/300
0/0
760/760
696/694
196/296
380/380
380/380
680/680
200/200
500/500
STEAM
CUMULATIVE
(MW's)
qi n?/9Qpn
O 1 Ut/ L. jO\J
3402/3280
3402/3280
4162/4040
4858/4734
5054/5030
5434/5410
5814/5790
6494/6470
6694/6670
7194/7170
OTHER
ADDITIONS
(MW's)
«BBgj3»J5| ^^^^^^^^^^^^^^^m^^^^^^^^S
309/323
0/0
141/171
-Z/-2
-188/-288
0/0
0/0
0/0
0/0
0/0
OTHER
CUMULATIVE
(MW's)
107^/1 IQd
1 U/ Of \ \ 3H
1382/1517
1382/1517
1523/1688
1521/1686
1333/1398
1333/1398
1333/1398
1333/1398
1333/1398
1333/1398
TOTAL
ADDITIONS
(MW's)
™i— -~~r— ™
609/623
0/0
901/931
694/692
8/8
380/380
380/380
680/680
200/200
500/500
TOTAL
CUMULATIVE
(MW's)
A 1 7£//l 1 7A
't 1 / O/ H \ 1 "t
••"- ' ~
4784/4797
4784/4797
5685/5728
6379/6420
6387/6428
6767/6808
7147/7188
7827/7868
8027/8068
8527/8568
-------
MONTANA
--
-
:
L
<
-
tf
_
81 82 83 84 85 86
YEAR
Fiaure 6
11
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TABLE 3
MONTANA NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
STEAM
ADDITIONS
(MW's)
0/0
0/0
0/0
700/700
700/700
0/0
0/0
0/0
-6.4/-7.S
0/0
STEAM
CUMULATIVE
(MW's)
960.2/968.2
960.2/968.2
960.2/968.2
960.2/968.2
1660.2/1668.2
2360.2/2368.2
2360.2/2368.2
2360.2/2368.2
2360.2/2368.2
2353.8/2360.9
2353.8/2360.9
OTHER
ADDITIONS
{MW's}
125/125
0/0
21.6/29.4
0/0
0/0
0/0
499/283
90/90
0/0
0/0
OTHER
CUMULATIVE
(MW's)
2588.6/2455.4
2713.6/2580.4
2713.6/2580.4
2735.2/2609.8
2735.2/2609.8
2735.2/2609.8
2735.2/2609.8
3234.2/2892.8
3324.2/2982.8
3324.2/2982.8
3324.2/2982.8
TOTAL
ADDITIONS
{MW's)
125/125
0/0
21.6/29.4
700/700
700/700
0/0
499/283
90/90
-6.4/-7.S
0/0
TOTAL
CUMULATIVE
(MW's)
•3KAQ J3/1A9T (\
ODlO.O/ WCJ. D
3673.8/3548.6
3673.8/3548.6
3695.4/3578
4395.4/4278
5095.4/4978
5095.4/4978
5594.4/5261
5684.2/5351
5678/5343.7
5678/5343.7
-------
8.5-1
8.0-
NORTH DAKOTA
t
::
i
s
-
75 76 77 78 79
80 81
YEAR
Figure 7
13
82 83
85 86
-------
TABLE 4
NORTH DAKOTA NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
STEAM
ADDITIONS
(MW's)
0/0
470/470
466/466
0/0
827.. 5/827. 5
0/0
0/0
416/416
-16.6/-17.3
0/0
1
STEAM
CUMULATIVE
(MW's)
1641.3/1642
1641.3/1642
2111.3/2112
2577.3/2578
2577.3/2578
3404.8/3405.5
3404.8/3405.5
3404.8/3405.5
3820.8/3821.5
3804.2/3804.2
3804.1/3804.2
OTHER
ADDITIONS
(MW's)
ifiliiil! ffiKgHSS^I
0/0
0/0
0/0
0/0
0/0
0/0
0/0
0/0
0/0
0/0
OTHER
CUMULATIVE
(MW's)
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
508.1/516.2
TOTAL
ADDITIONS
(MW's)
!
0/0
470/470
466/466
0/0
827.5/827.5
0/0
0/0
416/416
-16.6/-17.3
0/0
TOTAL
CUMULATIVE
(MW's)
2149.2/2158.2
2149.4/2158.2
2619.4/2628.2
3085.4/3094.2
3085.4/3094.2
3912.9/3921.7
3912.9/3921.7
3912.9/3921.7
4328.9/4337.7
4312.2/4320.4
4312.3/4320.4
-------
c
„
.
2
s
-V
UJ
•_
8.5_
8.0_
7.5.
7.0-
6.5-
6.0.
5.5.
5.0.
4.5.
4.0-
3.5.
3.0.
2.5
2.0
0.0
SOUTH DAKOTA
STEAM
OTHER
75
85 86
-------
TABLE 5
SOUTH DAKOTA NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
STEAM
ADDITIONS
(MW's)
25/0
-15.8/-16.3
0/0
0/0
0/0
0/0
0/0
0/0
0/0
0/0
STEAM
CUMULATIVE
(MW's)
602.3/628.1
627.3/628.1
611.5/611.8
611.5/611.8
611. 5/611 08
611.5/611.8
611.5/611.8
611.5/611.8
611.5/611.8
611.5/611.8
611.5/611.8
OTHER
ADDITIONS
(MW's)
34/54
180.1/204.1
17/27
22/28
0/0
0/0
0/0
0/0
-2.4/-2.6
0/0
OTHER
CUMULATIVE
(MW's)
1CO1 O /ICQ/1 1
1 bol ,o/ 1 oyf . 1
1715.8/1748.1
1895.9/1952,2
1912.9/1979,2
1934,9/2007.2
1934.9/2007.2
1934,9/2007.2
1934.9/2007.2
1934.9/2007.2
1932.5/2004.6
1932.5/2004.6
TOTAL
ADDITIONS
(MW's)
59/54
164.3/187.8
17/27
22/28
0/0
0/0
0/0
0/0
-2.4/-2.G
0/0
TOTAL
CUMULATIVE
(MW's)
2284 1/2322.2
2343.1/2376.2
2507.4/2564
2524.4/2591
2546.4/2619
2546.4/2619
2546.4/2619
2546.4/2619
2546.4/2619
2544/2616.4
2544/2616.4
CTi
-------
UTAH
1/1
c
c
L.
g
UJ
Z
:
§
YEAR
Figure 9
17
-------
TABLE 6
UTAH NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
1976
1977
1978
1979
1980
1981
1982
1982
1984
1985
1986
STEAM
ADDITIONS
(MW's)
400/400
400/400
0/0
400/400
0/0
0/0
0/0
250/250
250/250
1250/1250
STEAM
CUMULATIVE
(MW's)
940/940
1340/1340
1740/1740
1740/1740
2140/2140
2140/2140
2140/2140
2140/2140
2390/2390
2640/2640
3890/3890
OTHER
ADDITIONS
(MW's)
^^^^^S^^f X^^^^^^^K^^^^SSS^^^^^
0/0
0/0
0/0
0/0
0/0
0/0
131/131
0/0
0/0
0/0
OTHER
CUMULATIVE
(MW's)
192/195
192/195
192/195
192/195
192/195
192/195
192/195
323/326
323/326
323/326
323/326
TOTAL
ADDITIONS
(MW's)
ma
400/400
400/400
0/0
400/400
0/0
0/0
131/131
250/250
250/250
1250/1250
TOTAL
CUMULATIVE
(MW's)
1132/1135
1532/1535
1932/1935
1932/1935
2332/2335
2332/2335
2332/2335
2463/2466
2713/2716
2963/2966
4213/4216
oo
-------
.
-
u
1
_
"r
.:
WYOMING
75 76
79 80
YEAR
Figure 10
19
81 82 83 84 85 86
-------
TABLE 7
WYOMING NET GENERATING CAPACITY PROJECTIONS TO DEC. 31, 1986
YEAR
ENDING
DEC. 31
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
STEAM
ADDITIONS
(MW's)
0/0
330/330
500/500
900/900
500/500
0/0
830/830
400/400
0/0
0/0
STEAM
CUMULATIVE
(MW's)
3025/3028
3025/3025
3355/3358
3855/3858
4755/4758
5255/5258
5255/5258
6085/6088
6485/6488
6485/6488
6485/6488
OTHER
ADDITIONS
(MW's)
4/4
0/0
8/8
0/0
0/0
•o/o
0/0
0/0
0/0
0/0
OTHER
CUMULATIVE
(MW's)
250/214
254/218
254/218
262/226
262/226
262/226
262/226
262/226
262/226
262/226
262/226
TOTAL
ADDITIONS
(MW's)
4/4
330/330
508/508
900/900
500/500
0/0
830/830
400/400
0/0
0/0
TOTAL
CUMULATIVE
(MW's)
3275/3242
3279/3246
3609/3576
4117/4084
5017/4984
5517/5484
5517/5484
6347/6314
6747/6714
6747/6714
6747/6714
ro
o
-------
BLANK PAGE
21
-------
111 • GENERATING FACILITIES
This section provides general state-by-state information on specific
electric generating plants in the EPA, Region VIII.
Figures 11 and 12 show individual plant locations by state for general
classifications of "steam electric" and "other electric" respectively. The
"steam electric" classification in figure 11, includes specific categories of
(1) Steam Turbine-Non Nuclear and (5) Combined Cycle. Category (2) Steam-HTGR
Nuclear is shown separately. Figure 12 shows facilities identified as "other
electric" which includes categories (3) Internal Combustion, (4) Combustion
Turbine, (6) Conventional Hydro and (7) Pumped Storage.
The generating facilities are divided into seven categories and further
subdivided into existing and projected subcategories. The seven categories
are: 1 a and b Steam Turbine - Non Nuclear, 2 a & b Steam - HTGR Nuclear;
3 a & b Internal Combustion, 4 a & b Combustion Turbine, 5 a & b Combined
Cycle, 6 a & b Conventional Hydro, and 7 a & b Pumped Storage.
Specific information on existing, as of December 31, 1976, and proposed,
through December 31, 1986, generating facilities begin in part A Colorado.
Information is provided on the operating utility, as keyed to the system
identification codes in Table 8; the plant name, number of units, and location;
the size of the units; the primary and alternate type of fuels, also keyed to
Table 8; the projected on-line date; and the participants in the facility if
appropriate. The information as presented under the heading of "Net Generating
Capacity (MW)" represents the net generating capacity of the successive units
as identified under the heading units. For example under A. Colorado la
Steam Turbine - Non Nuclear, the George Birdsall plant is shown to have three
units. It is then shown under "Net Generating Capacity (MW)", that the first
unit has a net capacity of 17 MW as does the second unit, while the third unit
has a net capacity of 23 MW. In some instances individual unit sizes were
not available and the net generating capacity is shown as total.
22
-------
IQ
ro c
w -s
ID
f" ~ ~ " "" " "1 , &&»
^
\ MONTANA
OOP
f
\
\
\ y_/x" ••
'•r-
\
* 1
SOUTH -•
22 g 023
D26 021
14 ©,2
0,.wO*»15
I e ^^inNuclear
1 n Proposed Nuclear
Ma ior Cities
f\ no J ^
1
KM. COLORADO
• 1] e 8 A 2 I
^J-^ i
• 16 °
••4 — 1 T
»7 /If .18
•20
05 .19
>
3 \
*\
<
1
-------
/ •
I I
c
i'-
!B22
19
NORTH
DAKOTA 2.\
"10
\ 0
MONTANA
BI*jJ.«
«rck
<
'\ «9 ^
X—ATi "~"i
i •
i
IIAIW
WYv.
14
13oao 12
UTAH
.
SOUTH B OB
• DAKOTA ?• Lp 6 ;
3" 8« 9BB*18 I
IB in 22 • 14B
Si**1 l
Rapid City {<)• 12« f«j}.*
i lejpi ')• ;
" zJ" 13 ,5X;
tMIKin Ciiper . -"^ 2J.P- /
'MINU g "^
.11 LEGEND'-
ChejtuM
3 BB4J
! • Existing Other Electric
32 ?(L?" ^610 O Additions/Retirements
29 •• ' 2"R H • Q Proposed Other Electri
25 •«D..«r 4 MaJ°r Cit
q^'ST.i 3 2 COLORADO1*1.
• ^Bl7 °38 .B13
2 « A ^4
4
IBB*18 5. -1
19 *
B B
-------
TABLE 8
System Identification Key
Initials Utility System
BEPC Basin Electric Power Cooperative
BHPL Black Hills Power & Light Company
CCS City of Colorado Springs
COL City of Lamar, Colorado
CPA Cooperative Power Association
CUEA Colorado-Ute Electric Association
I PC |daho Power Company
LDWP City of Los Angeles Dept. of Water & Power
MDU Montana-Dakota Utilities Company
MFC Montana Power Company
MPCI Minnkota Power Cooperative, Inc.
MPLC Minnesota Power & Light Company
NEVP Nevada Power Company
NSPC Northern States Power Company
NWPS Northwestern Public Service Company
OTP Otter Tail Power
PPL Pacific Power & Light Company
PRPA Platte River Power Authority
PSC Public Service of Colorado
SCPC So. Colorado Power Div. Central
Telephone & Utilities Corp.
TRND Trinidad, City of
TSGT Tri-State Generation & Transmission
Association, Inc.
UPA United Power Association
UPLC Utah Power & Light Company
USBR U.S. Bureau of Reclamation (USER)
Upper Missouri Region-Eastern Area
USCE U.S. Corps of Engineers (North Pacific Div.)
USLM U.S.B.R. - Lower Missouri Region
USPN U.S.B.R. - Pacific Northwest Region
USUC U.S.B.R. - Upper Colorado Region
WU&L Walsenburg Utilities and Light Co.
Washington Water Power Company
Initial Fuel Type
C Coal
G Natural Gas
0 Oil (both heavy and middle)
N Nuclear
Q Water (median head)
25
-------
III. GENERATING FACILITIES
A. Colorado
la. Existing Steam Turbine - Non Nuclear
Uti 1 .
CCS
CCS
CCS
CCS
COL
CUBA
CUBA
CUBA
a CUBA
* CUBA
PSC
PSC
PSC
PSC
PSC
PSC
PSC
PSC
SCPC
SCPC
SCPC
SCPC
SCPC
TEND
WU&L
Name, Units, Location
George Birdsall 1-3, Colo.
Martin Drake 1, 3 & 4, Colo
Martin Drake 2A , &2B, Colo.
(1/80 retire)
Martin Drake 5-7, Colo Spgs
Lamar 1-4 , Lamar
Bullock 1-2, Montrose (1/80
Durango 2-4, Durango (1/84
Hayden 1-2, Hayden
Nucla 1-3, Nucla
Oliver 1-2, Somerset
Alamosa 4-6, Alamosa
Arapahoe 1-4, Denver
Cameo 1-2, Grand Junction
Cherokee 1-4, Denver
Comanche 1-2, Pueblo
Valmont 1-4, Boulder
Valmont 5, Boulder
Zuni 1-2, Denver
W.N. Clark 1-2, Canon City
Pueblo 1, Pueblo
Pueblo 2, Pueblo
Pueblo 3, Pueblo
Rocky Ford 1, Rocky Ford
Trinidad, Trinidad
Walsen Plant, Walsenburg
(hit. Geii Cap.
Suiiiiir.ri"
Spgs. 17-17-23
. Spgs. 4-4-10
Spgs.
2-2
52-80-138
2-3-6-28
retire) 6-6
retire) 1-1-4
175-261
12-12-12
1-2
2-5-10
45_45-45-101
24-52
(MU)
Winter Date
Same
Same
3-3
Same
Same
Same
Same
Same
Same
Same
3-5-10
Same
Same
104-107-156-339 Same
350-350
29-29-29-33
175
39-48
19-24
8
8
19
8
7
7
Same
0
Same
25-65
Same
0
Same
Same
Same
Same
Same
Fuel
Prime/Alt.
G/0
G/C
G/0
C/0
G/0
C
C
C
C
0/G
C/G
C/G
C/G
C
G
C
0/G
C/G
G
G
G/0
G/C
G
C
Codes/
Notes
Cl
r*o
LZ
/~\ o
C2
C2
f^ 7
C3
C4
CS
C6
C7
C8
VJ*-*
C9
CIO
Cll
C12
VJ -*- *•"
C13
C14
CIS
C16
C17
C17
C17
CIS
C19
C20
Total Net Generating Capacity
3102
2980
-------
GENERATING FACILITIES
A. Colorado (con't)
Ib. Proposed Steam Turbine - Non Nuclear
Util.
ro
CCS
CCS
CCS
CUBA
CUEA
CUBA
CUEA
CUEA
CUEA
PRPA.
PSC
PSC
PSC
PSC
Name, Units, Location
2a.
2b.
Drake, 2A & B, Colo. Spgs. (Retire
Ray D. Nixon 1, Colo. Spgs.
Ray D. Nixon 2, Colo. Spgs.
Bullock 1-2, Montrose (Retire)
Craig 1, Craig
Craig 2, Craig
Craig 3, Craig
Craig 4, Craig
Durango 2-4, Durango (Retire)
Oliver 1-2, Suraerset (Retire)
Rawhide 1, Wellington
Pawnee 1, Fort Morgan
Southeastern 1, Southeastern Co.
Southeastern 2, Southeastern Co.
Valmont 1-4, Boulder (convert to
Comb. Cyc)
Total Generating Capacity
Existing Steam - HTGR Nuclear
(None commercially operative)
Proposed Steam - HTGR Nuclear
Nbt Leii Cap
iuiiimer
-4(tot]
200
200
-12
380
380
380
380
-5
-3( tot)
200
500
500
500
-72
. (MW)
Winter
-6(tot)
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Fuel
Date Prime/A)
1-80
4-80
11-85
1-84 .
1-79
9-79
4-82
4-83
1-84
1-84
6-84
7-80
4-84
4-86
4-81
G/0
C
C
C
C
C
C
C
C
C
C
C
C
C
G
Code/
t, Notes
cz
C21
C21
C4
C22/29% CUEA,
SRP, 24%
18% prpa
C22/As Above
C22/50% CUEA,
PSC
C/22As Above
CS
C8
C23
C24
C2S/PSC, TSGT
C25/As above
C14
29%
TSGT
50%
, GUI
3524
3522
PSC
Ft. St. Vrain 1, Platteville
330
Same
5-77
C26
Total New Generating Capacity
330
330
-------
III. GENERATING FACILITIES
A. Colorado (Con't)
3a. Existing Internal Combustion
ro
oo
Utll.
COL
CUEA
PSC .
SCPC
SCPC
USUC
USUC
3b.
CUEA
4a.
PSC
PSC
PSC
PSC
TSGT
Name, Units, Location
Lamar Diesel 1-2, Lamar
Pagosa Diesel, Pagosa Spgs (1-80 reti
Cherokee Diesel, Denver
Pueblo Diesel, Pueblo
Rocky Ford Diesel (5), Rocky Ford
Delta 1-5, Delta
Delta 6-7, Delta
Total Net Generating Capacity
Proposed Internal Combustion
Pagosa Diesel, Pagosa Springs (Retire
Total Net Generating Capacity
Existing Combustion Turbine
Alamosa Terminal 1, Alamosa
Fort Lupton 1-2, Fort Lupton
Fruita 1, Fruita
Valmont CT1, Boulder
Republican R Stat 1-3, Wray
Net Gen Cap.
Summer
1-1
re) 1-1
3
10
10(tot }
2( tot)
1-2
32
) -2(tot)
-2
17
45-50
19
47
72-72-72
(MU)
Winter
Same
Same
Same
Same
Same
Same
Same
32
Same
-2
21
Same
23
57
Same
Fuel
Date Prime/Alt.
0
0
0
0
0
G/0
G/0
1-80 0
0/G
0/G
0/G
0/G
0
Code/
Notes
C01
C02
C03
C04
COS
C06
C06
C02
C07
COS
C09
C010
con
Total Net Generating Capacity
394
412
-------
III. GENERATING FACILITIES
A . Colorado (con ' t)
4b. Proposed Combustion Turbine
Utll.
PSC
PSC
PSC
TSGT
TSGT
5a.
5b.
PSC
PSC
6a.
CCS
CCS
CUBA
Name, Units, Location
Alamosa Terminal 2, Alamosa
Valmont CT 2-4, Boulder
Valmont CT 1-4, Boulder
Burlington 1, Burlington
Burlington 2, Burlington
Total New Generating Capacity
Existing Combined Cycle
( None )
Proposed Combined Cycle
Valmont CG 1-4, Boulder
Valmont CS 1-4, Boulder
Total New Generating Capacity
Existing Conventional Hydro
Manitou (2), Manitou Springs
Ruxton (1), Manitou Springs
Ames ( 1 ) , Opher
11,. I i. iii Cap.
Summer
17
141
-188
46
46
62
188
80
268
3
1
4
(MW)
Winter
21
171
-228
51
51
66
228
Same
308
2
o
4
Fuel
Date Prime/Al
6-77 0/G
4-79 0/G
4-81 0/G
7-77 0
8-77 0
4-81 0/G
4-81 0/G
Q
Q
Q
Code/
t. Notes
C07
C010
COlO/converts to cc
bustion cycle 4-81)
CGI 2 / (peaking unit)
C012/ (peaking unit)
C010
C010
C013
C014
C015
-------
co
o
III. GENERATING FACILITIES
A. Colorado (con't)
6a. Existing Conventional Hydro (con't
Util.
CUBA
CUEA
CUEA
CUEA
PRPA
PSC
PSC
PSC
PSC
PSC
USLM
USLM
USLM
USLM
USLM
USLM
USLM
USUC
USUC
Name, Units, Location
Upper Molina (1), Molina
Lower Molina (1), Molina
Ouray ( 1 ) , Ouray
Tacoma (3), Durango
Estes Park (1), Estes Park
Boulder Hydro (2), Boulder
Georgetown Hydro (2), Georgetown
Palisade Hydro (2), Grand Junction
Salida Hydro (2), Salida
Shoshone Hydro (2), Glenwood Spgs .
Big Thompson (1), Loveland
Estes (3) , Estes Park
Flatiron (3), Loveland
Green Mountain (2), Kremmling
Marys Lake (1), Estes Park
Pole Hill (1 ) , Loveland
Williams Fork (1), Parshall
Blue Mesa (2), Gunnison
Morrow Point (1), Gunnison
Ut.-t Geii Cap.
Suii'iu; • r
9
5
1
7
1
5(tot)
2(tot }
2( tot)
2(tot)
15(tot)
5
54(tot )
82(tot)
12(tot)
8
35
3
72(tot)
146
(MU)
Winter Date
9
5
1
7
0
20
l(tot)
3(tot)
Same
13(tot)
0
Same
83(tot )
5(tot)
Same
Same
1
Same
Same
Fuel
Prime/Alt.
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Code/
Notes
C016
C017
C018
C019
C020
C021
C022
C023
C024
C025
C026
C027
C028
C029
C030
C031
C032
C033
C034
Total Net Generating Capacity
6b. Proposed Conventional Hydro
USUC Crystal 1, Gunnison
USUC Morrow Point 2, Gunnison
Total Net Generating Capacity
474
31
69
design
100
471
Same
Same
100
10-77
4-77
Q C035
Q C036Capacity not fir
until Crystal DC
complete
-------
III. GENERATING FACILITIES
A. Colorado (con't)
7a. Existing Pumped Storage
Util.
PSC
Name, Units, Location
Cabin Creek (2), Georgetown
Total Net Generating Capacity
7b. Proposed Pumped Storage
USLM Mount Elbert 1, Leadville
Hut Gt-ii Cap. (MW)
Diunuui- Winter
Date
Fuel
Prime/Alt.
162
162
100
268
268
Same
Q
10-77
Q
Code/
Notes
C037
C038
CO
Total Net Generating Capacity
100
100
-------
00
ro
III. GENERATING FACILITIES
B. Montana
la.
lltil
MDU
MDU
MPC
MPC
MPC
Ib.
MDU
MPC
Existing Steam Turbine - Non Nuclear
Name, Units, Location
Glendive 1-2, Glendive (5-85 retire)
Lewis & Clark 1, Sidney
Bird, Billings
Colstrip 1-2, Colstrip
Corette, Billings
Total Net Generating Capacity
Proposed Steam Turbine - Non nuclear
Glendive 1-2, Glendive (retire)
Colstrip 3, Colstrip
Net Gen
Summer
6.4(tot)
43.8
70
330(each)
180
960.2
-6.4(tot)
700
Cap. (MW)
Winter Date
7.3(tot)
50.9
Same
Same
Same
968.2
-7.3(tot) 5-85
Same 1 0-80
Fuel
Prime/Al
C
C
0 /G
C
C
C
C
Code/
t. Notes
Ml
M2
M3
M4/50% MPC 50% PS
M5
Ml
M4/30% MPC 25% PS
ono/ nrc 1 Co/
MPC Colstrip 4, Colstrip
Total Net Generating Capacity
2a. Existing Steam - HTGR Nuclear
(None)
2b. Proposed Steam - HTGR Nuclear
(None)
700
1393.6
Same
1392.7
8-81
WWPC, 10% Pf
M4/(As above)
-------
HI. GENERATING FACILITIES
B. Montana (con't)
3a. Existing Interna1 Combusti on
Util. Name, Units, Location
Net Gen Cap. (MW)
Summer Winter
Date
Fuel
Prime/Alt.
Code/
Notes
CO
CO
MDU
Miles City 1, Miles City
Total Net Generating Capacity
3b. Proposed Internal Combustion
(None)
4a. Existing Combustion Turbine
PPL Libby Turbine, Libby
Total Net Generating Capacity
4b. Proposed Combustion Turbine
MDU Glendive GT-1, Glendive
Total Net Generating Capacity
5a. Existing Combined Cycle
(none)
5b. Proposed Combined Cycle
(None)
21.6
21.6
28
28
21.6
21.6
29.4
29.4
Same
28
29.4
29.4
5-79
0
0
M01
M02
Ml
-------
co
HI. GENERATING FACILITIES
B. Montana (con't)
6a. Existing Conventional Hydro
Util.
MPC
MPC
MPC
MPC
MPC
MPC
MPC
MPC
MPC
MPC
MPC
MPC
MPC
USER
USBR
USBR
USCE
Name, Units, Location
Black Eagle (3), Missouri R.
Cochrane (2), Missouri R.
Flint Creek (2), Flint Cr.
Hauser (6), Missouri R.
Holter (4), Missouri R.
Kerr (3), Flathead R.
Madison (4), Madison R.
Mi mown (5), Clark Fork R.
Morony (2), Missouri R.
Mystic (2), ^est Rosebud R.
Rainbow (8), Missouri R.
Ryan (6), Missouri R.
Thompson Falls (6), Clark Fork R.
Canyon Ferry (3), Canyon Ferry
Ft. Peck (5), Fort Peck
Yellowtail (4), Hardin
Libby (4), Kootenay R.
Net Gen
Summer
18
50
1
17
49
180
9
3
47
12
35
60
40
60
199
288
483
Cap. (MW)
Winter Date
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
Same
263
452
Fuel
Prime/Alt.
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
Code/
Notes
M03
M04
M05
M06
M07
M08
M09
M010
M011
M012
M013
M014
M015
M016
M017
M018
M019
-------
CO
en
III. GENERATING FACILITIES
B. Montana (con't)
6a. Existing Conventional Hydro (con't)
Util
USPN
WWPC
WWPC
6b.
USCE
USCE
USCE
USCE
WWPC
Name, Units, Location
Hungry Horse (4), S. Fork Flathead
Cabinet Gorge (4), Clark Fork R.
Noxon Rapids (4), Clark Fork R.
Total Net Generating Capacity
Proposed Conventional Hydro
Libby Units (5-8), Kootenay R.
Libby Rereg 1, Kootenay R.
Libby Rereg 2, Kootenay R.
Libby Rereg 3-4, Kootenay R.
Noxon Rapids 5, Clark Fork R.
Net Gen
Summer
328
230
430
2539
484 (tot)
15
30
60(tot)
125
Cap. (MW)
Winter Date
243
Same
Same
2398
268(tot) 11-83
Same 12-83
Same 2-84
Same 4-84
Same 11-77
Fuel
Prime/Alt.
Q
Q
Q
Q
Q
Q
Q
Q
Code/
Notes
M020
M021
M022
M019
M019
M019
M019
M019
Total Net 'Generating Capacity
7a. Existing Pumped Storage
(None)
7b. Proposed Pumped Storage
(None)
714
498
-------
III. GENERATING FACILITIES
C. North Dakota
la. Existing Steam Turbine - Non Nuclear
Utll.
BEPC
BEPC
MDU
MDU
MDU
MDU
MPCI
MPCI
&MPLC
UPA
Name, Units, Location
Leland Olds 1 -2 , Stanton
William J. Meal 1, Voltaire
Dakota 3, Beulah (5-85 retire)
Heskett 1-2, Mandan
Knife River 1-2, Beulah
(5-85 retire)
Will iston 1 , Williston
(5-85 retire)
Franklin P. Wood 1-3, Grand Forks
Milton R. Young 1, Center
Milton R. Young 2, Center (shared
in 1-85)
Stanton 1 , Stanton
Met Gen Cap.
Summer
217-433
36
8.2
28-73
6.0 (tot)
2.4
23 (tot)
240
408
166.7
(MU)
Winter Date
Same
Same
8.6
Same
6.3 (tot)
Same
Same
Same
Same
Same
Fuel
Prime/Alt.
C
C
C
C
C
C
C
C
C
C
Code/
Notes
ND1
ND2
ND3
ND4
ND5
ND6
ND7
ND8
ND8
ND8
Total Net Generating Capacity
Ib. Proposed Steam Turbine - Non Nuclear
1641.3
1642
BEPC
BEPC
CPA
CPA
MDU
MDU
MDU
MPCI
MPLC
OTP
Antelope Valley 1, Beulah
Antelope Valley 2, Beulah
Coal Creek 1, Underwood
Coal Creek 2, Underwood
Dakota 3, Beulah
Knife River 1-2, Beulah
Williston 1, Williston
Milton R. Young 2, Center
Milton R. Young, Center
Coyote 1, Beulah
416
416
470
466
-8.2
-6.0 (tot)
-2.4
120.0
-120.0
411 .5
Same
Same
Same
Same
-8.6
-6.3(tot)
Same
120.0
-120.0
411 .5
9/81
9/84
11/78
11/79
5-85
5-85
5-85
1-85
1-85
5-81
C
C
C
C
C
C
G
C
C
C
ND10
ND10
ND11/255 MW CPA 21!
MW UPA
NDll/As above
ND3/Retire
*ND4 /Retire
iND8/( Share additi<
ND8/{ Share derate
ND'2/35^ OTP, 30%
MPCI, 20% MDU
10% NWPS, 5%
MPLC
? ~\ A
2162.2
-------
III. GENERATING FACILITIES
C. North Dakota (con't)
iii.-t. 1,01, Cap. (MU) Fuel Code/
Util. Name. Units, Location __ '..uu.^-r Winter Date Prime/Alt. Notes
2a. Existing Steam - HTGR Nuclear
(None)
2b. Proposed Steam - HTGR Nuclear
(None)
3a. Existing Interna1 Combustion
0 ND01
0 ND02
0 XD02
MPCI Harwood 1-3, Harwood 4.8(tot) Same 0 NDQ3
CO
MDU
MPCI
MPCI
Ellendale 1-
Grand Forks
Grand Forks
2,
1
2
Ellendale
(1-6) ,
(7-11)
Grand
. Grand
Forks
Forks
2
5
5
.61
.11
.51
Itot)
:tot)
;tot)
2.8(
Same
Same
tot
Total Net Generating Capacity 18 18.2
3b. Proposed Internal Combustion
(None)
4a. Existing Combustion Turbine
MDU Williston 2-3, Williston 10(tot) Same G
OTP Jamestown 1, Jamestown 21.1 29-0 0
Total Net Generating Capacity 31.1 39-0
-------
III. fitrttRATING FACILITIES
C. North Dakota (con't)
Utll.
Name, Units, Location
CO
00
4b. Proposed Combustion Turbine
(None)
5a. Existing Combined Cycle
(None )
5b. Proposed Combined Cycle
(None)
6a. Existing Conventional Hydro
.-I Gen Cap. (MU)
.iii^r Winter
Date
Fuel
Prime/Alt.
Code
Notes
USSR Garrison 1, Garrison
USER Garrison 2-5, Garrison
Total Net Generating Capacity
6b. Proposed Conventional Hydro
(None)
7a. Existing Pumped Storage
(None)
7b. Proposed Pumped Storage
91.0 Same
92.0 (each) Same
Q
Q
ND06
ND06
459
459
-------
Co
III. bLNERTUING >AULiiit:>
D. South Dakota
la. Existing Steam Turbine - Non Nuclear
Util.
BHPL
BHPL
BHPL
MDU
NSPS
NSPS
NWPS
NWPS
OTP
Ib.
NWPS
NWPS
OTP
Name, Units, Location
Ben French, Rapid City
Kirk 1-3, Lead
Kirk 4, Lead
Mobridge 2, Mobridge (9-77 retire)
Lawrence 1-3, Sioux Falls (12-77 retire)
Pathfinder 1, Sioux Falls
Aberdeen 3, Aberdeen (11-78 retire)
Mitchell 3, Mitchell (11-78 retire)
Big Stone 1, Big Stone Lake
Total Net Generating Capacity
Proposed Steam Turbine - Non Nuclear
Aberdeen 3, Aberdeen (Retire)
Mitchell 3, Mitchell (retire)
Big Stone 1, Big Stone Lake
Net Gen Cap.
Summer
22
5.0(each)
16.0
8.5
12-21-21
65.0
7.3
8.5
415
602.3
-7.3
-8.5
25.0
(MW)
Winter
Same
Same
Same
Same
Same
Same
7.8
8.8
440
628.1
-7.8
-8.8
0.0
Fuel Code/
Date Prime/Alt. Notes
C/0
C
C
C
C
0
C
C
C
11-78 C
11-78 C
10-77 C
SD1
SDZ/low pressure
peaking only
SD2
SD3
SD4
SD5
SD6
SD7
SD8/47.5% OTP, 32.5%
NPC 20% MDU
SD6
SD7
SD8/Uprate 47.5% OTF
32.5% NWPC, 20%
MDU
Total Net Generating Capacity
9.2
-16.6
-------
HI- GENERATING FACILITIES
D. South-Dakota (_con't)
2a. Existing Steam-HTGR Nuclear
Util.
2b.
3a.
BHPL
MDU
NSPC
NWPS
NWPS
NWPS
NWPS
NWPS
NWPS
NWPS
NWPS
NWPS
NWPS
(None)
Name, Units, Location
Proposed Steam - HTGR Nuclear
(None)
Existing Internal Combustion
Ben French 1C 1-5, Rapid City
Mobridge 1+2, Mobridge (5-85 retire)
Salem 1-3, Salem
Armour 1-3, Armour
Chamberlain 1-4, Chamberlain
Clark 1, Clark
Faulkton 1 , Faulkton
Highmore 1-2, Highmore
Mobile Unit 1, Huron
Redfield 1-3, Redfield
Webster 1-2, Webster
Woonsocket 1 , Woonsocket
Yankton New 1-3, Yankton
Net Gen Cap.
Summer
2(each)
2.4(tot)
1.6(tot)
4.5(tot)
6.7(tot)
2.7
2.6
1.8(tot)
0.5
3.9(tot)
2.6(tot)
1.0
11.4(tot)
(MW)
Winter Date
Same
2.6(tot)
Same
Same
y.o(tot)
Same
2.7
2.0(tot)
Same
4.0(tot)
2.7(tot)
1.3
Same
Fuel
Prime/Al
P
0
0
0
0
0
0
0
0
0
0
0
0
Code/
t. Notes
SDOl/Cold start erne:
gency peaking
SD02
SD03
SD04
SD05
SD06
SD07
SD08
SD09
SD10
SDH
SD12
SD13
-------
III. GENERATING FACILITIES
D. South Dakota (con't)
3a. Existing Internal Combustion (Con't)
Util.
NWPS
3b.
MDU
-p.
4a.
NWPS
4b.
BEPC
BHPL
BHPL
BHPL
NWPS
NWPS
Name, Units, Location
Yankton Old 1,2,4 & 5, Yankton
Total Net Generating Capacity
Proposed Internal Combustion
Mobridge 1+2, Mobridge (retire)
Total Net Generating Capacity
Existing Combustion Turbine
Huron 1 , Huron
Total Net Generating Capacity
Proposed Combustion Turbine
Spirit Mound 1-2, Gayville
Ben French CT 1-2, Rapid City
Ben French CTr-3, Rapid City
Ben French CT-4, Rapid City
Aberdeen GT-1 , Aberdeen
Mitchell QTV1, Mitchell
Net Gen
Summer
7.3(tot)
59.0
-2.4
-2.4
11.8
11.8
120
17(each)
17
17
22
22
Cap. (MW)
Winter Date
Same
60.3
-2.6 5-85
-2.6
14.8
14.8
Same 5-78
27(each) 5-77
27 5-78
27 5-79
28 5-78
28 5-80
Fuel
Prime/Alt.
0
0
0
0
0
0
0
0
0
Code/
Notes
SD013
SD02
SD014
SD015
SD016
SD016
SD016
SD017
SD017
-------
HI. GENERATING FACILITIES
D. South Dakota (con't)
5a. Existing Combined Cycle
Util
OTP
5a.
PO 5b.
6a.
USBR
USBR
USBR
USBR
USBR
USBR
USBR
Name, Units, Location
Lake Preston 1, Lake Preston
Total Met Generating Capacity
Existing Combined Cycle
(None)
Proposed Combined Cycle
(None)
Existing Conventional Hydro
Big Bend 1-4, Ft. Thompson
Big Bend 5-8, Ft. Thompson
Ft. Randall 1-5, Fort Randall
Ft. Randall 6-8, Fort Randall
Gavins Point 1-3, Gavins Point
Oahe 1-5, Oahe
Oahe 6-7, Oahe
Net Gen Cap
Summer
21.1
231.1
61.0(each)
60.0(each)
43.0(each)
42.0(each)
34.0(each)
98.0(each)
97.0(each)
. (MM)
Winter Date
29.1 5-78
313.0
66.0(each)
65.0(each)
39.0(each)
38.0(each)
Same
Same
Same
Fuel
Prime/Alt.
0
Q
Q
Q
Q
Q
Q
Q
©de/
Notes
SD018
SD019
SD019
SD020
SD020
SD021
SD022
SD022
Total Net Generating Capacity
1611
1619
-------
-
OJ
III. GENERATING FACILITIES
D. South Dakota (continued)
Util Name, Units, Location
6b. Proposed Conventional Hydro
(None)
7a, Existing Pumped Storage
(None)
7b, Proposed Pumped Storage
(None)
E. Utah
in. Existinq Steam Turbine - Non Nuclear
UPLC Carbon 1-2, Castle Gate
UPLC Cal Pac Utl Co., Cedar City
UPLC Gadsby, Salt Lake City
UPLC Gadsby 2-3, Salt Lake City
UPLC Hale 1-2, Orem
UPLC Huntington 2, Huntington
UPLC Jordan 3, Salt Lake City
USUC Provo City 1-4, Provo
Net Gen Cap. (MW) Fuel Code/
Summer Winter Date Prime/Alt. Notes
66-105 Same C Ul
7 same C U2/Non Member - 2
units
66 Same S U3
75-105 Same C U3
18-45 Same C U4
415 Same C US
24 Same 0 U6
14 (tot) Same G/C U7
Total Net Generating Capacity
940
940
-------
III. GENERATING FACILITIES
E. Utah (Con't)
Util.
Ib.
Proposed
Name, Uni
Steam Turbine
ts
-
, Location
Non Nuclear
Net Gen
Summer
Cap.
(MW)
Winter
Date
Fuel
Prime/Al
t.
Code/
Notes
LDWP Intermountain 1, Wayne County
750
NEVP
Warner Valley 1, St. George
250
(None)
2b. Proposed Steam - HTER Nuclear
Same
1-86
Same
6-84
NEVP
UPLC
UPLC
UPLC
UPLC
2a.
Warner Valley 2, St. George
Emery 1 , Emery County
Emery 2, Emery County
Huntington 1, Huntington
Nephi 1 , Nephi
Total Net Generating Capacity
Existing Steam - HTER Nuclear
250
400
400
400
500
2950
Same
Same
Same
Same
Same
2950
6-85
6-78
6-80
6-77
6-86
C
C
C
C
U8/50% LDWP, 15%
Anaheim, 15%
ICPA, 10% River-
side, 5% PASA,
2.5% BURB, 2.5%
Glen.
U9/ 50% LDWP, 25%
NEVP, 25% St.
George
U9/(as above)
U10
U10
U5
Ull
(None)
-------
III. GENERATING FACILITIES
E. Utah (Con't)
3a. Existing Internal Combustion Net Gen Cap> (m} Fuel Code/
Util. Name, Units. Location Summer Winter Date Prime/Alt. Notes
3_a. Existing Internal Combustion
USUC Bountiful City 1-2, Bountiful 8 Same 6/0 U01
USUC Logan City 2-6, Logan City 4 (tot) Same G/0 U02
USUC Murray City 2-6, Murray 7 (tot) Same G/0 U03
Total Net Generating Capacity 19 19
3b. Proposed Internal Combustion
(None)
4a. Existing Combustion Turbine
UPLC Little Mountain, Ogdan 15 Same G U04
Total Net Generating Capacity 15 15
4b. Proposed Combustion Turbine
(None)
5a. Existing Combined Cycle
(None)
5b. Proposed Combined Cycle
(None)
-------
III. GENERATING FACILITIES
E. Utah (con't)
6a. Existing Conventional Hydro
en
Util
UPLC
UPLC
UPLC
UPLC
USUC
USUC
USUC
6b.
USUC
USUC
USUC
7a.
7h
Name, Units, Location
Olmsted (4), Provo R.
Pioneer (2), Ogden R.
Upper Beaver (2), Beaver R.
Weber (1), Weber R.
Boulder (3), Boulder
Flaming Gorge (3), Dutch John
Misc. Hydro (30), Utah
Total Net Generating Capacity
Proposed Conventional Hydro
Dyne, New Thistle
Sixth Water (2), New Thistle
Syar, Near Thistle
Total Net Generating Capacity
Existing Pumped Storage
(None)
Prooosed Puraoed Storaae
Net Gen Cap.
Summer
6(tot)
4(tot)
l(tot)
2
3(tot)
132(tot)
10
158
33
45(each)
8
131
(MW)
Winter
Same
Same
Same
Same
Same
Same
13
161
Same
Same
Same
131
Fuel
Date Prime/Alt.
Q
Q
Q
Q
Q
Q
Q
1-83 Q
1-83 Q
1-83 Q
Code/
Notes
U05
U06
U07
U08
U09
U010
-
.
U011
U012
U013
-------
III. GENERATING FACILITIES
F. Wyoming
la. Existing Steam Turbine - Non Nuclear
Util. Name, Units, Location
Net Gen Cap. (MW)
Summer Winter
Date
Fuel
Prime/Alt.
Code/
Notes
BHPL Neil Simpson 1, 3-5, Wyodak
BHPL Osage 1-3, Osage
PPLC Dave Johnston 1-4, Glenrock
PPLC Jim Bridger 1-3, Rock Springs
PPLC Trona, Green R.
UPLC Naughton 1-3, Kemmerer
Total Net Generating Capacity
^ lb. Proposed Steam Turbine - Non Nuclear
BEPC Laramie R. Station 1, Wheatland
BEPL
Laramie R. Sta. 2, Wheatland
BEPC Laramie R. Sta. 3, Wheatland
BHPL Wyodak 2, Gillette
PPLC Wyodak 1, Gillette
PPLC Jim Bridger 4, Rock Springs
UPLC Naughton 4, Kemmerer
UPLC Naughton 5, Kemmerer
2-1-1-16 2-1-2-18
10(each) Same
100-100-220-330 Same
500(each) Same
15
160-220-330
3025
500
Same
3028
Same
500
500
330
330
500
400
400
Same
Same
Same
Same
Same
Same
Same
4-80
10-81
4-83
5-83
5-78
12-79
4-80
6-84
C
C
C
C
G/0
C
Wl
W2
W3/Mine mouth
W4/ 67% PPLC, 337
IPC
W7/42% BEPC, 24°/
TSGT, 17% MB1«
13% LE, 5%
Heartland Cor
1% Wy. muni
power
W7/As above
C W?AS at>ove
C W8/ 40% BHPL , 60%
open
C W8/90% PPLC, 10%
BHPL
C W4/67% PPLC, 33%
IPC
C . W6
C W6
Total Net Generating Capacity
3460
3460
-------
lit. GENERATING FACULTIES
F. Wyoming (con't)
utn.
Name ,_Unj ts, Locati on
Net Gen Cap. (MU) Fuel
Summer Winter Date Prime/AU.
Code
Notes
2a. Existing Steam ~ HTGR Nuclear
(None)
2b. Proposed Steam - HTGR Nuclgar
(None)
4s. 3a, Existing Internal Combustion
oo
BHPL Osage 1C, Osage
MFC Lake, Yellowstone Park
PSC Cheyenne Diesel 1-5, Cheyenne
PSC Corlett Diesel 1, Cheyenne
lOftot)
3
Same
Same
0 WOl/cold start
emergency pee-
ing
0 W02/fiummer only
0 W03
0 W04
Total Net Generating Capacity
17
3_b . Proposed.Internal Combustion
(None}
Aa. Existing Combustion Turbine
(None}
-------
III. GENERATING FACILITIES
F. Wyoming (con't)
Util.
Name, Units, Location
flel Gen Cap.
(MW)
Winter
Date
Fuel
Prime/Alt.
Code/
Notes
4b. Proposed Combustion Turbine
(None)
5a. Existing Combined Cycle
(None)
5b. Proposed Combined Cycle
(None)
6a. Existing Conventional Hydro
USLM Alcova (2), Alcova
USLM Boysen (2), Thermopolis
USLM Fremont Canyon (2), Alcova
USLM Glendo (2), Glendo
USLM Guernsey (2), Guernsey
USLM Heart Mountain 1, Cody
USLM Kortes (3), Sinclair
USLM Semmoe (3), Sinclair
USLM Shoshone (3), Cody
USUC Fontenelle 1, Kemmerer
40(tot)
17(tot)
55(tot)
24(tot)
7(tot)
6
39(tot)
25(tot)
7(tot)
13
Same
12(tot
50(tot
0
o
Same
Same
37(tot
3(tot)
Same
Q
Q
Q
Q
Q
Q
Q
Q
Q
Q
WO 5
WO 6
WO 7
W08
W09
W010
won
W012
W013
W014
Total Net Generating Capacity
233
200
-------
III. GENERATING FACILITIES
F. Wyoming (con't)
Uti 1.
Maine, Units, Location
in
o
6b. Proposed Conventional Hydro
USLM Seminoe 1-2, Sinclair
USLM Seminoe 3, Sinclair
Total Net Generating Capacity
7a. Existing Pumped Storage
(None)
Jb. Proposed Pumped Storage
(None)
flet Gen Cap.
8(tot)
4
(MM)
Winter
Same
Same
Date
9-79
12-77
Fuel Code/
Prime/Alt. Notes
Q W012/rebuilt to
larger size
Q W012/(as above)
12
12
-------
BLANK PAGE
51
-------
IV. PLANT SPECITIC INFORMATION
This section provides specific information on the individual power
plants identified in Section III, category la, Existing Steam Turbine -
Non Nuclear, of this publication. Not all plants identified in Section III
category la are included herein as data on some plants was not available.
The plant structural and operation information included in this section
were extracted from Federal Power Commission form FPC 67 while the air
emission values were calculated. The air emission values as shown were
calculated from the fuel composition and consumption data presented in
FPC 67 in association with the emission factors presented in EPA publication
AP-42, Part A, "Compilation of Air Pollutant Emission Factors," Second
Edition. When available the estimates of annual air emissions as presented
in FPC 67 were included for comparison.
In some instances plant specific information was extracted from draft
and final Environmental Impact Statements for inclusion in this publication.
Table 9 provides the abbreviations of the boiler manufactures, type of
boiler firing and emission control equipment manufactures as utilized in this
section.
52
-------
TABLE 9
PLANT EQUIPMENT
Boiler(s)
Manufacturers:
B&W - The Babcock & Wilcox Co.
CE - Combustion Engineering, Inc.
ERIG - Erie City Iron Works
FW - Foster Wheeler Corp.
RILY - Riley Stoker Corp.
VOGT - Henry Vogt Machine Co., Inc.
OTHE - Other (Specify in footnote)
Type of Firing:
PCFR - Pulverized Coal
PCOP - Pulverized Coal
PCTA - Pulverized Coal
CYCL - Cyclone
SPRE - Spreader Stoker
OSTO - Other Stoker
FUJI - Fluidized Bed
RFRO - Residual Oil
ROPP - Residual Oil
RTAN - Residual Oil
Front Firing
Opposed Firing
Tangential Firing
Front Firing
Opposed Firing
Tangential Firing
GFRO - Gas: Front Firing
GOPP - Gas: Opposed Firing
GTAN - Gas: Tangential Firing
OTHE - Other (Specify in footnote)
Emission Control Equipment
Manufacturers:
AAFC - American Air Filter Co., Inc.
AMST - American Standard, Inc.
BELC - Belco Pollution Control Corp.
BUEL - Buell Engineering Co., Inc.
DUCO - The Ducon Co., Inc.
FIKL - Fischer-Klosterman, Inc.
FULL - Fuller Co., Draco Products
KIRK - Kirk & Blum Manufacturing Co.
KOPP - Koppers Co., Inc.
PPCI - Precipitair Pollution Control, Inc.
PAOA - Precipitation Associates of America, Inc.
PLVR - Pulverizing Machinery Division
COTT - Research-Cottrell, Inc.
SVRS - Seversky Electronatom Corp.
UOP - UOP Air Correction Division
TORI - The Torit Corp.
WEST - Western Precipitation Division
WHEE - Wheelabrator Corp.
ZURN - Zurn Industries, Inc.
OTHE - Other (Specify in footnote)
53
-------
Flue Gas Mechanical Collectors:
GRAV - Gravitational or baffled chamber
SCTA - Single cyclone-Conventional reverse flow,
tangential inlet
MCTA - Multiple cyclones-Conventional reverse
flow, tangential inlet.
MCAX - Multiple cyclones-Conventional reverse
flow; axial inlet
CYCL - Straight-through-flow cyclones
IMPE - Impeller collector
VENT - Wet collector: Venturi
WETC - Wet Collector: Other (Specify in footnote)
BAGH - Baghouse (Fabric Collector)
OTHE - Other (Specify in footnote)
Electrostatic and Combination Mechanical
Electrical Precipitators
E = Electrostatic Precipitator
C = Combined
-------
POWER PLANT SUMMARY FORM
Code No. Cl
Data Year 1974/1976.
PLANT NAME (Capacity): George Birdsall [52 MW )
OPERATING COMPANY: City of Colorado Springs-Dept of Public Utilities
STATE: Colorado COUNTY: El Paso CITY: Colorado Springs
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): __NA
Source: NA :
Oil:
Gas:
Average:
Range:
% S
NA
NA
% Ash
NA
NA
% Moisture
NA
NA
BTU/lb
NA
NA
Consumption (1000 bbls. per year):
Source: Accent Petroleum
6.0
.7
same
Average:
Range:
Consumption (106 Cubic feet Per Year):
BTU/Cu Ft
Average:
Range:
BTU/Gal
148,160
same
847.8
_9_93_
55
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
cl
1974/1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Towers
Cooling Intake Avg. CFS/source:
0.33/City of Colorado Springs
Cooling Discharge avg. CFR/source: Nil/NP
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas {106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
J.7
1953
17
1957
RFRO
/GFRO
RFRO
/GFRO RFRO/
GFRO
Springfield Springfield Springfield
2212
MA
2.0
246
32.9/0
217/G
JJA
1308
1 .6
125.4
32.9/0
217/G
NA
2602
2.4
44.8/0
296/6
Nft
Mfl
KjJL
*Rates: Coal in Tons/nr,oil in Bbls/nr, gas in 1000 cubic ft./hr.
56
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
cl
Date Year 1974/J-976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm X103):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
_44
2.3
74
54.1
290
273
27.1
19.8
18
44
74
54.1
303
280
27.1
.8
18
44
2.3
74
55.2
315
265
39.2
27.6
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TRY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
IKoil
IKoil
4.8
7 (Tot, reported
0)
86.7(011) 86.7(011) 118(oil)
3.9 2.4 5 .7(Tot.reported
152(gas ) 152(gas ) 207(gas ) ° '
324 320
447(Tot.reported
200
57
-------
POWER PLANT SUMMARY FORM
Code No.
Data Year
C2
1976
PLANT NAME (Capacity): Martin Drake (287 MW )
OPERATING COMPANY: City of Colorado Springs Dept of Public Utilitij
STATE: noiorado___ COUNTY: El Paso CITY: Colorado Springs
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
726
Source: Edna Mine. Empire Energy Corp. and Sunflower Corp. ,
Colorado
Oil:
Gas:
Average:
Range:
_S
.59
.45- .85
% Ash
9.4
7 .2-11^7
Consumption (1000 bbls. per year):
Source: MJ
% Moisture
14 .31
12.Q3-17.1?
Mnne
% S
MA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year):
BTU/Cu Ft
Average: 993
Range: 986-1010
BTU/Gal
MA
NA
1904.9
BTU/lb
10,325
i n m A-
10,65
58
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
c2
1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet cooling towers
Cooling Intake Avg. CFS/source: 2.7/City of Colorado Springs
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
0,24/Fountain Creek
1,2,4
15,15.10
1948..'92.' 49.
1.2.4
RFRQ/GFRO
B&W,B&W
484
50
1962
none
55
RILY
ft 7_8 f,
120.6
none
591.7
23T/199K 31/599R
none
NA
NA
NA
M&ESP
1971
AMST
8Q
1Q68
RAW
225.9
none
440.8
112
1Q74
Pf.FJl
GFRO
72.10
387.8
none
817.4
39C/865g 61C/1341i
MFESP
1Q68
ELSE,
3 97.4
AMST
QQ.6 TSP QQ fi TSP 99 ? TSP
*Rates: Coal in Tons/nr,oil in Bbls/hr, gas in 1000 cubic ft./hr.
59
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
c2
1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rat* (cfm X103):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
1,2
17
1.9
39
1.4
62
3.3
62
3.8
53.15
38.0
312
290
28.9
20.6
14.5/29.4
65.6
48.3
292
272
68.9
50.7
26.4
176.0
134.0
240
226
30.9
23.6
dn.fi
277.0
212.0
243
227
37
?R.4
43 Tl
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
Neg
73,73
Neg
73
104,104 104
18.R
29.4
1001
1350
1349
1809
55.2
1259
2530
1775
3388
60
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
(Continued)
c2
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate {cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
62
4.7
497.0
3RQ.O
250
234
43.8
33.5
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
74.2
189.5
]970
4343
2768
5817
61
-------
POWER PLANT SUMMARY FORM
Code No.
C3
Data Year 1976
PLANT NAME (Capacity): Unit #6 (25 MW)
OPERATING COMPANY: Utilities Board of the City of Lamar
STATE: Colorado COUNTY: Prowers CITY: Lamar 81502
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): None
Source:
Oil:
Gas:
NA
Average:
Range:
% S
NA
NA
* Ash
NA
NA
% Moisture
NA
NA
BTU/lb
NA
NA
Consumption (1000 bbls. per year):
NP
Source:
.043
% S
Average:
Range:
BTU/Gal
145000
NP
NP
Consumption (10 Cubic feet Per Year)
BTU/Cu Ft
Average: 984
Range: 962-996
1338
62
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
C3
1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Once-through flow
Cooling Intake Avg. CFS/source:
20.I/wells
Cooling Discharge avg. CFR/source:
20.I/Arkansas River via Lamar Canal
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
25
1972
GFRO/RFRO
CE
8528
none
.043
1338
66/0
318/G
None
NA
NA
NA
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
63
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
C3
1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
21.2
2.1
101.2
76.4
300
288
43.8
33.1
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Ma*. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
22.1
6.7
87
.5
291
468
64
-------
POWER PLANT SUMMARY FORM
PLANT NAME (Capacity): Hayden (465 MH)
OPERATING COMPANY: Colorado-Ute Electric Association
STATE: Co1orado COUNTY: Routt
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 1028.9
Source: Seneca Mine, Peabody Coal Co.
Code No. C6
Data Year 1976
CITY: Hayden
Oil:
Gas:
Average:
Range:
% S
.5
.44-. 54
% Ash
10.6
9.1-11.9
% Moisture
11.2
10.1-12.5
BTU/lb
10616
10190-1085
Consumption (1000 bbls. per year)
Source: NP
Average:
Range:
BTU/Sal
130,000
NP
Consumption (10 Cubic feet Per Year):
BTU/Cu Ft
Average:
Range:
NA
NA
65
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
C6
1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet cooling towers
Cooling Intake Avg. CFS/source: 6.4/Yampa
Cooling Discharge avg. CFR/source: 0-5 / NP
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
163.2
1965
PCFR DRY
RILY
8071
684.6
3.792
None
91/C
ESP
1974
BUELL
275
1976
PCTA DRY
CE
1780
344.3
11.6
None
126/C
HSESP
1976
WHEE
98.3 (Tsp) 92
*Rates: Coal in Tons/iir, oil in Bbls/nr, gas in 1000 cubic ft./hr.
66
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
C6
Date Year 1974
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm
100% Load
75% Load
Exit Gas Temperature (OF)
100% Load
75% Load
Exit Gas Velocity (FPS):
1007o Load
752 Load
Distance to Next Stack:
Center to Center (m)
75
6.7
782.7
587
285
280
34.3
25.7
76
120
7.3
1121
740
292
255
41.3
27.3
EMISSIONS ESTIMATES:
TSP: Max. (Ifa/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
312
1048
1187
6503
1638
6161
2039
2479
2585
3268
2268
3096
67
-------
POWER PLANT SUMMARY FORM
PUNT NAME (Capacity): Nucla (34.5 HH)
OPERATING COMPANY: Colorado - Ute Electric Association
STATE: Colorado COUNTY: Montrose
Code No.
Data Year
C7
CITY:
Nuc?a
FUEL DATA:
Coal_: Consumption (1000 Tons Per Year):
90.3
Oil:
Gas:
Source: Southern Colorado, Peabody Coal Nucla Mine
Average:
Range:
% S
.74
. 7. W
% Ash
13.44
l?-?-14 .9
% Moisture
6.5
5 f-in,3Q
BTU/1b
11598
indQfi-17 07
Consumption {1000 bbls. per year):
Source: NA
None
Average: NA
Range-' NA
Consumption (TO6 Cubic feet Per Year)
BTU/Cu Ft
Average: NA
Range: NA
BTU/Gal
NA
NA
None
68
-------
POWER PLANT SUMMARY - PAGE 2
C7
Data Year
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: NP
Cooling Intake Avg. CFS/source:
1.2 / San Mi duel River
Cooling Discharge avg. CFR/source: 0.1 / San Miguel River
OPERATING DATA:
Unit No,
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
NP
NP
NP
NP
NP
5477
31.5
none
none
NP
Baghouse
1974
WHEE
NP
NP
NP
NP
NP
5230
30.3
none
none
NP
Baghouse
1974
WHEE
NP
NP
NP
NP
NP
4874
28.5
none
none
NP
Baghouse
1973
WHEE
99.4 (TSP) 99.4 (TSP) 99.4 (TSP)
*Rates: Coal in Tons/nr,oil in Bbls/hr, gas in 1000 cubic ft./hr.
69
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
C7
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
30.3
1.7
78300
58725
350
340
54.9
41.2
18.2
30.3
1.7
78300
58,725
350
340
54.9
41.2
16.1
30.3
1.7
78300
58,725
350
340
54.9
41.2
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
22
442
21
426
19
400
70
-------
POWER PLANT SUMMARY FORM
Code No. CIO
Data Year 1976
PLANT NAME (Capacity):
OPERATING COMPANY: _
STATE: Colorado
Arapahoe (250.5 MM)
Public Service Company of Colorado
COUNTY: Denver
GUY: Denver 80223
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Oil:
Gas:
661.9
Source: 498.9 X 103 t/gr Northern Colorado, 54.4 X 103 t/yr Southern
Colorado, 156 X 103 t/yr Wyoming
% S
Average:
Range:
.54
.44-.67
% Ash
9.06
7.12-10.51
Consumption (1000 bbls. per year):
Source: NA
% Moisture
11.2
Same
None
BTU/lb
10490
9991-10884
Average:
Range:
NA
NA
Consumption (10 Cubic feet Per Year):
BTU/Cu Ft
Average: 993
Range: 985-1000
BTU/Gal
_NA
NA
5371.1
71
-------
POWER PLANT SUMMARY - PAGE 2
CIO
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cool 1 no Mechanism: Wet Coolin9
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/ fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
Tower - Mechanical Draft
3.97 / ground water, Denver
0.60 / NP
1
44
1950
1
NP
B&W
5017
69.6
22 I
None
1776
491/G
3085/C
MCTA&C
1950-7$ 1<
UQP-BU£L
85-99. 2(TSP)
2
44
1951
1
NP
B&W
8388
76.9
156.4
None
1290
491/G
3085/C
MCTA&C
^1-lQfiQ
HOP
85-95. 7 (T
Municipal
3
44
1951
2
NP
B&W
8404
82.4
17R.Q
None
R7R.7
491/G
3085/C
Mf.TA&r.
1951-1966
imp
Sp)Rn QR 7(
4
100
1955
2
NP
B&W
8170
80.4
^07 ^
None
17?Q
1200/G
6025/C
MPAX-f.
WER
1955-1965-
1973
IJOP
TSP)ftn_ft7-
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
72
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
CIO
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIQ3):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (in)
75.8
3.9
500
315
NP
62.8
NP
58.2
75.8
3.9
800
NP
320
NP
86.6
NP
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
281
531
1837
1712
1110
1606
431
1008
4978
2528
1639
4350
73
-------
PLANT NAME (Capacity):
OPERATING COMPANY: _
STATE: Colorado
POWER PLANT SUMMARY FORM
Cameo (75
Code No.
Cll
Data Year 1976
Public Service Company of Colorado
COUNTY:
Mesa
CITY: Palisade
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): _
Source: Routt, Mesa and La Plata Counties, Colorado
Gas:
162.5
Average:
Range: .44-.88
% S
.66
% Ash
10.1
% Moisture
9.1
BTU/lb
10825
8,03-11.47
Same
10541-11585
Oil: Consumption (1000 bbls. per year): '6267
Source: F"el Resources Development Co., Sinclair, Wy.
% S
.31
.28-.32
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average: 1QQ7
Range: 995-1030
BTU/Gal
137,110
136729-137318
2513.751
74
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
Cll
1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: nnr.P through flnw
Cooling Intake Avg. CFS/source: 68.27/Rnvprnment
r.anal
Cooling Discharge avg. CFR/source: 67.70/Government Hiohlina Canal
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
22
1957
PCFR
B&W
7947
.353
.6238
2096.519
12.15/C
9.9/0
400/G
MCAX
1957
UOP
75(TSP)
44
1960
PCFR
B&W
8248
162.1
.0029
417.2
20.9/c
2TTZ70
400/G
MCAX+ESP
1960-1965
West-UOP
97.6 + flue gas conditioning
system (JSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
75
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Cll
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
45
2.3
115
NP
290
NP
43.39
NP
68.8
60
2.7
221.3
NP
280
NP
57.97
NP
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
600
7.6
900
500
766
110
334
2000
2032
660
1600
76
-------
PLANT NAME (Capacity):
OPERATING COMPANY: _
STATE: Colorado
POWER PLANT SUMMARY FORM
Cherokee (801.3 MW)
Code No. C12
Data Year 1974/1976
Public Service Company of Colorado
COUNTY: Adams
CITY: Denver
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
1779
Oil:
Gas:
Source: Energy Mine, Routt County, Colorado; Belle Ayr Mine, Campbell
County, Wyoming
Average:
Range:
% S
.45
.38-.49
% Ash
8.41
6.46-11.42
% Moisture
10.1
10.1
BTU/lb
10645
10341-11,101
Consumption (1000 bbls. per year):
Source: NA
% S
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year):
BTU/Cu Ft
Average:
Range:
BTU/Gal
NA
NA
5881
993
990-1000
77
-------
POWER PLANT SUMMARY - PAGE 2
C12
Data Year 1974/1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet cooling towers
Cooling Intake Avg. CFS/source: 28.4/Denver Municipal Ground water and Ditch water
Cooling Discharge avg. CFR/source: 14.7/NP
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
100
1957
PCTF
B&W
6642
295
N A
452
61.35/C
1240/6
W-
57.65.73
UOP, WEST
UOP
no
1959
PCTF
B&W
7703
337
INA
994
61.35/C
1240/G
MCTA. E
UOP,
COTT
150
1962
PCFR
B&W
8194
367
3R3Q
62.4/C
404/G
MCI
350
1968
PCTA
_CE
6450
778
NA
151.1/C
3480/G
MCTA, E,
WETC
K?^?? 68.68,74
WEST, WEST COTT, KOPP,
UOP HOP
99.3(TSPl 94.2fTSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
78
-------
100% Load
(1) Total reported = 860 TPY
(2) Total reported - 13,100 TPY
(3) Total reported - 14,700 TPY
79
POWER PLANT SUMMARY - PAGE 3 C12
Date Year 1974/1976
STACK PARAMETERS:
Stack No. 1 2 3
Stack Height (m): 91.4 91.4 121.9
(above ground elevation)
Inside Diameter of Flue:
at top (m): 4.9 5.9 6.7
Flue Gas Rate (cfm X103):
100% Load 970 545 1390
75% Load NP NP NP
Exit Gas Temperature (°F):
100% Load 290 272 267
75% Load _NP JJP JP.
Exit Gas Velocity (FPS):
80.41 30.41 60.94
75% Load NP NP NP
Distance to Next Stack: 7o.8 67.8
Center to Center (m)
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr) 773 1211 176
Avg. (TPY)H) 1545 2623 334
S02: Max. (Ib/hr) 2284 1162 2813
Avg. (TPY) (2) 5265 3156 6690
NOX: Max (Ifa/hr) 2952 1405 3763
Avg (TPY) (3^ 5907 4646 7092
-------
POWER PLANT SUMMARY FORM
Code No. CIS
Data Year 1976
PLANT NAME (Capacity): Comanche (765 MW)
OPERATING COMPANY: Public Service Company of Colorado
STATE: Colorado COUNTY: Pueblo CITY: Pueblo
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 2445
Source: 2661 XIO3 tons/yr, Wyoming
Average:
Range:
% S
.41
.37-. 50
% Ash
5.44
5.18-5.78
% Moisture
30.1
Same
BTU/lb
8488
8345-8629
Oil: Consumption (1000 bbls. per year):
Source: Sinclair, Wyoming 23.3 XIO^ bbls.
% S BTU/Gal
Average: -36 138527
Range. -3-.42 136736-140850
Gas: Consumption (106 Cubic feet Per Year): 7.9
BTU/Cu Ft
Average: 981
Range: 970-1002
80
-------
POWER PLANT SUMMARY - PAGE 2
C13
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Tower
Cooling Intake Avg. CFS/source:
13.81 / St. Charles River
Cooling Discharge avg. CFR/source: 2.26 / St. Charles River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
382.5
1973
PCTA
CE_
6454
971
7.5
7.7
214/C
ESP
1973
COTT
382.5
NP
PCTA
CE_
8197
1473
n
.2
214/C
ESP
NP
COTT
99.6 (TSP) 99.6 (TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
81
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
C13
1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
752 Load
Exit Gas Temperature (°F):
10051 Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
151
NP
2522
NP
235
47
36
NP
151
NP
2522
NP
261
235
47
36
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
75.7
180
3252.8
7564
3852
8740
75.7
272
3252.8
11474
3852
13257
82
-------
POWER PLANT SUMMARY FORM
Valmont (281 MM)
Code No. C 14
Data Year
1976
PLANT NAME (Capacity): _
OPERATING COMPANY: Public Service Company of Colorado
STATE: Colorado COUNTY: Boulder CITY: Boulder 80302
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source: Fnprgy MinP, HnloraHn; Rn«;phiifl MinP. Wyoming
Oil:
Gas:
Average: . 84
Range:
.73-.93
% Ash
8.43
7.94-8-91
Consumption (1000 bbls. per year):
Source: NJi
% Moisture
12.4
same
none
% S
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year);
BTU/Cu Ft
Average: jnn?
Range: 996-1 n"] R
BTU/Gal
NA
NA
BTU/Tb
10669
10517-10930
83
-------
POWER PLANT SUMMARY - PAGE 2
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Cooling Pond
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/ fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
3/68/Valmont, Hi
: 1.73/Coolinq
11, 12,
13r 14
1924
1
PCOP
B&W
2690
None
None
1768
3.5/C
None
NA
NA
NA
Data
11 crest
pond
21 r 22
1941
2
PCOP
B&W
2690
NP
NP
NP
13.2/C
None
NA
NA
NA
C14
Year 1976
& Legqet Lakes
23
1937
2
PCOP
B&W
2690
NP
NP
NP
9.8/C
None
NA
NA
NA
24
1931
1
PCOP
B&W
2690
NP
NP
NP
9.8/C
None
NA
NA
NA
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
84
-------
POWER PLANT SUMMARY - PAGE 2 (Continued)
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism:
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100£ feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency; (Pollutant)
Data Year
C14
1976
1969
_5
dry PCTA
CE
8125
300.3
None
94.25
"MUM, E,
WETC & PSC
'64, '64,
'74, '71
COTT, COTT,
PSC. UOP
99.3 TSP/90S02
*Rates: Coal in Tons/nr, oil in Bfals/hr, gas in 1000 cubic ft./hr.
85
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
C14
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XI03):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
117
,365
NP
450
NP
41
101
6.7
.590
NP
450
NP
25 A
NP
1-2
53.3
NP
2-3
50.3
78
5.2
.746
NP
271
NP
54.8
NP
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
a a
61ft
100
1V1
481
1936
3701
86
-------
POWER PLANT SUMMARY FORM
Code No. CIS
Data Year 1974/1976
PLANT NAME (Capacity): Zuni (115.25 MW )
OPERATING COMPANY: Public Service Company of Colorado
STATE: Colorado COUNTY: Denver CITY: Denver
FUEL DATA:
Coal: Consumption (TOGO Tons Per Year):
Source:
Oil
Gas:
NA
NA
% S
NA
NA
on (1000 bbls.
% Ash
NA
NA
per year):
% Moisture
NA
NA
500.514
BTU/lb
NA
NA
Average:
Range:
Source: 217.A Sinclair, Wyo, Ref. Corp. Denv, 84.4, Asamera
Denv. 40.0 Cont. Oil Denvi 84.9, Milt Adams (Reclaimed
% S BTU/Gal 1.4 Denver
.94
147,509
Average:
Range: .73-1.13 147,370-149,096
Consumption (105 Cubic feet Per Year): 7378
BTU/Cu Ft
Average: QQ3
Range: g»R-i nnn
87
-------
POWER PLANT SUMMARY - PAGE 2
C15
Data Year 1974/1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: once through flow UNITS i &•*
-.m-ft-
Cooling Intake Avg. CFS/source: 61.54 / South Platte R. and Denver
Municipal Supply
Cooling Discharge avg. CFR/source: 60.25/So..uth Platt R. _
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
35
1948
1
PDF
B&W
7757
NA
207(1+2^
2999(1+2)
29.3/0
470/G
MCTA
1948
UOP
14
1948
GFRO
B&W
7757
75
(TSP
NA
237/G
none
NA
NA
NA
1954
PDF
B&W
8784
NA
4411
45.Q/0
87Q/G
ESP
1 Qfi?
81.3(TSP
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
88
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
C15
Date Year 1974/1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (ra):
Flue Gas Rate (cfm XI O3):
Load
75% Load
Exit Gas Temperature (OF);
100% Load
75% Load
Exit Gas Velocity (FPS):
1003 Load
75% Load
Distance to Next Stack:
Center to Center (m)
88. 5
3.6
186 .
NP
430
NP
34.63
NP
1 + 2)
34.5
13.6
1.8
71 .8
NP
450
NP
42.33
NP
(2-3}
67 .4
75.;
3.3
?Q7.n
NP
340
NP
52.07-
NP
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: MBLX. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
7.2 (1+2)
22.2 (1+2)
218 (1+2
642 (1 + 2J_
458 (1 + 2J_
15J5_
4.4
13.3 (Tot, rep. 17
342
Q10 fTot . reo.l. 623J
8JL1
2iqR (Tot . rep ,2_,54QJ
89
-------
POWER PLANT SUMMARY FORM
Code No. C16
Data Year 1976
PLANT NAME (Capacity): W. N. Clark (38.5 MW)
OPERATING COMPANY: S.Colorado Power Division Central Telephone & Utilities Corp
STATE: Colorado COUNTY: Fremont CITY: Pueblo
FUEL DATA:
Coal: Consumption (1000 Tons Per Year}:
Source: Southern Colorado
Oil:
Gas:
110.8
Average:
Range:
X S
.7
same
% Ash
24
same
% Moisture
10(est.)
same
BTU/lfa
10149
9885-10332
Consumption (1000 bbls. per year):
Source: NA
None
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year): 1585.2
BTU/Cu Ft
Average: 981
Range: 961-1002
BTU/Gal
NA
NA
90
-------
POWER PLANT SUMMARY - PAGE 2
C16
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Once through cooling - WCT Available
Cooling Intake Avg. CFS/source: 60/Arkansas River
Cooling Discharge avg. CFR/source: 59/Arkansas River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
16.5
1955
1
22.0
1959
SPRE/GFRO SPRE/GFRO
B&W B&W
8429
39.3
None
S7q.fi
1Q/C
8395
71.5
Nonp
21Q/G
MCAX
1955
12/C
264/G
MCAX
195Q
WFST
rniT
(TSP)
fTSP)
*Rates: Coal in Tons/hr, oil in Bfals/hr, gas in 1000 cubic ft./hr.
91
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
C16
1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (ra):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (ra)
45.5
2.3
123
101
425
400
46.3
64.2
45.5
2.3
172
138
325
400
65
52
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr) 269 322
Avg. (TPY) 528 960
S02: Max. (Ib/hr) 266 319
Avg. (TPY) 522 950
NOX: Max (Ib/hr) coal/gas 150/147 180/184
Avg (TPY) coal/gas 215/327 436/256
92
-------
POWER PLANT SUMMARY FORM
Code No. C17
Data Year 1974/1976
PLANT NAME (Capacity): Pueblo (30 HW)
OPERATING COMPANY: Southern Colorado Power Division - Centrat Telephone & Utill-
~~ "" ties Corp.
STATE: Colorado COUNTY: Pueb1° CITY: Pueb1°
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): NA
Source: NA
Average:
Range:
% S
NA
NA
% Ash
NA
NA
% Moisture
NA
NA
BTU/lb
NA
NA
Oil: Consumption (1000 bbls. per year): 3-3
Source: Acorn Petroleum Co., Pueblo
% S BTU/Gal
Average: !£_ 142'000
Range: Same Same
Gas: Consumption (106 Cubic feet Per Year): 2178.2
BTU/Cu Ft
Average: 847
Range: 839-854
93
-------
POWER PLANT SUMMARY - PAGE 2
C17
Data Year 1974/1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: once through
Cooling Intake Avg. CFS/source: 45 / Arkansas River
Cooling Discharge avg. CFR/source: 45 / Arkansas River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
15
49
GFRD
PCFR
OTHE
B&W
8641
NA
3.1
2034
290.4/G
MCTA
49
BUEL
7.5
41
GOPP
OTHE
MORT
970
JNA
.2
143
120/G
GRAV
41
OTHE
1, 2, 3
7.5(each)
22
GOPP
OTHE
flTHF
n
0
75(each)/G
93(TSP) 93(TSP)
GRAV
22
OTHE
NP(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
94
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
C17
Date Year 1974/1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
45.7
2.7
137
103
NP
35.8
26.8
61
82.3
4.6
70
52.6
397
NP
6.6
5.0
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
3.5
neg.
.3
95
-------
POWER PLANT SUMMARY FORM
Code No. CZ2
Data Year EIS
PLANT NAME (Capacity): Craig (821-8 2 units)
OPERATING COMPANY: Colorado Ute Electric Assoc.. Inc.
STATE: Colorado COUNTY: Moffat CITY: Craig
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source: Adjacent Coal Mine Colorado
Oil:
Gas:
5,600 (A Units
Average:
Range:
% S
.36
,2k -.65
% Ash
8.81
5.64-22.61
% Moisture
16.68
15.69-13.73
BTU/lb
9614
8176-102
Consumption (1000 bbls. per year):
Source:
% S
Average:
Range:
Consumption (10° Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
BTU/Gal
96
-------
POWER PLANT SUMMARY - PAGE 2
C22
Data Year EIS
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Towers
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
Yamoa River
380
380
78
7Q
1.4
1.4
215
215
380
1 .4
215
380
1 .4
215
Scrubber Scrubber Scrubber Scrubber
HSESP/ HSESP/ HSESP/ HSESP/
99+/50
99+/50
99+/50
99+/50
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
97
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
C22
Date Year EIS
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3}:
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (ra)
181
5.5
150
181
1SJL
5.5
15CL
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
Max. (Ib/hr)
Avg. (TPY)
Max (Ifa/hr)
S02:
NOX:
Avg (TPY)
2941
9264
2941
9264
2941
9264
2941
Q264
98
-------
POWER PLANT SUMMARY FORM
Code No.
M2
Data Year 1976
PLANT NAME (Capacity): Lewis and Clark (50 MWs)
OPERATING COMPANY: Montana - Dakota Utilities Co.
STATE: Montana COUNTY: Richland
CITY: Sidney
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Oil:
Gas:
313.1
Source: Knife River Coal Mining Co.. Savage Mine
Average:
Range: 0.5-0.6
% s
0.5
% Ash
8.4
% Moisture
37.5
BTU/lb
6471
6.9-9.9
36.6-39.1
Consumption (1000 bbls. per year):
Source: NA .
None
% S
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year):
BTU/Cu Ft
Average:
Range:
BTU/Gal
NA
NA
19.1
982
953-1018
6330-6565
99
-------
POWER PLANT SUMMARY - PAGE 2
M2
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: once-through flow
40.0 / Yellowstone River
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source: 39.9 / Yellowstone River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
50
58
1&2
PCTA
CE
8074
313.1
None
19.1
49/c
MCAX/miL
58/NP
HEST/NP
85.7/98.7 (TSPl
*Rates: Coal in Tons/hr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
100
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
M2
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
61
2.1
243
180
380
350
103
76
MP
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
liqT7 (reported 300)
8B2.3
2348.3 (repoc±fid_32DO)
1044.4
2198.4 (repojci£d_2*800)
101
-------
POWER PLANT SUMMARY FORM
Code No. M3
Data Year 1974
PLANT NAME (Capacity): Frank Bird (69 Mw's)
OPERATING COMPANY: Montana Power Company
STATE: Montana COUNTY: Yellowstone CITY: Billings
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source: NA
Gas:
None
Average:
Range:
% S
NA
% Ash
NA
% Moisture
NA
NA
NA
NA
BTU/lb
NA
NA
Oil: Consumption (1000 bbls. per year): 12*°
Source:
Continental Oil Co., Billings, Mt.
Average:
Range:
% S
1074
Same
BTU/Gal
145,976
145,862- 146,300
Consumption (10 Cubic feet Per Year):
BTU/Cu Ft
Average:
Range:
77
1182
1162-1186
102
-------
POWER PLANT SUMMARY - PAGE 2
M3
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: once-through flow
Cooling Intake Avg. CFS/source: 55 est. / Yellowstone River
Cooling Discharge avg. CFR/source: 55 est. / Yellowstone River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
69
51
1
RFRO/GFRO
FW
388
None
12
77
138/0
755/G
None
NA
NA
NA
*Rates: Coal in Tons/nr,oil in Bbls/hr, gas in 1000 cubic ft./hr.
103
-------
POWER PLANT SUMMARY - PAGE 3
M3
STACK PARAMETERS:
Date Year
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm X103):
100% Load
75% Load
Exit Gas Temperature (OF):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
45.7
3.4
190.6
148.7
357
340
25.22
19.67
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
53.9
2.4 (reported none)
910.4
68.9 (reported 70.)
1137.1
53.4 (reported 41)
104
-------
POWER PLANT SUMMARY FORM
J. E. Corette (172.8 MW's)
Code No. ____
Data Year 1974
PLANT NAME (Capacity):
OPERATING COMPANY: Montana Power Company
STATE: M°ntana COUNTY: Yellowstone
CITY: Billings
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source: Col strip Montana
Oil:
Gas:
526
Average:
Range:
% S
0.85
0.63-1.29
% Ash
8.7
7.6-9.2
% Moisture
23.9
14.7-26.3
BTU/lb
8662
8357-9742
Consumption (1000 bbls. per year)
Source: NA
None
% S
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
8TU/Ga1
NA
NA
425
1182
1162-1186
105
-------
POWER PLANT SUMMARY - PAGE 2
M5
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: nnce-through flow
Cooling Intake Avg. CFS/source: 90 est. / Yellowstone River
Cooling Discharge avg. CFR/source: 90 est. / Yellowstone River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
172.8
68
PCTA
CE
7776
526
NONE
425
91/c
68
COTT
96(TSP)
*Rates: Coal in Tons/hr,oil in Bbls/hr, gas in 1000 cubic ft./hr.
106
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
M5
Date Year 1974
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (op)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
106.7
3.5
565
441
285
265
90.5
70.5
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
569.3
1555.9 (reported 1460)
4460.8
4895.0 (reported 8420)
1638
4882.7 (reported 4,730)
107
-------
POWER PLANT SUMMARY FORM
Leland Olds #1 (216 HW)
Code No.
Data Year
1974
PLANT NAME (Capacity):
OPERATING COMPANY: Basin Electric Power Cooperative, Inc.
STATE: North Dakota COUNTY: Mercer CITY: stanton
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source:
Oil:
Gas:
1,320.621
Consolidated Coal Co. - Stanton, N.D.
Average:
Range:
% S
0.59
same
% Ash
13.16
11.43 - 15.76
% Moisture
37.16
35.87-38.39
BTU/lb
6,572
6406-6796
Consumption (1000 bbls. per year):
Source: NP
2.4 (Boiler Ignition)
% S
NP
NP
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
BTU/Gal
140,000
same
none
NA
NA
108
-------
POWER PLANT SUMMARY - PAGE 2
ND1
Data Year -1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Once-through flow
162.64/Missouri River
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source: 162.59/Missouri River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (lt>6 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
246
1966
_J
PCOP
B&W
7875.2
1.320.7
2.4
None
175/C
MCTA/E
66/74
COTT/COTT
85.5(TSP)/99.5(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
109
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
ND1
Date Year 1974
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (ra):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F);
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
106.7
6.7
897.0
696.5
385
370
67.3
48.3
N/A
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
96.5
308.2(reported 1,500)
3097.5
ll,687.5(reported 15,000)
2450
9244.3(reported 11,500-8,000)
110
-------
POWER PLANT SUMMARY FORM
Code No.
ND 2
Data Year 197A
PLANT NAME (Capacity): Wm . J. Meal (36 MW )
OPERATING COMPANY: Ra.qin Klectrir, Power Cooperative f Inc.
STATE: North Dakota
COUNTY:
McHenry
CITY:
Velva
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
315.1
Source: Consolidation Coal Co., Ward County. M.D.-Velva Mine
Oil:
Gas:
Average:
Range:
-------
POWER PLANT SUMMARY - PAGE 2
ND2
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Towers
Cooling Intake Avg. CFS/source: I/deep wells
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
1002 feed (rate*/fue1)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
o
17.25
52
PCFR
CE
81QQ.A
17.25
52
PCFR
CE
81QQ.4
(combined
none
nnnp
? 5 / r.
MCAX
West
none
nnnp.
? 5 / r
MCAX
West
*Rates: Coal in Tons/hr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
112
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
ND2
1974
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F);
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
42.4
1.8
114.85
N/A
407
N/A
N/A
11 .Q
42.4
1.8
111.30
N/A
405
N/A
63
N/A
1 -Q
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
404.9
combined
1099.8(reported 3460) combined
435 combined
1370.7 (reported 2110) combined
700 _combined
2 ,205.7 (reported 1.Q25) combined
113
-------
POWER PLANT SUMMARY FORM
Code No. ND4
Data Year
I97b
PLANT NAME (Capacity): R.M. Heskett (100 MW)
OPERATING COMPANY: Montana-Dakota Utilities Co.
STATE: North Dakota
COUNTY: Morton
CITY: Mandan
Oil:
Gas:
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 535.2
Source: v^f* River Coal Mining Go's. South Beulah Mine. Mercer and
^mint-IPs.
% S
n.a
Average:
Range: 0.7-0.9
% Ash
7.9
fi.3^S.8
Consumption (1000 bbls. per year):
Source: NA _
% Moisture
33.8-37.1
Nnnp
% S
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
BTU/Gal
NA
NA
NA
BTU/Tb
6770-7185
114
-------
POWER PLANT SUMMARY - PAGE 2
ND4
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Once-Through flow
Cooling Intake Avg. CFS/source: 57.5/Mlssouri River
Cooling Discharge avg. CFR/source: 57.4/Missouri River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
25
1954
SPRE
RTT.Y
7433.3
159.2
None
None
27.9/C
75
COTT
75
1963
2
SPRE
RJT-V
7667.5
376.0
None
None
6D.2/C
MCAX/C
63/75
WEST/COTT
9JLJLC1SP) 88/Q7.QCTSP')
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
115
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
ND4
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
91.4
2.2
165.0
112.6
441
394
fefi.fi
10Q.T
91.4
3.6
433.2
3Q4.7
340
fiV.ft
/./. Q
1f)Q
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
17.2
40.1
7-S3.3
iQin.4
167.4
477.6
111.2
284.2 (reported Total
162S.4
367. 2
1128
(reported Total 8000)
(reported total 4800)
116
-------
POWER PLANT SUMMARY FORM
Code No. ND8
Data Year
1976
PLANT NAME (Capacity): Milton R. Young #1 (256.5 MW)
OPERATING COMPANY: Minnkota Power Cooperative, Inc.
STATE: North Dakota
COUNTY: Oliver
CITY:
Center
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 1580.835
011 :
Gas:
Average:
Range:
Consumpt
Source:
Center Mine,
Center, NoHh Dakota (Bankot Noonan)
*_S
0.52
0.40-0.78
on (1000 bfals
Standard
% Ash % Moisture
8.21 36.62
5.13-12.34 35.26-37.54
. per year): 16.665
Oil Company
BTU/lb
6395.33
6054-6777
% s
0.3
same
Average:
Range:
Consumption (10 Cubic feet Per Year):
.BTU/Cu Ft
Average:
Range:
BTU/Gal
140,000
same
None
NA
NA
117
-------
POWER PLANT SUMMARY - PAGE 2
ND8
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Cooling Pond
Cooling Intake Avg. CFS/source: 263 / cooling pond (Square Butte Cr.)
Cooling Discharge avg. CFR/source: 259.68 / cooling pond
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (1C6 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
256.6
1970
cycl
B&W
8188
1580.835
16.665
None
1820/C
MCAX/E
1970/-
COTT/-
65/99.6(TSP)
*Rates: Coal in Tons/hr, oil In Bbls/hr, gas in 1000 cubic ft./hr.
118
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
ND8
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
91.4
5.8
1,040
990
325
350
60
45
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
134.7
389.7(reported value 395)
4261.8
12,346.9(reported value 16,441)
3100.7
13,473.8(reported value 6345)
119
-------
POWER PLANT SUMMARY FORM
PLANT NAME (Capacity): Stanton (172 MM)
OPERATING COMPANY: United Power Association
STATE: North Dakota COUNTY: Mercer
Code No. ND9
Data Year 1976
CITY: Stanton
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source:
Gas:
741.7
Indianhead Mine
Average:
Range:
% S
0.71
0.60-0.81
% Ash
9.47
8.66-10.51
% Moisture
33.5
31.6-36.0
BTU/lb
6,877
6,668-7,031
Oil: Consumption (1000 bbls. per year): 13.7
Source: Standard Oil Company, Mandan, North Dakota
% S
0.5
same
Average:
Range:
Consumption (10 Cubic feet Per Year):
BTU/Cu Ft
Average:
Range:
BTU/Gal
137,550
same
None
NA
NA
120
-------
POWER PLANT SUMMARY - PAGE 2
ND9
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Once through flow
Cooling Intake Avg. CFS/source: 223/ Missouri River
Cooling Discharge avg. CFR/source: 223 /Missouri River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
172
66
PCFR
_FW
7.271.5
741.7
13.7
_0
123/C
MCTA/E
66/76
COTT/COTT
61.8/98.6(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
121
-------
POWER PLANT SUWARY - PAGE 3
STACK PARAMETERS:
ND9
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Ra-te (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
77.7
4.6
993.0
775.0
338
325
90
68
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
Max (Ifa/hr)
NOX:
Avg (TPY)
126.7
344.2(reported value 5,0fi0j_
2988.9
7921.7(reported value 10.000)
1722
5222.1(reported value 5,000)_
122
-------
UNITED STATES ENVIRONMENTAL PROTECTION A^^iCfY/p ,,
< ~~ i % *"
V°Roifc° REGION viii -*" •' A. Rpqir, K, i,
!8SO UNCOUN STREET
DENVER. COLORADO 8O2O3 ;£T 7 i! ' T *U '"'""
' ' 'i till ||j
SEP I 9
REF: SEA
Region IX Library
TOO California Street
San Francisco, California 94111
Dear
The net electrical generating capacity of the EPA Region VIII is
projected to almost double in the next ten years; increasing from the
December 1976 capacity of 16,500 megawatts to a projected December 1986
capacity of 32,000 megawatts. Coal-fired power plants will represent a
significant portion of that projected increase.
It is important to know where and when this development is projected
to occur. The enclosed publication, "Region 8, 1977 Power Plant Summary"
can provide such information.
Graphical summaries showing projected ten year capacity changes are
provided as are numerical and graphical summaries of annual changes over
the same period. Generalized maps show existing and projected development
locations. General plant characteristics for individual plants are pre-
sented on a state-by-state basis. Also provided when data were available
is plant specific design information and gross emission estimates based
upon that design.
This document is provided to you as part of the EPA Energy/Environment
program series. If you desire additional copies of this report or wish to
know about other publications in this series please contact Ms. Betty Thalhofer
of my staff.
Sincere
Enclosure
Trt H.
Acting D/ysctor
Office ef/Energy
-------
PLANT NAME (Capacity):
OPERATING COMPANY: _
STATE:
POWER PLANT SUMMARY FORM
Coal Creek (1100 MW two units)
Code No. ND11
Data Year "T976
Cooperative Power Association
North Dakota COUNTY: McLean
CITY:
Underwood
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 5.700 (projected)
Oil:
Source:
Bureau of Mines Dist. 21, North Dakota/South Dakota
Average:
Range:
Consumptio
% S
0.63 (proj)
NP
n (1000 bbls.
% Ash
NP
NP
per year):
% Moisture
NP
NP
32 (projected)
BTU/lb
6?497(proj)
NP
Source: Domestic - unspecified
Average:
Range:
% S
NP
BTU/Gal
150,000(projected)
NP
NP
Gas: Consumption (106 Cubic feet Per Year):
None
Average:
Range:
BTU/Cu Ft
NA
NA
123
-------
POWER PLANT SUMMARY - PAGE 2
ND11
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet cooling towers
Cooling Intake Avg. CFS/source: IS/HIssourl River
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Coal (MTPY)
Name Plate Generating
Capacity (MW): NA
Date Unit on Line: NA
Service Stack No.: NA
Type of Firing: NA
Boiler Manufacturer: NA
Operation (hr/yr): NA
Fuel Consumption Actual:
NA
Oil (MBPY) NA
Gas (106 CFPY) NA
100% feed (rate*/fuel) NA
NA
Emission Control Equipment: NA
Year Installed: NA
Manufacturer: NA
Efficiency: (Pollutant) NA
*Rates: Coal in Tons/nr,oil in Bfals/hr, gas in 1000 cubic ft./hr.
124
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
ND11
Date Year
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
NA
NA
NA
NA
NA
NA
125
-------
POWER PLANT SUMMARY FORM
Code No. NP12
Data Year
PLANT NAME (Capacity): Coyote (455.675 MW - 1981)
OPERATING COMPANY: Montana - Dakota Utilities
STATE: North Dakota COUNTY:
Mercer
CITY: Beulah
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 1.470 (projected)
Source: Bureau of Mines, Region 21 (N.D./S.D.)
Oi 1 :
Average:
Range;
% S
0.8(Proj)
NP
% Ash
NP
NP
% Moisture
NP
NP
BTU/lb
7.046(Proj.)
NP
Consumption (1000 bbls. per year): 47.6 distillate (projected)
Source: NF>
Average:
Range:
% S
NA
BTU/Gal
NA
NA
NA
Gas: Consumption (106 Cubic feet Per Year);
None
Average:
Range:
BTU/Cu Ft
NA
NA
326
-------
POWER PLANT SUMMARY - PAGE 2
OD12
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Towers
Cooling Intake Avg. CFS/source: 15.2 /Missouri River
Cooling Discharge avg. CFR/source: 1.3 / Missouri River
OPERATING DATA:
Unit No. 1
Name Plate Generating
Capacity (MW): 455.657
Date Unit on Line: 1981
Service Stack No.: 1
Type of Firing: NP
Boiler Manufacturer: NP
Operation (hr/yr): NP
Fuel Consumption Actual;
Coal (MTPY) M70
Oil (MBPY) 47-6
Gas (106 CFPY) None
100% feed (rate*/fue1) NP
Emission Control Equipment: NP
Year Installed: NP
Manufacturer: NP__
Efficiency: (Pollutant) NP
*Rates: Coal in Tons/nr,oil in Bbls/hr, gas in 1000 cubic ft./tor.
127
-------
POWER PLANT SUMMARY - PAGE 3
ND12
Date Year 1976
STACK PARAMETERS:
Stack No. 1
Exit Gas Temperature (°F)
100% Load
Stack Height (m): NP
(above ground elevation)
Inside Diameter of Flue:
at top (m): NP
Flue Gas Rate (cfin X103}:
100% Load NP
75% Load NP
75% Load NP
Exit Gas Velocity (FPS):
100% Load NP
75% Load NP
Distance to Next Stack: NP
Center to Center (ra)
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
128
-------
POWER PLANT SUMMARY FORM
Data Year
Code No. SD2
PLANT NAME (Capacity): Kirk (32 MH's)
OPERATING COMPANY: Rlark Hi'TU Power and I ioht Company
STATE: Smith Dakota COUNTY: Lawrence CITY: Deadwood
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 182.334
Source: Wvodak Resources Development Corp.. k'yodak. Uy.
% s % Ash % Moisture BTU/lb
Average: 0.43 6.1 29.9 8092
Range: Same 5.1-8.0 29.4-31.1 8010-8309
Oil: Consumption (1000 bbls. per year): None
Source: MA _ __ _ ___
% S BTU/Gal
Average: M/\ - MA
Range: NA _ NA
Gas: Consumption (106 Cubic feet Per Year): _ None
BTU/Cu Ft
Average:
Range:
129
-------
POWER PLANT SUMMARY - PAGE 2
SD2
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Coolinq Mechanism: -vfet. mnlinq tnw^r
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/ fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
0.620/ Homes t^kp Mining Compqny
0.195 / Whitetail Creek
1
5
35
1
SPPF
FW
7473
30.577
None
None
76.1/c
None
NA
NA
NA
2
5
35
2
SPRE
FW
7885
33.298
None
None
76.5/c
Npne
NA
NA
NA
3
5
35
3
SPRE
FW
6952
27.691
None
None
75.4/c
None
NA
NA
NA
4
16.5
56
/I
SPRE
CE
8147
90.768
None
None
90.4/c
JdCAX.
56
WEST _
92/TSP _
*Rates: Coal in Tons/nr,oil in Bfals/hr, gas in 1000 cubic ft./hr.
130
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
SD2
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
2.1
23.5
2.1
?3.fi
2.1
33 ft
2.3
45
NP
570
NP
23.2
NP
45
NP
570
NP
23.2
NP
45
NP
570
NP
23.2
NP
99.6
NP
350
NP
38.3
NP
iJ:i- i2\2 i£i i?:f
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY) (1)
S02: Max. (Ib/hr)
Avg. (TPY) (2)
NOX: Max (Ib/hr)
Avg (TPY) (3)
7914.4
7956
7841.6
(1) Reported Total = 2,780 TPY
(2) Reported Total = 400. TPY
(3) Reported Total = 1500 TPY
752.1
1211.6
1243.5
247.8
1141.5
229.3
1320.3
1250.0
272.0
1147.5
249.7
1097.9
1232.0
226.2
1131
207.7
287.9
1477.1
741.6
1356
680.8
131
-------
POWER PLANT SUMMARY FORM
Code No. SD4
Data Year 1976
PLANT NAME (Capacity): Lawrence (48.0 MW)
OPERATING COMPANY: Northern States Power Company
STATE: South Dakota COUNTY: Minnehaha CITY: Sioux Falls
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): _
Source: 75% Oklahoma. 25% Wyoming
51.567
Oil:
Gas:
Average:
Range: 0.8-3.9
% s
1.9
% Ash
11.8
% Moisture
17.7
BTU/lb
9,712
6.9-18.7
9.0-22.5
Consumption (1000 bbls. per year):
Source: Kpch Refining, Wichita, Kansas
0.726
Average:
Range:
% S
<0.5
Same
BTU/Gal
137.935
Same
Consumption (10 Cubic feet Per Year)
BTU/Ct: Ft
Average:
Range:
162.823
998
988-1,003
8804-11,114
132
-------
POWER PLANT SUMMARY - PAGE 2
SD4
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism:
wet cooling towers
Cooling Intake Avg. CFS/source:
0.67/ Big Sioux River and Wells
Cooling Discharge avg. CFR/source: 0.20/ Big Sioux River
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
12.5
48
12.5
49
SERE/J3QPP _S£EE/fiOPP
RAW R&U
2R37 cnmbinpd
29.941 combined
0.174 combined
47.416 combined
10/c 10/c
193/G
MCTA
48
BUEL
193/G
MCTA
49
BUEL
23
51
_EC£R/fiFRO
FW
21.626
0.552
115.407
17/c
314/G
MCAX
WEST
77.0(TSP) 78.8(TSP) 76.4(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
133
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
SD4
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
50.3
2.9
77.6
62.6
480
452
17.6
14.2
1-2
17.4
50.3
2.9
77.6
62.6
480
452
17.6
14.2
2-1
17.4
50.3
2.9
90.3
68.3
323
309
20.5
15.5
~T^3
17.4
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
Max. (Ib/hr)
Avg. (TPY)
Max (Ib/hr)
S02:
NOX:
Avg (TPY)
537.7
537.7
507.6 combined
1422-1
Uft? .1
10SL_2_combi npd
135.1 135.1
286.4 comb'tned
1276.1
512.1 (reported tot.
TZDJ
781.6 (repnrfpd tot.
1800)
219.8
236.2 (reported tot.
460)
134
-------
POWER PLANT SUMMARY FORM
PLANT NAME (Capacity): Pathfinder (75.0 MW)
OPERATING COMPANY: Northern States Power Company
Code No.
Data Year
SD5
STATE: South Dakota
COUNTY: Minnehaha
CITY: Sioux Falls
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source: NA
Oil:
Gas:
None
% s
Average: NA
Ranqe: NA
% Ash
NA
NA
% Moisture
NA
NA
BTU/lb
NA
NA
Consumption (1000 bbls. per year): 130.079
Source: El Bride; Simba Ltd.. and Skelly Petroleum
% s
1.5
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
BTU/Gal
151.267
•553.973
135
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
SD5
1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet cooling towers
Cooling Intake Avg. CFS/source: o.
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MM):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
Si TJP 1 1 g
Cooling Discharge avg. CFR/source: n.n7/Np
12 & 1"* (combined)-
75(combined)
fiQ
CYCL
RAW
None
130.079
553.971
Nnnc*
NA
*Rates: Coal in Tons/nr,oil in Bbls/hr, gas in 1000 cubic ft./hr.
136
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
SD5
1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
45.7
2.4
245
19]
360
350
82.5
.-i
T3A
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
18.3
2A.6(total Tpporrpd 0) .
ASS..1
643.5(total reported 610)
405.9
480.7 (total reported 390")
137
-------
POWER PLANT SUMMARY FORM
PLANT NAME (Capacity): Big Stone (455.657 MM)
OPERATING COMPANY: Otter Tail Power Company
STATE:
Code No. SD8
Data Year 1976
South Dakota
COUNTY: Grant
CITY'
Stone City
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
011 :
Gas:
2,255.0
Source:
Knife River Coal Company, Gascoyne, N. Dakota
Average:
Range:
% S
0.8
0.7-1.0
% Ash
6.9
5.7-8.1
% Moisture
42.3
41.1-43.2
BTU/lb
6168
5999-6261
Consumption (1000 bbls. per year): 13-6
Source* Champlin Petroleum Company
% S
0.5 est.
same
Average:
Range:
Consumption (106 Cubic feet Per Year);
BTU/Cu Ft
Average: NA
Range: NA
BTU/Gal
140,000
same
None
138
-------
POWER PLANT SUMMARY - PAGE 2
SD8
Data Year 1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Cooling pond
Cooling Intake Avg. CFS/source: 2.2 / pond (Big Stone Lake)
Cooling Discharge avg. CFR/source: °
OPERATING DATA:
Unit No. j_
Name Plate Generating
Capacity (MW): 455.657
Date Unit on Line: NP
Service Stack No.: NP
Type of Firing: NP
Boiler Manufacturer: NP
Operation (hr/yr): 6895
Fuel Consumption Actual:
Coal (MTPY) 2255.0
Oil (MBPY) 13.6
Gas (106 CFPY) None
100% feed (rate*/fuel) NP
NP
Emission Control Equipment: E
Year Installed: J?L
NP
Manufacturer:
Efficiency: (Pollutant) 99(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
139
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
SD8
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
NP
NP
NP
NP
NP
NP
NP
NP
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Ma*. (Ib/hr)
Avg. (TPY)
NOX: Ma* (Ib/'nr)
Avg (TPY)
140
-------
POWER PLANT SUMMARY FORM
Code No. U5
Data Year 19/4
PLANT NAME (Capacity): Huntlngton #2 (411 Mw)
OPERATING COMPANY: Utah Power and Light Company
STATE: Utah COUNTY: Emery CITY: Huntinqton Canyon
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 454
Source: Peabody Coal Co., Deer Creek Mine;Hunt1ngton.Utah
% s % Ash % Moisture BTU/lb
Average: Q.48 11 .40 6.99 11 ,860
Range: n.42-0.54 10.05-13.44 5.49-7.78 11.S58-12.134
011: Consumption (1000 bbls. per year): 17.0 _
Source: Chevron Oil Co..Salt Lake 19.8: Gary Western Oil Co. ,
Lakewood, Colorado 4.3
% S BTU/Gal
Average: 0.35(est) 19.626
Range: Same Same
Gas: Consumption (TO6 Cubic feet Per Year): None
BTU/Cu Ft
Average: NA
Range: NA_
141
-------
POWER PLANT SUMMARY - PAGE 2
U5
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Tower
Cooling Intake Avg. CFS/source: 1 0.7/Huntington River
Cooling Discharge avg. CFR/source: 0/NA
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MM):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
411
1974
PCTA
CE
3399
454
17.0
NA
NP
1974
BUEL
99.5(TSP)
*Rates: Coal in Tons/nr,oil in Bbls/hr, gas in 1000 cubic ft./hr.
142
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Rue:
at top (m):
Flue Gas Rate (cfm XIO3):
WQ% Load
75% Load
Exit Gas Temperature (op);
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
Date Year
U5
1974
#2
182.9
7.3
1,518
1,125
260
NP
56
41
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/Kr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
4.8 est
_L2_JL_est
J_8_£L-est
143
-------
POWER PLANT SUMMARY FORM
Code No. W1
Data Year 1Q74/1Q76
PLANT NAME (Capacity): Neil Simpson (28.8 MW ) _
OPERATING COMPANY: Black Hills Power & Light Co. _
STATE: Wyoming COUNTY: Camnhell CITY: r.i n Pt.t-.P
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Source: WyndaUr Bpgnnr»rg.c, np-.rQir.pmpr.i- — Cnrpnrati nn
Oil:
Gas:
15?
Average:
Range:
% S
.43
% Ash
6.1
% Moisture
29.9
same "5.1-8.0 27.6-31.1
Consumption (1000 bfals. per year): l .6S6
Source: Mobile Oil Corporation
% S
NP
NP
Average:
Range:
Consumption (106 Cubic feet Per Year):
BTU/Cu Ft
Average: NA
Range: NA
BTU/Gal
135000
same
NA
BTU/lb
8092
8DP5-83QQ
144
-------
POWER PLANT SUMMARY - PAGE 2
Wl
Data Year 1Q74/1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Dry Cooling Tower #l&5, Wet #3&4
Cooling Intake Avg. CFS/source: lo/wells
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (M8PY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
0.01/NP
3 1.5
1961 1929
2.0
1948
20.2
1969
1 "U4 3&4 5
PCFR SPRE
B&W B&W
864 6572
2.3 14.0
NA NA
NA NA
5.4 1.6
SPRE
B&W
4044
10.0
HA
NA
3.9
PCFR
FW
7456
126.
1.6
17.7
GRAY
1929
GRAY
1948
MCAX
1969
UOP
pn(TSP)
?n(TSP)
80 (T:
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
145
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Wl
Date Year 1Q74/1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
17.3
1.6
2Q.184
MP
600
NP
20
NP
12
5 3 . o ._
1.7
32.784
MP .
560
NP
20
NP
12
91 R
l.R
?nn
MP
580
NP
27.5
NP
18
T3
? .4
?n n
MP
500
NP
NP
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
734
119
88.2
1 8.8
07 .?..
21
133
444
Pfi.l
1 1 A ,8
75
324
317
ft 3 . 7
ftp
105
(2000
(1,600
1134
(1,400)*
* Total reported values
146
-------
POWER PLANT SUMMARY FORM
PLANT NAME (Capacity): Osage (33 MW)
OPERATING COMPANY: Black Hills Power and Light Company
STATE: Wyoming COUNTY: Weston CITY:
Code No.
Data Year
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
Osage
248.95
Source: Wyodak Resources Development Corporation, Wyddak, Wyoming
Oil:
Gas:
Average:
Range:
% S
0.43
% Ash
6.1
% Moisture
29.9
Same
5.1 - 8.0
27.6 - 31.1
BTU/lb
8092
8010-8309
Consumption (1000 bbls. per year):
Source: NA
None
% S
NA
NA
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
NA
NA
BTU/Gal
NA
NA
None
147
-------
POWER PLANT SUMMARY - PAGE 2
Data Year
W2
1976
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Towers
/ wells
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source: 0.22 / Poison Creek
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
NP
NP
NP
NP
NP
NP
NP
NP
NP
NP
NP
NP
NP
NP
NP
7424
77.25
None
None
NP
MCAX
_6J
COTT
8476
86.46
None
None
NP
MCAX
61
COTT
9KTSP) 9KTSP)
8505
85.24
None
None
NP
Mr. AX
61
COTT
9KTSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
148
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
W2
Date Year 1976
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm X103):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
24.4
2.0
73.871
NP
370
NP
35
NP
14.fi
24.4
2.0
73.871
NP
370
NP
35
NP
14.fi
24.4
2.0
73.871
NP
370
NP
35
NP
1d.fi
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
339
633
695
379
709
778
374
699
767
149
-------
POWER PLANT SUMMARY FORM
Code No. W3
Data Year 1974
PLANT NAME (Capacity): Dave Johnston (750.3 MVI)
OPERATING COMPANY: Pacific Power and Light Company
STATE: Wyoming COUNTY: Converse CITY: Glenrock
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 265.31
Source: Dave Johnston Mine, Converse County, Wyoming
Average:
Range:
% S
0.6
0.5-0.9
% Ash
11.8
9.9-15.9
% Moisture
27.2
25.7-28.4
BTU/lb
7442
7093-7765
Oil: Consumption (1000 bbls. per year): 15.7
Source. American Oil Caompany (21.7 X IP3 bbls) Little America
Refining Co (3.Z X \Q* bbisj
% S BTU/Gal
Average: 0.4 137.193 #2 oil
147,301 #6 oil
Range: sarne N/A
Gas: Consumption (106 Cubic feet Per Year): None
BTU/Cu Ft
Average:
Range: N/A
150
-------
POWER PLANT SUMMARY - PAGE 2
W3
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Units 1-3 once-through w/wet tower during summer #4 wet
Cooling Intake Avg. CFS/source:
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/ fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
cooling tower
292.9/North Platte
River
281.2/North Platte River
1
113.6
59
1
PCFR
B&W
8,182
519.8
0.9#2-0.2#6 1
None
77.5/C
MCAX
59
WEST
86.0{TSP)
2 3
113.6 229.5
61 64
2 3
PCFR PCOP
B&W B&W
7,691 7,754
484.4 727.2
.1#2 2.8#2/3.9#6
None None
77.5/C 163. 0/C
MCAX MCAX
61 64
WEST COTT
86.0(TSP) 82.0(TSP)
4
330.3
72
4
PCTA
CE
6,121
921.7
6.8#2
None
255. 8/C
VENT
72
OTHE**
98.8(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
** Chemical Construction Corporation
151
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
W3
Date Year 1974
Stack No,
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (ra):
Flue Gas Rate (cfra XIO3):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
76.2
3.8
76.2
3.8
76.2
4.9
75.9
7.0
790.0
655.0
290
264
107
89
1-2
41.8
790.0
655.0
290
264
107
89
2-3
45.3
1,565.0
1,160.0
268
256
130
96
3-4
83.2
1,235.1
915.5
130
125
50
37
4-3
83.2
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
2932
7299
2650
5925
1395
4678
2932
6801
2650
5522
1395
4359
7930
13128
5574
8290
2934
6544
138
184
4374
5253
4604
8295
152
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POWER PLANT SUMMARY FORM
Code No.
Data Year
1975
PLANT NAME (Capacity): Jim Bridger (508.6 MW)
OPERATING COMPANY: Pacific Power & Light Company
STATE: Wyoming COUNTY: Sweetwater
CITY: Rock Springs
FUEL DATA:
Coal: Consumption (1000 Tons Per Year):
14A5.9
Source: Rridger Coal Co. Mine Adjacent to the Plant
Oil:
Gas:
Average:
Range:
% S
.6
% Ash
10.5
.6
% Moisture
19.5
18.2-20.5
85.4
BTU/lb
9203
8905-9679
Consumption (1000 bbls. per year):
Source: Pasco (Mountain Fuel Supply) Sinclair, Wyo.
% S
0.2
same
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average: NA
Range: NA
BTU/Gal
137090
same
none
153
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POWER PLANT SUMMARY - PAGE 2
Data Year
W4
1975
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet Cooling Towers
Cooling Intake Avg. CFS/source: 8.24/Green River
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
508.6
1974
508.6
1975
PCTA
Dry
PCTA
Dry
CE
CE
508.6
1976
PCTA
CE
6272
1087.9
27.2
255
ESP
1974
2169
358
58.2
255
ESP
1975
255
ESP
1976
508.6
1Q7R
PCTA
CE
255
ESP/Na
Scrubber
1978
SF/Carborundam SF/Carborundam
99. A (TSP) 99.4(TSP)
994(TSP)
90(502)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
154
-------
POUER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
Date Year
W4
1975
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):-
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F):
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
7.3
1899
1483-
240
215
67
52
83
7.3
1899
1483.
240
215
67
52
81
1.5 L
7.3
1899
1483'.
240
215
67
52
7.3
189 9-. *
1483:.- *
240*
215*
67*
52*
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TRY)
S02: Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
301.7
583
6783
12402
45QQ_
9791
301.7
191
6783
4081
45QQ
3222
301.7
45QO
301.7
678
45QD
* These parameters may change due to scrubber operation
Units 1-3 to have scrubbers in future to meet 0.3 Ib 502/10° BTU
emission limit in Wyoming
155
-------
POWER PLANT SUMMARY FORM
Code No. W6
Data Year
PLANT NAME (Capacity): Naughton (707. 2 MM)
OPERATING COMPANY: _ Utah Power and Light
Wyoming
STATE:
COUNTY:
Lincoln
CITY- Kemmerer
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 2,185.198
Source: Kemmerer Coal Company, Kemmerer. Wyoming
Oil:
Gas:
Average:
Range:
of C
10 J
Q.5fest.)
same
% Ash
4.5fest.l
same
% Moisture
23.0fest.)
same
BTU/lb
9626
9529-9702
Consumption (1000 bbls. per year): 9.491 (ignition only)
Source: Phillips Petroleum Co., Kemmerer, Wyoming
% S
0.6(est.)
same
Average:
Range:
Consumption (106 Cubic feet Per Year)
BTU/Cu Ft
Average:
Range:
BTU/Gal
140,000
same
none
NA
NA
156
-------
POWER PLANT SUMMARY - PAGE 2
W6
Data Year 1974
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Wet cooling towers - mechanical draft
Cooling Intake Avg. CFS/source: 18.0/Hams Fork River
Cooling Discharge avg. CFR/source: 0 (blowdown to ash sluice tank)
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
152.6
58
PCTA wet
CE
7399
495.340
1.970
None
62/C
MCTA/E
63/74
200
63
CE
7602
692.151
3.626
None
113/C
MCTA
68
COTT?Log COTT COTT
306
71
PCTA wet PCTA wet
CE
7024
997.707
3.896
None
175/C
_7J
BUEL
80.0 /97.0(TSP) 80.0(TSP) 96(TSP)
*Rates: Coal in Tons/nr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
157
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
W6
Date Year 1974
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (°F)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
61.0
4.3
563.0
424.0
166
153
61
49
29.3
68.6
4.9
701.0
500.0
145
117
61
42
29.3
76.2
6.7
1162.0
834.0
149
120
82
59
40.1
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02: . Max. (Ib/hr)
Avg. (TPY)
NOX: Max (Ib/hr)
Avg (TPY)
108
435
1178
4705
1860
7430
1322
4056
2147
6575
3390
10382
409
1169
3325
9478
5250
14965
158
-------
POWER PLANT SUMMARY FORM
Code No. W7
Data Year J975
PLANT NAME (Capacity): Laramie River (1500 MW - 1983)
Basin Electric Power Coop
OPERATING COMPANY:
STATE: Wyoming COUNTY: P1atte CITY: Wheat! and
FUEL DATA:
Coal: Consumption (1000 Tons Per Year): 7600 (projected to 1985)
Source: NP
% Ash % Moisture BTU/lb
Average: .7 4 (est.) NP 8125
Range: NP _NP JJP NP_
Oil: Consumption (1000 bbls. per year): 27 (projected 1985)
Source: MP
%_S_ BTU/Gal
Average: NP _JL.
NP NP
Range:
Gas: Consumption (106 Cubic feet Per Year): None
BTU/Cu Ft
NA
Average:
NA
Range: NM
159
-------
POWER PLANT SUMMARY - PAGE 2
WZ
Data Year 1975
WATER SYSTEM REQUIREMENTS:
Cooling Mechanism: Met cooling Towers
Cooling Intake Avg. CFS/source: 26 / Grey Rocks Dam - on Laramie River
Cooling Discharge avg. CFR/source:
OPERATING DATA:
Unit No.
Name Plate Generating
Capacity (MW):
Date Unit on Line:
Service Stack No.:
Type of Firing:
Boiler Manufacturer:
Operation (hr/yr):
Fuel Consumption Actual:
Coal (MTPY)
Oil (MBPY)
Gas (106 CFPY)
100% feed (rate*/fuel)
Emission Control Equipment:
Year Installed:
Manufacturer:
Efficiency: (Pollutant)
None
500
500
1910
NP
NP
NP
1981
NP
NP
NP
none
288/C
none
288/C
ESP/S02 ESP/S02
scrub. scrub.
1980 1981
NP
NP
500
1983
NP
NP
NP
none
288
ESP/S02
scrub.
1983
NP
99.34/87.b 99.39/87.8 99.39/87.8
(TSP/S02) DT-90
or yO
or 90
*Rates: Coal in Tons/hr, oil in Bbls/hr, gas in 1000 cubic ft./hr.
160
-------
POWER PLANT SUMMARY - PAGE 3
STACK PARAMETERS:
W7
Date Year
Stack No.
Stack Height (m):
(above ground elevation)
Inside Diameter of Flue:
at top (m):
Flue Gas Rate (cfm XIO3):
100% Load
75% Load
Exit Gas Temperature (OF)
100% Load
75% Load
Exit Gas Velocity (FPS):
100% Load
75% Load
Distance to Next Stack:
Center to Center (m)
181
NP
NP
NP
NP
NP
NP
152
181
NP
NP
NP
NP
NP
NP
NA
EMISSIONS ESTIMATES:
TSP: Max. (Ib/hr)
Avg. (TPY)
S02:
HO,
Max. (Ifa/hr)
Avg. (TPY)
Max (Ib/hr)
Avg (TPY)
130
2000
900
4000
130
130
2000
900
4000
2000
900
4000
161
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
REPORT NO.
EPA 908/4-78-002
3. RECIPIENT'S ACCESSION NO.
4. TITLE AND SUBTITLE
Region 8
1977 Power Plant Summary
5. REPORT DATE
release July 1978
7 AUTHOR(S)
G.E. Parker
(<. hnult.fr
9 I'l W UHMINl. OHC;/\NI/A I ION NAMI ANUAIJUIU!
U.S. EPA, Region VIII
Office of Energy
1860 Lincoln St.
Denver, Colo. 80295
6. PERFORMING ORGANIZATION CODE
8. PERFORMING OHGANI.'Al ION Ml I'Oli 1 NO
IU I'M! XiMAM I I I Ml Ml NO
11. CONTRACT/GRANT NO.
12. SPONSORING AGENCY NAME AND ADDRESS
as above
13. TYPE OF REPORT AND PERIOD COVERED
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
16. ABSTRACT
This document provides summary information on power generation facilities located
in the U.S. EPA, Region VIII states of Colorado, Montana, North Dakota, South Dakota,
Utah and Wyoming. When available, plant specific information is presented.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
Power
Power Plants
Power Generation
b.IDENTIFIERS/OPEN ENDED TERMS
Fossil-Fuel Power Plants
c. COSATI F-'ield/Group
18. DISTRIBUTION STATEMENT
Distribution Unlimited
19. SECURITY CLASS (ThisReport}
unclassified
21. NO. OF PAGES
176
20. SECURITY CLASS (Thispage)
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22. PRICE
EPA Form 2220-1 (Rev. 4-77) PREVIOUS EDITION is OBSOLETE
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SI,Tc^
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