RBLC:
SO2
Control
Cost
Information
September
20,
2004
SO2
Control
Cost
Information
from
RACT/
BACT/
LAER
Clearinghouse
Unit
RBLC
ID
Permit
Number
Permit
Appl.
Date
Permit
Issue
Date
Start­
up
(
Actual
or
Estimated
Future
Year)
Date
Added
to
RBLC
Date
Modified
in
RBLC
C.
E.

$/
ton*
$
Year
$
Ann.
Cost
Control**
Emission
Limit
in
lb/
mmBtu
Boiler
Size
(
in
RBLC)
Boiler
Size
in
MW***

1
Bull
Mountain
(
boilers
1
and
2)
MT­
0022
3182­
00
7/
22/
02
7/
21/
03
7/
21/
07
2/
9/
04
6/
29/
04
$
393
NA
$
22,658,000
Dry
FGD
0.12
Two
at
390
MW
each
780
2
Chambers
Cogen
Lt.
Partnership
NJ­
0014
01­
89­

3086
NA
12/
26/
90
est.

7/
01/
1994
6/
3/
93
12/
18/
01
$
459
NA
NA
Spray
dryer
adsorber
scrubber
0.22
Two
at
1389
mmBtu/
hr
each
280
3
Black
Hills
Corporation
WY­
0057
CT­
3030
7/
30/
01
9/
25/
02
NA
4/
29/
03
9/
23/
03
$
470
NA
NA
Sodium
based
wet
scrubber
0.1
5145.7
mmBtu/
h
(
500
MW)
500
4
Two
Elk
Genration
Partners,
Limited
Partnership
WY­
0039
CT­
1352
10/
31/
96
2/
27/
98
est.

11/
1/
1999
3/
10/
99
3/
11/
04
$
479
1997
$
9,167,000
Lime
spray
dry
scrubber
0.2
250
MW
250
5
Whelan
Energy
Center,
unit
2
(
Hastings
Utilities)
NE­
0018
58048
10/
23/
02
3/
30/
04
est.

12/
1/
2009
3/
31/
04
8/
10/
04
$
500
NA
$
5,200,000
Spray
dryer
absorber
0.12
2210
mmBtu/
h
220
6
Keystone
Cogeneration
NJ­
0015
01­
89­

3983
10/
1/
89
9/
6/
91
est.

12/
1/
1994
6/
3/
93
3/
11/
04
$
519
NA
NA
Spray
dryer
adsorber
scrubber
0.16
2116
mmBtu/
h
210
7
Holcomb
Unit
#
2
(
Sand
Sage
Power,

LLC)
KS­
0026
0550087­

1C­
3855
6/
6/
01
10/
8/
02
NA
12/
9/
03
1/
16/
04
$
581
NA
$
33,885,000
Dry
FGD
0.12
660
MW
660
8
Hawthorn
Station,

Unit
5
(
Kansas
City
Power
and
Light)
MO­
0050
888
5/
1/
99
8/
17/
99
5/
16/
01
10/
23/
00
6/
12/
01
$
586
1998
$
16,526,730
Dry
FGD
0.12
384
T/
H
(
550
MW)
550
9
Ware
Cogen
(
boiler,
unit
2)
MA­
0033
1­
B­
90­

062
6/
8/
90
12/
2/
91
NA
11/
30/
01
12/
12/
02
$
602
NA
NA
Dry
scrubber
and
baghouse
0.24
30
MW
30
10
MidAmerica
Energy
Company
(
CBEC
4
boiler
&
3
carbon
silos)
IA­
0067
Project
02­

528
9/
25/
02
6/
17/
03
NA
7/
22/
03
3/
10/
04
$
605
2002
$
22,983,556
Lime
spray
dryer
FGD
0.1
7675
mmBtu/
h
(
790
MW)
790
11
Santee
Cooper
South
Carolina
Public
Service
Authority,
Unit
1
SC­
0028
0420­

0030
7/
9/
90
11/
28/
90
est.

12/
1/
1995
7/
14/
93
12/
18/
01
$
739
NA
$
7,613,000
Promoted
Limestone
FGD
0.34
500
MW
500
12
Black
Hills
Power
and
Light
Company­

Neil
Simpson
U
WY­
0046
CT­
1028
8/
6/
92
4/
14/
93
est.
8/
1/
1995
4/
13/
99
3/
11/
04
$
1,012
1992
$
9,410,000
Circulating
dry
scrubber
0.2
80
MW
80
13
WYGEN,
Inc.
­

WYGEN
Unit
One
WY­
0048
CT­
1236
2/
15/
95
9/
6/
96
est.
1/
1/
1998
4/
13/
99
3/
11/
04
$
1,149
1998
$
10,550,000
Circulating
dry
scrubber
0.2
80
MW
80
14
Encoal
Corporation­

Encoal
North
Rochelle
Facility
WY­
0047
CT­
1324
11/
21/
96
10/
10/
97
est.
1/
1/
1999
4/
13/
99
3/
11/
04
$
1,648
1996
$
9,200,000
Lime
spray
dryer
0.2
3960
mmBtu/
h
400
15
Deseret
Generation
and
Transmission
Co.
UT­
0060
DAQE­

523­
95
NA
6/
14/
95
NA
10/
17/
01
3/
3/
04
$
2,132
NA
$
32,010,600
BACT
scrubber
with
added
alkalai
0.15
4381
mmBtu/
h
440
(
cont.)

SO2
Control
Cost
Information
from
RACT/
BACT/
LAER
Clearinghouse
(
Annual
Costs,
but
no
Cost
Effectiveness
Data)
(
cont.)
RBLC:
SO2
Control
Cost
Information
September
20,
2004
16
Mon
Valley
Energy
Limited
Partnership
Poland
Mines
PA­
0133
30­
306­

001
10/
15/
92
8/
8/
95
3/
1/
98
3/
5/
96
12/
18/
01
NA
1994
$
2,900,000
Spray
dry
absorption
0.25
966
mmBtu/
hr
(
80
MW
cogen)
80
17
Dakota
Gasification
Company
(
Mercer
County)
ND­
0011
No
permit
number
6/
30/
89
3/
23/
93
NA
7/
13/
93
12/
2/
02
NA
1997
$
8,760,000
Ammonium
sulfate
scrubber
3230
lb/
hr
Three
at
763
mmBtu/
hr
each
230
Highest
value
$
2,132
$
33,885,000
0.24
790
Lowest
value
$
393
$
2,900,000
0.1
30
Median
value
$
586
$
9,410,000
0.18
280
Average
value
$
792
$
14,682,000
0.18
358
*
Shading
in
this
column
indicates
C.
E.
values
provided
by
state
contacts.

**
Coal­
fired
plants
without
add­
on
controls
(
often
using
low­
sulfur
fuel
and
/
or
fluidized
bed
systems)
are
not
listed
in
this
spread
sheet.

***
A
conversion
factor
of
10
mmBtu/
hr
=
1MW
was
used,
with
the
result
rounded
to
the
nearest
10
MW
to
enable
approximate
size
comparisons
among
boilers.
RBLC:
No
SO2
Control
Cost
Information
September
20,
2004
Coal­
fired
Units
with
Add­
on
SO2
Controls
but
no
RBLC
Cost
Information
Unit
RBLC
ID
Permit
Issue
Date
Start­
up
(
Actual
or
Estimated
Future
Year)
C.
E.

$/
ton*
$
Year
$
Ann.
Cost
Control**
Emission
Limit
in
lb/
mmBtu
Boiler
Size
Boiler
Size
in
MW***

18
AES
Puerto
Rico,
Cogeneration
Plant
PR­
0007
2001
NA
NA
NA
NA
CFB
with
Limestone
Injection
and
Circulating
Dry
Scrubber
0.02
450
MW
450
19
Birchwood
VA­
0213
1993
NA
NA
NA
NA
Lime
Spray
Dryer
FGD
220
lb/
hr
2200
mmBtu/
hr
220
20
Chambers
Cogen
Lt.
Partnership
NJ­
0038
1990
NA
NA
NA
NA
Spray
dryer
adsorber
scrubber
0.22
Two
at
1389
mmBtu/
hr
each
250
21
Cogentrix
of
Richmond
VA­
0178
1991
NA
NA
NA
NA
Dry
Scrubber
0.13
Eight
at
38MW
each
300
22
Cogentrix
of
Rocky
Mount
NC­
0050
1989
1990
NA
NA
NA
Dry
Lime
FGD
0.31
375
mmBtu/
hr
40
23
Deseret
Generation
and
Transmission
Company
UT­
0053
1998
NA
NA
NA
NA
Wet
Srcubber
0.1
500
MW
500
24
East
Kentucky
Power
Cooperative,
Inc.
KY­
0086
2002
NA
NA
NA
NA
CFB
w/
Limestone
Injection
and
a
Dry
lime
Scrubber
0.2
270
MW
270
25
Edison
Mission
Energy
PA­
0162
1999
2002
NA
NA
NA
Wet
Limestone
Scrubber
0.4
6600
mmBtu/
hr
660
26
Hadson
Power
13
VA­
0176
1990
NA
NA
NA
NA
Lime
Spray
Dryer/
CEM
0.16
70
MW
70
27
Indelk
Energy
Service
of
Otsego
MI­
0228
1993
1995
NA
NA
NA
Dry
Scrubber
0.32
778
mmBtu/
hr
80
28
JEA
Northside
FL­
0178
1999
NA
NA
NA
NA
CFB
Scrubber
0.2
2764
mmBtu/
hr
280
29
JEA
St
john's
River
Power
Units
1&
2
FL­
0177
1996
1998
NA
NA
NA
FGD
Scrubber
0.68
100,000
Lbs/
hr
NA
30
Kentucky
Mountain
Power,
LLC
KY­
0079
2001
NA
NA
NA
NA
Naturaly
Integrated
Desulfurization
System
and
SNCR
0.13
2550
mmBtu/
hr
260
31
Maple
Street
Power
House,
Unit
2
MA­
0012
1991
NA
NA
NA
NA
Spray
Dryer
Absorber
(
Dry
Scrubber)
0.12
30
MW
30
32
Mecklenburg
Cogen
VA­
0171
1990
(
EST)
1990
NA
NA
NA
Spray
Dryer
0.17
834.5
mmBtu/
hr
80
33
Mon
Valley
Energy,
Limited
Partnership,

Waynesburg
Plant
PA­
0107
1995
1998
NA
NA
NA
Limestone
Spray
Dry/
Absorption
0.3
80
MW
80
34
Old
Dominion
Electric
Cooperative,

Boiler
2
VA­
0181
1991
1995
NA
NA
NA
FGD
0.1
4085
mmBtu/
hr
410
(
cont.)
RBLC:
No
SO2
Control
Cost
Information
September
20,
2004
Coal­
fired
Units
with
Add­
on
SO2
Controls
but
no
RBLC
Cost
Information
(
cont.)

Unit
RBLC
ID
Permit
Issue
Date
Start­
up
(
Actual
or
Estimated
Future
Year)
C.
E.

$/
ton*
$
Year
$
Ann.
Cost
Control**
Emission
Limit
in
lb/
mmBtu
Boiler
Size
Boiler
Size
in
MW***

35
Orlando
Utility
Commission,
Stanton,

Unit
2
FL­
0044
1991
1997
NA
NA
NA
Wet
Lime
FGD
0.25
4286
mmBtu/
hr
430
36
Plum
Point
Energy
AR­
0074
2003
NA
NA
NA
NA
Dry
FGD
0.16
800
MW
800
37
Reliant
Limestone
Electric
Generating
Station
TX­
0342
2001
1986
NA
NA
NA
Wet
Limestone
FGD
0.82
2
@
7563
mmBtu/
hr
1570
38
Roanoke
Valley
Project
NC­
0057
1992
1995
NA
NA
NA
Dry
Lime
FGD
0.19
517
mmBtu/
hr
50
39
Roanoke
Valley
Project
II
NC­
0054
1991
1994
NA
NA
NA
Dry
Lime
FGD
0.21
1700
mmBtu/
hr
170
40
Rocky
Mountain
Power
Hardin
Generator
Project
MT­
0027
2002
2005
NA
NA
NA
Wet
Ventury
Scrubber,

selective
Catalytic
Reduction
0.14
110
MW
110
41
South
Carolina
Electric
and
Gas
Company,
COPE
Pwr
Stn
Unit
1
SC­
0027
1992
1996
NA
NA
NA
Spray
Dryer
Absorber
0.25
385
MW
385
42
Teco
Big
Bend
Station,
Tampa
Electric
Company,
Unit
4
FL­
0003
2001
1981
NA
NA
NA
Limestone
Scrubber,
Coal
washing
0.82
4330
mmBtu/
hr
430
43
Tennessee
Eastman
Company,
Boiler
30
TN­
0119
1992
1993
NA
NA
NA
Spray
Dryer
Absorber
0.41
780
mmBtu/
hr
80
44
Thoroughbred
Generating
Station
KY­
0084
2002
NA
NA
NA
NA
Wet
FGD,
WESP
0.17
2
@
7446
mmBtu/
hr
1500
45
W.
A.
Parish
Electric
Generating
Station,

Unit
8
TX­
0275
6/
24/
05
NA
NA
NA
NA
FGD
0.3
660
MW
660
