AEPA
United States
Environmental Protection
Agency
Industrial Environmental Research EPA-600/7-80-029d
Laboratory October 1980
Research Triangle Park NC 27711
EPA Utility FGD Survey:
July - September 1980
Interagency
Energy/Environment
R&D Program Report
-------
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Protection Agency, have been grouped into nine series. These nine broad cate-
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The nine series are:
1. Environmental Health Effects Research
2. Environmental Protection Technology
3. Ecological Research
4. Environmental Monitoring
5. Socioeconomic Environmental Studies
6. Scientific and Technical Assessment Reports (STAR)
7. Interagency Energy-Environment Research and Development
8. "Special" Reports
9. Miscellaneous Reports
This report has been assigned to the INTERAGENCY ENERGY-ENVIRONMENT
RESEARCH AND DEVELOPMENT series. Reports in this series result from the
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Development Program. These studies relate to EPA's mission to protect the public
health and welfare from adverse effects of pollutants associated with energy sys-
tems. The goal of the Program is to assure the rapid development of domestic
energy supplies in an environmentally-compatible manner by providing the nec-
essary environmental data and control technology. Investigations include analy-
ses of the transport of energy-related pollutants and their health and ecological
effects, assessments of, and development of, control technologies for energy
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EPA REVIEW NOTICE
This report has been reviewed by the participating Federal Agencies, and approved
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This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
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EPA-600/7-80-029d
October 1980
EPA Utility FGD Survey:
July - September 1980
by
M. Smith, M. Melia, N. Gregory, and M. Groeber
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-02-3173
Task No. 17
Program Element No. C2KN1E
EPA Project Officer: Norman Kaplan
Industrial Environmental Research Laboratory
Office of Environmental Engineering and Technology
Research Triangle Park, NC 27711
Prepared for
U.o. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
and
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Enforcement
Washington, DC 20460
-------
NOTICE
This report (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio under EPA Contract No. 68-01-4147, Task No. 143) is
provided as an information transfer document. Data in this
report are supplied voluntarily by utility representatives; flue
gas desulfurization (FGD) system designers and suppliers; regula-
tory personnel; and others. Neither EPA nor the designated con-
tractor warrants the accuracy or completeness of information
contained in this report.
Initial distribution of the report (generally one copy per
company) is limited to organizations and individuals indicating
a specific interest in the field of FGD technology. Additional
copies of this report and succeeding issues can be purchased from
National Technical Information Service, Springfield, Virginia
22151.
This report presents a summary of the FGD system design and
performance data stored in the Flue Gas Desulfurization Infor-
mation System (FGDIS), a computerized data base from which it is
generated. Plans are currently being formulated to allow access
to the FGDIS by private users (subject to the limitations ex-
pressed in the first paragraph above). It is anticipated that
this will be implemented during the fourth quarter, 1980, at which
time the service will be available to the public through the
National Technical Information Service for a usage charge (non-
profit) . Users will have the capability to access the additional
design and performance data stored within the data base that can-
not be conveniently printed in this report. In addition, users
will be able to tabulate the data in a manner consistent with
their specific information needs, as well as perform statistical
analyses of the numerical data (e.g., average liquid to gas ratio
for limestone FGD systems). When this service becomes available,
the current recipients of this report will be notified; and
classes will be provided on the use of the system.
ii
-------
USE OF THIS REPORT
This report is the third of three supplementary issues to
the October - December 1979 report. Supplementary issues are
cumulative, so that it is necessary to retain only the latest
issue and the October - December 1979 report (EPA-600/7-80-029a).
It should be noted that along with the design and performance
data for operational FGD systems contained in Section 3, this
report also contains a number of tables presenting tabulations of
some of the key data. The Executive Summary contains the number
and capacity of FGD systems as of the end of September 1980,
future projections (December 1990) of controlled and uncontrolled
generating capacity, and unit by unit summaries of status changes
and performance during the period.
Recent additions to this report include a section containing
design and performance data for U.S. operational particle scrub-
bers (Section 14) and a section containing design and performance
data for coal-fired operational Japanese FGD systems (Section
15). The regulatory classifications were recently modified to
accomodate the revised New Source Performance Standards (6/79)
and, as a result, the categories will differ slightly from those
of previous issues.
Appended to this report is a section containing reported and
adjusted cost data for U.S. FGD systems in which operational sys-
tems are stressed (Appendix A). Also included in the appendices
are definitions, a table of unit notation, and FGD process flow
diagrams.
iii
-------
ABSTRACT
This report is the third of three supplements updating the
October - December 1979 report (EPA-600/7-80-029a) and should be
used in conjunction with it. The report, which is generated by a
computerized data base system, presents a survey of operational
and planned domestic utility flue gas desulfurization (FGD) sys-
tems, operational domestic particle scrubbers, and Japanese
coal-fired utility boiler FGD installations. It summarizes in-
formation contributed by the utility industry, process suppliers,
regulatory agencies, and consulting engineering firms. It pre-
sents data on system design, fuel characteristics, operating
history and actual performance. Unit by unit dependability
parameters are included and problems and solutions associated
with the boilers, scrubbers, and FGD systems are discussed.
The domestic FGD systems are tabulated alphabetically by
development status (operational, under construction, or in the
planning stages), utility company, system supplier, process,
waste disposal practice, and regulatory class. FGD system
economic data, definitions, and a glossary of terms are appended
to the report. Current data for domestic FGD systems show 76
systems in operation, 39 systems under construction, and 93
planned systems. Projected 1990 FGD controlled capacity in the
U.S. is 99,252 MW.
IV
-------
CONTENTS
Notice
Use of This Report
Abstract
Tables
Executive Summary and Highlights
Section 1
Section 2
Section 3
Summary List of FGD Systems 1
Status of FGD Systems 8
Design and Performance Data for Operational
FGD Systems 44
Alabama Electric
Tombigbee 2 44
Tombigbee 3 46
Arizona Electric Power
Apache 2 48
Apache 3 50
Arizona Public Service
Cholla 1 52
Cholla 2 54
Four Corners 1 56
Four Corners 2 58
Four Corners 3 60
Basin Electric Power Coop
Laramie River 1 62
Big Rivers Electric
Green 1 65
Central Illinois Light
Duck Creek 1 67
Central Illinois Public Service
Newton 1 70
Colorado Ute Electric Assn.
Craig 2 73
Columbus & Southern Ohio Electric
Conesville 5 75
Conesville 6 77
Commonwealth Edison
Powerton 51 79
-------
CONTENTS (continued)
Cooperative Power Association
Coal Creek 1 82
Coal Creek 2 84
Delmarva Power & Light
Delaware City 1 87
Delaware City 2 90
Delaware City 3 93
Duquesne Light
Elrama 1-4 96
Phillips 1-6 99
Indianapolis Power & Light
Petersburg 3 102
Kansas City Power & Light
Hawthorn 3 104
Hawthorn 4 106
LaCygne 1 108
Kansas Power & Light
Jeffrey 1 111
Jeffrey 2 113
Lawrence 4 115
Lawrence 5 117
Kentucky Utilities
Green River 1-3 119
Louisville Gas & Electric
Cane Run 4 121
Cane Run 5 123
Cane Run 6 125
Mill Creek 3 127
Paddy's Run 6 129
Minnesota Power & Light
Clay Boswell 4 131
Minnkota Power Cooperative
Milton R. Young 2 135
Monongahela Power
Pleasants 1 138
Montana Power
Colstrip 1 140
Colstrip 2 142
Nevada Power
Reid Gardner 1 144
Reid Gardner 2 147
Reid Gardner 3 150
Northern Indiana Public Service
Dean H. Mitchell 11 152
VI
-------
Section 4
Section 5
CONTENTS (continued)
Page
Northern States Power
Sherburne 1 154
Sherburne 2 156
Pacific Power & Light
Jim Bridger 4 158
Pennsylvania Power
Bruce Mansfield 1 160
Bruce Mansfield 2 152
Bruce Mansfield 3 154
Public Service Company of New Mexico
San Juan 1 166
San Juan 2 169
San Juan 3 172
Salt River Project
Coronado 1 174
Coronado 2 176
South Carolina Public Service Authority
Winyah 2 179
Winyah 3 181
South Mississippi Electric
R.D. Morrow, SR. 1 183
R.D. Morrow, SR. 2 185
Southern Illinois Power Coop
Marion 4 187
Southern Indiana Gas & Electric
A.B. Brown 1 190
Springfield City Utilities
Southwest 1 193
St. Joe Zinc
G.F. Weaton 1 196
Tennessee Valley Authority
Shawnee 10A 198
Shawnee 10B 199
Widows Creek 8 201
Texas Utilities
Martin Lake 1 204
Martin Lake 2 206
Martin Lake 3 208
Monticello 3 210
Utah Power & Light
Hunter 1 212
Hunter 2 214
Huntington 1 216
Summary of FGD Systems by Company 218
Summary of FGD Systems by System Supplier 220
VI1
-------
CONTENTS (continued)
Section 6
Section 7
Section 8
Section 9
Section 10
Section 11
Section 12
Section 13
Section 14
Page
Summary of FGD Systems by Process 222
Summary of Operating FGD Systems by
Process and Unit 223
Summary of End-Product Disposal
Practices for Operational FGD Systems 225
Summary of FGD Systems in Operation 227
Summary of FGD Systems Under Construction 231
Summary of Contract Awarded FGD Systems 233
Summary of Planned FGD Systems 235
Total FGD Units and Capacity (MW)
Installed by Year 238
Design and Performance Data for
Operational Particle Scrubbers 239
Commonwealth Edison
Will County 1 239
Detroit Edison
St. Clair 6 242
Minnesota Power and Light
Syl Laskin 1 244
Syl Laskin 2 246
Clay Boswell 3 248
Montana-Dakota Utilities
Lewis & Clark 1 250
Pacific Power and Light
Dave Johnston 4 252
Potomac Electric Power
Dickerson 1 253
Dickerson 2 255
Dickerson 3 257
Public Service of Colorado
Arapahoe 4 259
Cherokee 1 261
Cherokee 4 263
Valmont 5 265
Southwestern Public Service
Harrington 1 267
viii
-------
CONTENTS (continued)
Section 15
Appendix A
Appendix B
Appendix C
Appendix D
Design and Performance Data for
Operational Foreign FGD Systems
Chugoku Electric
Shimonoseki 1
Electric Power Development Company
Isogo 1
Isogo 2
Takasago 1
Takasago 2
Takehara 1
FGD System Cost Data: Operational
and Nonoperational Systems
Introduction
Approach
Description of Cost Elements
Definition of Cost Elements
Costs for Operational FGD Systems
Costs for Nonoperational FGD Systems
Definitions
Table of Unit Notation
FGD Process Flow Diagrams
Page
269
269
271
273
275
277
279
A-l
A-2
A-4
A-7
A-l 5
A-20
A-25
B-l
C-l
D-l
IX
-------
TABLES
N£I. Page
I Number and Total Capacity of FGD Systems xi
II Summary of Changes, July - September 1980 xiii
III Performance of Operational Units,
July - September 1980 xiv
FIGURE
No. Page
1 Computerized Data Base Structure Diagram xii
-------
EXECUTIVE SUMMARY
This report is prepared quarterly (every three months) by
PEDCo Environmental, Inc., under contract to the Industrial
Environmental Research Laboratory/Research Triangle Park and the
Division of Stationary Source Enforcement of the U.S. Environ-
mental Protection Agency. It is generated by a computerized data
base system, the structure of which is illustrated in Figure 1.
Table I summarizes the status of FGD systems in the United
States at the end of September 1980. Table II lists the units
that have changed status during the third quarter 1980, and Table
III shows the performance of operating units during this period.
TABLE I. NUMBER AND TOTAL CAPACITY OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD
systems
TOTAL
No. of
units
76
39
30
7
18
38
208
Total
controlled
capacity, MW*
28,564
17,155
15,014
5,590
9,709
23,220
99,252
Equivalent
scrubbed ,
capacity, MW
25,832
16,442
14,164
5,590
9,709
23,000
94,737
* Total Controlled Capacity (TCC) is the summation of the gross unit
capacities (MW) brought into compliance with FGD systems regardless
of the percent of the flue gas scrubbed by the FGD system(s).
Equivalent Scrubbed Capacity (ESC) is the summation of the effective
scrubbed flue gas in equivalent MW based on the percent of flue gas
scrubbed by the FGD system(s).
XI
-------
X
p-
Figure 1. Computerized data base structure diagram.
-------
TABLE II. SUMMARY OF CHANGES
JULY - SEPTEMBER 19.80
FGD status report
June 30, 1980
Atlantic City Electric
Cumberland Station )
Basin Electric Power
Coop.
Laramie River 1
Big Rivers Electric
D. B. Wilson 1
D. B. Wilson 2
Central Power S Light
Coleto Creek 2
Cooperative Power
Association
Coal Creek 2
Oeseret Gen. ft Trans.
Coop.
Moon Lake 1
Grand Haven Brd. of
Light S Power
J. B. Sims 3
Louisville Gas S
Electric
Trinble County 1
Trimble County 2
Northern States Power
Sherburne 3
Pacific Power S Light
Jim Bridger 1
Jim Bridger 2
Jim Bridger 3
Public Service of Indiana
Gibson 5
Salt River Project
Coronado 2
Southwestern Electric
Power
Dolet Hills 1
Oolet Hills 2
United Power Association
Stanton 1A
Utah Power 1 Light
NJuqhton
west Texas Utilities
Ok 1 dun Ion 1
TOTAL
Operational
No.
73
+1
+1
+ 1
76
MW« „
21,655°
570
327
280
25,832
Under
construction
No.
38
-1
-1
+1
+1
-1
+ 1
»1
39
MW"
16,524
570
327
65
650
280
50
330
16,442
Contract
awa
No.
29
+1
*1
+1
-1
-1
+1
-1
30
ded
MW*
13,919
440
440
410
65
650
720
50
14,164
Letter
Of 1
No.
7
7
tent
MWa
5,590
5,590
Requesting/
eval bids
No.
15
-1
+1
+ 1
-1
tl
«1
+1
18
MWa
8,179b
410
575
575
860
560
550
550
9,709
Considering
FGD
No.
38
+1
-1
-1
*1
-1
-1
+1
+1
38
MWa
22,540
330
440
440
720
575
575
720
720
23,000
T tal
No.
200
*1
*1
-1
+1
»1
+1
+ 1
+1
»1
+1
208
MW*
90,407b
330
720
860
550
550
550
720
720
330
720
94.737
' Equivalent scrubbed capacity.
b This value was modified slightly due to a MM correction.
Xlll
-------
TABLE III.
PERFORMANCE OF OPERATIONAL UNITS
JULY - SEPTEMBER 1980
Plant
loobigbec 2
Toacigbee 3
Apache 2
Apache 3
Cholla 1
Cholla 2
Four Corntn 1
Four Corner* 2
Four Corners 3
larwie River 1
Green 1
Duck Creek 1
Newton 1
Craig 2
Conesvllle 5
Conesvllle 6
Powerton 51
Coal Creek 1
Coal Creek 2
Delaware City 1
Delaware City 2
Delaware City 3
Elrama 1-4
Phillips 1-6
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne 1
Jeffrey 1
Jeffrey 2
Lawrence 4
Lawrence 5
Green River 1-3
Cane Run 4
Cane Run S
Cane Run 6
FGO tyttea
capacity.
179
179
96
98
119
264
175
175
229
570
242
416
617
400
411
411
450
327
327
60
60
60
510
408
532
90
90
820
540
490
125
420
64
188
200
299
Flue gas
S scrubbed
70
70
50
50
100
100
100
100
100
100
100
100
100
87
100
100
100
60
60
100
100
100
100
100
100
100
100
100
75
70
100
100
100
100
100
100
FGD capacity
on line
during
perjog.
179
179
98
98
119
570
416
617
400
411
411
450
327
327
60
60
60
510
408
90
90
820
540
490
125
420
64
188
200
299
No information
for this
period, l*r
264
175
175
229
242
532
Shutdown
throughout
period.
July 1980
Dependability V1
AVL
SO
100
100
29
100
88
2
67
90
98
100
97
50
95
100
95
97
100
100
97
100
100
86
79
100
OPR
49
68
86
30
99
76
2
55
76
87
100
97
SO
95
83
87
100
100
96
100
100
97
100
93
88
100
RtL
50
100
86
90
100
85
2
56
78
88
100
97
SO
95
98
95
96
100
100
97
100
93
88
100
UTL
27
59
85
29
99
66
2
47
47
85
87
91
50
95
83
87
65
78
77
69
95
97
96
0
86
79
83
August 1980
Dependability Jr1'
AVL
50
100
97
99
91
54
67
97
94
100
93
73
100
92
97
100
100
100
100
100
100
50
99
OPR
42
94
66
67
85
16
65
86
76
100
93
73
98
83
96
100
100
100
100
99
58
95
RtL
42
100
95
95
91
40
67
88
78
100
93
73
100
92
97
100
100
100
100
99
58
95
UTL
9
74
63
54
82
36
59
50
55
100
93
73
98
83
70
85
100
100
82
0
77
50
85
September 1980
Dependability X '
AVL
46
99
78
88
94
98
100
100
97
100
100
100
87
99
OPR
44
68
77
79
90
91
100
100
100
100
100
98
99
REL
46
83
79
80
90
97
100
100
100
100
100
98
100
UTL
44
33
77
79
89
54
100
100
40
96
0
36
87
87
X
H-
(continued)
-------
TABLE III (continued)
Plant
Mill Creek 3
Paddy's Run 6
Clay Boswell 4
Hilton R. Young Z
Pleasants 1
Col strip 1
Colstrlp 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 11
Sherburne 1
Sherburne 2
Jin Brldger 4
Bruce Mansfield 1
Bruce Mansfield 2
Bruce Mansfield 3
San Juan 1
San Juan 2
San Juan 3
Coronado 1
Coronado 2
Winy ah 2
Winy ah 3
R.D. Morrow, Sr. 1
R.D. Morrow, Sr. 2
Marlon 4
A.B. Brown 1
Southwest 1
C.F. weaton 1
Shawnee 10A
Shawnee 108
Widows Creek 8
Martin Lake 1
Martin Lake 2
Martin Lake 3
FGO syste*
capacity.
442
72
475
185
618
360
360
125
125
125
115
740
740
550
917
917
917
361
350
534
280
280
140
280
124
124
173
265
194
60
10
10
550
595
595
595
Flue gas
X scrubbed
100
100
85
42
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
80
80
50
100
62
62
100
100
100,.
N/A*
N/*H
N/Ad
100
75
75
75
FGD capacity
on line
during
>#*•
442
72
475
185
618
125
125
125
115
740
740
550
361
350
534
280
280
140
280
124
124
173
265
194
60
10
10
550
595
595
595
No information
for this
period, MW^
360
360
917
917
917
Shutdown
throughout
period,
July 1980
Dependability JT'"
AVI
92
100
65
87
88
96
100
100
100
98
100
98
76
100
13
94
80
97
92
69
99
OPR
91
96
65
95
77
96
0
100
100
83
92
77
90
100
13
99
81
100
93
54
73
REL
91
100
66
87
86
96
100
100
98
90
100
13
99
81
100
93
72
98
JTL
84
0
95
52
84
75
95
0
100
83
80
92
68
75
100
13
94
80
96
88
54
66
August 1980
Dependability JT'
AVL
59
100
99
86
97
100
84
100
100
96
100
98
83
98
18
100
99
100
95
73
OPR1
82
76
99
86
96
100
66
100
100
85
95
85
82
98
20
100
100
100
95
61
REl
82
100
99
84
96
100
66
100
100
95
93
100
83
98
20
100
100
100
95
62
UTL
59
0
66
98
72
80
100
31
99
100
78
95
81
80
88
18
100
99
91
95
61
September 1980
Dependability if'*
AVL
57
100
100
91
100
97
69
100
100
61
99
97
97
0
99
99
100
100
68
OPR
60
80
98
91
97
S3
100
100
93
56
59
100
0
100
100
100
100
43
RE Li
60
100
100
91
97
53
100
100
95
63
59
100
0
100
100
100
100
44
UTL
57
0
80
90
90
0
97
45
100
100
51
52
46
87
0
92
99
100
100
39
(continued)
-------
TABLE III (continued)
FCO system
capacity.
Plant MM"
Montlcello 3 800
Hunter 1 360
Hunttr 2 360
Hunting ton 1 366
TOTAL
Flu* gas
X scrubbed
100
90
90
85
FGO capacity
on line
during
•»»•
800
360
360
366
20.512
No information
for this
period. MW*
s.oaa
Shutdown
throughout
period.
0
July 1980
Dependability V1"
AVL
OPR
100
100
100
RtL
UTL
100
99
87
August 1980
Dependability JT1"
AVL
100
100
100
OPR
RtL
UTL
September 1980
Dependability X0'*
AVL
100
0
OPR
REL
UTL
X
<
H-
* Equivalent scrubbed capacity.
b This category includes the flue gas capacity being handled by the FGO system at least part of the time during the report period.
The percent figures listed are average values for all system scrubbing trains during the period.
Flue gas X scrubbed for prototype *nd demonstration units 1s not applicable unless the system is designed to bring a unit into compliance
with SO, emission standard.
' Availability, operability, reliability, and utilization as defined 1n Appendix C of this report.
-------
As indicated in Table I, 76 power generating units (all coal-
fired) are now equipped with operating FGD systems. These units
represent a total controlled capacity of 28,564 MW. Current pro-
jections indicate that the total power generating capacity of the
U.S. electric utility industry will be approximately 833 GW by
the end of 1990.a (This value reflects the annual loss resulting
from the retirement of older units, which is considered to be 0.4
percent of the average generating capacity at the end of each
year.b) Approximately 370 GW or 44 percent of the 1990 total
will come from coal-fired units. The distribution of power
generation sources, both present (December 1979) and future
(December 1990) is as follows:3
December 1979
December 1990
Coal
39%
44%
Nuclear
9%
14%
Oil
25%
20%
Hydro
13%
11%
Gas
13%
10%
Other
1%
1%
GW (total)
603
833
Based on the known commitments to FGD by utilities as presented
in Table I, the percentage of electrical generating capacity
controlled by FGD for both the present (September 1980) and the
future (December 1990) is as follows:
September 1980*
December 1990
Coal-fired generating
capacity, %
12.1
27.1
Total generating
capacity, %
4.7
11.9
In light of the revised New Source Performance Standards, actual
FGD control is expected to be greater than what is reflected by
the figures above. For example, about 40 to 50 systems repre-
senting approximately 20,000 to 25,000 MW of generating capacity
presently fall into the uncommitted category. These are systems
that cannot be included in the committed group at this time
because information regarding their status is not ready for
public release.
In an effort to show general FGD usage and projected usage
trends, the table below gives a current (September 1980) and a
projected (December 1990) breakdown of throwaway product systems
versus salable product systems as a percent of the total known
commitments to FGD as of the end of the third quarter 1980:
The number of committed FGD systems is as of September 1980;
however, the figure used for the total generating capacity and
coal-fired generating capacity is based on the available
December 1979 figures.
xvi i
-------
Throwaway product process
Wet systems
Lime
Limestone
Dual alkali
Sodium carbonate
N/Aa
Dry systems
Lime
Sodium carbonate
Salable product process
Byproduct
Gypsum
Sulfur
Sulfuric acid
Process undecided
Total
Percent of total MW
September 1980
39.5
46.1
4.6
3.6
-
3.4
2.8
-
100.0
December 1990
21.1
36.0
2.1
3.3
6.7
3.2
0.5
2.4
1.1
2.7
20.9
100.0
aNA - Not available (these systems are committed to a throwaway product
process; however, the actual process is unknown at this time).
HIGHLIGHTS: JULY - SEPTEMBER 1980
The following paragraphs highlight FGD system developments during
the third quarter 1980.
Alabama Electric Cooperative reported that the Tombigbee 3 FGD
system achieved availabilities of 100% for both July and August
with no major mechanical problems being encountered. Operational
data for the month of September are not yet available.
Atlantic City Electric has announced plans to construct Cumber-
land Station 1 in Millville, New Jersey. The unit will have a
gross rating of 330 MW and will fire a 3.25% sulfur coal. The
utility is considering only FGD for SC-2 control, although a
specific process type has not been decided. Initial operations
are expected to begin in January 1988.
XVlll
-------
Initial and commercial FGD operations began on July 1, 1980, at
Laramie River 1 of Basin Electric Power Cooperative. This unit,
which is rated at 570 MW (gross), fires a subbituminous coal with
an average sulfur content of 0.81%. The FGD system, which is
preceeded by a cold side ESP for primary particle control, con-
sists of five Research Cottrell limestone packed tower modules.
The design SC>2 removal efficiency of the system is 90%. The flue
gas exits the system through a 600 foot acid resistant brick
lined stack. No initial system start up problems have been re-
ported .
A contract was awarded during the third quarter 1980 to Pullman
Kellogg by Big Rivers Electric for the installation of two wet
limestone FGD systems to control SC>2 emissions from the planned
D.B. Wilson units 1 and 2. Each unit will be rated at 440 MW
(gross). Currently, initial operations are scheduled to begin in
1984 and 1985 for units 1 and 2, respectively.
Central Power and Light has announced plans to construct unit 2
at its Coleto Creek station in Fannin, Texas. The unit will fire
a subbituminous coal with an average sulfur content of 0.39%.
Central and Southwestern Services, the holding company for
Central Power and Light, will construct the unit. Only dry
scrubbing is being considered as a SC-2 control strategy. Startup
of the system is scheduled for September 1986.
Initial operations began at Coal Creek 2 of Cooperative Power
Association during July 1980. The unit is rated at 545 MW
(gross) and fires a pulverized lignite with an average sulfur
content of 0.63%. The lime/alkaline flyash FGD system was
supplied by Combustion Engineering and treats 60% of the flue gas
before it exits through a 650 foot stack. The remaining gas is
used for bypass reheat. A cold side ESP preceeds the FGD system
to provide primary particle control. The sludge is stabilized
with flyash before being disposed of in a clay lined pond.
Operational data are not yet available from the utility.
Deseret Generation and Transmission Coop announced that a con-
tract has been awarded to Combustion Engineering for the in-
stallation of a wet limestone FGD system on the Moon Lake 1 unit.
The boiler, which will be located in Vernal, Utah, will fire coal
having an average sulfur content of 0.50% and will be rated at
410 MW (gross). The FGD system will feature a fabric filter
supplied by Ecolaire for primary particle control. Operations at
Moon Lake 1 are scheduled to commence in September 1984.
Grand Haven Board of Light and Power announced that construction
began in July 1980 on the FGD system being supplied by Babcock
and Wilcox to control SO2 emissions from the new J.B. Sims 3
unit. This unit, which is being constructed in Grand Haven,
Michigan, will be rated at 65 MW (gross) and will burn coal with
xix
-------
an average sulfur content of 2.75%. The wet lime FGD system will
consist of two spray towers with an overall design S02 removal
efficiency of 90%. Initial operations are expected to begin in
June 1983.
Kansas City Power and Light reported that the La Cygne FGD system
achieved availabilities of 97%, 97%, and 98% for the months of
July, August, and September, respectively. No major FGD related
problems were encountered during the three month period.
Kansas Power and Light reported 100% availability for the third
quarter 1980 for both the Jeffrey 1 and 2 FGD systems. The only
problems reported for the three month period at each unit were
boiler related.
Kansas Power and Light also reported that the Lawrence 4 FGD
system achieved availabilities of 97%, 100%, and 97% for the
months of July, August, and September, respectively. The only
major FGD related problem occurred during July when a storage
tank eroded causing a two day outage. The Lawrence 5 FGD system
was available 100% of the time during the third quarter, 1980
with no FGD related problems being experienced.
The dual alkali system installed on the Cane Run 6 unit of
Louisville Gas and Electric achieved availabilities of 100%, 99%,
and 99% for the months of July, August, and September, respec-
tively. An acceptance test that took place during July indicated
that the system was attaining a 95.1% SC>2 removal efficiency
level.
Louisville Gas and Electric announced that bids for a wet scrub-
bing system to control S02 emissions from the planned Trimble
County units 1 and 2 are currently being requested/evaluated.
Each unit will be rated at 575 MW (gross) and will burn bitumin-
ous coal with an average sulfur content of 4.0%. ESP's will be
utilized for primary particle control. Operations for units 1
and 2 are scheduled to commence in 1985 and 1988, respectively.
Northern States Power reported that the FGD systems installed on
Sherburne 1 and 2 each had availabilities of 100% for the entire
third quarter of 1980. The only problems reported for this
period were boiler related.
Northern States Power announced during the third quarter 1980
that plans for a unit 3 at the Sherburne County station have been
suspended. The utility is planning further engineering studies
and is considering locating this new unit at a different site.
Pacific Power and Light is currently requesting/evaluating bids
for sodium carbonate FGD systems to be retrofitted on units 1, 2,
and 3 at the Jim Bridger station located in Rock Springs, Wyoming.
Each boiler is rated at 550 MW (gross) and fires subbituminous
xx
-------
coal with an average sulfur content of 0.56%. Initial FGD
operations are scheduled to begin in 1988, 1984, 1986 for units 1,
2, and 3, respectively.
Construction began on the FGD system being installed at Public
Service of Indiana's Gibson 5 during July 1980. The FGD system
is being supplied by Pullman Kellogg and will utilize a magnesium
promoted limestone process. The system will consist of four
horizontal Weir absorber modules. Initial operation is scheduled
to begin in 1982.
Salt River project announced that initial operations of the
limestone FGD system at Coronado 2 commenced in July. The FGD
system, which was supplied by Pullman Kellogg, consists of two
limestone horizontal Weir absorber modules. Primary participate
matter removal is provided by two hot side ESP's. The utility
reports that bearing inspection has been completed and the unit
is expected to begin commercial operations in November.
South Mississippi Electric Power reported availabilities of 94%,
100%, and 99% for the R.D. Morrow, Sr. 1 FGD system during July,
August, and September, respectively. During July some FGD system
outage time was caused by a malfunction of the ball mill. The
R.D. Morrow, Sr. 2 FGD system achieved availabilities of 80%,
99%, and 99% during the same three month period, respectively.
The lower availability experienced during July was attributed to
ball mill repairs.
Southern Indiana Gas and Electric reported that the A.B. Brown 1
FGD system achieved availabilities of 92%, 95%, and 100% for the
months of July, August, and September, respectively. Problems
with recirculation pumps and sludge disposal equipment were
reported for this three month period.
Southwestern Electric Power announced that a contract has been
awarded to the Air Correction Division, UOP for the installation
of a wet limestone FGD system to control S02 emissions from unit
1 at the new Dolet Hills station. This unit is located in
Mansfield, Louisiana, and will be rated at 720 MW (gross). The
FGD system will be preceeded by an ESP for primary particle
removal. Initial system operations are expected to begin in
1986.
Southwestern Electric Power has also announced plans for a second
unit to be installed at the Dolet Hills station. Unit 2 is
scheduled to become operational in 1988, and the utility is
currently considering a wet limestone FGD system for S(>2 control.
United Power Association announced that the FGD system being
supplied by Research-Cottrell at the Stanton station, located in
Stanton, North Dakota, is now under construction. The FGD system
will utilize a lime/spray drying process to control SC>2 emissions
xx i
-------
from the 50 MW (gross) boiler, followed by a fabric filter for
primary particle control. Initial start up of the system is
projected for June 1982.
The FGD System being retrofitted on the Naughton 3 unit of Utah
Power and Light is currently under construction. This boiler,
which is located in Kemmerer, Wyoming, is rated at 330 MW (gross)
and fires coal with an average sulfur content of 0.55%. The FGD
system is being supplied by the Air Correction Division, UOP, and
will use a wet sodium carbonate process. Initial system start up
is scheduled for June 1981.
West Texas Utilities announced plans during the third quarter
1980 for a new unit to be located near Oklaunion, Texas. The
unit will be rated at 720 MW (gross). Currently, the utility is
considering only FGD as a means for S02 control. Initial opera-
tions are scheduled to begin in 1987.
REFERENCES
a. U.S. Department of Energy. Energy Information Administra-
tion. Office of Coal and Electric Power Statistics. Elec-
tric*Power Statistics Division. Inventory of Power Plants
in the United States, December 1979. Publ. No. DOE/EIA-0095
(79).
b. Rittenhouse, R.C. New Generating Capacity: When, Where,
and by Whom. Power Engineering 82(4):57. April 1978.
xxii
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC COOP
TOMBIGBEE
TOMBIGBEE
ARIZONA ELECTRIC POWER COOP
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC COOP
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARANIE RIVER
LARAMIE RIVER
LARA1IE RIVER
BIG RIVERS ELECTRIC
D.B. UILSOM
D.B. WILSON
SREEM
GREEN
CAJUN ELECTRIC POWER COOP
SIS CAJUN III
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
CENTRAL ILLINOIS PUBLIC SERVIC
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
CENTRAL POWER S LIGHT
COLETO CREEK
CINCINNATI GAS ( ELECTRIC
EAST BEND
EAST BEND
UNIT
2
3
2
3
1
Z
t
1
2
3
4
5
3
1
1
2
1
2
3
1
2
1
2
1
1
2
1
2
1
2
1
2
NO. UNIT LOCATION
LEROY
LEROV
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIN6TON
FARHINGTON
FARMINGTON
FARHINGTON
FARMINGTON
MOBERLY
MILLVILLE
BEULAH
BEDLAM
WHEATLAND
WHEATLAND
WHEATLAND
SEBREE
SEBREE
DE SOTO PARISH
CANTON
CANTON
NEUTON
NEWTON
PENOBSCOT BAY
FANNIN
RABBITHASH
RABBITHASH
ALABAMA
ALABAMA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
MISSOURI
NEW JERSEY
NORTH DAKOTA
NORTH DAKOTA
WYOMING
UYOHING
WYOMING
KENTUCKY
KENTUCKY
LOUISIANA
ILLINOIS
ILLINOIS
ILLINOIS
ILLINOIS
MAINE
TEXAS
KENTUCKY
KENTUCKY
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
6/81
11/79
11/79
11/79
0/82
0/82
1/82
1/88
4/83
10/8$
7/80
6/81
4/82
7/84
1/86
12/79
11/80
0/85
7/76
1/86
9/79
12/82
1/89
9/86
10/87
12/80
STATUS
1
1
t
1
1
1
2
1
1
1
3
3
2
6
2
5
1
2
2
3
3
1
2
6
1
5
1
7
6
6
6
2
REG
CLASS
B
B
t
D
C
C
C
C
C
C
C
C
A
C
D
C
C
C
C
A
A
B
B
A
B
A
B
A
A
A
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD. SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPSH2/71)
C. STAMDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARO(S) MORE STRINGENT THAN NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPS<6/79>
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(12/71>
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 1
SUMMARY LIST Of F6P SYSTEMS
COMPANY NAME/
UNIT NAME
COLORADO UTE ELECTRIC ASSN
CRAIG
CRAIG
CRAI6
COLU1BUS ( SOUTHERN OHIO ELEC
CONESVILLE
CONESVILLE
POSTON
POSTON
COMMONWEALTH EDISON
POWERTON
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
DELNARVA POWER I LIGHT
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
VIENNA
DESERET GEN 1 TRANS COOP
MOON LAKE
HOON LAKE
DUflUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER COOP
J.K. SMITH
J.K. SMITH
SPURLOCK
FLORIDA POWER K LIGHT
MARTIN
MARTIN
6ENERAL PUBLIC UTILITIES
COAL
COAL
COAL
COAL
COHO
SEWARD
GRAND HAVEN BRD OF LIGHT I PUR
J.B. SIMS
HOOSIE& ENERGY
HER DPI
NEROM
HOUSTON LIGHTING C POWER
LIMESTONE
LIMESTONE
tf.A. PARISH
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPS<12/71>
C. STANDARD(S) "ORE STRINGENT
D. STANDARD(S) MORE STRINGENT
UNIT
1
2
3
5
6
5
6
51
1
2
1
2
3
9
1
2
1-4
1-6
1
2
2
3
4
1
2
3
4
1
7
3
1
2
1
Z
8
4.
5.
6.
7.
THAN
THAN
NO. UNIT LOCATION
CRAIG COLORADO
CRAIG COLORADO
CRAIG COLORADO
CONESVILLE OHIO
CONESVILLE OHIO
NELSONVILLE OHIO
NELSONVILLE OHIO
PEKIN ILLINOIS
UNDERWOOD NORTH DAKOTA
UNDERWOOD NORTH DAKOTA
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
VIENNA MARYLAND
VERNAL UTAH
VERNAL UTAH
ELRAMA PENNSYLVANIA
SOUTH HEIGHT PENNSYLVANIA
MAYSVILLE KENTUCKY
MARTIN COUNTY FLORIDA
MARTIN COUNTY FLORIDA
UNDECIDED UNDECIDED
UNDECIDED UNDECIDED
UNDECIDED UNDECIDED
UNDECIDED UNDECIDED
GIRARD PENNSYLVANIA
EAST WHEATFIELDPENNSYLVAN1A
GRAND HAVEN MICHIGAN
SULLIVAN INDIANA
SULLIVAN INDIANA
JEWITT TEXAS
JEW1TT TEXAS
BOOTH TEXAS
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTIN6/EVALUATTNC BIDS
START-UP
DATE
10/80
12/79
0/82
1/77
6/78
8/86
0/89
4/80
7/79
7/80
5/80
5/80
5/80
6/87
9/84
0/88
10/75
7/73
1/85
1/87
1/81
0/87
0/89
12/92
5/94
12/95
5/97
5/91
5/87
6/83
5/82
9/81
12/84
12/85
11/82
STATUS
2
1
3
1
1
6
6
1
1
1
1
1
1
6
3
5
1
1
6
6
2
7
7
6
6
6
6
5
5
2
2
2
5
5
2
REG
CLASS
D
D
D
D
D
D
D
E
B
B
E
E
E
A
A
A
D
D
A
A
B
A
B
B
A
A
A
PLANNED - CONSIDERING ONLY F6D SYSTEMS
PLANNED - CONSIDERING F6D SYSTEMS; ALSO ALTERNATIVE
NSPS<6/79>
METHODS
NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSM2/71)
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 1
SUMMARY LIST OF F6D SYSTEMS
COMPANY NAME/
UNIT NAME
INDIANAPOLIS POWER t LIGHT
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
IOWA ELECTRIC LIGHT ( PWR
GUTHRIE CO.
JACKSONVILLE ELEC AUTHORITY
NEM PROJECT
NEW PROJECT
KANSAS CITY POWER I LI6NT
HAWTHORN
HAWTHORN
LA CYGNE
KANSAS POUER t LIGHT
JEFFREY
JEFFREY
LAWRENCE
LAWRENCE
UNIT NO.
1
2
J
3
4
1
1
2
3
4
1
1
Z
4
5
UNIT LOCATION
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
/
PANORA
EAST PORT SITE
EAST PORT SITE
KANSAS CITY
KANSAS CITY
LA CYGNE
WAMEGO
WAMEGO
LAURENCE
LAWRENCE
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
IOWA
FLORIDA
FLORIDA
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
START-UP
DATE
0/87
O/ 0
O/ 0
12/77
10/84
11/84
12/85
6/87
11/72
8/72
2/73
8/78
4/80
1/76
11/71
STATUS
6
6
6
1
2
5
6
6
1
1
1
1
1
1
1
REG
CLASS
C
C
C
B
B
A
A
A
D
D
E
D
D
D
D
KENTUCKY UTILITIES
GREEN RIVER 1-3
LAKELAND UTILITIES
NCINTOSH 3
LANSING BOARD OF WATER & LIGHT
ERICKSON 2
LOS ANGELES DEPT OF YTR I PWR
INTERMOUNTAIN 1
INTERMOUNTAIN 2
INTERMOUNTAIN 3
INTERMOUNTAIN 4
LOUISVILLE GAS I ELECTRIC
CANE RUN 4
CANE RUN 5
CANE RUN 6
HILL CREEK 1
MILL CREEK 2
KILL CREEK 3
MILL CREEK 4
PADDY'S RUN 6
TRIMBLE COUNTY 1
TRIMBLE COUNTY 2
MAR3UETTE BOARD OF LIGHT ( PWR
SHIRAS 3
MICHIGAN SO CENTRAL PWR AGENCY
PROJECT 1
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 5
ARKANSAS LIGNITE 6
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
CENTRAL CITY
LAKELAND
KENTUCKY
FLORIDA
DELTA TOWNSHIP MICHIGAN
DELTA UTAH
DELTA UTAH
DELTA UTAH
DELTA UTAH
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
LOUISVILLE KENTUCKY
BEDFORD KENTUCKY
BEDFORD KENTUCKY
MARfiUETTE MICHIGAN
LITCHFIELD MICHIGAN
ARKANSAS
ARKANSAS
9/75
8/81
1/87
0/86
0/87
0/88
0/89
8/76
12/77
4/79
1/81
12/81
8/78
6/82
4/73
7/85
7/88
10/82
6/82
0/90
0/92
6
6
6
6
1
1
1
2
2
1
2
1
5
5
5
3
4
4
E
D
B
E
A
A
A
A
1
«
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79J
B. FEDERAL NSPS(12/71)
C. STANDARDCS) MORE STRINGENT THAN NSPSC6/79)
D. STANDARDCS) MORE STRINGENT THAN NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPS(6/79>
E. STANDARDCS) EBUAL TO OR LESS STRINGENT THAN NSPSM2/71)
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 19f»C
SECTION 1
SUMMARY LIST OF F6D SYSTEMS
COMPANY NAME/
UNIT NAME
MIDDLE SOUTH UTILITIES
UN ASSIGNED
UNASSIGNED
MILTON
dILTON
UNIT
1
2
1
2
NO. UNIT LOCATION
CONVENT
CONVENT
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
START-UP
DATE
0/89
0/93
0/88
0/91
STATUS
4
t
4
4
REG
CLASS
A
A
A
A
MINNESOTA POWER g LIGHT
CLAY BOSWELL 4
MINNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONONGAHELA POWER
PLEASANTS 1
PLEASANTS 2
MONTANA POWER
COLSTRIP 1
COLSTRIP 2
COLSTRIP 3
COLSTRIP 4
MONTANA-DAKOTA UTILITIES
COYOTE 1
MUSCATINE POWER I WATER
MUSCATINE 9
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
NEVADA POWER
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
EARNER VALLEY
EARNER VALLEY
NEW YORK STATE £LEC I
SOMERSET
GAS
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
SCHAHFER
&CH1HFER
NORTHERN STATES POWER
RIVERSIDE
SHER9URNE
SHERBURNE
66
11
17
18
6,7
1
2
COHASSET
CENTER
BELMONT
BELMONT
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
BEULAH
MUSCATINE
SARGENT
SOMERSET
BUFFALO
GARY
WHEATFIELD
WHEATFIELD
MINNEAPOLIS
BECKER
BECKER
MINNESOTA
NORTH DAKOTA
WEST VIRGINIA
WEST VIRGINIA
MONTANA
MONTANA
MONTANA
MONTANA
NORTH DAKOTA
IOWA
NEBRASKA
1
2
3
4
1
2
3
4
1
2
LAS VEGAS
LAS VEGAS
LAS VEGAS
LAS VEGAS
MOAPA
MOAPA
KOAPA
MOAPA
ST. GEORGE
ST. GEORGE
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
UTAH
UTAH
MEW YORK
NEW YORK
INDIANA
INDIANA
INDIANA
MINNESOTA
MINNESOTA
MINNESOTA
4/80
9/77
3/79
10/80
9/75
5/76
5/83
3/84
3/81
9/82
3/87
6/84
4/82
7/76
6/83
6/85
11/80
3/76
3/77
6/86
6/87
6/8?
6/89
3/74
4/74
6/76
4/83
6/85
6/86
6
6
6
6
1
1
1
4
5
5
A
A
A
A
6
B
B
A
A
A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REOUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGO SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPSM2/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARDCS) MORE STRINGENT THAN NSPSM2/711 BUT NOT MORE STRINGENT THAN NSPSC6/79)
E. STANDARDCS) E8UAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 1
SUMMARY LIST Of FGO SYSTEMS
COMPANY NAME/
UNIT NAME
PACIFIC GAS R ELECTRIC
MONTEZUNA
•
D. STANDARD(S) MORE STRINGENT THAN NSPS<12/71) BUT NOT MORE STRIliGENT THAN NSPS<6/79)
E. STANOARDfS) EOUAL TO OR LESS STRINGENT THAN NSPS(12/71)
-------
EPA UTILITY FGD SURVEY: JULT - SEPTEMBER 1980
SECTION 1
SUMMARY LIST OF F&O SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
REG
STATUS CLASS
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 4
SOUTH MISSISSIPPI ELEC PMR
R.D. MORROW, SR. 1
R.O. MORROW, SR. 2
SOUTHERN ILLINOIS POWER COOP
MARION 4
MARION 5
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN 1
SOUTHWESTERN ELECTRIC POKER
DOLET HILLS 1
DOLET HILLS 2
HENRY w. PJRKEY 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
SPRINGFIELD WATER, LIGHT t PWR
BALL1AN 3
ST. JOE ZINC
G.F. WEATON 1
SUNFLOWER ELECTRIC COOP
HOLCOMB 1
TAMP* ELECTRIC
9IG SEND 4
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
PARADISE
PARADISE
SNAWNEE
SNAWNEE
WIDOWS CREEK
WIDOWS CREEK
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
TEXAS POWER » LIGHT
SANDOW
THIN OAKS
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
HILL CREEK
MILL CREEK
MONTICELLO
1-10
1
2
10A
10B
7
B
GEORGETOWN
HATTISBURG
HATTISBURG
MARION
MARION
SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
ILLINOIS
ILLINOIS
WEST FRANKLIN INDIANA
MANSFIELD LOUISIANA
MANSFIELD LOUISIANA
HALLSVILLE TEXAS
SPRINGFIELD MISSOURI
SPRINGFIELD ILLINOIS
MONACA PENNSYLVANIA
HOLCOMB KANSAS
TAMPA
FLORIDA
NEW JOHNSONVILLTENNESSEE
PARADISE
PARADISE
PADUCAH
PADUCAH
BRIDGEPORT
BRIDGEPORT
CARLOS
ROCKDALE
8REMOND
BREMOND
ATHENS
TATUM
TATUM
TATUM
TATUM
HENDERSON
HENDERSON
MT. PLEASANT
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
7/81
8/78
6/79
5/79
0/88
3/79
0/86
0/88
12/84
4/77
10/80
11/79
9/83
12/84
12/81
3/82
6/82
4/72
4/72
9/81
5/77
2
1
1
1
6
1
3
6
3
1
2
1
3
3
3
2
2
1
1
2
1
A
B
B
B
A
B
A
A
B
B
B
B
A
A
E
E
E
E
E
E
E
1/82
11/80
8/84
8/85
0/87
4/77
5/78
2/79
0/85
0/85
0/86
5/78
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
A.
B.
C.
D.
E.
4. PLANNED - LETTER OF INTENT SIGNED
s. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGO SYSTEMS
?. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
FEDERAL NSPS(6/79)
FEDERAL NSPSC12/71)
STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
STANDARD(S) MORE STRINGENT THAN NSPS(12/71) BUT NOT MORE STRINGENT THAN NSPSC6/79)
STANDARD(S) E8UAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 1
SUMMARY LIST OF FOO SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP DEC
DATE STATUS CLASS
TUCSON ELECTRIC POWER
SPRINGERVILLE 1
SPH1NGERV1LLE 2
UNITED POWER ASSOCIATION
STANTON 1A
UTAH POWER & LIGHT
HUNTER 1
HUNTER 2
HUNTER 3
HUNTER t,
HUNTINGTON 1
NAUGHTON 3
WEST PENN POWER
KITCHELL 33
WEST TEXAS UTILITIES
3KLAUNION 1
SPRINGERVILLE
SPRINGERVILLE
STANTON
CASTLE DALE
CASTLE DALE
CASTLE DALE
CASTLE DALE
PRICE
KEWMERER
COURTNEY
OKLAUNION
ARIZONA
ARIZONA
NORTH DAKOTA
UTAH
UTAH
UTAH
UTAH
UTAH
WYOMING
PENNSYLVANIA
TEXAS
1/85
3/87
6162
5/79
6/80
6/83
6/85
5/78
6/81
8/82
12/86
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGft SYSTEMS
7. PLANNED - CONSIDERING F6D SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSM2/71)
C. STANDARDfS) MORE STRINGENT THAN NSPS<6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSCI2/71) BUT NOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(12/71)
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19RC
SECTION 2
STATUS OF FGD SYSTEMS
JUT IDENTIFICATION
ABSTRACT
ALABAtA ELECTRIC COOP
T3OIG9EE
2
NEW 255.0 MM (GROSS)
179.0 MW (ESC)
C3AL
1.15 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.1X
STATUS 1 STARTUP 9/76
TOMB1GBEE 2 Of ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALAPAKA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953,000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.151 AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMMJSSION LIMITA-
TION VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE MATTER CONTROL IS PROVID-
ED BY A HOT SIDE ESP. THE S02 REMOVAL. E8UIPMENT CONSISTS OF TWO SPRAY
TOWERS SUPPLIED BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TOWER AND THE FLUE
GAS is REHEATED .ITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID-
BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND
SPENT APSORBENT IS DISPOSED OF IN AN ON-SITE LINED POND.
4LABA-U ELECTRIC COOP
I01BIGBEE
3
1EW 255.0 *u (GROSS)
179.0 «« (ESC)
C3AL
1.15 XS BITUMINOUS
LIMESTONE
PEABOOY PROCFSS SYSTEMS
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 6/79
TOMB1GBFE 3 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953,000
ACFM AND BURNS PITUM1NOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.15* AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE CONTROL IS PROVIDED BY A MOT
SIDE ESP. THE SOt REMOVAL E8UIPMENT CONSISTS OF TWO SPRAY TOUERS SUPPLIED
BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REAGENT. A CHEVRON
MIST ELIMINATOR IS INCLUDED IN EACH TOWER, AND THE FLUE GAS IS REHEATED
WITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID BRICK LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MOBE, AND SPENT ABSORBENT
IS DISPOSED IN AN ON-SITE LINED POND.
ARIZONA ELECTRIC POWER COOP
APACHE
2
1EW 195.0 RW (GROSS)
98.Cl MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
USEARCH-COTTRELL
ENERGY CONSUMPTION: 4.1X
STATUS 1 STARTUP 8/78
APACHE 2 OF ARIZONA ELECTRIC POWER COOP IS LOCATED IN COCHISE, ARIZONA AND
IS A DRY POTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOW OF 735,000
ACFM. BITUMINOUS COAL WITH A HEATING VALUE OF 10,000 BTU/LB, A SULFUR CON-
TENT OF 0.55X AND AN ASH CONTENT OF 15* IS THE FUEL USED FOR THIS UNIT.
PHRTICULATE CONTROL IS EFFECTED BY A HOT SIDE ESP. HALF THE FLUE GAS
PASSES THROUGH TWO PACKED TOWERS EMPLOYING LIMESTONE ABSORBENT AND
HAVING A DESIGN S02 REMOVAL OF 85X WERE SUPPLIED BY RESEARCH-COTTRELL.
MIST ELIMINATION IS PROVIDED BY CHEVRON TYPE ELIMINATORS. NO REHEAT IS
EMPLOYED. A 400 FT COLE BRAND CXL2000 LINED STACK IS IN USE. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP MODE AND WASTE MATERIAL IS DISPOSED OF IN
OFF-SITE SLUDGE PONDS. OPERATIONS COMMENCED IN AUGUST 1978.
ARIZONA ELECTRIC POWER COOP
APACHE
I
NEW 195.0 MW (GROSS)
98.0 MW (ESC)
COAL
.55 tS BITUMINOUS
LI1ESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.1*
STATUS 1 STARTUP 6/79
APACHE 3 OF ARIZONA ELECTRIC POWER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOW CC.55X) SULFUR BITUMINOUS COAL WITH AN
AVERAGE HEATING VALUE OF 10,000 BTU/LB PRODUCES A MAXIMUM FLUE GAS FLOW OF
735,000 ACFM. HALF OF THE FLUE 6AS PAjSSES THROUGH A HOT SIDE ESP TO TWO
RESEARCH COTTRELL PACKED TOWERS, WHERE LIMESTONE IS USED TO REMOVE 85* OF
THE S02. THE GAS EXITS A HORIZONTAL CHEVRON MIST ELIMINATOR INTO ITS OWN
CEILCOTE LINED FLUE IN THE 400 FOOT STACK IT SHARES WITH UNIT 2. THE FGD.
WHICH HAS BEEN OPERATIONAL SINCE JUNE OF 1979, USES NO REHEAT. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP AND SLUDGE IS DISPOSED OF IN TWO OFF SITE
LINED PONDS WITH 20 YEARS' EXPECTED LIFESPAN. TWO ADDITIONAL PONDS ARE
PLANNED, WHICH WOULD ADD ANOTHER 20 YEARS' CAPACITY.
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT 119.0 MW (GROSS)
119.0 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 3.4*
STATUS 1 STARTUP 10/73
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOSEPH CITY. ARIZONA AND
IS A TANGENTIALLV FIRED, WET BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF 0.5* AND A HEATING VALUE OF
10,150 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED DISC SCRUB-
BERS. THE FGD SYSTEM BEGAN IN OCTOBER, 1973 AND IS NOW OPERATIONAL. S02 Is
CONTROLLED BY ONE TOWER WITH MUNTERS PACKING EMPLOYING A LIMESTONE
ABSORBENT. THE UNIT WAS SUPPLIED BY RESEARCH COTTRELL AND HAS A DESIGN
REMOVAL OF 92*. CHEVRON MIST ELIMINATORS ARE LOCATED PRIOR TO AN IN-LINE
STEAM REHEAT SYSTEM. THE TREATED FLUE GAS IS VENTED TO A 256 FT ACID BRICK
LINED STACK. THE FGD SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND THE
UNTREATED WASTE IS DISPOSED OF IN AN ON-SITE UNLINED POND.
ARIZONA PUBLIC SERVICE
CHOLLA
2
NEW 264.0 MW (GROSS)
264.0 MW (ESC)
COAL
.51? XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: **««X
STATUS 1 STARTUP 4/78
CHOLLA 2 OF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZONA. THE
BOILER BURNS PULVERIZED BITUMINOUS COAL (0.5* S, 10,150 BTU/LB). MECHANI-
CAL COLLECTORS PROVIDE PRIMARY PARTICULATE CONTROL. FOUR PARALLEL
FLOODED DISC AND PACKED TOWER S02 ABSORBER TRAINS (THREE ARE REQUIRED FOR
FULL LOAD) REMOVE THE FLUE GAS S02. THE DESIGN S02 REMOVAL fOR THE
SYSTEM, WHICH BEGAN OPERATIONS IN APRIL, 1978, IS 751. THE CLEANED GAS
PASSES THROUGH AN IN-LINE STEAM REHEfcTER INTO AN ACID BRICK LINED STACK.
THE OPEN WATER LOOP SYSTEM DEPOSITS ITS SLUDGE INTO A FLY ASH POND.
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
JVIT IDENTIFICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
CrfOLLA
4
NEK 375.0 «W (GROSS)
126.D »W (ESC)
C3AL
,5n XS
L11ESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: «***X
STATUS 2 STARTUP 6/81
CHOLLA I. OF ARIZONA PUBLIC SERVICE IS PRESENTLY UNDER CONSTRUCTION IN
JOSEPH CITY, ARIZONA. THE PULVERIZED COAL (0.5X S, 10,ISO BTU/LB) FIRED
BOILER WILL EXHAUST FLUE GAS THROUGH AN ESP TO A DOUBLE LOOP COMBINATION
TOWER (RESEARCH-COTTRELL DESIGN) WHICH WILL TREAT 36X OF THE GAS WITH
LIMESTONE. THE SYSTEM IS SCHEDULED TO START UP IN JUNE 1981.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175.C1 "y (GROSS)
175.0 NW (ESC)
C3AL
.75 XS SUBBITUMINOUS
LINE/ALKALINE FLTASH
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: »***X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1, 2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
302 REMOVAL. INITIALLY, THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 9650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 CHENICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.SX. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
F3UR CORNERS
2
RETROFIT 175.0 WW (GROSS)
175.0 NW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIIE/ALKALINE FLTASH
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ***«X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
502 REMOVAL. INITIALLY, THE FRONT FIRED. DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 6650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 CHEMICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.SX. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
F3UR CORNERS
3
RETROFIT 229.0 My (GROSS)
229.0 WU (ESC)
C3AL
.75 XS SUflBITUMINOUS
LUE/ALKALINE FLYASH
CHEMICO DIVISION, F.NVIROTECH
ENERGY CONSUMPTION: ***«X
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
SC2 REMOVAL. INITIALLY, THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 8650 BTU/LB) UNIT 3 SUPPLIES 1,030,000 ACFM INTO 2
CHEMICO VENTURI SCRUBBERS FOR PRIMARY PARTICULATE CONTROL AND APPROXIMATE-
LY 5 OX SO? REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02 REMOVAL EFFICI-
ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 67.5X.
OPERATIONS COMMENCED IN NOVEMBER. 1979.
ARIZONA PUBLIC SERVICE
F3UR CORNERS
4
RETROFIT 755.0 iy (GROSS)
755.0 MH (ESC)
COAL
.75 XS
LME
JMITED ENGINEERS
E1ERGY CONSUMPTION: •*«*X
ARIZONA PUBLIC SERVICE AWARDED A CON.TRACT TO UNITED ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. BASED ON THE PROTOTYPE HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY THE UTILITY, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75X S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED* BY AN ESP. START UP IS EXPECTED IN
1982.
STATUS 3
STARTUP 0/82
ARIZONA PUBLIC SERVICE
F3UR CORNERS
5
RETROFIT 755.0 NW (GROSS)
755.0 «W (ESC)
C3AL
.75 XS
LIKE
JUITED ENGINEERS
EVERGY CONSUMPTION: ***«X
STATUS 3 STARTUP 0/82
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO UNITED ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND S AT ITS FOUR CORNERS STA-
TION IN FARMINGTON, MEW MEXICO. BASED ON THE PROTOTYPE HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY THE UTILITl, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75X S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESP. START UP IS EXPECTED IN
1982.
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ASSOCIATED ELECTRIC COOP
THOMAS HILL
}
1EW 737.0 flU {GROSS)
670.0 MW (ESC)
COAL
4.80 XS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: *••**
STATUS 2 STARTUP 1/82
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A PULVERIZED COAL (4.8X S,
9,700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN MOBERLY, MISSOURI. TUO COLD
SIDE ESP'S WILL PRECEDE THE FOUR 91.SX EFFICIENT PULLMAN KELL06G HORIZONTA
WEIR FGD MODULES USING MAGNESIUM-PROMOTED LIMESTONE AS THE ABSORBENT. THE
CLEANED GAS HILL PASS THROUGH A VERTICAL CHEVRON MIST ELIMINATOR TO A 620
FOOT BRICK LINED STACK. REHEAT WILL BE ACCOMPLISHED BY BYPASS. DRY FIXATED
SLUDGE WILL BE TRUCKED TO AN ACTIVE STRIP MINE. THE SYSTEM WILL USE A
CLOSED HATER LOOP. THE FGD SYSTEM IS UNDER CONSTRUCTION AND START UP IS
EXPECTED IN JANUARY 1982.
ATLANTIC CITY ELECTRIC
CUMBERLAND
1
NEW 330.0 MW (GROSS)
330.0 MW (ESC)
COAL
3.25 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****!
STATUS 6 STARTUP 1/88
CUMBERLAND 1 IS A PULVERIZED COAL (7.25XS) FIRED BOILER TO BE LOCATED IN
MILLVILLE, NEW JERSEY. THE UTILITY IS CONSIDERING AN FGD SYSTEM WITH A
THROWAHAY PRODUCT FOR S02 CONTROL. OPERATIONS ARE SCHEDULED TO BEGIN IN
JANUARY 1988.
3ASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
1
«EW 440.0 MU (GROSS)
440.0 KW (ESC)
COAL
.68 XS LIGNITE
L11E/SPRAY DRYING
J3Y MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 4/83
UNIT 1 OF.BASIN ELECTRIC POWER COOP'S ANTELOPE VALLEY PLANT IS PRESENTLY
UNDER CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT WILL BURN PULVERIZED
COAL (0.6SX S, 6600 BTU/LB LIGNITE) AND SUPPLY 2.055,000 ACFM TO * DRY
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM WILL CONSIST OF S NIRO ATOXZZER SPRAY DRYERS AND TWO BAGHOUSES.
THE CLEANED GAS, ALONG WITH A 4X BYPASS REHEAT, WILL EXIT A 600 FOOT
PVC LINED STACK. THE SYSTEM WILL USE A CLOSED WATER LOOP AND THE DRV
POWDER WILL BE USED FOR LANDFILL IN A COAL MINE. START UP IS EXPECTED
IN APRIL 1983.
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
2
1EU 440.0 MU (GROSS)
440.0 MW (ESC)
COAL
.68 XS LIGNITE
LUE/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: .OX
STATUS 5 STARTUP 13/85
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POWER COOP HILL BE LOCATED IN BEULAH,
NORTH DAKOTA. THE UTILITY IS PRESENTLY CONSIDERING VARIOUS FGD PROCESSES
FOR THIS LIGNITE (0.68X S, 6600 BTU/LB) FIRED UNIT. THE UNIT WILL BE
REQUIRED TO COMPLY WITH STATE EMISSIONS STANDARDS VIA BEST AVAILABLE
CONTROL TECHNOLOGY. START UP IS SCHEDULED FOR OCTOBER 1985.
JASIN ELECTRIC POWER COOP
LARAMIE RIVER
1
MEW 57".0 MW (GROSS)
570.0 MW (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: .OX
STATUS 1 STARTUP 7/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS A PULVERIZED COAL
(0.8X S, 8139 BTU/LB) FIRED UNIT LOCATED IN WHEATLAND, WYOMING.
THE BOILER FEEDS 2,300,000 ACFN OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH
REMOVE 90X OF THE S02. THE CLEANED GAjS EXITS FROM A VERTICAL CHEVRON
DEMISTER INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT IS USED.
THE FLYASH FIXATED SLUDGE IS DEWATERfcD TO 83X SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM EMPLOYS A CLOSED WATER LOOP. OPERATIONS
BEGAN ON JULY 1, 1980.
3ASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
*EW 570.0 MW (GROSS)
570.0 MU (ESC)
C3AL
.61 XS SUBBITUMINOUS
LIMESTONE
»ESEARCH-COTTRELL
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 6/81
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 2 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLAND. WYOMING. THE PULVERIZED COAL (0.81X S. 8139 BTU/LB)
FIRED BOILER WILL FEED 2,300,000 ACFH OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH WILL
REMOVE 90X OF THE S02. THE CLEANED GAS WILL EXIT FROM A VERTICAL CHEVRON
DENISTER INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE USED.
THE FLYASH FIXATED SLUDGE WILL BE DEWATERED TO 83X SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM WILL EMPLOY A CLOSED WATER LOOP. START UP IS
SCHEDULED FOR JUNE 1981.
10
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
3ASIN ELECTRIC POWER COOP
LARAMIE RIVER
5
MEW 570.0 MW (GROSS)
57P.O MW (ESC)
CDAL
.54 XS SUB8ITUMINOUS
LIME/SPRAY DRYING
3ABCOCK ! WILCOX
ENERGY CONSUMPTION: .31
STATUS 2 STARTUP 4/82
LARAMIE RIVER 3 OF BASIN ELECTRIC POWER COOP IS UNDER CONSTRUCTION IN
WHEATLAND, WYOMING, AND WILL UTILIZE FOUR DRY LIME INJECTION MODULES.
AND A COLD SIDE ESP. THE BOILER WILL FIRE PULVERIZED COAL (0.5*1 S,
8100 BTU/LB) AND WILL SUPPLY 2,800,000 ACFM OF FLUE GAS TO THE FGD
SYSTEM, WHICH WILL REMOVE 85X OF THE SO? BEFORE THE GAS EXITS THROUGH
A 600 FOOT ACID BRICK LINED STACK. A 3X BYPASS WILL BE USED FOR REHEAT.
THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP. AND WILL LANDFILL THE
DRY POWDER WASTE. OPERATIONS ARE SCHEDULED TO COMMENCED IN APRIL
1982.
316 RIVERS ELECTRIC
D.B. WILSON
1
NEW 44?.0 MW (GROSS)
440.0 MW (ESC)
COAL
***** XS BITUMINOUS
LIMESTONE
PULLMAN KELLOG
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 7/84
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS WILL HAVE A MW RATING OF 440 EACH.
PULLMAN KELL06 HAS BEEN AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM. STARTUP IS SCHEDULED FOR JULY 1984.
31G RIVERS ELECTRIC
D.B. tflLSON
2
NEW 44C.O MW (GROSS)
440.0 MW (ESC)
COAL
***** XS BITUMINOUS
LIMESTONE
PULLMAN KELLOG
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 1/86
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS WILL HAVE A HW RATING OF 440 EACH.
PULLMAN KELLOG HAS BEEN AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM. STARTUP IS SCHEDULED FOR JANUARY 1986.
JIG RIVERS ELECTRIC
SSEEN
1
NEW 242.0 MW (GROSS)
242.0 MW (ESC)
C3AL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 12/79
UNIT 1 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN
SEBREE,KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S. 9750 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL REMOVE 90Z OF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A SAUERtSEN 72 LINED STACK AfTER IT IS HEATED BY STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN DECEMBER 1979.
316 RIVERS ELECTRIC
SHEEN
2
NEW 242.0 MW (GROSS)
242.0 MW (ESC)
CDAL
S.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *«**X
STATUS 2 STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRIC'S GREEN STATION IS BEING CONSTRUCTED IN
SEBREE, KENTUCKY. THE DRV BOTTOM PULVERIZED COAL (3.75X S, 9750 BTU/LB)
FIRED BOILER WILL SUPPLY 1,000.000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL REMOVE 90S OF THE
S02. THE CLEANED GAS WILL PASS THROUGH A CHEVRON MIST ELIMINATOR AND
WILL EXIT A SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM WILL BE POZ-0-TEC
STABILIZED. START UP IS SCHEDULED FOR NOVEMBER 1980.
CAJUN ELECTRIC POWER COOP
316 CAJUN III
1
NEW 540.0 MW (GROSS)
540.C1 MW (ESC)
COAL
***** XS LIGNITE
IUOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/85
CAJUN ELECTRIC HAS PLANS TO CONSTRUCT A 540 MW UNIT, BIG CAJUN 3. TO BE
LOCATED IN DE SOLO PARISH, LOUISIANA. THE UTILITY IS PRESENTLY CONSIDER-
ING A DRY SCRUBBING PROCESS TO CONTROL EMISSIONS FROM THE PULVERIZED
COAL FIRED BOILER. THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN 1985.
11
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 198C
SECTION 2
STATUS Of FGO SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
CENTRAL ILLINOIS LIGHT
BJCK. CREEK
1
NEW (16.0 MW (GROSS)
416.T MW
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CINCINNATI GAS t ELECTRIC
EAST SEND
1
MEU 650.0 My (GROSS)
650.0 MU (ESC)
COAL
••*** IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9X
STATUS 6 STARTUP 10/87
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NEW UNIT, EAST BEND 1, TO
BE LOCATED ADJACENT TO EAST BENT 2 AT THE RABBITHASH, KENTUCKY SITE. THE
COAL FIRED BOILER VILL HAVE A GENERATING CAPACITY OF 650 My. THE UNIT IS
SCHEDULED TO STARTUP IN OCTOBER 1987.
CINCINNATI GAS & ELECTRIC
EAST BEND
2
MEM 650.0 MW (GROSS)
650.0 My (ESC)
CDAL
5.00 IS
LIME
9ABCOCK K UILCOX
ENERGY CONSUMPTION: 2.9X
STATUS i STARTUP 12/80
EAST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL (51 S)
FIRED BOILER UNDER CONSTRUCTION IN RABBITHASH, KENTUCKY. THE EMISSION
CONTROL SYSTEM CONSISTS OF A HOT SIDE ESP FOLLOWED BY THREE BABCOCK AND
UILCOX LIME FGD MODULES. THE 87Z CLEANED GAS WILL PASS THROUGH A CHEVRON
MIST ELIMINATOR BEFORE BEING WARMED BY AN INDIRECT HOT AIR REHEATER AND
EXITING THROUGH A BRICK LINED 65C FOOT STACK. THE SLUDGE FROM THIS CLOSED
y*TER LOOP SYSTEM WILL BE P02-0-TEC STABILIZED BEFORE DISPOSAL IN Ah ON
SITE LANDFILL. START UP IS EXPECTED IN DECEMBER 1980.
COLORADO UTE ELECTRIC ASSN
CRAIG
1
HEW 4*7.0 My (GROSS)
447.0 MU (ESC)
COAL
.45 IS SU9BITUMINOUS
LIMESTONE
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
STATUS 2 STARTUP 10/80
THE COLORADO UTE ELECTRIC ASSN IS PRESENTLY CONSTRUCTING CRAIG 1 IN CRAIG,
COLORADO. BOTH UNITS WILL FIRE PULVERIZED SUBBITUMINOUS COAL (0.45X S,
10,000 BTU/LB). THE EMISSION CONTROL SYSTEM FOR THIS UNIT yILL CONSIST OF
A HOT SIDE ESP AND FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS FOR
REMOVAL OF PARTICULATE MATTER AND 85X OF THE S02. THE SCRUBBER EXHAUST
WILL Bt HEATED BY AN IN-LINE STEAM COIL REHEATER AND WILL PASS THROUGH A
600 FOOT ACID LINED STACK. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP
AND THE STABILIZED SLUDGE WILL BE DISPOSED OF IN AN OFF SITE M1NEFUL.
UNIT 1 START UP IS EXPECTED IN OCTOB6R 1980.
COLORADO UTE ELECTRIC ASSN
CRAIG
2
VI* 45S.O My (GROSS)
400.0 My (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.5X
STATUS 1 STARTUP 12/79
THE CRAIG 2 UNIT OF THE COLORADO UTE ELECTRIC ASSN IS LOCATED IN CRAIG,
COLORADO AND FIRES PULVERIZED SUBBITUMINOUS COAL (0.45XS, 10,000 PTU/LB).
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP AND
FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS FOR REMOVAL OF PARTICULATE
MATTER AND 85X OF THE S02. THE SCRUBBER EXHAUST IS HEATED BY AN IN-LINE
STEAM COIL REHEATER AND PASSES THROUGH A 6CO FOOT ACID BRICK LINED STACK.
THE SYSTEM OPERATES IN A CLOSED LOOP, AND THE STABILIZED SLUDGE IS DIS-
POSED OF IN AN OFF SITE MINEFILL. START UP OF UNIT 2 WAS IN DECEMBER 1979.
COLORADO UTE ELECTRIC ASSN
CRAIG
S
«E» 447.0 MW (GROSS)
447.0 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIME/SPRAY DRYING
3ABCOCK t WILCOX
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/82
COLORADO UTE ELECTRIC ASSN. HAS PLANS FOR A NEW UNIT, CRAIG 3, TO BE
LOCATED IN CRAIG, COLORADO ALONG WITH UNITS 1 AND 2. THE UNIT WILL FIRE
PULVERIZED SUBBITUMINOUS COAL (0.45X S, 1C,000 BTU/LB). A CONTRACT HAS
BEEN AyARDED TO BABCOCK AND WILCOX FOR A DRY SCRUBBING SYSTEM UTILIZING
LIME INJECTION. THE UNIT WILL HAVE A FABRIC FILTER FOR PARTICLE CONTROL.
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN 1982.
COLUMBUS I SOUTHERN OHIO ELEC
CDNESVILLE
5
1EW 411.0 MW (GROSS)
411.0 MW (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.9X
STATUS 1 STARTUP 1/77
CONESVILLE 5 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JANUARY 1977, IS 89.51 (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT TALL ACID BRICK LINED STACK.
THE POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN WATER LOOP.
13
-------
EPA JTILITT FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of fGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLUM9US I SOUTHERN OHIO ELEC
CONESYILLE
&
MEW 411.0 MW (GROSS)
411.0 MW (ESC)
COAL
4.67 XS BITUMINOUS
LIME
MR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.9X
STATUS 1 STARTUP 6/78
CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1.393.893 ACFM OF FLUE
GAS AND PASSES IT TO TyO THIOSORBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JUNE 1978, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAPMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT TALL ACID BRICK LINED STACK.
THE POI-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN WATER LOOP.
COLUMBUS
POSTON
5
NEW
I SOUTHERN OHIO ELEC
425.0 MW (GROSS)
375.0 MW (ESC)
COAL
••*** xs
PROCESS NOT SELECTFD
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS. POSTON S
AND 6, TO BE LOCATED IN ATHENS. OHIO. THE COAL (2.5X S. 11,000 BTU/LB)
FIRED UNITS WILL UTILIZE EITHER A LIME, LIMESTONE. OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 5 IS EXPECTED IN 1986.
STATUS 6
STARTUP 8/86
COLUM3US t SOUTHERN OHIO ELEC
POSTON
&
NEH 425.0 MW (GROSS)
375.0 MW (ESC)
COAL
2.5P XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
STATUS 6 STARTUP 0/89
COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS, POSTON 5
AND 6, TO BE LOCATED III ATHENS, OHIO. THE COAL (2.5X S. 11,000 BTU/LB)
FIRED UNITS WILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 6 IS EXPECTED IN 1989.
COMMONWEALTH EDISON
P3WEPTON
51
RETROFIT 450.0 MW (GROSS)
450.0 MW (ESC)
COAL
J.53 XS
LI1ESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.6*
STATUS 1 STARTUP 4/80
COMMONWEALTH EDISON HAS RETROFITTED BOILER NUMBER 51 AT ITS POWERTON
STATION KITH A UOP LIMESTONE FGD SYSTEM. UNIT 51 IS ONE OF TWO IDENTICAL
BOILERS SUPPLYING STEAM TO AN 850 MW TURBINE. THE PULVERIZED COAL
(7.53X S, 10,500 BTU/LB) FIRED BOILER FEEDS FLUE 6AS THROUGH AN ESP
TO 3 TCA MODULES WHICH ARE DESIGNED TO REMOVE 74X OF THE S02. A STEAM
INDIRECT HOT AIR REHEATER BOOSTS THE TEMPERATURE BEFORE THE £AS EXITS
AN ACID BRICK LINED STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP,
AND THE SLUDGE IS POZ-0-TEC STABILIZED AND DISPOSED OF IN A LANDFILL.
THE FGD SYSTEM COMMENCED OPERATION IN APRIL, 1980.
COOPERATIVE POWER ASSOCIATION
C3AL CREFK
1
NEW 545.0 MW (GROSS)
327.0 MW (ESC)
COAL
.67 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ***»X
STATUS 1 STARTUP 7/79
COAL CRFEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (9.63X S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. HIST ELIMINATION IS PROVIDED BY A BULK ENTRAPMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90S. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE FLVASH STABILIZED SLUDCE IS
DISPOSED IN A CLAY LINED POND. UNIT 1 OPERATIONS BEGAN IN JULY 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
NEW 545.0 MW (GROSS)
327.0 MW (ESC)
COAL
.6? IS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: «**«X
STATUS 1 STARTUP 7/80
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63X S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES ?,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED 8V A BULK ENTRAPMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE FLVASH STABILIZED SLUDGE IS
DISPOSED OF IN A CLAY LINED POND. UNIT 2 COMMENCED OPERATIONS IN JULY
1980.
14
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of FGD SYSTEMS
J«IT IDENTIFICATION
ABSTRACT
DELMARVA POWER & LIGHT
DELAWARE CITY
1
RETROFIT 60.0 MW (GROSS)
60.0 MW (ESC)
COKE
7.00 XS FLUID PETROLEUM COKE
4ELLHAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: *«**X
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF OELHARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7-81 S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF 500*
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM Of FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE HIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
MELLMAN-LORO SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL, IS USED FOR S02 CON-
TROL. HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK. THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE. IT IS A
CLOSED LOOP WATER SYSTEM. IT WAS MADE OPERATIONAL IN MAY 1980.
DELMARVA POUFB & LIGHT
DELAWARE CITY
2
RETROFIT 60.0 "W (GROSS)
60.0 MM (ESC)
C3KE
7.00 XS FLUID PETROLEUM COKE
BELLMAN LORD
DAVY HCKEE
ENERGY CONSUMPTION: •«*«%
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND J OF CELFIARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY Of 500K
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE HIST ELIMINATOR
TO A WET FSP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
yELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL, IS USED FOR S02 CON-
TPOL. HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 500 FT.
STACK. THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE. IT IS A
CLOSED LOOP WATER SYSTEM. IT WAS HADE OPERATIONAL IN HAY 1980.
DELMARVA POWER * LIGHT
DELAWARE CITY
}
RETROFIT 6C.O "W (GROSS)
60.0 MW (ESC)
C OKE
7.CO XS FLUID PETROLEUM COKE
riELLMAN LORD
DAVY NCKEE
ENERGY CONSUMPTION: »«*«X
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY Of 500K
LB/HR EACH. THE BOILERS GENERATE STfcAH AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID HIST REMOVAL. A FOUR STAGE
WELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL, IS USED FOR S02 CON-
TROL. HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT A 503 FT.
STACK. THE EMISSION CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE. IT IS A
CLOSED LOOP WATER SYSTEM. IT WAS MADE OPERATIONAL IN MAY 1980.
DELMARVA POWER ft LIGHT
VIENNA
?
HEW 550.0 MW (GROSS)
550.0 MW (ESC)
COAL
2.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/87
DELMARVA POWER AND LIGHT IS PLANNING A NEW 550 MW (GROSS) UNIT, VIENNA 9,
BE CONSTRUCTED IN VIENNA, MARYLAND. THE UTILITY IS PRESENTLY CONSIDERING
A LIMESTONE FGD UNIT FOR EMISSION CONTROL. THE PULVERIZED COAL FIRED UNIT
WILL BURN COAL WITH AN AVERAGE SULFUR CONTENT OF 2.7X AND IS EXPECTED TO
COMMENCE OPERATIONS IN JUNE 1987.
DESERET GEN ( TRANS COOP
NOON LAKE
1
NEW 410.0 MW (GROSS)
410.0 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 9/84
MOON LAKE 1 IS A PULVERIZED COAL (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION AND TRANSMISSION COOP TO BE LOCATED IN
VERNAL, UTAH. A CONTRACT WAS AWARDED TO COMBUSTION ENGINEERING FOR
A WET LIMESTONE SCRUBBING SYSTEM HAVING A S02 REMOVAL EFFICIENCY OF 951.
THE SYSTEM WILL FEATURE A BAGHOUSE, SUPPLIED BY ECOLAIRE, TO REMOVE 99.6X
OF THE PARTICULATE MATTER. THE UNIT WILL OPERATE IN A CLOSED WATER LOOP
WITH SLUDGE DISPOSAL ON SITE IN A LANDFILL. OPERATIONS ARE SCHEDULED TO
COMMENCE IN SEPTEMBER 1984.
DESERET GEN 8
NOON LAKE
2
NEW
TRANS COOP
410.0 MW (GROSS)
410.0 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *•••*
STATUS 5 STARTUP 0/88
MOON LAKE 2 IS A PULVERIZED COAL (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION AND TRANSMISSION COOP TO BE LOCATED IN
VERNALi UTAH. THE UTILITY IS PRESENTLY REQUESTING BIDS FOR A MET LIME-
STONE SCRUBBING SYSTEM HAVING A S02 REMOVAL EFFICIENCY OF 95X. THE SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED TO REMOVE 99.6X OF THE PARTICULATE. THE
UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON SITE
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1988.
15
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 198C
SECTION 2
STATUS Of FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
DUQUESNE LIGHT
ELRAMA
1-4
RETROFIT 510.0 MM (GROSS)
510.0 MW (ESC)
COAL
2.20 XS
LIME
CrtENICO DIVISION, FNVIPOTECH
ENERGY CONSUMPTION: 3.5X
STATUS 1 STARTUP 10/75
ELRAMA 1-4 Of DUQUESNE LIGHT CONSISTS OF FOUR PULVERIZED COAL (2.2Z S,
11,350 BTU/LB) FIRED UNITS LOCATED IN ELRAMA, PENNSYLVANIA. THE EMISSION
CONTROL SYSTEM ON THIS SITE CONSISTS OF AN ESP FOLLOWED BY A MECHANICAL
COLLECTOR AND FIVE VARIABLE THROAT VENTURI LIME ABSORBER MODULES SUPPLIED
BY CHEMICO, WHICH ARE DESIGNED TO REMOVE 83* OF THE S02 FROM THE FLUE GAS.
THE CLEANED GAS PASSES THROUGH A DIRECT OIL FIRED REHEATER BEFORE EXITING
A 400 FOOT ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER
LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE IS HAULED TO AN OFF SITE LAND-
FILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER 1975.
BJQUESNE LIGHT
PHILLIPS
1-6
9ETROFIT 408.0 MW (GROSS)
408.0 MW (ESC)
COAL
1.92 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 7/73
THE PHILLIPS POWER STATION OF DUBUESNE LIGHT CONSISTS OF SIX DRY POTTOM
PULVERIZED COAL (1.92* S, 11,350 BTU^LB) FIRED UNITS LOCATED IN SOUTH
HEIGHT, PENNSYLVANIA. PARTICULATE CONTROL IS ACCOMPLISHED BY SIX ESP/
MECHANICAL COLLECTOR COMBINATIONS (ONE/BOILER). ONE TWO STAGE AND THREE
SINGLE STAGE VARIABLE THROAT VENTURI LIME FGD MODULES SUPPLIED BT CHEMICO
ARE DESIGNED TO REMOVE 832 OF THE S02 FROM THE FLUE GAS. TWO CHEVRON MIST
ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT OIL FIRED REHEATER WHICH RAIS-
ES THE GAS TEMPERATURE BY 20 DEC F BEFORE IT LEAVES VIA A 340 FOOT TALL
ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND
THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO AN OFF SITE LANDFILL. THE
SYSTEM HAS BEEN OPERATIONAL SINCE JUDY 1973.
EAST KENTUCKY POWER COOP
J.K. S11TH
1
1EW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
••••* XS
HOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 1/85
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TWO NEW UMTS. THE J.K.
SMITH UNITS 1 AND 2 WILL UTILIZE EITHER A DRY PROCESS OR A WET LIME
PROCESS FOR EMISSION CONTROL. UNIT 1 IS EXPECTED TO START UP IN JANUARY
1985.
EAST KENTUCKY POWER COOP
J.K. SMITH
2
NEW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
• •*•* XS
»ROCFSS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 1/87
THE EAST KENTUCKY POwER COOP HAS PLANS TO FIRE TWO NEW UMTS. THE J.K.
SPITH UNITS 1 AND 2 WILL UTILIZE EITHER A ORY PROCESS OR A WET LIME
PROCESS FOR EMISSION CONTROL. UNIT 2 IS EXPECTED TO START UP IN JANUARY
m?.
EAST KENTUCKY POWER COOP
SPURLOCK
2
NEW 500.0 MW (GROSS)
500.0 MW (ESC)
CDAL
3.50 XS
LME
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 1/81
SPURLOCK 2 Of EAST KENTUCKY POWER COOPERATIVE IS A BALANCED DRAFT PULVER-
IZED COAL (3.5* S, 11.UOO BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN MAYS-
VILLE, KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOL-
LOWED BY AN ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME FGD SYSTEM (90S
DESIGN SO? REMOVAL EFFICIENCY). FLUE GAS FROM UNIT ONE WILL BE USED TO
REHEAT THE CLEANED GAS. THE SYSTEM, SLATED FOR START UP IN JANUARY 1981,
WILL EMPLOY A CLOSED WATER LOOP AND POZ-0-TEC SLUDGE STABILIZATION.
FLORIDA POWER S LIGHT
-------
EP* UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
FLORIDA POWER I LIGHT
NARTIN
4
NEW 800.0 MW (GROSS)
800.0 «W (ESC)
CDAL
FLORIDA POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA. THE PULVERIZED COAL FIRED BOILERS
WILL HAVE A MW RATING OF 800 EACH. THE UTILITY IS CONSIDERING F6D AND
ALTERNATIVE METHODS FOR EMISSION CONTROL. THE START UP FOR UNIT 4 IS
PROJECTED FOR 1989.
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGT CONSUMPTION: ****X
STATUS 7 STARTUP 0/89
SENERAL PUBLIC UTILITIES
CDAL
1
NEW 625.0 MW (GROSS)
625.0 MW (ESC)
C3AL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 12/92
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MW UNIT, COAL 1.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.51 S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1992.
GENERAL PUBLIC UTILITIES
COAL
I
NEW 625.0 MV (GROSS)
625.0 MM (ESC>
CDAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»*X
STATUS 6 STARTUP 5/94
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 MW UNIT, COAL 2.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1994.
SENERAL PUBLIC UTILITIES
COAL
3
NEW 625.0 MM (GROSS)
625.0 ly (ESC)
COAL
3.5T XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 12/95
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 MW UNIT, COAL 3.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1995.
SENERAL PUBLIC UTILITIES
C3AL
t
NEW 625.0 MV (GROSS)
625.0 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***»»
STATUS 6 STARTUP 5/97
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MW UNIT, COAL 4.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1997.
SENERAL PUBLIC UTILITIES
COHO
1
NEW 690.0 MW (GROSS)
690.0 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.4X
STATUS 5 STARTUP 5/91
COHO 1 IS A (3.5X S) COAL FIRED UNIT PLANNED BY GENERAL PUBLIC UTILITIES T
BE LOCATED IN ERIE, PENNSYLVANIA. PRESENTLY BIDS ARE BEING REQUESTED. THE
UTILITY IS PRIMARILY CONSIDERING A LIME OR LIMESTONE NON-SLURRY TYPE FGD
SYSTEM. OPERATIONS ARE SCHEDULED TO COMMENCE IN MAY 1991.
17
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SENERAL PUBLIC UTILITIES
SEUARD
T
NEW 690.0 NW (GROSS)
690.0 HU (ESO
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.4X
STATUS 5 STARTUP 5/87
GENERAL PUBLIC UTILITIES IS PLANNING A NEW UNIT, SEUARD 7, TO BE BUILT IN
SEUARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY REQUESTING BIOS FOP AN F6D
SYSTEM, WITH NON-SLURRY TYPE LIME AND LIMESTONE SYSTEMS BEING THE
PRIMARY CONSIDERATION. START UP IS EKPECTED IN MAY 1987.
GRAND HAVEN BRD OF LIGHT I
J.B. SINS
s
NEW
COAL
2.75 XS
LIME
9ABCOCK t
65.0 MU (GROSS)
65.0 MU (ESC)
BITUMINOUS
WILCOX
PWR THE GRAND HAVEN BOARD OF LIGHT AND POWER'S J.B. SIMS 3 IS A BITUMINIOUS
COAL (2.75X S, 11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN
GRAND HAVEN, MICHIGAN. A CONTRACT HAS BEEN AWARDED TO BABCOCK AND WILCOX
TO SUPPLY TWO SPRAY TOWERS TO CONTROL S02 EMISSIONS. EACH SCRUBBER SYSTEM
WILL UTILIZE A CHEVRON MIST ELIMINATOR AND AN IN-LINE REHEATER. THE
SLUDGE IS TO BE DISPOSED OF IN AN OFF SITE LANDFILL. OPERATIONS ARE TO
COMMENCE IN JUNE 1983.
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 6/83
HOOSIER ENERGY
1EROM
1
NEU 490.0 MU (GROSS)
441.0 MU (ESC)
COAL
3.50 SS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: «***X
STATUS 2 STARTUP 5/82
MEROH 1 AND 2 ARE TWO NEW UNITS BEING BUILT BY HOOSIER ENERGY IN SULLIVAN
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WILL PRODUCE 1,732,000
ACFM OF FLUE GAS WHICH WILL BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
MITSUBISHI LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE
SYSTEM WILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDGE WILL
BE STABILIZED AND LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 1 IS SCHEDULED FOR MAY 1982.
HOOSIER ENERGY
4EROM
2
NEW 490.0 MU (GROSS)
441.0 MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****X
SIATUS 2 STARTUP 9/61
MEROH 1 AND 2 ARE TWO NEU UNITS BEING BUILT BY HOOSIER ENERGY IN SULLIVAN.
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WILL PRODUCE 1,732,000
ACFM OF FLUE GAS WHICH WILL BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
MITSUBISHI LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE
SYSTEM WILL UTILIZE BYPASS REHEAT AND. A 700 FOOT STACK. THE SLUDGE WILL
BE STABILIZED AND LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 2 IS SCHEDULED FOR SEPTEMBER 1981.
HOUSTON LIGHTING ( POWER
LIMESTONE
1
NEW 750.0 MM (GROSS)
750.0 MU (ESC)
COAL
1.08 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 5 STARTUP 12/84
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, TO BE LOCATED IH JEUITT, TEXAS. THE PULVERIZED COAL (1.081 S,
6177 BTU/LB) FIRED BOILER UILL UTILIZE A VET LIMESTONE SCRUBBING PROCESS
FOR PRIMARY S02 COLLECTION. A COLD SIDE ESP WILL ALSO BE USED FOR PRIMARY
PARTICLE CONTROL. THE UTILITY IS PRESENTLY REOUESTING/EVALUATING BIDS
FOR THE FGO SYSTEM. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN 1984.
HOUSTON LIGHTING t POWER
LIMESTONE
2
MEW 750.0 MU (GROSS)
750.0 MU (ESC)
COAL
1.08 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 1?/85
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, TO BE LOCATED IN JEUITT, TEXAS,. THE PULVERIZED COAL (1.08X S,
6177 BTU/LB) FIRED BOILER UILL UTILIZE A WET LIMESTONE SCRUBBING PROCESS
FOR PRIMARY S02 COLLECTION. A COLD SIDE ESP WILL ALSO BE USED FOR PRIMARY
PARTICLE CONTROL. THE UTILITY IS PRESENTLY REQUESTING/EVALUATING BIDS
FOR THE FGD SYSTEM. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS IN 198S.
18
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SFCTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
HOUSTON LIGHTING I POWER
4.A. PARISH
S
NEW 600.P MW (GROSS)
492.0 WW (ESC)
COAL
.60 XS SUBBITUPIINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *»**X
STATUS 2 STARTUP 11/82
W.A. PARISH 8 OF HOUSTON LIGHTING 1 POWER IS A PULVERIZED COAL C0.6X S,
8700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN THOMPSONS, TEXAS. CHEMICO
WILL SUPPLY A LIMESTONE FGD SYSTEM WHICH WILL REMOVE 82X OF THE FLUE
GAS S02. REHEAT WILL BE PROVIDED BY BYPASSING 18X OF THE PARTICULAR
CLEANED FLUE GAS. SLUDGE WILL BE OEWATERED, BLENDED WITH FLYASH, AND
DISPOSED IN AN ON SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE
IN NOVEMBER 1082.
INDIANAPOLIS POWER K LIGHT
PATRIOT
1
NEW 650.0 MW CGROSS)
65?.0 MW (ESC)
COAL
3.5? XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»*X
STATUS 6 STARTUP 0/87
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POWER fc LIGHT
PATRIOT
2
NEW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
3.5" XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **«*X
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POWER t LIGHT
PATRIOT
S
NEW 650.0 NW (GROSS)
650.0 MW (ESC)
COAL
S.5P XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***«X
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS. PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POWER t LIGHT
PETERSBURG
3
NEW 53?.0 MW (GROSS)
532.0 MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER AND LIGHT IS LOCATED IN PETERSBURG,
INDIANA, AND BURNS 3.2SX S BITUMINOUS COAL (11,000 BTU/LB). TWO COLD SIDE
ESP'S ARE LOCATED UPSTREAM OF 4 85X EFFICIENT UOP LIMESTONE TCA MODULES.
A HORIZONTAL MIST ELIMINATOR PRECEDES AN INDIRECT HOT AIR REHEATER THAT
BOOSTS THE GAS TEMPERATURE BY 30 DEC F BEFORE IT EXITS THE 616 FOOT RI6I-
FLAKE 4850 LINED STACK. STABILIZED SLUDGE IS DISPOSED IN AN ON SITE POND,
AND THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. THIS UNIT HAS BEEN
OPERATIONAL SINCE DECEMBER 1977.
INDIANAPOLIS POWER I LIGHT
PETERSBURG
4
NEW 530.0 MW (GROSS)
530.0 My (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 2.1X
STATUS 2 STARTUP 10/84
PETERSBURG 4 OF INDIANAPOLIS POWER AMD LIGHT IS A BITUMINOUS COAL (3.501 S
11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN PETERSBURG, INDIANA. THE
LIMESTONE FGD SYSTEM FOR THIS UNIT MILL BE SUPPLIED BY RESEARCH COTTRELL.
THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP, AND SLUDGE WILL BE POZ-0-
TEC STABILIZED BEFORE PONDING. START UP IS SLATED FOR OCTOBER 198*.
19
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 198C
SECTION 2
STATUS OF FGO SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
IOWA ELECTRIC LIGHT I PWR
GUTHRIE CO.
1
NEW 730.0 MW (GROSS)
720.0 MW CESC)
COAL
.40 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **•*»
STATUS 5 STARTUP 11/84
IOWA ELECTRIC LIGHT AND POWER HAS PLANS TO CONSTRUCT A 720 MW UNIT,
GUTHRIE COUNTY 1, TO BE LOCATED IN PANORA, IOWA. THE PULVERIZED SUBBITU-
HINDUS COAL (9.4X S, 8180 BTU/LB) FIRED BOILER WILL UTILIZE A WET LIME-
STONE SCRUBBING SYSTEM AND AN ESP FOR EMISSION CONTROL. THE CLEANED
FLUE GAS WILL EXIT A 650 FOOT STACK. THE UTILITY STARTED REQUESTING/
EVALUATING BIDS IN JANUARY 1960 AND HAS PROJECTED THE STARTUP TO BE
IN OCTOPER 1984.
JACKSONVILLE ELEC AUTHORITY
NEW PROJECT
1
NEW 600.0 MW (GROSS)
600.C MW (ESC)
COAL
3.or xs
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 12/85
THE JACKSONVILLF ELECTRIC AUTHORITY HAS PLANS FOR TWO NEk UNITS, NEW
GENERATING PROJECT 1 AND 2, TO BE LOCATED IN EAST PORT, FLORIDA. EACH
UNIT WILL BURN PULVERIZED COAL (2-4% S) AND SUPPLY 2,660,000 ACFM TO A
hET LIMESTONE FGD PROCESS AND AN ESP FOR EMISSION CONTROL. THE CLEANED
FLUE GAS IS TO EXIT A 285 FOOT STACK. UNIT 1 IS SCHEDULED TO COMMENCE
OPERATIONS IN 1965.
JACKSONVILLE ELEC AUTHORITY
NEW PROJECT
2
NEW 630.0 MW (GROSS)
600.0 MW (ESC)
COAL
3.00 TS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/87
THE JACKSONVILLE ELECTRIC AUTHORITY HAS PLANS FOR TWO NEk UNITS, NEW
GENERATING PROJECT 1 AND 2, TO BE LOCATED IN EAST PORT, FLORIDA. EACH
UNIT WILL BURN PULVERIZED COAL (2-41 S) AND SUPPLY 2,660,000 ACFM TO A
WET LIMESTONE FGD PROCESS AND AN ESP FOR EMISSION CONTROL. THE CLEANED
FLUE GAS IS TO EXIT A 285 FOOT STACK. UNIT 2 IS SCHEDULtD TO COMMENCE
OPERATIONS IN 1
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Or FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS POMER t LIGHT
JEFFREY
1
NEW 720.0 MU (GROSS)
5*0.0 MU (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 8/78
KANSAS CITY POMER AND LIGHT'S JEFFRE* 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (0.32X S. 8125 BTU/LB) UNIT IN UAMEGO, KANSAS. THE EMISSION CONTROL
SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED BY SIX (ONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN SO? REMOVAL EFFICIENCY IS SOX (INCLUDING A 30X BYPASS REHEAT).
THE UNIT HAS BEEN OPERATIONAL SINCE AUGUST 1978.
KANSAS POUER I LIGHT
JEFFREY
2
NEW 700.0 MU (GROSS)
490.0 MU (ESC)
COAL
.30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 4/80
UNIT 2, PRESENTLY OPERATING AT KANSAS POWER AND LIGHT'S JEFFREY ENERGY
CENTER IN JEFFREY, KANSAS, BURNS 0.3X S PULVERIZED COAL (8100 BTU/LB).
THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS OF A COLD SIDE ESP
AND COMBUSTION ENGINEERING LIMESTONE SPRAY TOWERS. A 30X FLUE GAS
BYPASS PROVIDES REHEAT OF THE CLEANED. GAS BEFORE IT EXITS THROUGH A
6CO FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. AND
THE SLUDGE IS STABILIZED WITH BOTTOM ASH AND PIPED TO AN ON-SITE CLAY
LINED POND. INITIAL OPERATIONS COMMENCED IN APRIL 198C.
KANSAS POUER & LIGHT
LAURENCE
4
RETROFIT 125.0 MW (GROSS)
125.0 MU (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 1/76
LAWRENCE 4 OF KANSAS POUER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIREt
PULVERIZED COAL (0.551 S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMPUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER IN JANUARY 1977. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAPMENT SEPARATOR FOLLOWING EACH OF THE TUO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DE6 F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
KANSAS POWER & LIGHT
LAURENCE
5
RETROFIT 420.0 MW (GROSS)
420.0 MU (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/71
LAURENCE 5 OF KANSAS POUER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAURENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BFD TAIL END SCRUBBER IN APRIL 1978. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, UITH A DESIGN S02 REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TUO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TUO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEG F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOUS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED UATER LOOP.
KENTUCKY UTILITIES
GREEN RIVER
1-3
RETROFIT 64.0 MU (GROSS)
64.0 MU (ESC)
COAL
4.OH XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3.1X
STATUS 1 STARTUP 9/75
GREEN RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRV BOTTOM PULVERIZED
BITUMINOUS COAL (4X S, 11,000 BTU/LB) FIRED UNITS LOCATED IN CENTRAL
CITY, KENTUCKY. EACH BOILER SUPPLIES 360.000 ACFM OF FLUE GAS TO A
VARIABLE THROAT VENTURI FOLLOUED BY AN AMERICAN AIR FILTER LIME MOBILE
BED CONTACTOR (BOX DESIGN S02 REMOVAL EFFICIENCY). A RADIAL VANE MIST
ELIMINATOR IS FOLLOUED BY A STEAM TUBE REHEATER AND A 165 FOOT STACK.
SLUDGE IS DISPOSED IN AN ON-SITE UNLINED POND, AND THE SYSTEM OPERATES
IN A CLOSED WATEK LOOP. THE SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER
1975.
LAKELAND UTILITIES
MCINTOSH
J
NEU 364.0 MU (GROSS)
364.0 MU (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK t UILCOX
ENERGY CONSUMPTION: ***«X
STATUS 2 STARTUP 8/81
MCINTOSH 3 OF LAKELAND UTILITIES IS HE IN 6 CONSTRUCTED IN LAKELAND,
FLORIDA. PABCOCK AND UILCOX HAS BEEN AWARDED A CONTRACT TO SUPPLY AN
85X EFFICIENT (S02) LIMESTONE FGD SYSTEM FOR THIS UNIT. THE EMISSION CON-
TROL SYSTEM UILL CONSIST OF A COLD SIDE ESP FOLLOWED BY TWO PARALLEL FGD
MODULES AND A 25G FOOT ACID BRICK LINED STACK. THE SYSTEM UILL OPERATE IN
A CLOSED UATER LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE UILL BE USED AS
A CONSTRUCTION BASE. CONSTRUCTION BEGAN IN NOVEMBER 1979 AND START
UP IS SCHEDULED TO BE IN AUGUST 1981.
21
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LANSIN6 BOARD OF WATER I LI6HT THE ERICKSON 2 STATION OF THE LANSING BOARD OF WATER AND LIGHT IS A
ERICKSON
2
NEW 160.Q MW (GROSS)
160.0 NW
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 1/87
PLANNED UNIT TO BE LOCATED IN DELTA TOWNSHIP, MICHIGAN. THE UNIT WILL
HAVE A MW RATING OF BETWEEN UO AND 250, DEPENDING ON WHETHER OTHER MUNI-
CIPALITIES WILL JOIN IN THIS PROJECT. THE UTILITY IS PRESENTLY CONSIDER-
ING THE USE OF FGD FOR EMISSION CONTROL. OPERATIONS ARE SCHEDULED TO
COMMENCE IN 1987.
LOS ANGELES DEPT OF WTR * PWR
INTERNOUNTAIN
1
NEW 820.0 MW (GROSS)
820.0 MW (ESC)
COAL
.79 XS SUBBITUHINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»*Z
STATUS 6 STARTUP 0/86
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND «, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERISED COAL (0.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM,
A HORIZONTAL WEIR TYPE SCRUBBER ALONG WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
WILL EXIT A 750 FOOT STACK. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1986.
LOS ANGELES DEPT OF WTR t PWR
1NTERNOUNTAIN
2
NEW 820.0 MW (GROSS)
820.0 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTIONt *****
STATUS 6 STARTUP 0/87
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 KW BOILER WILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER ALOfufc WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
WILL EXIT A 750 FOOT STACK. UNIT Z IS SCHEDULED TO COMMENCE OPERATIONS
IN 1987.
LOS ANGELES DEPT OF WTR 8 PWR
INTERNOUNTAIN
3
NEW 820.0 MW (GROSS)
820.0 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/88
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM,
A HORIZONTAL WEIR TYPE SCRUBBER ALONfi WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
WILL EXIT A 750 FOOT STACK. UNIT 3 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1988.
LOS ANGELES DEPT OF WTR K PWR
INTERMOUNTAIN
4
NEW 820.0 MW (GROSS)
820.0 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LINE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/89
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (C.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM,
A HORIZONTAL WEIR TYPE SCRUBBER ALONG WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FlUE GAS
WILL EXIT A 750 FOOT STACK. UNIT 4 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1989.
LOUISVILLE GAS » ELECTRIC
CANE RUN
4
RETROFIT 188.0 MW (GROSS)
188.0 MW (ESC)
COAL
3.75 XS BITUMINOUS
LINE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6*
STATUS 1 STARTUP 8/76
UNIT 4 AT LOUISVILLE GAS AND ELECTRIt'S CANE RUN STATION IS A PULVERIZED
BITUMINOUS COAL (3.75* S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. AN ESP AND TWO AMERICAN AIR FILTER CARBIDE LIME MOBILE BED ABSORBER
MODULES (85* DESIGN S02 REMOVAL) TREAT 734,000 ACFM OF FLUE GAS FROM THE
BOILER. TWO CHEVRON HIST ELIMINATORS/NODULE ARE FOLLOWED BY A DIRECT
COMBUSTION REHEATER AND A 250 FOOT STACK. THE WATER LOOP IS OPEN. AND
THE SLUDGE IS DISPOSED IN AN ON-SITE LINED POND. THIS RETROFIT SYSTEM
HAS BEEN OPERATIONAL SINCE AUGUST 1976.
22
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
RETROFIT 200.0 MW (GROSS)
200.0 NW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.5X
STATUS 1 STARTUP 1Z/77
CANE RUN 5 OF LOUISVILLE CAS AND ELECTRIC IS A PULVERIZED BITUMINOUS COAL
(3.75X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLt, KENTUCKY. THE
BOILER SUPPLIES 700,000 ACFM OF FLUE GAS TO AN EMISSION CONTROL SYSTEM
CONSISTING OF AN ESP FOLLOWED AND TWO COMBUSTION ENGINEERING 85X EFFICIENT
(DESIGN) CARBIDE LIME SPRAY TOWERS. A STEAM TUBE REHEATER RAISES THE GAS
TFMPERATURE 40 DEC F. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED. OPERATION OF THIS RETROFIT SYSTEM
BEGAN IN DECEMBER 1977.
LOUISVILLE GAS t ELECTRIC
CANE RUN
6
RETROFIT 299.0 MW (GROSS)
299.0 MW (ESC)
COAL
4.80 XS BITUMINOUS
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 1.0*
STATUS 1 STARTUP 4/79
LOUISVILLE GAS AND ELECTRIC'S CANE RUN 6 IS A PULVERIZED BITUMINOUS COAL
(4.BOX S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KENTUCKY. AOL/COMBUS-
TION EQUIPMENT ASSOCIATES SUPPLIED A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS UNIT. THE EMISSION CONTROL SYSTEM, DESIGNED TO REMOVE
951 OF THE FLUE GAS SOZ, CONSISTS OF A COLO SIDE ESP AND TWO TRAY TOWER
MODULES. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TWO
DIRECT COMBUSTION REHEATERS BEFORE EXITING A 518 FOOT STACK. THE WATER
LOOP IS OPEN, AND THE SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED POND.
FOR A ONE YEAR PERIOD FOLLOWING THE FIRST QUARTER OF OPERATION (WHICH BE-
GAN IN APRIL 1979), THE U.S.EPA WILL SUBSIDIZE A MAX OF $4.5 MM FOR OPER-
ATION, R&D, AND REPORT WRITING (NOT APPLIED TO ANY CAPITAL EXPENDITURES).
LOUISVILLE GAS t ELECTRIC
HILL CREEK
1
RETROFIT 358.0 MW (GROSS)
358.0 NW (ESC)
COAL
3.75 XS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4*
STATUS 2 STARTUP 1/81
MILL CREEK 1 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY UNDER CONSTRUC-
TION ON THIS PULVERIZED COAL (3.75X S, 11,500 BTU/L8) FIRED UNIT.
COMBUSTION ENGINEERING IS SUPPLYING THE LIME/LIMESTONE FGD SYSTEM
WHICH WILL COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1981.
LOUISVILLE 6AS ft ELECTRIC
HILL CREEK
2
RETROFIT 350.0 MU (GROSS)
350.0 MW (ESC)
COAL
J.75 XS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 2 STARTUP 12/81
MILL CREEK 2 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY UNDER CONSTRUC-
TION ON THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT.
COMBUSTION ENGINEERING IS SUPPLYING THE LIME/LIMESTONE FGD SYSTEM WHICH
WILL COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1982.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
3
NEW 442.0 MW (GROSS)
442.0 NW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 8/78
LOUISVILLE GAS AND ELECTRIC'S MILL CREEK 3 IS A 3.75X S COAL (11,500 BTU/
LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. AMERICAN AIR FILTER SUP-
PLIED A CARBIDE LIME FGD SYSTEM FOR THIS UNIT WHICH WAS DESIGNED TO REMOVE
85X OF THE SO? FROM THE FLUE GAS. AN ESP IS FOLLOWED BY FOUR MOBILE BED
SPRAY TOWERS AND A STEAM TUBE REHEATER. THE WATER LOOP IS OPEN, AND THE
FLYASH AND LIME STABILIZED SLUDGE IS PONDED. THIS UNIT HAS BEEN OPERATION-
AL SINCE AUGUST 1978.
LOUISVILLE GAS £ ELECTRIC
MILL CREEK
4
NEW S30.0 MW (GROSS)
495.0 MW (ESC)
COAL
5.75 XS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: • •••X
STATUS 2 STARTUP 6/82
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN LOUISVILLE,
KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP AND FOUR
MOBILE BED SPRAY TOWERS. THE SYSTEM'S WATER LOOP WILL BE CLOSED, AND
THE SLUDGE WILL BE STABILIZED WITH LIME AND FLVASH. STEAM TUBES HILL
PROVIDE REHEAT Of THE CLEANED GASES. THE SYSTEM IS SCHEDULED TO START
UP IN JUNE 1982.
23
-------
EPA UTILITY FGD SURVEY: JULT - SEPTEMBER 19f»0
SECTION 1
STATUS Of FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE SAS & ELECTRIC
PADDY'S RUN
6
RETROFIT 72.0 MW (GROSS)
72.P MW (ESC)
COAL
2.5P XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.8X
STATUS 1 STARTUP 4/73
UNIT 6 AT LOUISVILLE GAS AND ELECTRIC'S PADDY'S RUN STATION IS A DRY BOT-
TOM PULVERIZED COAL (2.5X S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. A RETROFIT CARBIDE LIME F6D SYSTEM BY COMBUSTION ENGINEERING TREATS
400,000 ACFM OF FLUE GAS FROM THE BOILER. AN ESP IS FOLLOWED BY TWO MARBLE
BED ABSORBERS, A DIRECT COMBUSTION REHEATER, AND A 250 FOOT STACK. MIST
ELIMINATION IS PROVIDED BY ONE CHEVRON/MODULE. THE LIME FIXATED SLUDGE IS
TRUCKED TO AN UNLINED POND, AND THE HATER LOOP IS CLOSED. THE FGD SYSTEM
BEGAN INITIAL OPERATIONS IN APRIL 1973.
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
1
NEW 575.0 MW (GROSS)
575.0 MW (ESC)
COAL
4.OP XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • »***
STATUS 5 STARTUP 7/85
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING (90* RFMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START UP IN JULY 1985.
LOUISVILLE GAS I ELECTRIC
TRIMBLE COUNTY
2
NEW 575.0 MW (GROSS)
575.0 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***»X
STATUS 5 STARTUP 7/88
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL B£ CLEANED BY ESP'S AND WET SCRUBBING (90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS SCHEDULED
FOR START UP IN 1988.
MAROUETTE BOARD OF LIGHT £ PWR
SH1RAS
3
NEW 44.0 MW (GROSS)
44.0 MW (ESC)
COAL
**••• XS
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • ***!
STATUS 5 STARTUP 10/82
SHIRAS 3 OF THE MARQUETTE BOARD OF LIGHT AND POWER IS K PULVERIZED COAL
FIRED BOILER PLANNED FOR LOCATION IN MARBUETTE, MICHIGAN. PRESENTLY,
THE UTILITY IS REQUESTING BIDS FOR A DRY LIME SCRUBBING PROCESS TO
CONTROL EMISSIONS. THE UTILITY WILL UTILIZE A FABRIC FILTER TO OBTAIN
A PARTICLE REMOVAL EFFICIENCY OF 99.8X. THE UNIT IS SCHEDULED TO
COMMENCE OPERATIONS IN OCTOBER 1982.
MICHIGAN SO CENTRAL PWR AGENCY THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POWER AGENCY IS TO BE CON-
55.0 MW (GROSS)
55.0 MW (ESC)
PROJECT
t
NEW
COAL
2.25 XS
LIMESTONE
9ABCOCK t WILCOX
ENERGY CONSUMPTION: •***X
STATUS 3 STARTUP 6/62
STRUCTED IN LITCHFIELD, MICHIGAN, AND WILL UTILIZE A UET LIMESTONE FGD
PROCESS. THE PULVERIZED COAL FIRED BOILER WILL FEED ITS FLUE GAS THROUGH
A HOT SIDE ESP FOLLOWED BY A BABCOCK AND WILCOX LIMESTONE SPRAY TOWER.
THE CLEANED GAS WILL PASS THROUGH A MIST ELIMINATOR BEFORE BEING WARMED
BY AN IN-LINE REHEATER AND EXITING A 250 FOOT STACK. THE SLUDGE IS TO
BE DISPOSED OFF SITE. START UP IS SCHEDULED FOR JUNE 1982*
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
5
NEW 890.0 MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: • *•*»
STATUS 4 STARTUP 0/90
UNIT 1 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.5* S) FIRED
BOILER. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH
COMBUSTION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
24
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
&
NEW 890.0 MW (GROSS)
890.0 AW (ESC)
COAL
.50 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **«»t
STATUS 4 STARTUP 0/92
UNIT Z Of THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.51 S) FIRED
BOILER. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH
COMBUSTION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
KIDDLE SOUTH UTILITIES
UNASSIGNED
1
NEW 890.0 MW (GROSS)
890.0 MM (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS I STARTUP 0/89
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS,
THE PLANT NAME HAS NOT BEEN ASSIGNED. THE PL1NT WILL BE LOCATED
SOMEWHERE IN LOUISIANA. STARTUP IS SCHEDULED FOR 1989.
KIDDLE SOUTH UTILITIES
UNASSIGNED
2
NEW 890.0 Mw (GROSS)
890.0 MW (ESC)
COAL
.5H XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 4 STARTUP 0/93
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED. THE PLANT WILL BE LOCATED
SOMEWHERE IN LOUISIANA. STARTUP IS SCHEDULED FOR 1993.
IIDCILE SOUTH UTILITIES
41LTON
1
NEW 890.0 MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **«*X
STATUS 4 STARTUP 0/88
WILTON 1 IS A COAL (.501 S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. STARTUP IS SCHEDULED FOR 1988.
MIDDLE SOUTH UTILITIES
MILTON
2
NEW 890.0 MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 0/91
WILTON 2 IS A COAL (.SOX S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. STARTUP IS SCHEDULED FOR 1991.
MINNESOTA POWER t LIGHT
CLAY BOSWELL
4
NEW 554.0 MW (GROSS)
475.0 MW (ESC)
COAL
.94 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.JX
STATUS 1 STARTUP 4/80
CLAY BOSWELL 4 OF MINNESOTA POWER AND LIGHT IS A SUBBITUMINOUS COAL (0.94X
S, 8896 BTU/LB) FIRED UNIT LOCATED IN COHASSET, MINNESOTA. PEABODY
PROCESS SYSTEMS HAS SUPPLIED A LIME/ALKALINE FLYASH SYSTEM WHICH
IS DESIGNED TO REMOVE 64.6X OF THE S02 IN THE FLUE GAS. TWO HOT SIDE ESP'S
ARE FOLLOWED BY VENTURI/SPRAY TOWER JRAINS. MIST ELIMINATION IS PROVIDED
BY A SIEVE TRAY FOLLOWED BY A SPIN VANE CHEVRON, AND REHEAT IS SUPPLIED
BY BYPASSING 5X OF THE FLUE GAS. THE SYSTEM OPERATES IN A CLOSED WATER
LOOP MODE, AND THE SLUDGE IS DISPOSED IN A LINED POND. OPERATIONS
COMMENCED IN APRIL 1980.
25
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION I
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MINNKOTA POWER COOPERATIVE
HILTON R. YOUN6
2
MEW 440.0 MW (GROSS)
185.0 'NW (ESC)
COAL
.70 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 1.6Z
STATUS 1 STARTUP 9/77
MINNKOTA POWER COOPERATIVE'S HILTON R. YOUNG 2 IS A CYCLONE FIRED LIGNITE
(0.70XS, 6500 BTU/LB) BOILER LOCATED IN CENTERt NORTH DAKOTA. THE BOILER
PRODUCES 2,021,400 ACFH OF FLUE GAS, HALF OF WHICH IS CLEANED BY TWO ESP'S
AND TWO ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME/ALKALINE FLYASH SPRAY
TOWERS (75X DESIGN S02 REMOVAL EFFICIENCY). THE CLEANED GAS PASSES THROUGH
A CHEVRON MIST ELIMINATOR BEFORE IT JOINS A 151 BYPASS REHEAT. ALONG WITH
THE UNSCRUBBED CAS, EXITS A 550 FOOT STACK. THE WATER LOOP IS OPEN, AND TM
SLUDGE IS TRUCKED TO AN OFF-SITE MINEFILL. OPERATIONS BEGAN IN 1977.
MONONGAHELA POWER
PLEASANTS
1
NEW 618.0 MW (GROSS)
618.0 MW (ESC)
COAL
3.70 XS BITUMINOUS
LIME
BABCOCK I WILCOX
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 3/79
NONONGAHELA POWER PLEASANTS 1 IS A BITUMINOUS COAL (3.70S S, 12,150
BTU/LB) FIRED BOILER IN BELMONT, WEST VIRGINIA. BABCOCK AND WILCOX SUP-
PLIED A LINE FGD SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS SO? FROM
THIS UNIT. THE EMISSION CONTROL SYSTEM INCLUDES AN ESP UPSTREAM OF FOUR
SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1200 FOOT PLACITE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM ON THIS
UNIT HAS BEEN OPERATIONAL SINCE MARCH 1979.
HONONGAHELA POWER
PLEASANTS
2
NEW 618.0 MW (GROSS)
618.0 NW (ESC)
COAL
4.50 XS BITUMINOUS
LIME
BABCOCK S WILCOX
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 10/80
HONONGAHELA POWER PLEASANTS 2 IS A BITUMINOUS COAL U.5X Si 12.15C
BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN BELMONT, WEST VIRGINIA. BABCOCK
AND WILCOX IS SUPPLYING A LIME F60 SYSTEM DESIGNED TO REMOVE 90X OF THE
BOILER FLUE GAS S02. THE EMISSION CONTROL SYSTEM ON THIS UNIT WILL INCLUDE
AN ESP UPSTREAM OF FOUR SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM
WILL PROVIDE REHEAT OF THE CLEANED 6*5 BEFORE IT IS DISCHARGED THROUGH A
1200 FOOT PLACITE LINED STACK. THE SYSTEM WILL OPERATE IN AN OPEN WATER
LOOP. F60 SYSTEM START UP IS EXPECTED IN OCTOBER 1980.
MONTANA POWER
COLSTRIP
1
NEW 360.0 MW (GROSS)
360.0 MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 9/75
COLSTRIP 1 OF MONTANA POWER IS A SUBBITUMINOUS COAL (0.77X S, 8843 6TU/LB>
FIRED UNIT LOCATED IN COLSTRIP. MONTANA. ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON HIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 500
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN SEPTEMBER 1975.
MONTANA POWER
COLSTRIP
2
NEW 360.0 MW (GROSS)
360.0 MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
COLSTRIP 2 Of MONTANA POWER IS A SUBBITUMINOUS COAL (C.77X S, 8843 BTU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONTANA. ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS. A STEAM TUBE REHEATER, AND A SCO
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY 1976. *
MONTANA POWER
COLSTRIP
3
NEW 700.0 NW (GROSS)
700.0 HW (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: *«*«X
STATUS 2 STARTUP 5/83
MONTANA POWER'S COLSTRIP 3 IS A LOW SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN
AWARDED TO ADL/COHBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLYASH
FGD SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR 1983.
26
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA POWER
COLSTRIP
4
NEW 700.0 MW (GROSS)
700.0 MW (ESC)
COAL
.70 XS
LIKE/ALKALINE FLVASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: *«**X
STATUS 2 STARTUP 3/84
MONTANA POWER'S COLSTRIP 4 IS A LOU SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN
AWARDED TO ADL/COMBUST10N EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLYASH
FED SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR 1984.
MONTANA-DAKOTA UTILITIES
COYOTE
1
NEW 440.0 MM (GROSS)
440.0 MW (ESC)
COAL
.87 XS LIGNITE
SODIUM CARBONATE/SPRAY DRYING
MHEELABRATOR-FRYE/R.I.
ENERGY CONSUMPTION: 1.1X
STATUS 2 STARTUP 3/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LIGNITE (0.87X S, 70SO BTU/LB)
BOILER UNDER CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT IS JOINTLY
OWNED BY FIVE UTILITIES. WITH MONTANA-DAKOTA UTILITIES BEING THE MAJOR
OWNER AND CONSTRUCTOR. A SODIUM CARBONATE DRV fGD SYSTEM DESIGNED TO
REMOVE 70X OF THE S02 IS BEING SUPPLIED BY WHEELABRATOR-FRYE AND ROCKWELL
INTERNATIONAL. THE SPRAY DRYER/6A6HOUSE SYSTEM IS SCHEDULED TO START UP
IN 1981.
HUSCATINE POWER I WATER
NUSCATINE
9
NEW 166.0 MW (GROSS)
166.0 MW (ESC)
COAL
3.00 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.6X
STATUS 3 STARTUP 9/82
HUSCATINE 9 IS A PULVERIZED BITUMINOUS COAL (31 S, 11,200 BTU/LB) fIRED
UNIT PLANNED BY MUSCATINE POWER AND WATER TO BE LOCATED IN MUSCAT1NE,
IOWA. A CONTRACT WAS AWARDED TO RESEARCH COTTRELL FOR A LIMESTONE UNIT FOR
EMISSION CONTROL. THE FGD SYSTEM WILL FEATURE AN ESP, TWO 100X CAPACITY
TOWERS, STEAM COIL REHEAT, A CLOSED WATER LOOP. AND FORCED OXIDATION OF
THE SLUDGE BEFORE LANDFILL. THE DESIGN S02 REMOVAL WILL BE 94X. START UP
WILL TAKE PLACE IN 1982.
NEBRASKA PUBLIC POWER DISTRICT FOSSIL III 1 IS A PULVERIZED SUBBITUMINOUS COAL (0.36X S, 8500 BTU/LB)
FOSSIL III
1
NEW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
.36 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••«*X
STATUS 6 STARTUP 3/87
FIRED UNIT PLANNED BY THE NEBRASKA PUBLIC POWER DISTRICT TO BE LOCATED
NEAR SARGENT, NEBRASKA. THE UTILITY IS CONSIDERING A DRY SCRUBBING
FGD PROCESS TO CONTROL EMISSIONS FROM THE 650 MW BOILER. STARTUP FOR
THE UNIT IS SCHEDULED FOR 1987.
NEVADA POWER
HARRY ALLEN
1
NEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
••*•* XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/86
NEVADA POWER'S HARRY ALLEN 1 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1986.
NEVADA POWER
HARRY ALLEN
2
NEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****!
STATUS 6 STARTUP 6/87
NEVADA POWER'S HARRY ALLEN 2 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1987.
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
HARRY ALLEN
3
NEW
COAL
500.0 MW (GROSS!
500.0 MW (ESC)
NEVADA POWER'S HARRY ALLEN 3 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT VET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1988.
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/86
NEVADA POWER
HARRY ALLEN
4
NEW 500. 0 MW (GROSS)
500.0 MW (ESC)
NEVADA POWER'S HARRY ALLEN * IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEK. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1989.
COAL
XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 6/89
NEVADA POWER
REID GARDNER
1
RETROFIT 125.0 MW (GROSS)
125.0 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****!
STATUS 1 STARTUP 5/74
REID GARDNER 1 IS A WET BOTTOM LOW SULFUR COAL (0.5X S, 12,450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR PEHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 901. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1974.
NEVADA POWER
REID GARDNER
2
RETROFIT 125.0 MU (GROSS)
125.0 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ••••X
STATUS 1 STARTUP 4/74
REID GARDNER 2 IS A WET BOTTOM LOW SULFUR COAL (O.SX «, 12,450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICIPATE CONTROL is PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR flEHEATER
AND A ZOO FOOT STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN SO? REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL 1974.
NEVADA POWER
REID GARDNER
3
NEW 125.0 MW (GROSS)
125.0 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 6/76
REID GARDNER 3 IS A WET BOTTOM LOW SULFUR COAL (O.SX S, 12,450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADL/COMBUST ION EQUIPMENT ASSOCI-
ATES CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFORATED PLATE WASH
TOWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90T. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1976.
NEVADA POWER
REID GARDNER
4
NEW 250.0 MW (GROSS)
25P.O MW (ESC>
COAL
.75 XS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: •••*:
STATUS 4 STARTUP 4/83
REID GARDNER 4 OF NEVADA POWER IS A COAL (0.75X S, 12,450 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN MOAPA, NEVADA. A LETTER OF INTENT HAS BEEN
SIGNED WITH COMBUSTION EQUIPMENT ASSOCIATES TO PROVIDE A SODIUM CARBONATE
FGD SYSTEM. A BAGHOUSE WILL PRECEED THE FGD SYSTEM FOR PARTICLE
CONTROL' CONSTRUCTION IS EXPECTED TO BEGIN IN 1980, AND START UP IS
EXPECTED IN 1983.
28
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
EARNER VALLEY
1
NEW 295.0 MW (GROSS)
295.0 MW (ESC)
COAL
1.15 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 6/85
NEVADA POWER'S WARNER VALLEY 1 IS A PLANNED COAL (1.15X S) FIRED UNIT TO
BE LOCATED IN ST. GEORGE, UTAH. THE UTILITY IS CURRENTLY EVALUATING BIDS
FOR AN FGD SYSTEM. NO ANNOUNCEMENTS HAVE VET BEEN MADE CONCERNING THE
EMISSION CONTROL STRATEGY FOR THIS UNIT. START UP IS EXPECTED IN JUNE
1985.
NEVADA POWER
EARNER VALLEY
2
NEW 295.0 MW (GROSS)
295.0 MW (ESC)
COAL
1.15 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 6/86
NFVADA POWER'S WARNER VALLEY 2 IS A PLANNED COAL (1.15X S> FIRED UNIT TO
TO BE LOCATED IN ST. GEORGE, UTAH. THE UTILITY IS CURRENTLY EVALUATING
FOR AN FGD SYSTEM. NO ANNOUNCEMENTS HAVE YET BEEN MADE CONCERNING THE
EMISSION CONTROL STRATEGY FOR THIS UNIT. START UP IS EXPECTED IN JUNE
1986.
NEW YORK STATE ELEC & GAS
SOMERSET
1
NEW 625.0 MU (GROSS)
625.0 MW (ESC)
COAL
2.29 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS S STARTUP 6/84
THE SOMERSET 1 UNIT OF THE NEW YORK STATE ELECTRIC t 6AS CORP. IS A
PULVERIZED COAL BOILER LOCATED IN SOMERSET, NEW YORK. THE BOILER
GENERATES A FLUE GAS FLOW OF 2,227,000 ACFM AND FIRES A BITUMINOUS COAL
WITH AN AVERAGE SULFUR CONTENT OF 2.2X AND AN AVERAGE HEAT CONTENT OF
12,400 BTU/LB. A COLD SIDE ESP WITH A DESIGN EFFICIENCY OF 99.771! WILL
PROVIDE THE PRIMARY PARTICULATE REMOVAL. A LIMESTONE ABSORBER WITH A
DESIGN REMOVAL EFFICIENCY OF 90X WILL BE USED FOR S02 REMOVAL. THE
SYSTEM WILL OPERATE IN A CLOSED LOOP MODE. THE SLUDGE IS TO BE DEWATERED
AND STABILIZED BEFORE BEING LANDFILLED. OPERATIONS ARE SCHEDULED FOR 1984.
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY
66
RETROFIT 100.0 *w (GROSS;
100.0 MW (ESC)
COAL
1.80 XS
A8UEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 4/82
CHARLES R. HUNTLEY 66 OF NIAGARA POWER COOP IS A PULVERIZED COAL (1.8X S,
12,500 BTU/LB) FIRED UNIT LOCATED IN BUFFALO, NEW YORK. A CONTRACT WAS
AWARDED TO ROCKWELL INTERNATIONAL FOR THE DESIGN AND INSTALLATION OF A 9CX
EFFICIENT RETROFIT AQUEOUS CARBONATE FGD SYSTEM WHICH WILL PRODUCE ELEMEN-
TAL SULFUR AS AN END PRODUCT. FUNDS ARE BEING PROVIDED BY THE U.S.EPA AND
THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. A SPRAY DRYER WILL BE
FOLLOWED BY TWO BANKS OF EIGHT CYC LOWES AN ESP, AND A 200 FOOT STEEL LINED
STACK. THE WATER LOOP WILL BE OPEN. START UP OF THE FGD SYSTEM WILL BE IN
1982.
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
RETROFIT 116.0 MW (GROSS)
115.0 RW (ESC)
COAL
$.50 XS
WELLNAN LORD
DAVY MCKFE
ENERGY CONSUMPTION
STATUS 1
12.U
STARTUP 7/76
NORTHERN INDIANA PUBLIC SERVICE'S DEAN H. MITCHELL 11 IS A COAL (3.5X S,
11,000 BTU/LB) FIRED UNIT LOCATED IN GARY, INDIANA. A RETROFIT UELLMAN
LORD FGD SYSTEM BY DAVY POWERGAS HAS BEEN OPERATING ON THIS UNIT SINCE
JULY 1976. AN ESP IS FOLLOWED BY A VARIABLE THROAT VENTURI SCRUBBER
AND A TRAY TOWER ABSORBER (90X DESIGN S02 REMOVAL EFFICIENCY). A DIRECT
COMBUSTION RAISES THE CLEANED GAS TEMPERATURE SO DEG F BEFORE THE GAS
IS DISCHARGED THROUGH A 166 FOOT STAINLESS STEEL AND FRP LINED STACK.
ELEMENTAL SULFUR AND SULFATE IS PRODUCED BY THE PROCESS DEVELOPED BY
ALLIED CHEMICAL. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
NORTHERN INDIANA PUB SERVICE SCHAHFER 17 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
SCHAHFER
17
NEW 421.0 MW (GROSS)
421.0 HW (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/83
UNIT PLANNED FOR CONSTRUCTION IN UHEATFIELD, INDIANA. THE UTILITY HAS
AWARDED A CONTRACT TO FMC FOR THE INSTALLATION OF A DUAL ALKALI
FGD SYSTEM AT THIS UNIT. PARTICULATE MATTER WILL BE COLLECTED BY AN ESP
AND THE SYSTEM WILL INCLUDE A REHEATED. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE 1983.
29
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NORTHERN INDIANA PUB SERVICE
SCHAHFER
IB
NEW 421.0 NW (GROSS)
421.0 MW
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PACIFIC POWER ( LIGHT
JIN BRIDGER
1
RETROFIT 550.0 MW (GROSS)
S5D.O MW (ESC)
COAL
.56 XS SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**X
STATUS % STARTUP 0/88
PACIFIC POWER AND LIGHT'S JIM BRID6E8 1 IS A DRV BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (O.S6XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING. THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR SO? CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. STARTUP IS SCHEDULED
FOR 1988.
PACIFIC POWER t LIGHT
JIM BRID6ER
Z
RETROFIT 550.0 HW (GROSS)
550.0 MW (ESC)
COAL
.56 XS SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••««!
STATUS 5 STARTUP 0/84
PACIFIC POWER AND LIGHT'S JIM BRIDGED 2 IS A DRV BOTTOM PULVERIZED SUB-
BITUMINOUS COAL C0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING. THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. STARTUP IS SCHEDULED
FOR 1984.
PACIFIC POWER ( LIGHT
JIM BRIDGER
3
RETROFIT SSO.O MW (GROSS)
5SO.O MW (ESC)
COAL
.56 XS SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ««**X
STATUS 5 STARTUP 0/86
PACIFIC POWER AND LIGHT'S JIM BRIDGED 3 IS A DRV BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING. THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFW OF FLUE GAS, IS BEING PLANNED. A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. STARTUP IS SCHEDULED
FOR 1986.
PACIFIC POWER t LIGHT
JIM BRIDGER
4
HEW 550.0 MW (GROSS)
550.0 MW (ESC)
COAL
.56 XS SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: .21
STATUS 1 STARTUP 9/79
PACIFIC POWER AND LIGHT'S JIM BRIDGES 4 IS A DRV BOTTOM PULVERIZED
SUBBITUMINOUS COAL (0.56X S, 9300 BTU/LB) FIRED BOILER LOCATED IN
ROCK SPRINGS, WYOMING. A 91X EFFICIENT SODIUM CARBONATE FGD SYSTEM FOR
THIS UNIT WAS SUPPLIED BY THE AIR CORRECTION DIVISION OF UOP. A COLO
SIDE ESP TREATS 2,720,000 ACFM OF FLUE GAS, FOLLOWED BY THREE SIEVE
TRAY ABSORBERS. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. A
SYSTEM CHECK OUT WAS CONDUCTED IN JULY 1979, AND OPERATIONS BEGAN
IN SEPTEMBER 1979.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
NEW 917.0 MW (GROSS)
917.0 HW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 6.OX
STATUS 1 STARTUP 12/75
BRUCE MANSFIELD 1 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IN SHIPPIN6PORT,
PENNSYLVANIA. A CHEMICO TH10SORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.1X) FROM 3,350,000 ACFM OF FLUE GAS. THE FGD SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT COMBUS-
TION REHEATERS, AND A 950 FOOT FLAKE6LASS STACK SHARED BY UNITS 1 AND 2.
THE WATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF SITE LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE DECEMBER
1975.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEW 917.0 MW (GROSS)
917.0 MW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
CHEMICO DIVISION* ENVIROTECH
ENERGY CONSUMPTION: 6.OX
STATUS 1 STARTUP 7/77
BRUCE MANSFIELD 2 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IN SHIPPINGPORT,
PENNSYLVANIA. A CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND SO? (92.1X) FROM 3,350,000 ACFM OF FLUE GAS. THE F6D SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT COMBUS-
TION REHEATERS, AND A 950 FOOT FLAKECLASS STACK SHARED BY UNITS 1 AND 2.
THE WATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF SITE LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
31
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION I
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PENNSYLVANIA POWER
9RUCE MANSFIELD
J
NEW 917.0 MW (GROSS)
917.0 NW
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE INDIANA
GIBSON
5
NEW 450.0 Mw (GROSS)
6SO.O MW
COAL
.80 XS SUBBITUMINOUS
riELLMktt LORD
DAVY HCKEE
ENER6Y CONSUMPTION: 4.6X
STATUS 1 STARTUP 8/78
SAN JUAN 2 OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL (0.8X S, 8100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFH OF
FLUE GAS TO A RETROFIT WELLMAN LORD fGD SYSTEM BY DAVY POVERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODUCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
NEW 534.0 MU (GROSS)
534.0 MU (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS 1 STARTUP 12/79
SAN JUAN 3 IS A COAL (0.8X S, 8100 BTU/L8) FIRED UNIT OF THE PUBLIC
SERVICE OF NEW MEXICO AND IS LOCATED IN WATERFLOW, NEW MEXICO. THE FGD
SYSTEM, SUPPLIED BY DAVY POWERGAS IS AN INTEGRATION OF THE WELLNAN
LORD 502 RECOVERY PROCESS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR
PROCESS. FIVE (OKE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSORBER (90X DE-
SIGN SO? REMOVAL) TRAINS FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AIR
REHEATER BOOSTS THE GAS TEMPERATURE 50 DEG F. THE SYSTEM OPERATES
IN A CLOSED WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER 1979.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
t
NEW 534.0 MU (GROSS)
534.0 HU (ESC)
COAL
.80 XS SUBBITUHINOUS
rfELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS 2 STARTUP 6/82
SAN JUAN 4 IS A COAL (0.8X S, 8100 BTU/LB) FIRED UNIT OF THE PUBLIC SER-
VICE OF NEW MEXICO UNDER CONSTRUCTION IN WATERFLOW, NEW MEXICO. THE F6D
SYSTEM BEING SUPPLIED BY DAVY POWERGAS IS AN INTEGRATION OF THE WELLMAN
LORD S02 RECOVERY PROCESS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR
PROCESS. FIVE (ONE SPARE) VENTURI SCftUBBER/SPRAY TOWER ABSORBER (90X DE-
SIGN SOZ REMOVAL) TRAINS WILL FOLLOW A HOT SIDE ESP. AN INDIRECT HOT MR
REHEATER WILL BOOST THE GAS TEMPERATURE 50 DEG F. THE SYSTEM WILL OPERATE
IN A CLOSED WATER LOOP MODE. START UP IS EXPECTED IN JUNE 1982.
PWR AUTHORITY OF STATE OF NY
FOSSIL
NEW 700.0 MU (GROSS)
700.0 MU (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 6 STARTUP 4/87
THE POWER AUTHORITY OF NEW YORK PLANS A NEW 3.OX SULFUR COAL FIRED UNIT
WHICH WILL BE LOCATED AT THE ARTHUR KILL FACILITY ON STATEN ISLAND. THE
UTILITY IS PRESENTLY CONSIDERING FGD SYSTEMS FOR THIS UNIT. PUBLIC SERVICE
COMMISSION HEARINGS ARE CURRENTLY IN PROGRESS. START UP IS EXPECTED IN
APRIL 1987.
33
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of F60 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SALT RIVER PROJECT
CORONADO
1
NEW 350.0 HW (CROSS)
280.0 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIMESTONE
PULLMAN KCLL06G
ENERGY CONSUMPTION: 4.31
STATUS 1 STARTUP 11/79
SALT RIVER PROJECT'S CORONADO 1 IS A DRY BOTTOM PULVERIZED SUBBITUHINOUS
COAL (1.0X S, 8300 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS.
ARIZONA. PULLMAN KELLOGG SUPPLIED THE TWO LIMESTONE HORIZONTAL WEIR SPRAV
TOWERS WHICH REMOVES 82.SX OF THE S02 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL HIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS PROVIDES REHEAT. THE WATER LOOP IS AN OPEN MODEi AND THE
UNSTABILIZED SLUDGE IS DISPOSED IN AN UNLINED POND. START UP HAS
IN NOVEMBER 1979.
SALT RIVER PROJECT
CORONADO
2
NEW 350.0 Mu (GROSS)
280.0 MU (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIMESTONE
PULLMAN KELL066
ENERGY CONSUMPTION: 4.3X
STATUS 1 STARTUP 7/80
SALT RIVER PROJECT'S CORONADO 2 IS * DRY BOTTOM PULVERIZED SUBBITUMINOUS
COAL (1.0X S, 8300 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS, ARIZONA.
PULLMAN KELLOGG SUPPLIED TWO LIMESTONE HORIZONTAL WEIR SPRAY TONERS
WHICH REMOVES 82.SX OF THE S02 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL HIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS PROVIDES REHEAT. THE WATER LOOP IS AN OPEN MODE, AND THE
UNSTABILIZED SLUDGE IS DISPOSED IN AN UNLINED POND. START UP WAS IN
JULY 1980.
SALT RIVER PROJECT
CORONADO
3
NEW 400.0 HW (GROSS)
280.0 MW (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUHPTION: 3.8X
STATUS 6 STARTUP 0/89
CORONADO 3 IS A DRV BOTTOM PULVERIZED SUBBITUMINOUS COAL (.60* S, 8300 BTU
/LB) FIRED UNIT PLANNED BY SALT RIVER PROJECT TO BE LOCATED IN ST. JOHN'S,
ARIZONA. THE UTILITY IS PRESENTLY CONSIDERING THE INSTALLATION OF TWO HOR-
IZONTAL SPRAY TOWERS UTILIZING LIMESTONE AS THE ABSORBENT. PLANS FOR AN
EMISSION CONTROL SYSTEM HAVE NOT BEEN FINALIZED. THE SYSTEM WILL HAVE A
20X BYPASS REHEAT, AND THE SLUDGE WILL PROBABLY BE PONDED. SCHEDULED OPER-
ATION DATE IS 1989.
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
1
NEW 400.0 MW (GROSS)
400.0 MW (ESC)
COAL
1.7C XS LIGNITE
LIMESTONE
BABCOCK ( WILCOX
ENERGY CONSUMPTION: 5.OX
SAN MIGUEL 1 OF THE SAN MIGUEL ELECTRIC COOP IS A LIGNITE (1.7X S, 5000
BTU/LB) FIRED RADIANT BOILER UNDER CONSTRUCTION IN SAN MIGUEL, TEXAS. THE
EMISSION CONTROL SYSTEM ON THIS UNIT WILL CONSIST OF A COLD SIDE ESP FOL-
LOWED BY FOUR BABCOCK AND WILCOX 86X EFFICIENT LIMESTONE TCA MODULES.
CHEVRON HIST ELIMINATORS WILL PRECEDE AN IN-LINE REHEATER AND AN ACID
BRICK LINED STACK. THE WATER LOOP WILL BE CLOSED, AND THE DEWATERED SLURRY
WILL BE MIXED WITH FLVASH BY RESEARCH COTTRELL AND DISPOSED IN AN OFF SITE
LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN NOVEMBER 1980.
STATUS 2
STARTUP 11/80
SEMINOLE ELECTRIC
SEMINOLE
1
NEW 620.0 MW (GROSS)
620.0 MW (ESC)
COAL
2.7S XS SUBBITUHINOUS
LIMESTONE
PEABODV PROCESS SYSTEMS
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 3/83
SEMINOLE 1 OF SEMINOLE ELECTRIC IS A COAL (2.75X S, 11.700 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN PALATKA. FLORIDA. THE EMISSION CONTROL SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE F6D SYSTEM. THE F6» SYSTEM WILL BE
SUPPLIED BY PEABODV PROCESS SYSTEMS. START UP IS EXPECTED IN MARCH
1983.
SEMINOLE ELECTRIC
SEMINOLE
2
NEW 620.0 MW (GROSS)
620.0 MW (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABODV PROCESS SYSTEMS
ENERGY CONSUMPTION: ***«X
STATUS 3 STARTUP 3/85
SEMINOLE 2 OF SEHINOLE ELECTRIC IS A COAL (2.7SX S, 11,700 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CONTROL SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE FGD SYSTEM. THE F6D SYSTEM WILL BE
SUPPLIED BY PEABODY SYSTEMS. START Uf> 1$ EXPECTED IN MARCH 1985.
34
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SIERRA PACIFIC POWER
VALMV
2
NEW 376.0 MW (GROSS)
276.0 MW (ESC)
COAL
***** XS
LINE/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 7 STARTUP 8/84
SIERRA PACIFIC POWER HAS PLANS TO CONSTRUCT A 276 MU UNIT TO BE LOCATED
IN VALMY, NEVADA. THE FOSTER WHEELER PULVERIZED COAL FIRED BOILER AT THE
VALHV 2 STATION WILL UTILIZE AN FGD SYSTEM OR FIRE LOU SULFUR COAL TO
CONTROL S02 EMISSIONS. IF FGD IS SELECTED, A DRV LIME SYSTEM WILL BE
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN AUGUST 1984.
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTON
1
NEW 235.0 MW (GROSS)
235.0 MU (ESC)
COAL
2.80 XS
LIMESTONE
BABCOCK 8 WILCOX
ENERGY CONSUMPTION: 1.61
STATUS 2 STARTUP 3/81
THE SIKESTON BOARD OF MUNICIPAL UTILITIES' SIKESTON 1 IS A PULVERIZED COAL
(2.8X S, 11,340 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN SIKESTON, MIS-
SOURI. BABCOCK AND WILCOX IS SUPPLYING AN EMISSION CONTROL SYSTEM CONSIST-
ING OF TWO ESP'S AND THREE SOX CAPACITY LIMESTONE VENTURI FGD MODULES. THE
CLEANED GAS WILL PASS THROUGH CHEVRON MIST ELIMINATORS BEFORE EXITING A
450 FOOT FRP LINED FLUE (A SECOND CARBON STEEL LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK). THE HATER LOOP WILL BE OPEN, AND THE
SLUDGE WILL BE PONDED. START UP IS SLATED FOR MARCH 1981.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
NEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
1.60 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 3/85
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO NEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA. EACH 500 MW
BOILER WILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.G AND 2.3X.
THE UTILITY HAS SIGNED A CONTRACT WITH PEABODY PROCESS SYSTEMS FOR THE
INSTALLATION OF A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN MARCH 1985.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
2
NEW SOO.O MU (GROSS)
500.0 MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: *«**X
STATUS 3 STARTUP 11/83
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO NEW UNITS.
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA. EACH 500 MW
BOILER WILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.0 AND 2.3X,
THE UTILITY HAS SIGNED A CONTRACT WITH PEABODY PROCESS SYSTEMS FOR THE
INSTALLATION OF A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS IN NOVEMBER 1983.
SOUTH CAROLINA PUBLIC SERVICE
UINYAH
2
NEK 280.0 MW (GROSS)
140.0 MW (ESC)
COAL
1.70 XS BITUMINOUS
LIMESTONE
BABCOCK I WILCOX
ENERGY CONSUMPTION: 1.1X
STATUS 1 STARTUP 7/77
WINTAH 2 OF SOUTH CAROLINA PUBLIC SERVICE IS A PULVERIZED BITUMINOUS COAL
(1.70X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA,
A COLD SIDE ESP AND A BABCOCK AND WILCOX VENTURI SCRUBBER/LIMESTONE TRAY
TOWER ABSORBER TRAIN DESIGNED TO REMOVE 45X OF THE S02 FROM THE BOILER
FLUE GAS MAKE UP THE EMISSION CONTROL SYSTEM ON THIS UNIT. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE SLUDGE IS DISPOSED IN AN ON-SITE
UNLINED POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
SOUTH CAROLINA PUBLIC SERVICE
3
NEW 280.0 MW (GROSS)
280.0 MW (ESC)
COAL
1.70 XS
LIMESTONE
BABCOCK t WILCOX
ENERGY CONSUMPTION: 2.ix
STATUS 1 STARTUP 5/80
WINVAN 3 OF SOUTH CAROLINA PUBLIC SERVICE IS A DRY BOTTOM BOILER WHICH
FIRES 1.7X SULFUR COAL (11,500 BTU/LB) AND IS LOCATED IN GEORGETOWN,
SOUTH CAROLINA. AN ESP PRECEDES A BABCOCK AND WILCOX LIMESTONE FGG
SYSTEM AND AN INDIRECT STEAM REHEATER. THE SYSTEM OPERATES IN A CLOSED
WATER LOOP MODE. OPERATIONS COMMENCED IN MAY 1980.
35
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTH CAROLINA PUBLIC SERVICE
t
NEU 280.0 MW (GROSS)
280.0 MW <£SC>
COAL
1.75 XS BITUMINOUS
LIMESTONE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 2.tX
STATUS 2 STARTUP 7/81
SOUTH CAROLINA PUBLIC SERVICE'S UINYAH * IS A BITUMINOUS COAL (1.70X S,
11,500 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN GEORGETOWN, SOUTH
CAROLINA. TWO AMERICAN AIR FILTER LIMESTONE SLURRY SPRAY TOWERS MILL
FOLLOW AN ESP. THE TEMPERATURE OF THE CLEANED GAS HILL BE RAISED BY AN
INDIRECT STEAM REHEATED. THE SYSTEM HILL OPERATE IN A CLOSED WATER LOOP
MODE. START UP IS EXPECTED IN JULY 1981.
SOUTH MISSISSIPPI ELEC PWR
R.O. MORROW, SR.
1
NEW 200.0 MU (CROSS)
124.0 MM (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: 5.5X
STATUS 1 STARTUP 8/78
R.D. MORROW 1 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S. 12.000 BTU/LB) FIRED UNIT IN HATTISBURG. MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS Of A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38Z BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 4C8 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED. AND THE FLTASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST 1978.
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
2
NEW 200.0 MH (GROSS)
124.0 MW (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: S.SX
STATUS 1 STARTUP 6/79
R.D. MORROW 2 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S. 12.000 BTU/LB) FIRED UNIT IN HATTISBURG, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERlNfi. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 4C8 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1979.
SOUTHERN ILLINOIS POWER COOP
HAR10N
4
HEW 173.0 MW (GROSS)
173.0 MW (ESC>
COAL/REFUS
3.75 XS BITUMINOUS
LIMESTONE
9ABCOCK ( WILCOX
ENERGY CONSUMPTION: 2.3X
STATUS 1 STARTUP 5/79
UNIT 4 AT SOUTHERN ILLINOIS POWER COOP'S MARION STATION IN MARION. ILLI-
NOIS IS A CYCLONE FIRED COAL (3.5X S, 9000 BTU/LB) BOILER WHICH IS SERVED
BY A 89.4X EFFICIENT (DESIGN) LIMESTONE FGD SYSTEM SUPPLIED BY BABCOCK AND
WILCOX. TWO SPRAY TOWERS AND A BRICK LINED STACK ARE DOWNSTREAM OF AN ESP
IN THIS SYSTEM. THE WATER LOOP IS OPEN, AND THE FLYASH STABILIZED SLUDGE
IS DEWATERED AND LANDF1LLED. THE SYSTEM BECAME OPERATIONAL DURING MAY
1979.
SOUTHERN ILLINOIS POWER COOP
KARION
5
NEW 300.0 MW (GROSS)
300.0 MW (ESC)
COAL
3.CO XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 6 STARTUP 0/88
MARION 5 IS A COAL (3.OX S. 9000 BTU/LB) FIRED UNIT PLANNED BY SOUTHERN
ILLNOIS POWER COOP FOR LOCATION IN MARION, ILLINOIS. THE UTILITY HAS NOT
YET DECIDED ON Ah F60 PROCESS AS IT IS WAITING FOR THE FINALIZATION OF
THE S02 REGULATIONS THE UNIT WILL HAVE TO MEET. START UP IS EIPECTED IN
1988.
SOUTHERN INDIANA 6AS ( ELEC
A.B. BROWN
1
NEW 265.0 MW (GROSS)
265.0 MW (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FNC
ENERGY CONSUMPTION: .ex
STATUS 1 STARTUP 3/79
SOUTHERN INDIANA GAS AND ELECTRIC'S A.6.BROUN 1 IS A DRY BOTTOM PULVERIZED
COAL (3.35X S, 13,010 BTU/LB) FIRED UNIT IN WEST FRANKLIN, INDIANA. FMC
SUPPLIED A DUAL ALKALI FGD SYSTEM DESIGNED TO REMOVE 85X OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CONTACTORS. A COLD SIDE ESP
PROVIDES PRIMARY PARTICULATE CONTROL, AND ONE CHEVRON HIST ELIMINATOR/MOD*
ULE PRECEDES A 498 FOOT ACID BRICK LINED STACK. THE SYSTEM PRODUCES A
FILTER CAKE WASTE PRODUCT WHICH IS DISPOSED IN AN ON SITE LANDFILL. THE
WATER LOOP CAN BE EITHER OPEN OR CLOSED. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1979.
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
1
NEW
720.0 MW (GROSS)
720.0 My (ESC)
COAL
.70 IS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, HOP
ENERGY CONSUMPTION: «»*«X
STATUS 3 STARTUP 0/86
DOLET HILLS 1 OF SOUTHWESTERN ELECTRIC POWER IS A PLANNED 720 HU LIGNITE
(P.7XS, 7100BTU/LB) FIRED BOILER TO BE LOCATED IN MANSFIELD, LOUISIANA.
THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOR PARTICULATE CONTROL
AND A WET LIMESTONE FGD SYSTEM FOR S02 CONTROL. THE FLUE GAS WILL EXIT
THROUGH A 525 FOOT STACK. A CONTRACT HAS BEEN AWARDED TO UOP FOR THE FGO
SYSTEM. THE UNIT IS SCHEDULED TO STARTUP IN 1986.
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
2
COAL
.80 IS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: •««•!
STATUS 3 STARTUP 12/84
HENRY W. PIRKEV 1 IS A WET BOTTOM LIGNITE (0.81 S, 6300 BTU/LB) FIRED UNIT
PLANNED BY SOUTHWESTERN ELECTRIC POWER FOR LOCATION IN HALLSVILLE, TEXAS.
A CONTRACT HAS BEEN AWARDED TO THE AIR CORRECTION DIVISION OF UOP FOR FOUR
LIMESTONE SPRAY TOWERS (99*1 EFFICIENCY). MIST ELIMINATION WILL BE PRO-
VIDED BY TWO STAGE CHEVRONS, AND THE STACK WILL BE ACID BRICK LINED. NO
REHEAT IS PLANNED. THE WATER LOOP WILL BE CLOSED. AND THE SLUDGE WILL BE
POZ-0-TEC STABILIZED. START UP IS EXPECTED BY DECEMBER 1984.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
MEW 194.0 MW (GROSS)
194.0 MW (ESC)
COAL
3.50 IS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 4/77
SPRINGFIELD CITY UTILITIES' SOUTHWEST 1 IS A PULVERIZED BITUMINOUS COAL
(3.5X S, 12,SCO BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD, MISSOURI. THE
EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED
BY TWO UOP LIMESTONE TCA MODULES WHICH WERE DESIGNED TO REMOVE BOX OF THE
FLUE GAS S02. ONE CHEVRON/NODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
THE DRV FLYASH STABILIZED SLUDGE IS DEWATERED BY A ROTARY DRUM VACUUM AND
TRUCKED TO A LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE APRIL 1977.
SPRINGFIELD WATER, LIGHT & PWR DALLNAN 3 OF SPRINGFIELD WATER, LIGHT, AND POWER IS A PULVERIZED COAL
(?.3X S, 10,500 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN SPRINGFIELD,
ILLINOIS. RESEARCH COTTRELL IS SUPPLVING A LIMESTONE FGD SYSTEM DESIGNED
TO REMOVE 95X OF THE S02 FROM 850,000 ACFM OF BOILER FLUE GAS. A HOT SIDE
ESP WILL PRECEDE TWO PACKED TOWER ABSORBERS, ONE HORIZONTAL CHEVRON PER
MODULE, AND A 500 FOOT ACID BRICK LINED STACK. NO REHEAT WILL BE PROVIDED.
A SLUDGE DISPOSAL STRATEGY HAS NOT BEEN FINALIZED, BUT THE UTILITY IS CON-
SIDERING EITHER PONDING OR LANDFILL. FGD OPERATIONS SHOULD BEGIN IN
OCTOBER 1980.
3
MEW
205.0 MW (GROSS)
205.0 MW (ESC)
COAL
3.39 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 5.9X
STATUS 2 STARTUP 10/80
ST. JOE ZINC
G.F. WEATON
1
RETROFIT 60.0 MW (GROSS)
63.0 MW (ESC)
COAL
2.00 XS BITUMINOUS
CITRATE
MORRISON 8 KNUDSEN/U.S.B.H.
ENERGY CONSUMPTION: ••••»
STATUS 1 STARTUP 11/79
G.F. WEATON 1, OWNED BY ST. JOE ZINC, IS A COAL (2.OX S, 12,500 BTU/LB)
FIRED BOILER LOCATED IN MONACA, PENNSYLVANIA. THE BUREAU OF MINES RE-
TROFITTED A PROTOTYPE CITRATE FGD SYSTEM ON THIS UNIT, WHICH PROVIDES
POWER FOR THE LOCAL UTILITY GRID. ONE VENTURI SCRUBSER/ABSORBER TRAIN
FOLLOWS A COLD SIDE ESP. TWO CHEVRON MIST ELIMINATORS ARE FOLLOWED BY
A COMBINATION OF INDIRECT HOT AIR AND DIRECT COMBUSTION REHEATERS. AND A
102 FOOT FIBERGLASS LINED SCRUBBER STACK. THE SYSTEM SO2 REMOVAL EFFICIEN-
CY WILL BE OVER 90X. THE WATER LOOP IS CLOSED LOOP MODE. THE FGD SYSTEM
COMMENCED OPERATION IN NOVEMBER 1979.
37
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SUNFLOWER ELECTRIC COOP
MOLCOMB
1
NEW 347.0 MU (GROSS)
347.0 MU (ESC>
COAL
.47 XS SUBBITUNINOUS
LINE/SPRAY DRYING
JOY MFG/MIRO ATOMIZER
ENERGY CONSUMPTION: .9X
STATUS 3 STARTUP 9/83
SUNFLOWER ELECTRIC COOP'S HOLCOMB 1 STATION IS A PLANNED 347 MW UNIT TO 8E
LOCATED IN MOLCOMB, KANSAS. THE PULVERIZED COAL (0.47X S, 8800
BTU/LB) FIRED BABCOCK AND UILCOX BOILER WILL UTILIZE A JOY MANUFACTURING/
NIRO ATOMIZER DRV SCRUBBING PROCESS FOR S02 CONTROL. A FABRIC FILTER
WILL BE UTILI7EO FOR PRIMARY PARTICLE CONTROL. THE UNIT IS SCHEDULED
TO COMMENCE OPERATIONS IN THE FALL OF 1983.
TAMPA ELECTRIC
BIG BEND
4
NEW 475.0 MU (GROSS)
475.0 MU (ESC)
COAL
2.35 XS
LIME/LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 2.IX
STATUS 3 STARTUP 12/84
UNIT 4 AT TAMPA ELECTRIC'S BIG BEND STATION IS A PLANNED DRY BOTTOM PUL-
VERIZED COAL (2.35X S. 10.300 BTU/LB) FIRED UNIT TO BE LOCATED IN TAMPA,
FLORIDA. A CONTRACT HAS BEEN AWARDED TO RESEARCH-COTTRELL FOR A WET LIME/
LIMESTONE SCRUBBING PROCESS. AN ESP WILL PROVIDE PRIMARY PARTICULATE
CONTROL. THE FGD SYSTEM, WHICH WILL REMOVE 90X OF THE FLUE GAS S02. WILL
INCLUDE AN INDIRECT HOT AIR REHEATER LEADING TO A 490 FOOT CONCRETE LINEC
STACK. THE UNIT WILL PRODUCE GYPSUM AS A SALEABLE PRODUCT.
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
1-10
RETROFIT 1450.0 MU (GROSS)
600.0 MU (ESC)
COAL
3.10 XS
MAGNESIUM OXIDE
EHV1RONEERING. RILEY STOKER
ENERGY CONSUMPTION: •»**x
STATUS 3 STARTUP 12/81
UNITS 1 THROUGH 10 AT JOHNSONVILLE STATION OF TVA ARE COAL (3.1X S, 10,750
BTU/LB) FIRED BOILERS LOCATED IN NEW JOHNSONVILLEt TENNESSEE. UNITED EN-
GINEERS HAS BEEN AWARDED A CONTRACT TO PROVIDE ENGINEERING *SSIST«NCE TO
TVA FOR A 90X EFFICIENT MAGNESIUM OXIDE F6D SYSTEM TO BE RETROFITTED ON
THESE UNITS. SULFURIC ACID WILL BE PRODUCED AS A BYPRODUCT FROM THIS SYS-
TEM, WHICH WILL FEATURE FOUR VENTURI SCRUBBER/ABSORBER TRAINS (ONE SPARE),
6CI BYPASS REHEAT, AND A 600 FOOT STACK. START UP IS EXPECTED IN 1981.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 734.0 MU (GROSS)
704.0 MU (ESC)
COAL
4.20 XS
LIMESTONE
CMEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ••••*
STATUS 2 STARTUP 3/82
PARADISE 1 OF TVA IS A 4.2X SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2X EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS UILL FOLLOW AN ESP. INLET FLUE G«S WILL
BE USED TO HEAT WATER, WHICH IN TURN UILL BE USED TO REHEAT THE OUTLET
FLUE GAS. FORCED OXIDATION WILL 6E USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EKPECTS TO 6ET AN SOX SOLIDS LANDFILL*
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN MARCH 1982.
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 704.0 MU (GROSS)
704.0 MU (ESC)
COAL
4.20 XS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: **»«x
STATUS 2 STARTUP 6/62
PARADISE 2 OF TVA IS A 4.2X SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2X EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS UILL FOLLOW AN ESP. INLET FLUE GAS WILL
Bf USED TO HEAT WATER, WHICH IN TURN UILL BE USED TO REHEAT THE OUTLET
FLUE GAS. FORCED OXIDATION WILL BE USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EKPECTS TO GET AN SOX SOLIDS LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN JUNE 1982.
TENNESSEE VALLEY AUTHORITY
SHAUNEE
IDA
RETROFIT 10.o MU (GROSS)
10.0 MU (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION, OOP
ENERGY CONSUMPTION: *«««X
STATUS 1 STARTUP 4/72
SHAUNEE 10 OF TVA IS A 2.9X SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PADUCAH, KENTUCKY. MODULE 10A IS A RETROFIT PROTOTYPE LIME/LIMESTONE TCA
SYSTEM SUPPLIED BY THE »IR CORRECTION DIVISION, UOP. THE SYSTEM UTILIZES
A CHEVRON MIST ELIMINATOR AND A DIRECT COMBUSTION REHEATER. AND OPERATES
IN A CLOSED WATER LOOP. THIS TEST PROGRAM is FUNDED BY THE EPA WITH TVA AS
THE CONSTRUCTOR AND FACILITY OPERATOR. THE BECHTEL CORP. OF SAN FRANCISCO
IS THE MAJOR CONTRACTOR, TEST DIRECTOR, AND REPORT UR1TER. THE SYSTEM HAS
BEEN OPERATIONAL SINCE APRIL 1972.
38
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
SHAWNEE
13B
RETROFIT 10.0 MW (GROSS)
10.0 MU (ESC)
COAL
2.90 XS BITUMINOUS
LINE/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *«**X
STATUS 1 STARTUP 4/72
SNAUNEE 1C OF TVA IS A 2.
PADUCAH, KENTUCKY. MODULE
TURI SCRUflBER/SPRAY TOMER
TIONAL SINCE APRIL 1972,
COMBUSTION REHEATED, AMD
GRAM IS FUNDED BY THE EPA
TOR. THE BECHTEL CORP. OF
RECTOR, AND REPORT WRITER
9X SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
108 IS A RETROFIT PROTOTYPE LIME/LIMESTONE VEN-
ABSORBER SUPPLIED BY CHENICO. THE SYSTEM, OPERA-
INCLUDES A CHEVRON MIST ELIMINATOR AND A DIRECT
OPERATES IN A CLOSED WATER LOOP. THIS TEST PRO-
WITH TVA AS THE CONSTRUCTOR AND FACILITY OPERA-
SAN FRANCISCO IS THE MAJOR CONTRACTOR, TEST DI-
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
RETROFIT 575.0 MM (GROSS)
575.0 MW (ESC)
COAL
3.70 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: **«*X
STATUS 2 STARTUP 9/81
WIDOWS CREEK 7 IS A PULVERIZED BITUMINOUS COAL (J.7X S, 11,100 BTU/LB)
FIRED BOILER OF TVA LOCATED IN BRIDGEPORT, ALABAMA. COMBUSTION ENCINEERING
IS PRESENTLY RETROFITTING A LIMESTONE VENTRI ROD SCRUBBER/SPRAY TOWER AB-
SORBER FGD SYSTEM ON THIS UNIT. AN ESP WILL PRECEDE THE SCRUBBING TRAIN,
AND A COMBINATION OF A BULK ENTRAINMENT SEPARATOR, TWO CHEVRON MIST
ELIMINATORS AND A FINNED TUBE REHEATER FOLLOW THE SYSTEM. THE
SCRUBBER SLUDGE uILL BE DISPOSED IN A SLUDGE POND. CONSTRUCTION BEGAN
IN SEPTEMBER 1978, AND START UP IS EXPECTED IN SEPTEMBER 1981.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
RETROFIT 550.0 MW (GROSS)
550.0 MW (ESC)
COAL
3.70 XS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: 4.7X
STATUS 1 STARTUP 5/77
WIDOWS CREEK 8 OF TVA IS A BALANCED frRAFT, T AN6F.NT 1 ALLY FIRED COAL C3.7X
S, 10,000 BTU/LB) BOILER IN BRIDGEPORT, ALABAMA. TVA RETROFITTED THIS UNIT
WITH A LIMESTONE FGD SYSTEM (BOX DESIGN S02 REMOVAL EFFICIENCY) WHICH BE-
GAN OPERATIONS IN MAY 1977. AN ESP PRECEDES FOUR VARIABLE THROAT VENTURI
SCRUBBER/MULTIGRID TOWER ABSORBER TRAINS CONE OF THE TOWERS is PACKED).
ONE VERTICAL CHEVRON/TRAIN AND AN INDIRECT HOT AIR REHEATER ARE INCLUDED
IN THE SYSTEM. SLUDGE FROM THE FGD SYSTEM IS PONDED.
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
1
UEV 400.0 MW (GROSS)
400.0 MW (ESC)
COAL
1.06 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 1/82
GIBBONS CREEK 1 OF THE TEXAS MUNICIPAL POWER AGENCY IS A DRY BOTTOM PUL-
VERIZED LIGNITE (1.06X S, 4860 BTU/LB) FIRED UNIT PLANNED FOR LOCATION IN
CARLOS, TEXAS. THE EMISSION CONTROL SYSTEM UILL CONSIST OF A COLD SIDE ESP
FOLLOWED BY THREE 50X CAPACITY LIMESTONE SPRAY TOWERS. A CONTRACT HAS BEEN
AWARDED TO COMBUSTION ENGINEERING FOR THE F6D SYSTEM, WHICH INCLUDES A
CHEVRON MIST ELIMINATOR AND A STEAM COIL REHEATER. CLEANED FLUE GAS MILL
BE DISCHARGED THROUGH A 465 FOOT ACID BRICK LINED STACK. THE POZ-0-TEC
STABILIZED SLUDGE UILL BE USED AS STRIP MINE LANDFILL. START UP
IS EXPECTED IN JANUARY 1982.
TEXAS POWER 8 LIGHT
SANDOW
4
NEy 545.0 MW (GROSS)
382.0 MW (ESC>
COAL
1.60 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 11/80
SANDOW 4 IS A PULVERIZED 1.6X SULFUR LIGNITE FIRED BOILER OF TEXAS POWER
AND LIGHT UNDER CONSTRUCTION IN ROCKDALE , TEXAS. COMBUSTION ENGINEERING IS
SUPPLYING THREE LIMESTONE SPRAY TOWERS FOR THIS UNIT. A COLD SIDE ESP WILL
PROVIDE PRIMARY PARTICULATE CONTROL. A 30X BYPASS REHEAT WILL BE USED, AND
THE OVERALL S02 REMOVAL EFFICIENCY WILL BE 75X. THE SYSTEM WILL OPERATE IN
A CLOSED WATER LOOP, AND THE SLUDGE WILL BE PONDED. START UP IS EXPECTED
IN NOVEMBER 1980.
TEXAS POWER 8 LIGHT
TWIN OAKS
NEW 750.0 MW (GROSS)
750.0 »W (ESC)
COAL
.7? XS LIGMTE
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: **«*X
STATUS 3 STARTUP 8/84
TWIN OAKS 1 IS A 0.70X SULFUR LIGMTE FIRED BOILER PLANNED BY TEXAS POWER
AND LIGHT AND ALCOA FOR LOCATION IN BREMOND. TEXAS. A CONTRACT HAS BEEN
AWARDED TO CHEMICO FOR A LIMESTONE FGD SYSTEM ON THIS UNIT. START UP IS
EXPECTED IN AUGUST 1984.
39
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19SC
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS POWER K LIGHT
TWIN OAKS
Z
NEW 750.0 MW (GROSS)
750.0 MW (ESO
COAL
.70 XS LIGNITE
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: **«*X
STATUS 3 STARTUP 8/85
TWIN OAKS 2 IS A 0.70X SULFUR LIGNITE FIRED BOILER PLANNED BY TEXAS POWER
AND LIGHT AND ALCOA FOR LOCATION IN BREMOND, TEXAS. A CONTRACT HAS PEEN
AWARDED TO CHFMICO FOR A LIMESTONE FGD SYSTEM ON THIS UNIT. START UP IS
EXPECTED IN AUGUST 1985.
TEXAS UTILITIES
FOREST GROVE
1
NEW 750.0 M« (GROSS)
7SQ.C MW
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
HILL CREEK
1
MEW 750.0 MU (GROSS)
750.0 MW (ESC)
COAL
***** tS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/85
MILL CREEK 1 OF TEXAS UTILITIES IS A PLANNED LI6NITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY WILL INCLUDE AN F6D SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE PROCESS TYPE OR
VENDOR. ESP'S WILL PROVIDE PRIMARY PARTICLE CONTROL. START UP IS
EXPECTED IN 1985.
TEXAS UTILITIES
MILL CREEK
z
NEW 750.0 My (GROSS)
750.0 MW (ESC)
COAL
***** XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/86
MILL CREEK 2 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY WILL INCLUDE AN FGO SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE PROCESS TYPE OR
VF.NDOR. ESP'S WILL PROVIDE PRIMARY PARTICLE CONTROL. START UP IS
EXPECTED IN 1986.
HONTICELLO 3 OF TEXAS UTILITIES IS A LIGNITE (1.5X S, 7000 BTU/LB) FIRED
UNIT IN MT. PLEASANT, TEXAS. THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS
OF TWO COLD SIDE ESP'S FOLLOWED BY THREE CHEMICO LIMESTONE SPRAY TOWERS
(74X DESIGN S02 REMOVAL EFFICIENCY), ONE HORIIONTAL CHEVRON MIST ELIMINA-
TOR/MODULE, AND AN INDIRECT HOT AIR REHEATER. THE WATER LOOP IS CLOSED.
AND THE FLYASH STABILIZED SLUDGE IS DISPOSED IN AN ON SITE LANDFILL. THIS
SYSTEM HAS BEEN OPERATIONAL SINCE MAY 1978.
TEXAS UTILITIES
MONTICELLO
3
NEW 800.0 MW (GROSS)
830.0 MW (ESC>
COAL
1.50 IS LIGNITE
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/78
TUCSON ELECTRIC POWER
SPRINGERVILLE
1
NEW 370.0 MW (GROSS)
370.0 MW (ESC)
COAL
.61 XS SUBBITUNINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 1/85
TUCSON ELECTRIC POWER WILL BE BUILDING TWO NEW UNITS IN SPRINGERVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2. THE UNITS WILL FIRE PULVERIZED SUBBITU-
MINOUS COAL (0.53-0.69X S AND 8500-6900 BTU/LB). A CONTRACT HAS BEEN
AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING F6D
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SVSTFM WILL
BE DESIGNED TO ACCOMODATE A REHEATER (SHOULD ONE BE REQUIRED) AND WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. STARTUP IS SCHEDULED FOR JANUARY 1985.
TUCSON ELECTRIC POWER
SPRINGERVILLE
NEW 370.0 MW (GROSS)
370.0 MW (ESC)
COAL
.61 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 3/87
TUCSON GAS AND ELECTRIC WILL BE BUILDING TWO NEW UNITS IN SPRINGEPVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2. THE UNITS WILL FIRE PULVERIZED SIBB1TU-
HINOUS COAL (0.53-0.69X S AND 8500-8000 BTU/LB). A CONTRACT HAS BEEN
AWARDED TO JOY MANUfACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM WILL
BE DESIGNED TO ACCOMODATE A REHEATER (SHOULD ONE BE REQUIRED) AND WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. STARTUP IS SCHEDULED FOR MARCH 1987.
UNITED POWER ASSOCIATION
S1ANTON
1A
NEW 50.0 MW (GROSS)
50.0 MW (ESC)
COAL
.77 XS LIGNITE
LIME/SPRAY DRYING
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****x
STATUS 2 STARTUP 6/82
STANTON 1A OF THE UNITED POWER ASSOCIATION IS A PULVERIZED COAL (C.77X S,
7000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN STANTON, NORTH DAKOTA.
A CONTRACT HAS BEEN AWARDED TO KOMLINE AND SANDERSON FOR A LIME SPRAY
DRYER. A FABRIC FILTER SUPPLIED BY RESEARCH COTTRELL WILL BE DESIGNED
TO REMOVE 99X OF THE PARTICULATE. THE SYSTEM WILL OPERATE IN AN OPEN
LOOP MODE WITH SLUDGE DISPOSAL TO BE IN A CLAY LINED SETTLING POND.
OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1982.
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
UTAH POWER I LIGHT
HUNTER
1
NEW 400.0 MH (GROSS)
360.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LINE
CHEMICO DIVISION, ENWIROTECH
ENERGY CONSUMPTION: **»*X
STATUS 1 STARTUP 5/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.55X S, 12,500 BTU/LB) FIRED
UNIT IN CASTLEOALE, UTAH. CHEHICO SUPPLIED A PEBBLE LIME MET SCRUBBING
SYSTEM WHICH BECAME OPERATIONAL IN NAY 1979. THE SCRUBBING SYSTEM IS DE-
SIGNED TO OPERATE IN AN OPEN WATER LOOP WITH AN $02 REMOVAL EFFICIENCY OF
802. PRIMARY PARTICULATE CONTROL IS PROVIDED BY AN UPSTREAM ESP, AND STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE IS FLYASH STABILIZED AND DIS-
POSED ON-SITE.
UTAH POWER ( LIGHT
HUNTER
2
MEW 400.0 MW (GROSS)
360.0 MW (ESC)
COAL
.55 XS
LIME
CHEMICO DIVISION, FNVlftOTECH
ENERGY CONSUMPTION: ***«X
STATUS 1 STARTUP 6/80
UTAH POWER AND LIGHT'S HUNTER 2 IS A COAL (0.551 S, 12,500 BTU/LB) FIRED
UNIT LOCATED IN CASTLEDALE, UTAH. FOR EMISSION CONTROL, CHEMICO SUPPLIED
A PEBBLE LIME WET SCRUBBING SYSTEM DESIGNED TO OPERATE IN AN OP'EN WATER
LOOP WITH AN S02 REMOVAL EFFICIENCY OF SOX. AN UPSTREAM ESP PROVIDES
PRIMARY PARTICLE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT.
THE SLUDGE IS FLYASH STABILIZED AND DISPOSED OF ON-SITE. START UP OF BOTH
THE BOILER AND FGD SYSTEM TOOK PLACE IN JUNE 1980.
UTAH POWER t LIGHT
HUNTER
3
NEW 400.0 NW (GROSS)
400.0 MW (ESC)
COAL
.55 IS BITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: •**•!
STATUS 3 STARTUP 6/83
UTAH POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEDALE, UTAH. A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIME, NONREGENERABLE FGD UNIT JOR EMISSION CONTROL. THE PULVERIZED
COAL FIRED UNIT (o.ssx s, 12,500 BTU/LB) is TO BEGIN OPERATIONS in JUNE
1983.
UTAH POWER t LIGHT
HUNTER
4
NEW 400.0 MW (GROSS)
400.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: **••!
STATUS 3 STARTUP 6/85
UTAH POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS* HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEDALE, UTAH. A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIME, NONREGENERABLE FGD UNIT /OR EMISSION CONTROL. THE PULVERIZED
COAL FIRED UNIT (O.SSX S, 12,500 BTU/LB) IS TO BEGIN OPERATIONS IN JUNE
1985.
UTAH POWER ( LIGHT
HUNTINGTON
1
NEW 430.0 MW (GROSS)
366.0 MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 5/78
HUNTINGTON 1 OF UTAH POWER IS A TANGENTIALLY FIRED PULVERIZED COAL (C.55X
S, 12,500 BTU/LB) BOILER IN PRICE, UTAH. A COLD SIDE ESP TREATS 1,742,GOD
ACFM OF FLUE GAS AND IS FOLLOWED BY A CHEMICO LIME FGD SYSTEM CONSISTING
OF FOUR SPRAY TOWERS (60X DESIGN EFFICIENCY). ONE FOUR PASS CHEVRON/MODULE
PROVIDES MIST ELIMINATION, AND A COMBINATION OF A STEAM TUBE AND 10-20X
BYPASS REHEATERS BOOST THE GAS TEMPERATURE 45-50 DEG F. THE SYSTEM OPER-
ATES IN A CLOSED WATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS TRUCKED
TO AN ON-SITE LANDFILL. THE SYSTEM INCLUDES A 600 FOOT ACID BRICK LINED
STACK, AND HAS BEEN OPERATIONAL SINCE HAY 1978.
UTAH POWER 1 LIGHT
NAU6HTON
3
RETROFIT 330.0 MW (GROSS)
330.0 MW (ESC)
COAL
.55 XS SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 1.SX
STATUS 2 STARTUP 6/81
NAUGHTON 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (.5X S, 9500
BTU/LB) FIRED BOILER LOCATED IN KEMMERER, WYOMING. THE BOILER SUPPLIES
1.500,000 ACFM OF FLUE GAS TO AN ESP FOR PARTICULATE CONTROL. THE UNIT is
CURRENTLY BEING RETROFITTED WITH A UOP WET SODA ASH FGD SYSTEM FOR S02
CONTROL. THE F6D SYSTEM IS DESIGNED TO REMOVE 70t OF THE S02 BEFORE THE
FLUE GAS EXITS OUT A 475 FOOT STACK. INITIAL STARTUP IS SCHEDULED FOR
JUNE 1981.
42
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 2
STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
dEST PENN POWER
MITCHELL
33
RETROFIT 300.0 MW (GROSS)
300.0 MU (ESC)
COAL
2.80 XS BITUMINOUS
LIME
CHEMICO DIVISION* ENVIROTECH
ENERGY CONSUMPTION: 1.1X
STATUS 3 STARTUP 8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POWER STATION IN COURTNEYt
PENNSYLVANIA IS A 2.8* SULFUR COAL FIRED BOILER. A CONTRACT MAS
AWARDED TO CHEMICO FOR A LIME SCRUBBING PROCESS. S02 REMOVAL
EFFICIENCY UILL BE 95X. START UP IS PLANNED FOR AUGUST 1982.
UEST TEXAS UTILITIES
OKLAUNION
1
NEW 720.0 MW (GROSS)
720.0 nu test)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **••*
STATUS 6 STARTUP 12/86
WEST TEXAS UTILITIES HAS PLANS FOR * PULVERIZED COAL FIRED BOILER TO BE
LOCATED NEAR OKLAUNION, TEXAS. THE UTILITY HILL INCLUDE AN FGD SYSTEM
FOR EMISSION CONTROL FROM THE 720 MV UNIT. THE OKLAUNION 1 PLANT IS
SCHEDULED TO COMMENCE OPERATIONS IN 1986.
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T <«U
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1960
ALABAMA ELECTRIC COOP: TONBI6BEE 2 (CONT.)
PERIOD
MODULE
a
SYSTEM
AVAILABILITY
100.0
OPERABILITY
86.6
74.0
-PERFORMANCE DATA--
RELIABILITY UTILIZATION
86. 5
73.9
X REMOVAL
S02 PART.
PER
HOURS
720
BOILER
HOURS
719
FGD
HOURS
532
CAP.
FACTOR
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT FOR THE MONTH OF APRIL THE SYSTEM HAS
AVAILABLE 100X OF THE TIME.
5/80 A 34.9 34.7
B 92.8 92.2
SYSTEM 100.0 63.9 63.5 744 739 472
** PROBLEMS/SOLUTIONS/COHMENTS
THE FGD SYSTEM WAS AVAILABLE 100X DURING NAY.
6/80 A 100.0 88.0 100.0 11.0
B .0 .0 .0 .0
SYSTEM 50.0 44.0 50.0 5.5 720 90 40 7.0
•* PROBLEMS/SOLUTIONS/COMMENTS
MODULE B WAS OUT OF SERVICE THE ENTIRE MONTH OF JUNE DUE TO A DAMAGED
DAMPER DRIVE MOTOR.
NODULE A WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH, BUT HAS NEEDED
ONLY 79 HOURS.
7/80 A 100.0 97.6 100.0 54.5
B .0 .0 .0 .0
SYSTEM 50.0 48.8 50.0 27.3 744 415 203 26.7
•* PROBLEMS/SOLUTIONS/COMMENTS
THE B-MODULE REMAINED OUT OF SERVICE THROUGH JULY DUE TO THE DAMAGED
DAMPER DRIVE MOTOR.
THE A-HODULE OPERATED ON AN AS NEEDED BASIS WITH NO PROBLEMS.
S/BO A 100.0 84.0 84.0 18.3
B .0 .0 .0 .0
SYSTEM 50.0 42.0 42.0 9.2 744 162 68 14.9
«• PROBLEMS/SOLUTIONS/COMMENTS
DURING AUGUST MODULE B REMAINED OUT OF SERVICE DUE TO DAMAGED DAMPER
OPERATOR MOTORS.
»/80 SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
THE INFORMATION FOR THE MONTH OF SEPTEMBER IS NOT YET AVAILABLE.
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MU
NET UNIT 6ENERATIN6 CAPACITY W/F6D - My
EQUIVALENT SCRUBBED CAPACITY - MU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE NEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS 1VPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
A9SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»* DISPOSAL
TYPE
ALABAMA ELECTRIC COOP
TOHBIGBEE
3
LEROY
ALABAMA
255.0
235.0
179.0
I 115.00 BTU/LB)
COAL
BITUMINOUS
267*9.
14.00
7.00
1.15
.04
MET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEU
3.1
6/79
6/79
59.50
99.30
.0
.0
CLOSED
8.8
LINED POND
C 140 GPH)
. PERFORMANCE DATA — — .......
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
A
B
SYSTEM
69.2
4S.4
57.3
30.5
20.0
25.3
100.0 57.3 25.3 744 328
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY UNIT 3 HAS AVAILABLE THE ENTIRE MONTH.
188
2/80
A
B
SYSTEM
33.3
100.0
66.7
100.0
•* PROBLEMS/SOLUTIONS/COMMENTS
1.2
3.5
2.4
696
16
DURING FEBRUARY THE UNIT 3 BOILER AND FGD SYSTEM OPERATED ONLY 24 HOURS.
THE FGD SYSTEM HAS AVAILABLE THE ENTIRE MONTH.
3/80 SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMNENTS
.0
4/80 SYSTEM
DURING MARCH THE UNIT 3 GENERATOR WAS KEPT OUT OF SERVICE.
MAS AVAILABLE THE ENTIRE MONTH.
.0
744 0 0 .0
THE FGD SYSTEM
720 0 0 .0
46
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
ALABA«U ELECTRIC COOP: TONBISBEE 3 (CONT.)
PERFORMANCE DATA — — — — ———————
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*« PROBLEMS/SOLUTIONS/COHMENTS
THE UTILITY REPORTED THAT DURING APRIL THE BOILER DID NOT OPERATE.
5/80 A
B
SYSTEM
95.8
8.3
.0
4.2
.7
.0
.3 744 60 5
** PROBLEMS/SOLUTIONS/COMMENTS
THE F6D SYSTEM WAS AVAILABLE 713 HOURS DURING HAY; HOWEVER* THE BOILER
OPERATED 60 HOURS DUE TO BOILER RELATED PROBLEMS.
i/80 A
B
SYSTEM
100.0
100.0
100.0
THE B MODULE WAS OUT FOR
CAUSING THE DRIVE MOTOR
59.1 100.0
58.6 100.0
58.9 100.0
31 HOURS WHEN THE INLET DAMPER SWITCH FAILED
TO BURN OUT.
52.8
52.4
52.6 720 643 379
ONLY
52.0
• * PROBLEMS/SOLUTIONS/COMMENTS
NO FGD SYSTEM-RELATED PROBLEMS WERE ENCOUNTERED DURING JUNE.
7/80 A
B
SYSTEM
100.0
100.0
100.0
45.5 100.0
90.0 100.0
67.8 100.0
39.7
78.6
59.2 744 650 440
47.8
** PROBLENS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH OF JULY.
NODULES ARE UTILIZED ON AN AS NEEDED BASIS.
i/80 A
B
SYSTEM
100.0
100.0
100.0
95.7 100.0
91.6 100.0
93.7 100.0
75.8
72.6
74.2 744 590 552
THE
63.4
•* PROBLEflS/SOLUTIONS/COMNENTS
NO F60-RELATED PROBLEMS WERE ENCOUNTERED DURING THE MONTH OF AUGUST.
»/80 SYSTEM 720
•• PROBLEMS/SOLUTIONS/COMMENTS
THE INFORMATION FOR THE MONTH OF SEPTEHBER IS NOT VET AVAILABLE.
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
5ROSS UNIT 6ENERATIN6 CAPACITY - MU
NET UNIT 6ENERATIN6 CAPACITY W/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMHERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* HATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
•* DISPOSAL
TYPE
- X
ARIZONA ELECTRIC POyER COOP
APACHE
2
COCHISE
ARIZONA
195.0
175.0
98.0
COAL
BITUMINOUS
23260.
15.00
9.00
.55
********
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
4.1
8/78
1/79
42.50
99.50
100.0
1.0
C 10000 BTU/LB)
OPEN
115.9
POND
( 1840 6PM)
...._.._._—— —————— ——PERFORMANCE DATA —
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
744 731 426 56.1
1/80 SYSTEM 91.0 58.3 88.8 57.3 97.40
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY SOME OUTAGE TIME WAS DUE TO A PUMP MALFUNCTION.
OUTAGE TIME WAS ALSO CAUSED BY A BROKEN FEfcD BELT TO THE LIMESTONE BALL
MILL.
2/80 SYSTEM 92.8 96.7 92.8 92.8 97.40 696 668 646 87.4
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY OUTAGE TIME RESULTED FROM AN ESP FAILURE.
FORCED OUTAGE TIME WAS ALSO CAUSED BY A PUMP MALFUNCTION.
3/80 SYSTEM 99.1 99.1 99.0 99.1 744 744 738 74.1
** PROBLEMS/SOLUTIONS/COHNENTS
SOME OF THE OUTAGE TIME DURING MARCH OCCURRED BECAUSE OF PUMP FAILURES.
OUTAGE TIME RESULTED FROM STICKING VALVES AND LIMESTONE FEED-BELT
PROBLEMS.
4/80 SYSTEM
67.2
65.2
65.2
61.4
720 678 442
48
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ARIZONA ELECTRIC POWER COOP: APACHE 2 CCONT.)
_—... — — -. ——. -PERFORMANCE DATA — — — — —————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COMHENTS
DURING APRIL THE F6D SYSTEM HAS FORCED DOWN DUE TO PUMP FAILURES AND A
RUPTURE IN THE SLURRY RECIRCULATION LINE.
S/BO SYSTEM 90.5 90.5 90.5 V0.5 7** 744 673
** PROBLENS/SQLUTIONS/COMMENTS
DURING MAY THE UNIT HAS FORCED OFF LINE WHEN THE LIMESTONE CRUSHER
MALFUNCTIONED.
THE UNIT WAS ALSO FORCED OUT DUE TO PUMP AND VALVE FAILURES.
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMNENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF JUNE.
7/80 202 100.0 .0 .0
203 85.0 85.7 85.7 85.0
SYSTEM 100.0 85.7 85.7 85.0 7*4 738 633 77.8
** PROBLEMS/SOLUTIONS/COMMENTS
NODULE 202 HAS AVAILABLE THE ENTIRE MONTH. BUT MAS NOT OPERATED.
THE FED SYSTEM WAS DOWN IN JULY BECAUSE OF A CIRCUIT BREAKER MALFUNCTION.
FAILURE OF BOTH THE BYPASS DAMPCR AND THE PACKING PUMP ALSO CAUSED OUTAGE
TIME DURING THE MONTH.
8/80 202 .0 .0 .0
203 96.8 66.0 95.2 63.3
SYSTEM 96.8 66.0 95.2 63.3 744 714 471 61.0
** PROBLEMS/SOLUTIONS/COMMENTS
TOWER 202 WAS UNAVAILABLE IN AUGUST BECAUSE OF THE LINER BEING REPLACED.
A SAMPLE LINE FAILURE CAUSED TOWER 203 TO GO DOWN FOR 24 HOURS.
THE OPERATION OF THE F6D SYSTEM WAS REDUCED BECAUSE OF LOW LOAD CAPACITY.
»/80 SYSTEM 720
• * PROBLEMS/SOLUTIONS/COMKENTS
NO INFORMATION WAS AVAILABLE FOR SEPTEMBER 1980.
49
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
EROSS UNIT GENERATING CAPACITY - NW
MET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MM
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• DISPOSAL
TYPE
- X
ARIZONA ELECTRIC POWER COOP
APACHE
3
COCHISE
ARIZONA
19S.O
175.0
98. 0
COAL
BITUMINOUS
23260.
15.00
9.00
.55
********
MET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
4.1
6/79
4/79
42.50
99.50
100.0
1.0
< 10000 BTU/LB)
OPEN
340.2
POND
< 5400 6PH)
............ PERFORMANCE DATA— —— —————......___
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
744 744 682 89.7
1/80 SYSTEM 91.7 91.7 91.7 91.7 97.40
** PROBLENS/SOLUTIONS/COHMENTS
DURING JANUARY SOME OUTAGE TIME WAS DUE TO A PUMP MALFUNCTION.
OUTAGE TIME WAS ALSO CAUSED BY A BROKEN FEED BELT TO THE LIMESTONE BALL
MILL.
696 671 497 83.5
2/80 SYSTEM 95.6 74.1 96.0 71.4 97.40
** PROBLEMS/SOLUTIONS/COHMENTS
DURING FEBRUARY OUTAGE TIME RESULTED FROM AN ESP FAILURE.
FORCED OUTAGE TIME WAS ALSO CAUSED BY A PUMP MALFUNCTION.
5/80 SYSTEM 90.9 90.9 90.9 90.9 744 744 677 91.1
** PROBLEMS/SOLUTIONS/COMMENTS
SOME OF THE OUTAGE TIME DURING MARCH OCCURRED BECAUSE OF PUMP FAILURE.
OUTAGE TINE RESULTED FROM STICKING VALVES AND LIMESTONE FEED-BELT
PROBLEMS.
4/80 SYSTEM
99.0
96.9
96.9
30.6
720 227 220
SO
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ARIZONA ELECTRIC POWER COOP: APACHE 3 CCONT.)
......—.... ..-—.--.....-....—._pERFORHANCE DATA——————— ——————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F60 CAP.
502 PART. HOURS HOURS HOURS FACTOR
•• PROBLEMS/SOLUTIONS/COMNENTS
DURING APRIL THE FGD SYSTEM HAS FORCED DOWN DUE TO PUMP FAILURES AND A
RUPTURE IN THE SLURRY RECIRCULATION LINE.
5/80 SYSTEM .0 .0 .0 744 39 0
•< PROBLEMS/SOLUTIONS/COMHENTS
THE BOILER AND F6D SYSTEM WERE DOWN FOR A SCHEDULED OVERHAUL. THE LINERS
IN THE ABSORBER QUENCHER HAD TO BE REPAIRED. THE BOILER RETURNED TO SER-
VICE BEFORE REPAIR WORK FOR THE FGD SYSTEM WAS COMPLETE. THE FGD SYSTEM
MAS UNAVAILABLE IN MAY BECAUSE OF THIS OVERHAUL.
6/BO SYSTEM 720
•• PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION MAS NOT AVAILABLE FOR THE MONTH OF JUNE.
7/80 302 29.0 30.0 90.0 29.0
303 .0 .0 .0
SYSTEM 29.0 30.0 90.0 29.0 744 721 216 49.3
*• PROBLEMS/SOLUTIONS/COMMENTS
BOTH NODULES WERE UNAVAILABLE BECAUSE OF REPLACEMENT OF THE ABSORBER LINER.
NODULE 302 WAS OUT OF SERVICE FOR 22 DAYS, WHILE MODULE 303 WAS OUT OF
SERVICE DURING ALL OF JULY.
A PACKING PUMP FAILURE CAUSED THE FGD SYSTEM TO GO DOUN.
5/80 302 98.5 47.8 96.3 38.4
303 98.5 19.3 91.3 15.5
SYSTEM 98.5 67.1 94.8 54.0 744 599 402 41.5
•• PROBLEMS/SOLUT10NS/COHNENTS
TOWER 302 WAS UNAVAILABLE DURING PART OF AUGUST BECAUSE OF A QUENCHER
PUMP FAILURE.
DUE TO A SAMPLING LINE FAILURE IN AUGUST, TOWER 303 WAS SHUT DOWN FOR
PART OF THE MONTH.
THE REDUCED RATE OF FGD OPERATION IN AUGUSZ WAS A RESULT OF BOILER UNIT
PROBLEMS AND REDUCED LOAD CAPACITY.
9/80 SYSTEM 720
• * PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR SEPTEMBER 1980.
SI
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
DESIGN AND PERFORMANCE DATA
SECTION 3
FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
i/NIT NUMBER
CI1Y
STATE
SRCSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MB
ARIZONA PUBLIC SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
119.0
115.0
119.0
** FUEL DATA
FJEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•* GENERAL EMISSION CONTROL SYSTEM DATA
6ENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEH/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
532 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• DISPOSAL
TYPE
- X
COAL
BITUMINOUS
23609.
13.50
15.00
.50
.02
UET SCRUBBING
LIMESTONE
RESEAfiCH-COTTRELL
RETROFIT
3.4
10/73
12/73
S8.SO
80.00
.0
.0
( 10150 BTU/LB)
OPEN
7.6
( ICO 6PM)
POND
...—...b— —,—.. —— -—PERFORMANCE DATA——-
•ERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
11/79 A
B
SYSTEM
n/79 A
B
SYSTEM
1/80
5/80
4/80
A
B
SYSTEM
2/80 A
B
SYSTEM
100.0
A
B
SYSTEM
77.0
98.5
87.8
94.0
86.7
90.4
95.5
99.1
97.5
100.0
99.4
99.7
99.1
93.1
96.1
PROBLEMS/SOLUTIONS/COMMENTS
100.0
77.0
98.5
87.8
94.0
86.7
90.4
95.5
99.1
97.3
100.0
99.4
99.7
99.1
93.1
96.1
720 720 632
744 744 672
744 744 724 91.7
696 696 694 92.1
744 744 715 88.6
NO FORCED OUTAGES UERE REPORTED BY THE UTILITY FOR THE FIVE MONTH PERIOD
OF NOVEMBER 1979 THROUGH MARCH 1980. SOME SCHEDULED OUTAGE TIME HAS
REQUIRED FOR REPAIR OF THE REHEATER DUCTWORK.
A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
720 720
720 82.8
52
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
ARIZONA PUBLIC SERVICE: CMOLLA 1 (CONT.)
—— —— — — — --PERFORMANCE 6ATA— ——-— — ——~-
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
»* PR08LEMS/SOLUTIONS/CONMENTS
NO FGD-RELATED PROBLEMS WERE REPORTED FOR THE MONTH OF APRIL.
5/80 A 100.0 100.0 100.0 100.0
B 99.2 99.2 99.2 99.2
SYSTEM 99.6 99.6 99.6 99.6 744 744 741 87.6
** PROBLENS/SOLUT10NS/CONMENTS
THE B-MODULE OUTAGE TIME IN HAY WAS CAUSED BY PROBLEMS UITH THE BOOSTER
FAN.
i/80 A 100.0 80.7 100.0 68.7
B 99.3 87.7 99.1 74.6
SYSTEM 99.7 84.2 99.6 71.7 720 613 516 67.5
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE SCHEDULED MAINTENANCE MAS PERFORMED ON THE BOILER. THE
SCHEDULED OUTAGE TIME WAS NECESSARY TO ACID WASH THE CONDENSERS.
THE ONLY FGD-RELATED OUTAGE OCCURRED WHEN A BLOCK VALVE MALFUNCTIONED.
THE B-MODULE HAS OUT OF SERVICE FOR FIVE HOURS.
7/80 A 100.0 100.0 100.0 100.0
B 100.0 98.6 100.0 98.6
SYSTEM 100.0 99.3 100.0 99.3 744 744 739 95.8
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE 1OOZ OF THE TIME IN JULY. MODULE B WAS NOT
UTILIZED FOR PART OF THE MONTH DUE TO LOU BOILER LOAD.
S/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DATA FOR THE AUGUST AND SEPTEMBER MONTHS WfcRE NOT AVAILABLE DUE TO
PERSONNEL CHANGES.
53
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - NU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X-
ABSORBER SPARE COMPONENTS INDEX
•* HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
- X
ARIZONA PUBLIC SERVKE
CHOLLA
2
JOSEPH CITY
ARIZONA
264.0
235.0
264.0
COAL
BITUMINOUS
23609.
13.SO
15.00
.50
.02
MET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
*******
4/78
6/78
75.00
99.70
33.0
1.0
( 10150 6TU/LB)
OPEN
7.6
UNLINED POND
t 1CO GPM)
. . _ „__....—.-.-....—-._...._pERfORNANCE DATA—-——— —-—___.__„_
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
NO INFORMATION IS AVAILABLE AS OF YET WITH RESPECT TO THE CHOLLA 2 FGD
OPERATIONS.
4/80 SYSTEM
S/BO SYSTEM
4/80 SYSTEM
*• PROBLEMS/SOLUTIONS/COMNENTS
720
744
720
7/80 SYSTEM
1/80 SYSTEM
J/80 SYSTEM
THE FGD SYSTEM PERFORMANCE DATA FOR THE APRIL-JUNE PERIOD ARE NOT AVAILABLE
AT THIS TIME. "
744
744
720
54
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
ARIZONA PUBLIC SERVICE: CHOLLA 2
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY WANE
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MU
«ET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
FARMINGTON
NEW MEXICO
175.0
175.0
175.0
( 8600 BTU/L8)
- X
COAL
SUBBITUMINOUS
20004.
22.00
12.30
.75
.07
UET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
RETROFIT
*******
11/79
**/**
80.00
99.00
.0
.0
...—.-....——-— — .. PERFORMANCE DATA ———————————..___._.__
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X RbflOVAL PER BOILER FGD CAP
302 PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 720
12/79 SYSTEM 7**
*• PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/80 SYSTEM 744
a/80 SYSTEM 696
5/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
7/80 SYSTEM
i/60 SYSTEM
»/80 SYSTEM
ALTHOUGH THE FGD SYSTEM PERFORMANCE DATA ARE BEING LOGGED, THE UTILITY
REPORTED THAT IT IS UNAVAILABLE FOR RELEASE AT THIS TIME.
744
744
720
-------
EP* UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
ARIZONA PUBLIC SERVICE: FOUR CORNERS 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMNENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOT YET AVAILABLE.
57
-------
EPA UTILITY FGD SURVET: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - NW
HET UNIT GENERATING CAPACITY N/FGD - MU
EBUIVALENT SCRUBBED CAPACITY - KM
•• FUEL DATA
FUEL TTPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
tENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
FARMINGTON
NEW MEXICO
175.0
175.0
175.0
< 8600 BTU/LB)
- X
COAL
SUBBITUMINOUS
20004.
12.00
12.30
.75
.07
WET SCRUBBING
LIME/ALKALINE FLYASN
CHEMICO DIVISION, EMVIROTECH
RETROFIT
•»••**»
11/79
**/ •*
80.00
99.90
.0
.0
...........„„....——..--- -PERFORMANCE DATA-- ————————.—..___,.____
PERIOD NODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
720
744
11/79 SYSTEM
1Z/79 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/80 SYSTEM 744
Z/BO SYSTEM 696
5/80 SYSTEM 744
• * PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.
4/80 SYSTEM 720
5/80 SYSTEM 744
i/80 SYSTEM 720
** PROBLEHS/SOLUTIONS/COHMENTS
ALTHOUGH THE FGD SYSTEM PERFORMANCE DATA ARE BEING LOGGED, THE UTILITY
REPORTED THAT IT IS UNAVAILABLE FOR RELEASE AT THIS TINE.
7/80 SYSTEM
J/BO SYSTEM
9/80 SYSTEM
744
744
720
58
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ARIZONA PUBLIC SERVICE: FOUR CORNERS 2 (CONT.)
-PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
•* PROBLEHS/SOLUTIONS/COMMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOT YET AVAILABLE.
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 198C
SECTION 3
DESIGN ANO PERFORMANCE OAT* FOR OPERATIONAL DOMESTIC FGD SYSTEMS
CONPANY NAME
PLANT NAME
JN1T NUM3ER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - Mw
«ET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - »tf
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A3SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
FARMINGTON
NEW MEXICO
229.0
229.0
229.0
( 8600 BTU/LB)
COAL
SUBBITUMINOUS
20004.
22.00
12.30
.75
.07
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
RETROFIT
11/79
**/ ••
80.00
X 99.00
.0
.0
. — PERFORMANCE DATA -—._«.
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X RtWOVAL PER BOILER FGD C*p"~
SO? PART. HOURS HOURS HOURS FACTOR
720
744
744
696
744
11/79 SYSTEM
12/79 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/80 SYSTEM
2/80 SYSTEM
3/BO SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOWN/BEPUGGING PHASE OF OPERATION.
t/BO SYSTEM 720
5/80 SYSTEM 744
1/80 SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
ALTHOUGH THE FGD SYSTEM PERFORMANCE DATA ARE BEING LOGGED, THE UTILITY
REPORTED THAT IT is UNAVAILABLE FOR RELEASE AT THIS TIME.
7/80 SYSTEM
1/80 SYSTEM
7/80 SYSTEM
744
744
720
60
-------
EPA UTILITY FGB SURVEY: JULY - SEPTEMBER 1980
ARIZONA PUBLIC SERVICE: FOUR CORNERS 3 (CONT.)
..—._ _—._.—... PERFORMANCE DATA ——«—— —— —-—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
302 PART. HOURS HOURS HOURS FACTOR
•• PROBLENS/SOLUTIONS/COMNENTS
NO INFORMATION HAS AVAILABLE FOR THE THIRD QUARTER 1980.
61
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FCD SYSTEMS
COMPANY NAME
PLANT NAXE
JHIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION. LIMITATION - NG/J
«ET PLANT 6ENERATTNS CAPACITY - KW
SROSS UNIT GENERATING CAPACITY - My
»ET UNIT GENERATING CAPACITY U/F6D - My
VET UNIT GENERATING CAPACITY UO/F6D - MW
EOUIVALENT SCRUBBED CAPACITY - MW
•* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
HAXHUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - H
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - 3TU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - Z
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROMAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DFSIGN REMOVAL EFFICIENCY - X
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION INITIATION
CONTRACT AWARDED
LETTER OF INTENT SIGNED
• • ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICULATE OUTLET LOAD - G/CU.M
•• A9SOR3ER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
DIMENSIONS - FT
SHELL MATERIAL
BOILER LOAD/ABSORBER - I
SAS FLOW - CU.M/S
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
1
WHEATLAND
WYOMING
C
43. (
86. C
1500.0
570.0
500.0
500.0
570.0
BABCOCK ( WILCOX
PULVERIZED COAL
BASE
4/80
.tOO LB/MMBTU)
.COO LB/MMBTU)
1321.32
56.1
183.
8.7
COAL
SUBBITUMINOUS
18931.
7.89
******
28.92
******
.81
.15-.81
.04
******
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
BURNS K MCDONNELL
RESEARCH-COTTRELL
FULL SCALE
NEW
99.60
90.00
7/80
7/80
1/78
1/77
12/76
COLD SIDE
BABCOCK I WILCOX
59.6
1085.4
141.1
*******
.02
(2800000 ACFM)
( 133 F)
( 600 FT)
( 28.6 FT)
( 8139 BTU/LB)
******
C2300000 ACFM)
( 286 F)
(***** IN-H20)
( .01 GR/SCF)
GRID/SPRAY TOWER
4/80
RESEARCH-COTTRELL
30 X 30 X 88
316L SS CTOP3 UDDEHOLM 904L CBOTTOM]
25.0
1085.37 (2300000 ACFM)
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
BASIN ELECTRIC POWER COOP: LARAMIE RIVER 1 (CONT.)
SAS TEMPERATURE - C
L/6 RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - M/SEC
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE INLET LOAD - NG/J
PARTICULAR OUTLET LOAD- G/CU.M
PARTICULATE OUTLET LOAD - NG/J
PARTICULATE REMOVAL EFFICIENCY - X
S02 INLET CONCENTRATION - PPM
S02 INLET CONCENTRATION -NG/J
S02 OUTLET CONTRATION - PPM
S02 OUTLET CONCENTRATION- NG/J
S02 DESIGN REMOVAL EFFICIENCY - X
A3SORBER SPARE CAPACITY INDEX - X
A3SORBER SPARE COMPONENT INDEX
CENTRIFUGE
INLET SOLIDS - X
OUTLET SOLIDS - X
141.1
8.0
3.0
.0
21.
.0
21.
.0
800
*****
80
*** **
90.0
25.0
1.0
55. 0
60.0
( ?B6 F)
( 60*0 GAL/1000ACF)
C 10.0 FT/S)
( .015 GR/SCF)
( .050 LB/MMBTU)
( .015 GR/SCF)
( .050 LB/MMBTU)
(****,* LB/MMBTU)
(***«* LB/MMBTU)
** PASS
NUMBER
TYPE
SERVICE - WET/DRY
•* MIST ELIMINATOR
TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
•* THICKENER
NUMBER
CONSTRUCTION MATERIAL
DIAXETER - M
•* WATER LOOP
TYPE
FRESH MAKEUP HATER ADDITION - LITERS/S
•* REAGENT PREPARATION EQUIPMENT
NUMBER OF BALL HILLS
9ALL MILL CAPACITY- N T/H
REAGENT PRODUCT - X SLURRY SOLIDS
** BYPRODUCTS
DISPOSITION
** TREATMENT
TYPE
•* DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
INDUCED DRAFT
DRY
CHEVRON
VERTICAL
1
1
PH. SOLIDS, $02 INLET, ACFM, S02 OUTLET
AUTOMATIC
CONCRETE
33.5
CLOSED
16.9
2
13.6
30.0
LANDFILL
FORCED OXIDATION
FINAL
LANDFILL
ON SITE
CONVEYOR BELT
(110 FT)
( 269 6PM)
( 15.0 TPH)
_ . — ..—-PERFORMANCE DATA———-— .„.——._-—————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/80 SYSTEM
** PROBLLAS/SOLUTIONS/COMNENTS
744
8/80 SYSTEM
THE UNIT BEGAN INITIAL AND COMMERCIAL OPERATIONS ON JULY 1, 1980.
PROBLEMS HERE REPORTED DURING STARTUP.
744
NO MAJOR
63
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 198C
BASIN ELECTRIC POWER COOP: LARAHIE RIVER 1 CCONT.)
... . . PERFORMANCE DATA _
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
* SO? PART. HOURS HOURS HOURS FACTOR
>/80 SYSTE" 720
*• PROBLEftS/SOLUTIONS/COMWENTS
THE UNIT IS STILL IN THE STARTUP PHASE OF OPERATIONS. NO PERFORMANCE DATA
ARE CURRENTLY AVAILABLE.
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIEN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
«ET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»* GENERAL EMISSION CONTROL SYSTEM DATA
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
t« WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
BIG RIVERS ELECTRIC
GREEN
1
SEBREE
KENTUCKY
242.0
200.0
- X
COAL
BITUMINOUS
22678.
20.00
11.00
3.75
.05
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
( 9750 BTU/LB)
12/79
12/79
90.00
99.00
30.0
.4
CLOSED
POZ-0-TEC
(..»»* 6PM)
PERFORMANCE DATA
(•ERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
J/80 SYSTEM
696
7*4
j/80 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST OUARTERf 1980.
t/80 A
B
SYSTEM
65.0
65. D
65.0
56.0
56.0
56.0
78.8
79.0
79.0
45.0
45.0
45.0
720
576
3Z4
•* PROBLEMS/SOLUTIONS/COMMENTS
5/80 A
B
SYSTEM
73.7
73.7
73.7
THE FOLLOWING FIVE OUTAGES OCCURRED IN APRIL AND ACCOUNTED FOR THE LOW
AVAILABILITY OF THE FGD SYSTEM.
1. LOW ADDITIVE IN TANK
2. INSTRUMENT TROUBLE
3. WATER IN THE PANEL
4. LOW ON LIME IN THE HOLDING TANKS
5. THE ESPS TRIPPED
76.1
76.0
76.1
79.0
78.9
79.0
73.7
73.5
7J.7
744
720
548
65
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
JIB RIVERS ELECTRIC: 6REEN 1 (CONT.)
PERFORMANCE BATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
$02 PART. HOURS HOURS HOURS FACTOR
• •• —» —fc»—•— • ____•__•••_. _•__••_*••«.. •—._••••••• • •«••••••••• ••••• • •••• _•__« _••••_ ••«•• — ••••
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE FGD SYSTEM WAS OFF LINE FOR APPROXIMATELY 548 HOURS DUE
TO THE FOLLOWING PROBLEMS.
1. SULFUR OXIDES TOO HI6H
2. LOU LEVEL IN ADDITIVE TANK
3. INSTRUMENT TROUBLE
It. SCHEDULED MAINTENANCE OUTAGE
5. SOLIDS ON CARRY OVER
6. SOLID WASTE PROBLEM
7. UNIT TRIPPED
8. CONSTRUCTION WORK
i/80 SYSTE" 720
•* PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF JUNE.
7/80 SYSTEM 744
3/80 SYSTEM 744
>/80 SYSTEM 720
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE THIRD QUARTER 1980.
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FED SYSTEMS
COMPANY NAME
PLANT MA*E
JM1T NU«3ER
CITY
STATE
5ROSS UNIT GENESATIN6 CAPACITY - flu
«ET UNIT GENERATING CAPACITY W/FCD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULAR DESIGN REMOVAL EFFICIENCY
ABSORBER SPARF CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
• * DISPOSAL
TYPE
- X
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
CANTON
ILLINOIS
416.0
378.0
416.0
( 10396 BTU/LB)
COAL
BITUMINOUS
24181.
9.77
15.43
3.66
.06
WET SCRUBBING
LIMESTONE
ENVIRONEERING, R1LEY STOKER
NEW
2.9
7/76
8/78
85.00
.0
.0
CLOSED
37.8
LINED POND
C 600 GPM>
__ ... - — PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 A
B
C
D
SYSTEM
24.8
58.5
17.1
29.2
32.4
27.0
63.6
18.6
31.8
35.3
29.8
65.9
20.3
35.3
37.8
24.8
58.5
17.1
29.3
32.4
7(4 684 241 81.6
•• PROBLEMS/SOLUTIONS/COMMENTS
2/80
A
B
C
D
SYSTEM
11.8
72.7
70.7
41.3
49.1
MOST OF THE JANUARY OUTAGE TIME WAS REQUIRED FOR RECYCLE TANK COVERING
WORK.
THE HIST ELIMINATOR SECTION PLUGGED ALONG WITH THE NOZZLES HINDERING
SYSTEM OPERATIONS. THE HIST ELIMINATOR DRAIN LINE HAS MODIFIED ALSO
CAUSING OUTAGE TIME.
OTHER PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED A PLUGGED LIMESTONE
FEEDER, INLET DANPER PROBLEMS, SLURRY SUPPLY HEADER LEAKS AND STORAGE
PUMP DISCHARGE VALVE REPAIRS.
11.8
72.7
70.7
41.3
49.1
12.5
73.5
71.5
47.9
51.4
11.8
72.7
70.7
41.3
49.1
696 696
342 73.5
67
-------
EPA UTILITY fGO SURVEY: JULY - SEPTEMBER 1980
CENTPAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
•* PROBLE«S/SOLUTIONS/COMMENTS
DURING FEBRUARY SOME OUTAGE TIME VAS DUE TO MODULE D CLEANING AND THE
CLEANING OF THE MODULE D WIST ELIMINATOR SECTION.
THE INLFT DAMPER DRIVE WAS REPLACED DURING THE MONTH.
REPAIR OF THE FIBERGLASS ON THE SLURRY RECYCLE LINE HINDERED OPER-
ATIONS DURING THIS MONTH.
THE MODULES A AND D RECYCLE DISCHARGE VALVE WERE REPLACED CAUSING EXTENSIVE
DOWN TIME.
3/8P
A
B
C
D
SYSTEM
52.9
73.2
51.0
34.0
52.9
6?. 5 64.7 52.9
86.6 86.9 73.2
60.3 60.5 51.0
4T.2 45.9 34.0
6?. 4 65.1 52.8 74* 629 393 68.
6
** PROBLEXS/SOLUTIOSS/COMMENTS
4/80
A
B
C
D
SYSTEM
53.0
54.3
57.2
26.0
47.6
DURING MARCH NEW RECYCLE PUMP DISCHARGE VALVES WERE INSTALLED IN ORDER TO
ELIMINATE RESTRICTED FLOU OF THE OLD VALVES.
CARRIER SEARINGS ON THE INLET DAMPER WERE REPLACED IN ORDER TO MAINTAIN
MODULE ISOLATION CAPABILITY.
THE MIST ELIMINATOR WASH SYSTEM WAS CONVERTED TO RETURN WATER IN ORDER
TO ACHIEVE A HIGHER OUAL1TY ELIMINATION WASH WATER.
FIBERGLASS LINES ON THt RECYCLE PUMP DISCHARGE WERE ALSO REPAIRED DURING
EXTENSIVE
81.7 95.9 5J.9
83.6 87.5 54.2
88.3 95.3 57.2
40.1 71.9 26.0
73.4 89.2 47.6 720 466 342 35.
3
** PROBLEMS/SOLUTIONS/COMMENTS
THE MAJOR PROBLEM HINDERING SYSTEM OPERATIONS DURING APRIL WAS THE REBUILD
OF THE RECYCLE TANK MIXER.
5/80
A
B
C
D
SYSTEM
44.6
45.7
34.7
43.6
42.1
MINOR PROBLEMS DURING THE MONTH WERE CAUSED BY THE INOPERABIL IT V OF THE
LIMESTONE HANDLING SYSTEM.
68.6 72.0 44.6
70.3 73.5 45.7
53.3 59.1 34.7
67.0 73.9 43.6
64.8 69.7 42.1 744 484 314 49.4
** PROBLEMS/SOLUTIONS/COMMENTS
i/80
A
B
C
D
SYSTEM
87.6
86.8
84.5
80.0
84. R
DURING MAY REPAIRS WERE MADE TO THE RECYCLE TANK RUBBER LINER.
EXPANSION JOINT LEAKS WERE ALSO REPAIRED DURING THE MONTH.
OTHER OPERATIONAL PROBLEMS INCLUDED THE REPLACEMENT OF THE LIMESTONE
STORAGE TANK MIXER MOTOR, MODIFICATION OF ROD DECKS TO REDUCE SYSTEM
DIFFERENTIAL PRESSURE AND REPAIR OF THE LIMESTONE FEEDER SYSTEM.
82.3 87.1 82.1
82-6 86.0 82.3
«f«4 84.3 81.1
73.1 75.8 72.9
79'9 84.3 79.6 720 718 573 78.
5
68
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
. -PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
302 PART. HOURS HOURS HOURS FACTOR
• • PROBLEHS/SOLUTIONS/CONMENTS
A LEAK HAS REPAIRED IN THE SLURRY SUPPLY HEADER DURING JUNE.
riORK CONTINUED ON THE MODIFICATIONS BEING DONE ON THE ROD DECKS IN THE
ABSORBER MODULES.
7/80 A
B
C
D
SYSTEM
91.2
83.5
90.5
87.5
88.2
81.0
70.0
78.8
74.9
76.2
87.6
80.0
86. 4
85.4
84.9
70.1
60.6
68.2
64.8
65.9
744
644
490 67.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY FGD SYSTEM OUTAGE TINE RESULTED FROM THE NECESSARY REPAIR
OF THE SLURRY SUPPLY LINE AND REPAIR OF THE MALFUNCTIONING CLUTCH IN THE
MILL SYSTEM.
ADDITIONAL OUTAGE TIME OCCURRED SO REPAIRS TO THE 1B STORAGE TANK PUMP
DISCHARGE VALVES AND THE STORAGE TANK MIXER MOTOR COULD BE COMPLETED.
3/80
A
B
C
D
SYSTEM
88.6
91.4
91.3
90.6
90.5
85.4
86.3
84.6
85.1
85.4
92.7
90.8
88.9
90.1
90.7
81.9
82.7
81.0
81.6
81.9
744 713
609 76.5
*• PROBLEMS/SOLUTIONS/COMMENTS
THE SLURRY SUPPLY ISOLATION VALVE WAS REPAIRED IN AUGUST.
THE POND WATER RETURN LINE WAS ALSO REPAIRED DURING THE MONTH.
REPAIRS WERE HADE TO THE ELECTRICAL SYSTEM AFTER A POWER FAILURE IN THE
WASTEWATER BUILDING.
J/80
A
B
C
D
SYSTEM
43.1
47.8
45.6
44.3
45.6
39.2
47.2
43.2
46.0
43.9
41.5
48.2
45.9
47.6
45.9
39.2
47.2
43.2
46.0
43.9
720 720
316 81.3
** PROBLEMS/SOLUTIONS/COMMENTS
MAJOR PROBLEMS DURING SEPTEMBER INCLUDED REPAIR OF THE LIMESTONE BALL HILL.
AFTER IT WAS REPAIRED, THE BALL HILL MOTOR BURNED OUT AND HAD TO BE RE-
PLACED.
SLURRY CONTAMINATION OF THE HILL BEARING Oil AND REPAIR OF THE RECYCLE PUMP
SUCTION SCREEN CAUSED THE FSO SYSTEM TO BE DOWN FOR SEVERAL HOURS DURING
THE MONTH.
69
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FED SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
KROSS UNIT GENERATING CAPACITY - HW
»ET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A9SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
• • WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEWTON
ILLINOIS
617.0
575.0
617.0
( 10900 BTU/LB)
COAL
BITUMINOUS
25353.
12.70
9.SO
2.25
.20
WET SCRUBBING
DUAL ALKALI
BUELL DIVISION. ENViROTECH
NEW
9/79*
13/79
90.00
X 99.50
.0
.0
CLOSED
POZ-0-TEC
(««*»» 6PM)
_-_-.__-„_.._-__. — -— . .. -PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80
A
B
C
D
SYSTEM
68.3
66.4
5Z.2
21.0
52.0
57.1
60. 6
48.8
1?.1
46.4
6J.5
64.9
60.5
2«.3
53.8
55.5
58.9
47.4
18.5
45.1
7*4 723 336
«« PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY TESTS MERE CONDUCTED TO CERTIFY THE GAS EMISSIONS MONITOR
AT NEWTON.
PRESATURATOR CORROSION AND EXPANSION JOINT REPAIRS AND A DEPLETION OF THE
FLYASH USED FOR SLUDGE STABILIZATION ACCOUNTED FOR THE LOU JANUARY
DEPENDABILITY FIGURES.
2/80
A
B
C
D
SYSTEM
61.1
74.4
78.2
.0
53.4
42.4
55.7
55.5
.0
39.2
45.0
57.7
59.1
.0
40.4
42.4
55.7
58.5
.0
39.2
696 696
273
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE D-MODULE WAS UNAVAILABLE DUE TO THE COLLAPSE OF THE
PRECOOLER MIST ELIMINATORS CAUSED BY A TEMPERATURE EXCURSION.
REPAIR WORK ON THE PRESATURATOR CORROSION AND EXPANSION JOINTS AS WELL AS
THE FLYASH DEPLETION PROBLEM CONTINUED TO YIELD LOU DEPENDABILITY FIGURES
FOR FEBRUARY.
70
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
CENTRAL ILLINOIS PUBLIC SERV: NEWTON 1 (CONT.)
. — ... —— — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/80
A
B
c
ft
SYSTEM
53.4
47.0
44. 5
.0
36.2
53.6
42.3
41.1
.0
34.0
53.1
48.0
46.5
.0
36.9
52.3
42.1
41.0
.0
33.9
744 740 252
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER, 1980. THE FOLLOWING PROBLEMS WERE ENCOUNTERED:
THE VALVES AND PIPING IN THE PRECOOLER LOOP EXPERIENCED CORROSION.
THE WIST ELIMINATOR OH THE 0 MODULE FAILED.
THE FLY ASH SUPPLIES DEPLETED.
RUBBER LINING AND DUCTWORK LINING FAILURES OCCURRED.
BOOSTER FAN EXPANSION JOINT FAILURE OCCURRED.
THE THICKENER EXPERIENCED PLUGGING.
THESE COMBINED PROBLEMS ACCOUNTED FOR THE UOW MARCH PERFORMANCE FIGURES.
FOR THE aUARTER, THE TOTAL SYSTEM HAS AVAILABLE 47.2Z AND WAS UTILIZED
39.4X OF THE TIME.
4/80
A
B
C
D
SYSTEM
33.8
35.4
57.4
26.1
33.2
31.3
25.8
35.6
21.8
28.6
31.4
25.8
35.6
21.8
28.6
31.3
25.8
35.6
21.8
28.6
720 720
206
** PROBLEMS/SOLUTIONS/COMMENTS
THE NEWTON 1 FGD SYSTEM WAS OUT OF SERVICE DURING THE FIRST 12 DAYS OF
APRIL FOR NECESSARY REPAIRS ON THE OUTLET DUCT LININGS. THE UTILITY INDI-
CATED THAT THE LINING FAILURES MAY HAVE RESULTED FROM IMPROPER APPLICATION.
DURING THE LAST 18 DAYS OF APRIL MINOR PROBLEMS WERE EXPERIENCED WITH
THE OCCURANCE OF PLUGGING IN THE SODIUM CARBONATE THICKENER AND CORROSION
OF THE VALVES IN THE PRESATURATOR CIRCUIT.
S/80 A
B
C
D
SYSTEM
.0
9.7
9.7
.0
4.8
.0
9.6
9.6
.0
4.8
.0
9.6
9.6
.0
4.8
.0
6.2
6.2
.0
3.1
744 477
23 45.5
** PROBLEMS/SOLUTIONS/COHMENTS
DURING MAY, THE FGD SYSTEM WAS DOWN BECAUSE THE FLUIDIZING STONES WERE
CAKED WITH FLY ASH. THIS WAS CAUSED BY IMPROPER WIRING OF THE HEATER WHICH
9LOWS OVER THE STONES. THE HEATER WAS REWIRED AND THE FLUIOIZIN6 STONES
REPLACED. FLUIDIZING STONES ARE LOCATED IN THE FLVASH SILO. HEATED AIR
PASSES THROUGH THESE POROUS STONES TO AERATE OR "FLUIDIZE" THE FLYASH SO
THAT IT CAN BE CONVEYED TO THE FLVASH/SLUD6E MIXER. WHEN THE FLYASH
SUPPLY IS DEPLETED OR THE MATERIAL CANNOT BE DELIVERED TO THE MIXER THE
SCRUBBING SYSTEM IS SHUT DOWN. THE SLUDGE MUST BE TREATED WITH FLYASH
BEFORE DISPOSAL.
S/80 A
C
D
SYSTEM
.0
40.3
40.4
.0
20.?
.0
40.3
40.4
.0
20.2
.0
40.3
40.4
.0
20.2
.0
40.3
40.4
.0
20.2
720 720
145 63.0
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE A AND D MODULES WERE UNAVAILABLE FOR OPERATION BECAUSE
THE MIST ELIMINATORS COLLAPSED.
THE SYSTEM WAS SHUTDOWN DURING THE FIRST HALF OF THE MONTH TO REPAIR THE
DRY FLVASH COLLECTION SYSTEM WHICH ACCOUNTED FOR THE LOW B AND C MODULE
FIGURES.
71
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
CENTRAL ILLINOIS PUBLIC SERV: NEWTON 1 (CONT.)
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
7/80 A
B
C
D
SYSTEM
3.5
3.6
.0
.0
1.8
3.7
3.9
.0
.0
1.9
3.7
3.9
.0
.0
1.9
3.5
3.6
.0
.0
1.8
7** 698 13 67.8
•* PROBLEHS/SOLUTIONS/COMMENTS
DURING JULY PROBLEMS WERE
ENCOUNTERED WITH THE MIST ELIMINATORS.
SOME Of THE SYSTEM OUTAGE TIME RESULTED FROM
OCCURRENCE Of CORROSION IN THE PRES ATURATOR .
3/80 A
B
C
D
SYSTEM
.C
64.7
51.2
37.6
53.8
SCRUBBER PLUGGING
AVAILABILITY.
.0
50. 2
3t.1
21.9
36.4
DURING
.0
50.2
36.9
24.0
39.9
JULY CONTRIBUTED TO
.0
49.3
33.5
21.5
35.8
REPAIRS MADE NECESSARY BY THE
THE LOW FCD SYSTEM
744 731 266 68.2
»» PROBLEMS/SOLUTIONS/COMMENTS
PLUGGING PROBLEMS
AUGUST.
WITHIN
THE FGD SYSTEM WERE
BECAUSE OF CHANGES IN SYSTEM OPERATIONS, ONLY
CURRENT S02 REGULATIONS.
9/80 A
B
C
0
SYSTEM
69.0
99.6
96.9
99.6
99.1
20.3
74.6
35.8
80.8
67.8
48.6
80.3
66.8
80.8
82.5
10.0
36.8
17.6
39.9
33.4
THE CAUSE OF DOWN TIME IN
3 MODULES ARE NEEDED TO MEET
720 555 241 33.2
*• PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS TAKEN OUT OF SERVICE ON SEPTEMBER 16, 1980 FOR A SCHEDULED
MAINTENANCE OUTAGE.
72
-------
EP* UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FCD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - HW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S92 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
»* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
- X
COLORADO UTE ELECTRItC ASSN
CRAIG
2
CRAIG
COLORADO
455.0
415.0
400.0
( 10000 BTU/LB)
COAL
SUBBITUHINOUS
23260.
8.00
16.00
.45
.00
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEW
1.5
12/79
5/80
85.00
99.80
33.3
1.0
CLOSED
19.9
MINEFILL
( 3>6 GPN)
..... PERFORMANCE DATA" — —
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
J/BO
SYSTEM
SYSTEM
SYSTEM
*« PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE BOILER WAS DOWN AT THE END OF THE PERIOD DUE TO TURBINE RELATED
PROBLEMS.
WHEN FULL LOAD OPERATIONS WERE ATTEMPTED CONTROL PROBLEMS WERE ENCOUNTERED
WITH THE SCRUBBER.
PROBLEMS WITH OPENING/CLOSIN6 THE BYPASS DAMPER HAVE BEEN ENCOUNTERED.
LARGER OPERATORS ARE BEING TESTED THAT MAY SOLVE THE PROBLEM.
4/80
SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
720
THE FGD SYSTEM IS STILL IN THE STARTUP PHASE OF OPERATIONS. TESTING IS
BEING PERFORMED ON THE SYSTEM, BUT THERE HAS BEEN NO OPERATIONAL DATA
REPORTED.
5/80
38.4
42.5
47.0
27.5
32.1
37.2
28.4
33.1
38.4
24.5
28.5
33.1
73
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
COLORADO UTE ELECTRIC ASSN: CRAIG 2 (COMT.)
— : PERFORMANCE DATA ~--..„
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
D
SYSTEM
30.0
52.6
18.0
38.3
18.6
39.5
16.0
34.0
6*. TO,
640
661
253
76.8
*• PROBLEMS/SOLUTIONS/COHMENTS
THE CRAIG 2 UNIT (BOILER AND SCRUBBER) COMMENCED COMMERCIAL OPERATION ON
HAY 4, 1980.
NOTE: THIS SYSTEM EFFECTIVELY HAS ONE SPARE MODULE SO THAT ONLY THREE ARE
CURRENTLY NEEDED AT FULL LOAD TO MAINTAIN COMPLIANCE KITH S02 EMIS-
SION REGULATIONS. WHEN THE CURRENT LOU SULFUR COAL SOURCE IS
EXHAUSTED (SEVERAL YEARS FROM NOW) 6REATER SCRUBBING CAPACITY HILL
BE REBUIRED SO THAT THERE WILL NO LONGER BE AN ENTIRE MODULE SET
ASIDE AS A SPARE DURING FULL LOAD BOILER OPERATIONS. THE "SYSTEM"
DEPENDABILITY FACTORS MILL BE BASED ON THREE MODULES UNTIL THE
CURRENT COAL SOURCE IS EXHAUSTED.
6/80 A
a
c
D
SYSTEM
47.6
53.9
61.1
14.6
65.7
41.2
48.0
55.8
27.0
57.3
42.0
48.9
56.9
27.5
58.4
37.9
44.2
51.4
24.9
52.8
65.70
720 663
380 68.5
•• PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY AND JUNE, PROBLEMS HERE ENCOUNTERED WITH PLUGGING OF THE
ABSORBER SPRAY NOZZLES.
A PROBLEM HAS ALSO ENCOUNTERED DURING INITIATION OF COMMERCIAL OPERATION
ylTH A HIGH PH LEVEL IN THE THICKENER UNDERFLOW.
THE SCRUBBING SYSTEM IS STILL UNDERGOING SHAKEDOWN OPERATIONS.
7/80
A
B
C
D
SYSTEM
59.1
61.8
37.6
43.7
67.4
51.0
54.1
26.0
33.0
54.7
51.7
54.9
26.3
33.5
55.5
43.B
46.5
22.3
28.4
47.0
65.60
744 640 350 65.8
PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY, FGD OUTAGE TIME WAS CAUSED BY PLUGGED ABSORBER SPRAY NOZZLES.
a/so
A
B
C
D
SYSTEM
50.0
50. 0
50.0
50.0
66.7
46.7
48.4
47.5
52.3
65.0
48.3
50.0
49.1
54.0
67.1
42.2
43.7
42.9
47.2
58.7
65.60
744 672
327 75.6
•• PROBLEMS/SOLUTIONS/COMNENTS
DURING AUGUST THE FGD SYSTEM EXPERIENCED ASSORTED MECHANICAL PROBLEMS.
SPRAY NOZZLE PLUGGING OCCURRED. CAUSING ADDITIONAL OUTAGE TIME WHICH ADDED
TO THE LOW AVAILABILITY FACTOR DURING THE MONTH.
7/80 A
C
D
SYSTEM
48.6
58.2
61.1
67.4
78.4
47.5
58.8
59.6
66.2
77.4
48.4
59.9
60.7
67.4
78.8
47.1
58.2
59.0
65.6
76.6
65. 70
720 713
552 85.2
PROBLEMS/SOLUTIONS/COMMENTS
THE SPRAY NOZZLES IN THE ABSORBER MODULE CONTINUED TO PLUG UP DURING SEP-
TEMBER.
74
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT 6ENERATIN6 CAPACITY - NU
MET UNIT GENERATING CAPACITY U/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
• * FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
$02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
*» HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»• TREATMENT
TYPE
•• DISPOSAL
TYPE
COLUMBUS I SOUTHERN OHIO ELEC
CONESVILLE
5
CONESVILLE
OHIO
411.0
375.0
411.0
( 10850 BTU/LB)
- X
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
.01
WET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
1/77
2/77
89.50
.00
.0
.0
OPEN
31.5
POZ-0-TEC
POND
( 500 6PM)
.... . PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
1/80
A
B
SYSTEM
89.0
93.0
91.0
38.0
50.0
44.0
45.0
59.0
52.0
13.0
17.0
15.0
744 257
113 21.4
*• PROBLCMS/SOLUTIONS/COMMENTS
DURING JANUARY A BOILER OUTAGE OCCURRED FROM THE FIRST OF THE MONTH TO
JANUARY 20, DURING WHICH TIME MAINTENANCE WAS PERFORMED ON THE F6D SYSTEM.
2/80 *
B
SYSTEM
90.0
93.0
92.0
63.0
69.0
66.0
77.0
84.0
81.0
31.0
34.0
33.0
696 343
226 31.4
•» PROBLEMS/SOLUTIONS/CONMENTS
j/eo
B
SYSTEM
88.0
88.0
88.0
A BOILER OUTAGE LASTING APPROXIMATELY 17 DAYS ALSO OCCURRED DURING
FEBRUARY.
IN FEBRUARY. MIST ELIMINATOR NOZZLE PLUGGING OCCURRED CAUSING SOME F6D
SYSTEM OUTAGE TINE.
62.0
81.0
82.0
82.0
82.0
82.0
82.0
81.0
82.0
744 744
606 75.4
75
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
C3LUMSUS l SOUTHERN OHIO ELEC: CONESVILLE s (CONT.)
-PERFORMANCE DATA —• ——._._
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH PROBLEMS HERE EXPERIENCED WITH THE IUCS SLUDGE STABILIZATION
PROCESS AND SOME OUTAGE TIME RESULTED. ALSO DURING MARCH SOME GRID RODS
REQUIRED REPLACING AND SOME RUBBER LINER FAILURES OCCURRED.
THE MAJORITY Of THE MARCH FGO SYSTEM OUTAGE TIME WAS DUE TO CONTINUING
PROBLEMS WITH THE MIST ELIMINATOR NOZZLES.
1/80 A 94.6 8«.4 78.9
B 74.9 65.8 61.5
SYSTEM 84.7 75.2 70.3 720 673 506 63.1
•* PROBLENS/SOLUTIONS/COMMENTS
CONTINUAL PROBLEMS WITH THE DUMPERS, PRESATURATOR HOSES, AND NOZZLES WERE
THE CAUSES OF FGD SYSTEM OUTAGE TIME IN APRIL.
5/80 A 92.1 86.2 86.2
8 90.3 84.3 84.3
SYSTEM 91.3 85.2 85.2 744 744 634 69.5
•• PROBLERS/SOLUTIONS/COMMENTS
IN MAY, CONTROLS AND INSTRUMENTATION DEVELOPED PROBLEMS THAT CAUSED SOME
OUTAGE TIME.
6/80 A 89.6 71.0 70.7
B 94.3 74.8 74.4
SYSTEM 86.4 72.9 72.6 720 717 523 65.1
»• PROBLE1S/SOLUTIONS/COMMENTS
EXTERNAL CAUSES (IUCS DISPOSAL FACILITY, LOW UNIT DEMAND, SERVICE WATER
PROBLEMS, ETC.) HERE RESPONSIBLE FOR THE MAJORITY OF THE JUNE OUTAGES.
7/80 A 90.6 70.7 72.4 43.8
B 88.8 82.0 84.0 50:8
SYSTEM 89.7 76.4 78.2 47.3 744 461 352 36.6
•» PROBLEMS/SOLUTIONS/COMMENTS
THE PRESATURATOR HOSES AND NOZZLES PLUGGED CAUSING THE UNIT TO SHUT DOWN
FOR PART OF JULY.
J/BO A 98.0 83.5 84.9 48.5
B 95.4 88.8 90.4 51.6
SYSTEM 96.7 86.2 87.6 50.1 744 432 373 40.0
•• PROBLEMS/SOLUTIONS/COHHENTS
THE UTILITY REPORTED THAT PROBLEMS WITH THE RECLAIM WATER SYSTEM OCCURRED
IN AUGUST CAUSING SOME OUTAGE TIME.
»/80 * 84.8 73.4 74.4 73.1
B 85.9 85.1 86.3 82.0
SYSTEM 88.2 79.2 80.3 78.9 720 717 568 71.5
*• PROBLEMS/SOLUTIONS/COHMENTS
DURING THE JULY-SEPTEMBER PERIOD INLET DAMPER SEAL LEAKING WAS A MAJOR
PROBLEM.
THE PRESATURATOR PROBLEMS CONTINUED IN SEPTEMBER CAUSING ADDITIONAL OUTAGE
TIME FOR THE F6D SYSTEM.
76
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY H/F60 - MU
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
•* TREATMENT
TYPE
•* DISPOSAL
TTPE
SOUTHERN OHIO ELEC
C 10850 BTU/LB)
- X
COLUMBUS «
CONESVILLE
6
CONESVILLE
OHIO
411.0
375.0
411.0
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
.01
UET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
6/78
7/78
89.50
.00
.0
.0
OPEN
31.5
POZ-0-TEC
POND
t 500 GPM>
_._.....—... ......— ...... PERFORMANCE DATA- ...... ...—...... ....
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 A 88.0 74.0 74.0 74.0
B 89.0 78.0 78.0 78.0
SYSTEM 89.0 76.0 76. C 76.0
744 744 566 73.9
• * PROBLEMS/SOLUTIONS/COMRENTS
NO MAJOR FGD SYSTEM RELATED PROBLEMS UERE REPORTED FOR JANUARY.
2/80
A
B
SYSTEM
87.0
92.0
90.0
75.0
81.0
78.0
78.D
85.0
82.0
69.0
75.0
72.0
696
648
503 70.8
*• PROBLEMS/SOLUTIONS/COMRENTS
IN FEBRUARY, MIST ELIMINATOR NOZZLE PLUGGING OCCURRED CAUSING SOME OUTAGE
TIME.
3/80
A
B
SYSTEM
93.0
94.0
94.0
69.0
76.0
73.0
69.0
76.0
73.0
15.0
16.0
16.0
744
160
117 17.6
PROBLENS/SOLUTIONS/COMPENTS
THE BOILER WENT DOUN ON MARCH 9 FOR A BOILER/TURBINE INSPECTION AND
REMAINED OUT OF SERVICE THROUGH THE END OF THE MONTH.
77
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
COLUMBUS I SOUTHERN OHIO ELEC: CONESVILLE 6 (CONT.>
PERFORMANCE DATA -—»—..
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/80 A 98.8 25.6
B 98.9 54.2
SYSTEM 98.9 40.1
11.1
23.5
17.4 720 J12 125 1».a
•• PROBLE4S/SOLUTIONS/COMMENTS
CONTINUOUS PROBLEMS WITH DAMPERS, PRESATURATOR HOSES. AND NOZZLES
ACCOUNTED FOR MOST OF THE APRIL F6D SYSTEM OUTAGES.
5/80 A 96.9 58.3 55.0
B 96.1 33.8 31.9
SYSTEM 96.$ 46.1 43.4 744 701 323 J9.1
•* PROBLEMS/SOLUTIONS/COMMENTS
CONTROL AND INSTRUMENTATION PROBLEMS THAT DEVELOPED IN HAY WERE RESPONSI-
BLE FOR SOME F6D SYSTEM OUTAGE TIME.
6/80 A 97.1 73.6 73.1
SYSTEM 97.1 62.1 61.7 720 715 444 S2.5
»* PROBLEMS/SOLUTIONS/COMMENTS
THE MAJORITY OF THE JUNE FGD SYSTEM OUTAGES WERE A RESULT OF EITERNAL
CAUSES (IUCS DISPOSAL SYSTEM, LOW UNIT DEMAND, SERVICE WATER, ETC.).
7/80 A 96.0 85.1 £5.9 82.7
B 99.1 89.1 89.9 86.6
SYSTEM 97.5 87.1 87.9 64.6 744 722 630 61.7
•* PROBLEMS/SOLUTIONS/COMNENTS
THE FGD SYSTEM EXPERIENCED PROCESS CONTROL PROBLEMS DURING JULY.
PROBLEMS WITH LEAKING INLET DAMPER SEALS ALSO OCCURRED DURING JULY.
8/80 A 90.2 65.4 67.3 30.1
B 97.« 85.5 88.0 39.4
SYSTEM 93.8 75.5 77.6 34.7 744 343 259 28.3
•* PROBLCMS/SOLUTIONS/CONMENTS
THE UTILITY REPORTED THAT PROBLEMS WERE ENCOUNTERED WITH THE RECLAIM WATER
AND THE RECYCLE SLURRY SYSTEMS DURING AUGUST.
9/80 A 93.6 88.2 88.5 87.8
B 94.2 90.7 91.0 90.3
SYSTEM 93.9 89.5 89.8 89.0 720 716 641 72.6
•• PROBLEMS/SOLUTIONS/CONMENTS
THE INLET DAMPER SEAL PROBLEM CONTINUED THROUGH AUGUST AND SEPTEMBER.
EXTERNAL PROBLEMS WERE EXPERIENCED WITH THE IUCS SYSTEM.
78
-------
EPA UT1LITT F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NA1E
JMIT MUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - N6/J
MET PLANT GENERATING CAPACITY - MM
SROSS UNIT 6ENERATIN6 CAPACITY - MM
MET UNIT GENERATING CAPACITY V/F6D - MU
MET UNIT GENERATING CAPACITY VO/F6D - MW
EBUIVOLENT SCRUBBED CAPACITY - MM
COMMONWEALTH EDISON
POMERTON
51
PEKIN
ILLINOIS
E
4J. ( .tOO
774. ( 1.800
1700.0
450. 0
400.0
425.0
450.0
LB/MMBTU)
LB/MMBTU)
*• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIKUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANSE HEAT CONTENT - 9TU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANEE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
SOZ DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
• * FABRIC FILTER
NUMBER
»* ESP
NUMBER
TYPE
SUPPLIER
PARTICULAR DESIGN REMOVAL EFFICIENCY
FLUE GAS TEMPERATURE - C
*• MECHANICAL COLLECTOR
NUMBER
.* PARTICLE SCRUBBER
TYPE
*• ABSORBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
BABCOCK t WILCOX
CYCLONE
BASE
0/72
722.18
157.2
137.
6.4
(1530370 ACFM)
( 315 F)
( 450 FT)
C 21.0 FT)
COAL
******
24516.
( 10540 BTU/LB)
9.16
- X
16.34
******
3.53
******
.20
******
THROUAUAV PRODUCT
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
FULL SCALE
RETROFIT
75.50
6/81
4/80
8/80
3/77
2/76
1
COLD SIDE
RESEARCH-COTTRELL
98.7
157.2 < 315
NONE
MOBILE PACKED TOWER
AIR CORRECTION DIVISION, UOP
3
55 X 30 X 18
79
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 19*0
COMMONWEALTH EDISON: POWERTON 51 (CONT.)
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
33ILER LOAD/APSORBER - X
GAS FLOW - CU.M/S
G»S TEMPERATURE - C
LiauID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
P»RTICULATE INLET LOAD - NG/J
PARTICIPATE OUTLET LOAD - NG/J
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
•* CENTRIFUGE
NUMBER
CARBON STEEL
NEOPRENE RUBBER
FRP, CARPENTER 20
33.0
240.73
157.2
1575.
8.0
3.0
3.8
43.
43.
2696
660
75.5
( 510123 ACFM)
( 315 F)
(25000 6PH)
( 60.0 GAL/1000ACF)
(12.0 IN-H20)
( 12,5 FT/S)
( .100 LB/MMBTU)
( .1-00 LB/MMBTU)
•• FANS
TYPE
SERVICE - MET/DRY
** VACUUM FILTER
NUMBER
TYPE
CONSTRUCTION MATERIAL
CAPACITY - M T/D
OUTLET SOLIDS - X
•• MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
riASH SYSTEM
SUPERFICIAL GAS VELOCITY - M/S
•* PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
MODE
•* TANKS
SERVICE
RECYCLE
SLURRY MAKE-UP
4.E. HASH
HASTE SLURRY
LIMESTONE TRANSFER
RECLAIMED MATER
•• RtHEATER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
ENERGY REQUIRED
•• THICKENER
NUMBER
CONSTRUCTION MATERIAL
DIAMETER - M
OUTLET SOLIDS - I
»* HATER LOOP
TYPE
FRESH MAKEUP HATER ADDITION - LITERS/S
•• REAGENT PREPARATION EQUIPMENT
NUMBER OF BALL MILLS
BALL MILL CAPACITY- N T/H
•* TREATMENT
TYPE
CONTRACTOR
CENTRIFUGAL
DRY
ROTARY DRUM
CARBON STEEL
1088.4 ( 1200 T/D)
55.0
CHEVRON
FIBERGLASS REINFORCED PLASTIC
HORIZONTAL
WASH TOP AND BOTTOM LAYERS ONLY
2.7 ( 9.0 FT/S)
S02, GAS FLOW, PH
AUTOMATIC
FEEDBACK/FEED FORWARD
NUMBER
HOT AIR INJECTION
STEAM
13.9 ( 25 F)
71,000.000 BTU/HR
CARBON STEEL
51.8 <170 FT)
35.0
CLOSED
35.3
2
20.0
POZ-0-TEC
IUCS
< 560 GPM)
( 22.0 TPH)
80
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
COMMONWEALTH EDISON: POWERTON 51 (CONT.)
INLET- KS/S 20.6 < 2727 LB/MIN)
INLET SOLIDS - X 35.0
•» DISPOSAL
NATURE FINAL
TYPE LANDFILL
•* DISPOSAL
NATURE INTERIM
TYPE LINED POND
LOCATION ON SITE
CAPACITY - CU.M 122300 ( »OC.O ACRE-FT)
.-- PERFORMANCE DATA—
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIIATION X RE.MOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
t/80 SYSTEM 720
5/80 SYSTEM 744
5/80 SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
INITIAL FED SYSTEM OPERATIONS BEGAN IN APRIL. THE F6D SYSTEM IS CURRENTLY
OPERATING ON FLUE GAS GENERATED FROM THE BURNING OF LOU SULFUR WESTERN
COAL. ONLY TWO OF THE THREE ABSORBER MODULES HAD BEEN OPERATED AS OF THE
END OF JUNE. THE FGD SYSTEM IS NOT EXPECTE.D TO BE DECLARED COMMERCIAL
UNTIL DECEMBER 1980.
THE UTILITY REPORTED THAT CURRENT OPERATING AND MAINTENANCE COST PROJECT-
IONS INDICATE THAT MANPOWER REQUIREMENTS FOR UNIT 51 WILL DOUBLE AND THAT
ON A COST BASIS THE POTENTIAL OPTION OF BURNING LOU SULFUR COAL AS A
COMPLIANCE STRATEGY MILL PROVE LESS EXPENSIVE THAN FGD.
7/8C SYSTEM 744
S/80 SYSTEM 744
SYSTEM 720
*» PROBLEMS/SOLUTIONS/COMMENTS
NO DECISION HAS BEEN MADE TO START COMMERCIAL OPERATIONS. THERE ARE NO FGD
OPERATIONS EXCEPT TESTING IN ONE MODULE. PERFORMANCE DATA UILL BE AVAIL-
ABLE WHEN THE FGD SYSTEM GOES INTO COMMERCIAL OPERATION.
81
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
DESIGN AND PERFORMANCE DATA
SECTION 3
FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
VET UNIT GENERATING CAPACITY W/FGD - MW
E8UIVALENT SCRUBBED CAPACITY - MU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** MATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
- X
COOPERATIVE POUER ASSOCIATION
COAL CREEK
1
UNDERWOOD
NORTH DAKOTA
545.0
495.0
327.0
COAL
LIGNITE
14556.
7.14
39.83
.63
.02
WET SCRUBBING
LIME/ALKALINE FLVASH
COMBUSTION ENGINEERING
NEW
( 6258 BTU/LB)
7/79
8/79
54.00
99.50
.0
.0
OPEN
(***»•* 6PM)
•• TREATMENT
TYPE
** DISPOSAL
TYPE
FLVASH STABILIZATION
LINED POND
..._._..._.......—.-.. ......—..——PERFORMANCE DATA——
PERIOD MODULE AVAILABILITY OPERABUITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 100.0
•• PROBLEMS/SOLUTIONS/COMMENTS
96.1
744 715
715
DURING JANUARY TWO MODULES AT A TIME HERE TAKEN OFF-LINE FOR INSPECTION
AND CLEANING. SOME CRACKED NOZZLES AND PLUGGING PROBLEMS WERE FOUND
DURING THE INSPECTION. THE BOILER WAS OPERATED AT A REDUCED LOAD.
SOME OUTAGE TIME DURING THE MONTH WAS CAUSbD BY BOILER-RELATED PROBLEMS.
A BOILER TRIP WAS CAUSED BY A TURBINE ELECIRICIAL RELAY ON JANUARY 13.
AN HOUR OF OUTAGE TIME RESULTED FROM A LOSS OF POWER TO THE CONTROL
SYSTEM AND AN ABNORMAL BOILER DRUM LEVEL WAS ALSO ENCOUNTERED ON JANUARY
16 *
A THREE TO FOUR HOUR OUTAGE yAS SCHEDULED ON JANUARY 27 TO MAKE REPAIRS ON
FGD SYSTEM EQUIPMENT.
2/60 SYSTEM
•• PROBLEMS/SOLUTIOWS/COMMENTS
99.9
696 695
WHILE THE BOILER WAS OUT OF SERVICE DUE TO ID FAN PROBLEMS CAUSED BY
ELECTRICAL GROUNDING, TWO MODULES WERE TAKEN OUT OF SERVICE SO CALIBRA-
TIONS COULD BE DONE.
5/80 SYSTE"
100.0
96.1
744 715
715
82
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
COOPERATIVE POWER ASSOCIATION: COAL CREEK 1 (CONT.)
... .- PERFORMANCE KATA — — - — ~ """
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PROBLE1S/SOLUTIOSS/COMMENTS
90ILER TRIPS OCCURRED THREE TIMES DURING THE MONTH.
TO THE CUT DOWN OF TRANSMISSION POWER ON MARCH 12.
4/80 1 1
12
13
14
SYSTE1
96.7
100.0
100.0
100.0
99.2
THE FGD SYSTEM WAS SHUTDOWN
FILTER ON THE BOILER STATOR
DURING MARCH STACK EMISSION
WITH ONE MODULE DOWN DURING
SB. 3 100.0
81.7 100.0
96.1 10C.O
96.9 100.0
83.3 10?. 0
WITH THE BOILER FOR FOUR
COOLING PUMPS.
TESTS WERE UNDERTAKEN.
TESTING.
21.4
30.0
35.3
35.6
30.6
ONE TRIP WAS DUE
HOURS TO CLEAN THE
THE SYSTEM OPERATED
720 264 220 26.2
»» PROBLEMS/SOLUTIONS/COMMENTS
5/80 11
12
1!
14
SYSTEM
88.3
79.3
91.9
91.3
87.7
THE BOILER WAS OFF LINE FOR
AGE. THE SCRUBBING SYSTEM
68.8 1CO.O
18.6 10P.O
79.6 100.0
35.5 100.0
50.6 100.0
APPROXIMATELY 19 DAYS FOR THE ANNUAL UNIT OUT-
WAS AVAILABLE DURING THE BOILER OUTAGE.
34.4
9.3
39.8
17.7
25.3
744 372 188 28.2
«» PROBLEMS/SOLUTIOMS/COMMENTS
THE ANNUAL UNIT OUTAGE WAS COMPLETED IN THE, BEGINNING OF THE MONTH. THERE
HERE PROBLEMS WITH BOILER STARTUP AFTER THIS OUTAGE CAUSING LOW OPERA8ILITY
OF THE FGD SYSTEN.
i/80 11
12
13
SYSTEM
92.9
98.5
74.7
93.5
89.9
49.3 100.0
47.6 100.0
42.2 100.0
73.0 100.0
53.0 10Q.O
49.2
47.5
42.1
72.8
52.9
720 718 381 58.5
7/80
S/80
9/80
*• PROBLEMS/SOLUTIONS/COMMENTS
THERE WERE NO MAJOR PROBLEMS REPORTED DURING JUNE.
AND REPAIRS WERE DONE THROUGHOUT THE MONTH.
ROUTINE MAINTENANCE
744 648 648 47.1
SYSTEM 100.0 100.0 100.0 87.1
*• PROBLEMS/SOLUTIONS/COMWENTS
IN JULY, NO PROBLEMS WERE ENCOUNTERED WITH THE F6D SYSTEM.
SYSTEM 744
SYSTEM 720
*• PROBLEMS/SOLUT10NS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE MONTHS OF AUGUST AND SEPTEMBER.
83
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION J
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
BEGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
•• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - T
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
«* GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PftODUCT/THROWAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
502 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION INITIATION
»• ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PARTICULATE OUTLET LOAD - G/CU.M
•* PARTICLE SCRUBBER
TYPE
• * ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
COOPERATIVE POWER ASSOCIATION
COAL CREEK
UNDERWOOD
NORTH DAKOTA
B
43.
516.
1100.0
545.0
495.0
( .100 LB/MMBTU)
( 1.800 LB/MMBTU)
327.0
COMBUSTION ENGINEERING
PULVERIZED LIGNITE
BASE
**/ * *
*»••»*** (•»**.««* ACFM)
160.0 ( 320 F)
198. ( 650 FT)
6.7 < 22.0 FT)
COAL
LIGNITE
14556.
7.14
3.69-15.95
39.83
27.78-52.55
.63
0.18-1.41
.02
0.00-0.08
THROWAWAY PRODUCT
WET SCRUBBING
LIME/ALKALINE FLYASH
NONE
COMBUSTION ENGINEERING
BLACK S VEATCH
FULL SCALE
NEW
- X 99.50
54.00
9/80
7/80
8/77
1
COLD SIDE
WHEELABRATOR-FRYE
X 99.5
( 6258 BTU/LB)
3068-7660
(2310000 ACFM)
( 3C1 F)
( .01 GR/SCF)
1090.1
160.6
.02
NONE
SPRAY TOWER
11/79
COMBUSTION ENGINEERING
1
22 X 22 X 20
316L SS
NONE
84
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
CJOPERATIVE POWER ASSOCIATION: COAL CREEK 2 (CONT.)
NOZZLE TYPE
L/6 RATIO - L/CU.M
S32 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
»* FANS
NUMBER
TYPE
•• HIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
NUMBER OF STAGES
•* MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
»* PUMPS
SERVICE
BLEED STREAM
SLURRY FEED
REACTION TANK
*»*•»•
PROPRIETARY ATOMIZING
8.0 I 60.0 GAL/1000ACF)
1000
100
90.0
INDUCED DRAFT
CHEVRON
FIBERGLASS REINFORCED PLASTIC
2
SLAT IMPINGEMENT
FIBERGLASS REINFORCED PLASTIC
NUMBER
3
*** *
6
*** *
** TANKS
SERVICE
REACTION-RECYCLE-THICKENER
FLY»SH WETTING
LIME FEED
** REHEATER
TYPE
TEMPERATURE BOOST - C
•* WATER LOOP
TYPE
•* REAGENT PREPARATION EQUIPMENT
NUMBER OF SLAKERS
•* TREATMENT
TYPE
NUMBER
2
*** *
BYPASS
47.2 C 85 F)
OPEN
FLYASH STABILIZATION
** DISPOSAL
NATURE
TYPE
AREA - ACRES
FINAL
LINED POND
104.0
_. 1 PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Jt REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/80 SYSTEM
«• PROBLEMS/SOLUTIONS/COHPENTS
744
5/80 SYSTEM
j/80 SYSTEM
INITIAL OPERATION OF THE FGD SYSTEM BEGAN IN JULY 19&0. NO MAJOR STARTUP
PROBLEMS WERE REPORTED.
744
720
85
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
C30PERATIVE POWER ASSOCIATION: COAL CREEK 2 CCONT.)
............——. —-—-— — PERFORMANCE DATA—— -— ——-——— —»—..._
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION J REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*» PROBLE1S/SOLUTIONS/COMMENTS
THE FGD SYSTEM IS STILL IN THE INITIAL PHASE OF OPERATION. NO PERFORMANCE
DATA ARE AVAILABLE AT THE PRESENT TIME.
86
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION. LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MW
SftOSS UNIT GENERATING CAPACITY - MW
MET JNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
DELMARVA POWER
DELAWARE CITY
1
DELAWARE CITY
DELAWARE
E
129.
180.0
60.0
60.0
I LIGHT
( .300 LB/MMBTU)
*• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CUiM/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - 1
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANEE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROKAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
LETTER OF INTENT SIGNED
STARTED PREL1MINAY DESIGN
- X
RILEV STOKER
PULVERIZED COKE
BASE
10/56
417.63 ( 88SOOO ACFM)
215.6 ( 420 F>
152. ( 500. FT)
6.1 < 20.0 FT)
COKE
FLUID PETROLEUM COKE
32564. ( 1*000 BTU/LB)
13500-14500
.50
.3-.7
.70
.5-1.2
7.00
5-8
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
DAVY MCKEE
DAVY MCKEE
FULL SCALE
RETROFIT
90.00
90.00
5/80
5/80
4/80
1/78
9/77
8/76
10/77
*• FA9RIC FILTER
TYPE
• * ESP
NUMBER
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICULATE OUTLET LOAD - G/CU.M
•• MECHANICAL COLLECTOR
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
NONE
JOY WESTERN
- X 95.0
104.3
54.4
*******
.69
3
TUBULAR
PRAT-DANIEL
X 92.0
( 221000 ACFM)
( 130 F)
(***«* IN-H20)
( .30 GR/SCF)
87
-------
EPA JTUITY FED SURVEY: JULY - SEPTEMBER 1980
OELMARVA POWER & LIGHT: DELAWARE CITY 1 (CONT.)
•« PARTICLE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUM9ER OF STAGES
SHELL MATERIAL
LIMING MATERIAL
DUMBER OF NOZZLES
TYPE OF NOZ/LES
iOlLER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PRESSURE DROP - KPA
P«RTICULATt INLET LOAD - G/CU.H
PARTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN RE10VAL EFFICIENCY
S32 INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
•* »3SOR8ER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
30ILER LOAD/ABSORBER - X
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LI8UID RECIRCULATION RATE - LITER/S
PARTICULATE INLET LOAD - G/CU.M
PHRTICULATE OUTLET LOAD- G/CU.M
PARTICULATE REMOVAL EFFICIENCY - X
S02 INLET CONCENTRATION - PPM
S92 OUTLET CONTRATION - PPM
•* CENTRIFUGE
TYPE
•* FANS
NUMBER
CONSTRUCTION MATERIALS
SERVICE - WET/DRY
CAPACITY - CU.M/S
VENTURI
AIRPOL
1
CARBON STEEL
GLASS FLAKE, ACID BRICK, CAROBRAX BRICK
1
OPEN PIPE WITH REFRAX TIP
100.0
139.2 295000 ACFM)
215.6
400 6PM)
.100 GR/SCF)
.tOO 6R/SCF)
NONE
CARBON STEEL
DRY
139.21
( 295000 ACFM)
•• VACUUM FILTER
TYPE
•• MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
BEPTH - m
4ASH SYSTEM
PRESSURE DROP - KPA
•• PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
MODE
SENSOR LOCATION
t* PUMPS
SERVICE
NONE
3
CHEVRON
NORtL PLASTIC
HORIZONTAL
1
1
1.83
2.29
< 6.0 FT)
< 7.5 FT)
INTERMITTANT SPRAYS
.1
.3 IN-H20)
PH, SOLIDS. SP.G.. CONC.
AUTOMATIC
FEEDBACK
CAS OUTLET, SOLUTION OUTLET
NUMBER
88
-------
EPA UTILITV F60 SURVEY: JULY - SEPTEMBER 1980
PELNARVA POWER & LIGHT: DELAWARE CITY 1 (CONT.)
*• REHEATER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
»* THICKENER
TYPE
*• WATER LOOP
TYPE
•* BYPRODUCTS
BYPRODUCT NATURE
BYPRODUCT flUANTITY - M T/H
BYPRODUCT dUALITV - X
DISPOSITION
•* TREATMENT
TYPE
•* DISPOSAL
NATURE
TYPE
HOT AIR INJECTION
FLUE GAS
27.8 ( SO F)
NONE
CLOSED
SULFURIC ACID
11.3* ( 12,50 TPH>
93.0
MARKETED
NEUTRALIZATION
FINAL
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPtRABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/BD SYSTEM 100.C 100.0
•* PROBLEMS/SOLUTIONS/COMMENTS
100.3
32.3
744 240 240
THE FGD SYSTEM REGAN INITIAL AND COMMERCIAL OPERATIONS ON MAY 22i 19BC.
NO MAJOR PROBLEMS HERE ENCOUNTERED FROM STARTUP THROUGH THE END OF
THE HONTH.
0 SYSTE" 98.9 9«.9 98.9 98.9 720 720 712
«* PROBLE1S/SOLUTIOSS/COM»ENTS
NO MAJOR PROBLEMS WERE ENCOUNTERED DURING JUNE.
7/61 SYSTEM 97.2 97.0 97.C 90.7 744 696 675
** PROBLE*S/SOLUTION$/COM-«ENTS
THE FGD SYSTEM WAS DOWN FOR PART OF THE MONTH IN JULY TO REPAIR A LEAK IN
THE MIST ELIMINATOR.
99.9
99.9
3/6" SYSTEM 99.9 99.9
«• PROBLEMS/SOLUTIONS/COMMENTS
NO FGD-RELATED PROBLEMS WERE REPORTED CURING AUGUST.
J/8" SYSTEM 720
•• PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR SEPTEMBER 198C.
744 744 743
89
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/ J
S02 EMISSION LIMITATION - NG/j
NET PLANT GENERATING CAPACITY - MW
• ROSS UNIT GENERATING CAPACITY - MW
NET JNIT GENERATING CAPACITY U/FSD - MW
SET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
•• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
4.AXHUM BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTEHT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT • X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THftOHAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
P»RTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
LETTER OF INTENT SIGNED
STARTED PPELIMINAY DESIGN
•* FABRIC FILTER
TYPE
- X
DELMARVA POWER & LIGHT
DELAWARE CITY
2
DELAWARE CITY
DELAWARE
E
129.
180.0
60.0
.300 LB/MMBTU)
..*•* LB/MMBTU)
60.0
RILEY STOKER
PULVERIZED COKE
BASE
10/S6
417.63 < 885000 ACFM)
215.6 ( 420 f)
152. ( 500 FT)
6.1 < 20.0 FT)
COKE
FLUID PETROLEUM COKE
32564.
.50
.3-. 7
.70
.5-1.2
7.00
5-B
SALEABLE PRODUCT
UET SCRUBBING
WELLMAN LORD
DAVY HCKEE
DAVY HCKEE
DAVY HCKEE
FULL SCALE
RETROFIT
90.00
90.00
5/80
5/80
4/80
1/7S
9/77
8/76
10/77
NONE
( UOOO BTU/LB)
135QO-14500
• • ESP
NUMBER
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FUUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - *PA
PARTICULATE OUTLET LOAD - G/CU.M
•• MECHANICAL COLLECTOR
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
- X
JOY WESTERN
95.0
104.3
54.4
.69
TUBULAR
PRAT-DANIEL
X 92.0
( 33*000 ACFM)
C 130 M
(..*«» JM-H20)
C .30 GR/SCF)
90
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
DELMARVA POWER & LIGHT: DELAWARE CITY 2 (CONT.)
** PARTICLE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
NUMBER OF NOZZLES
TYPE OF NOZZLES
BOILER LOAD/SCRUBBER - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - X
*• A3SOD3ER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ABSORBER - X
SAS FLOW - CU.M/S
6»S TEMPERATURE - C
LI8UID RECIRCULATION RATE - LITER/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD- G/CU.M
PARTICULATE REMOVAL EFFICIENCY - X
S02 INLET CONCENTRATION - PPM
SOt OUTLET CONTRATION - PPM
•• CENTRIFUGE
TYPE
• • FANS
NUMBER
CONSTRUCTION MATERIALS
SERVICE - WET/DRV
CAPACITY - CU.M/S
** VACUUM FILTER
TYPE
*• MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
DEPTH - M
rfASH SYSTEM
PRESSURE DROP - KPA
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
NODE
SENSOR LOCATION
»* PUMPS
SERVICE
VENTURI
AIRPOL
1
CARBON STEEL
GLASS FLAKE, ACID BRICK, CAROBRAX BRICK
1
OPEN PIPE M1TH REFPAX TIP
100.0
139.2 i 295000 ACFMJ
215.6 ( *CO F)
315.0 ( 5000 GPM)
******* (***** IN-M20)
3.2 C 1.39 6R/SCF)
.6 C .250 GR/SCM
- X 81.5
3500.000
.0
TRAY TOWER
4/80
DAVY MCKEE
4
20 X 20
REINFORCED CONCRETE
TILE
316L SS
100.0
103.82
54.4
25.
.2
.2
.0
3500
390
NONE
CARBON STEEL
DRY
139.21
NONE
CHEVRON
NORYL PLASTIC
HORIZONTAL
1
1
1.83
2.29
( 220000 ACFB)
( 130 F)
( 400 6P«>
( .100 GR/SCF)
( .>OC 6R/SCF)
I 29SOOO ACFH)
( 6.0 FT)
I 7.5 FT>
INTERHITTANT SPRAYS
.1 ( .3 IN-H20)
PH, SOLIDS, SP.fc.t tONC.
AUTOMATIC
FEEDBACK
GAS OUTLET, SOLUTION OUTLET
NUMBER
*•* •
91
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19SO
&ELKARYA POWER i LIGHT: DELAWARE CITY 2 (CONT.)
•* REHEATER
TYPE
HEATING MEDIU"
TEMPERATURE BOOST - C
•• THICKENER
TYPE
•• WATER LOOP
TYPE
** BYPRODUCTS
BYPRODUCT NATURE
BYPRODUCT (1UANTITY - M T/H
3YPSODUCT BUALITY - *
DISPOSITION
TYPE
*• DISPOSAL
NATURE
TYPE
HOT AIR INJECTION
FLUE GAS
27.8 <
NONE
CLOSED
SO F)
SULFURIC ACID
11.34
93.0
MARKETED
NEUTRALIZATION
FINAL
LINED POND
( 12.SC TPH)
PERFORMANCE DATA — — .....
PERIOD MODULE AVAILABILITY OPERABUITY RELIABILITY UTILIZATION I REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 100.0 100.0
*« PROBLEMS/SOLUTIONS/COMMENTS
100.0
3?.3
744
240
240
THE FGD SYSTEM BEGAN INITIAL AND COMMERCIAL OPERATIONS ON MAY 22, 1980.
NO MAJOR PROBLEMS WERE ENCOUNTERED DURING STARTUP OR THROUGH THE REST OF
THE MONTH.
5/8P SYSTEM B0.« 60.4
•• PROBLEMS/SOLUTlONS/COMHENTS
80.4
80.4
720 720
579
THE CHEVRON PACKING IN THE MIST ELIMINATOR FAILED CAUSING SOME FGD SYSTEM
OUTAGE TIME DURING JUNE.
FAILURE OF THE CIRCULATION PUMPS ALSO CAUSED OUTAGE TIME DURING THE MONTH.
7/80 SYSTEM 50.1 50.1 50.1 50.1 744 744 373
•• PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS DOWN FOR PART OF THE MONTH TO REPAIR A LEAK IN THE HIST
ELIMINATOR. IT WAS ALSO DOWN TO REBUILD THE CHEVRON PACKING.
S/60 SYSTEM 92.9 92.9 92.9 92.9 744
•• PROBLEMS/SOLDIlONS/COMPENTS
REPAIRS WERE MADE TO THE ESP DURING AUGUST.
9/80 SYSTEM 720
• * PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR SEPTEMBER 19SO.
744
691
92
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SD2 EMISSION LIMITATION - NG/J
ATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT I.ARDED
LETTER Of 1NTFNT SIGNED
STARTED PRE.LIWINAY DESIGN
*• FA3RIC FILTER
TYPE
»• ESP
SJM?ER
SUPPLIER
PARTICULATE DFSIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICULATE OUTLET LOAD - G/CU."
•* MECHANICAL COLLECTOR
•4UM9ER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
- X
DELMARVA POWER I LIGHT
DELAWARE CITY
3
DELAWARE CITY
DELAWARE
E
- X
180.0
60.0
60.0
RILEY STOKER
PULVERIZED COKE
BASE
10/56
417.63
215.6
15?.
6.1
.300 LB/MMRTU)
•««•* LB/MMBTU)
( 8850CO ACFM)
( 420 F)
< 500 FT)
( 20.C FT)
COKE
FLUID PETROLEUM COKE
32564. ( 140CC BTU/LB)
13500-14500
.50
.3-. 7
.70
5-8
7.0C
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
DAVY MCKEE
DAVY MCKEE
FULL SCALE
RETROFIT
90.00
90.00
5/fcO
5/80
4/eo
1/78
9/77
8/76
10/77
NONE
JOY WESTERN
95.0
104.3
54.4
.69
TUBULAR
PRAT-DANIEL
X 92.0
( 221000 ACFM)
< 130 F)
(«••»• IN-H20)
( .30 6R/SCF)
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
DELNARVA POWER t LI6HT: DELAWARE CITY 3 (CONT.)
** PARTICLE SCRUBBER
DUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
NUM9ER OF N027LES
TYPE OF NOZZLES
33ILER LOAD/SCRUBBtR - X
FLUE GAS CAPACITY - CU.M/S
FLUE 6AS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - G/CU.M
P«RTICULATE OUTLET LOAD - G/CU.M
PARTICULATE DESIGN REMOVAL EFFICIENCY
502 INLET CONCENTRATION - PPM
502 DESIGN REMOVAL EFFICIENCY - X
*• A3SOP3ER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
SUM3ER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MITERIAL
INTERNAL "IATEPIAL
33ILER LOAD/APSORBER - X
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LiauiD PECIRCULATION RATE - LITER/S
PARTICULATE INLET LOAD - G/CU.H
PARTICULATE OUTLET LOAD- G/CU.M
PARTICULATE REMOVAL EFFICIENCY - X
S02 INLET CONCENTRATION - PPM
S32 OUTLET CONTRATION - PPM
•• CENTRIFUGE
TYPE
»• FANS
NUMBER
CONSTRUCTION MATERIALS
SERVICE - rfET/DRY
CAPACITY - CU.M/S
VENTURI
AIRPOL
1
CARBON STEEL
GLASS FLAKE, AC 1C BRICK, CAROBRAX BRICK
1
OPEN PIPE WITH REFRAX TIP
100.0
139.2 ( 295000 ACFH)
215.6 ( 460 F)
315.0 < 5000 GPf)
....... <«**.« IH-H20)
3.2 ( 1.39 GR/SCF)
.6 < .250 GR/SCF)
- X 81.5
3503.000
.0
TRAY TOWER
5/80
DAVY MCKEE
4
20 X 20
REINFORCED CONCRETE
TILE
316L SS
100.0
103.82
54.4
25.
.2
.2
.0
3500
390
NONE
( 220000 ACFM)
< 130 F>
( 400 6PM)
( .100 6R/SCF)
( .100 GR/SCF)
3
CARBON
DRY
139.21
STEEL
( 295000 ACFK)
•• VACUUM FILTER
TYPE
•* WIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
DEPTH - M
riASH SYSTEM
PRESSURE DROP - KPA
•• PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
MODE
SENSOR LOCATION
NONE
CHEVRON
NORYL PLASTIC
HORIZONTAL
1
1
1.83
2.29
< 6.0 FT)
{ 7.5 FT)
INTERMITTENT SPRAYS
.1
( .3 IN-M20)
PH, SOLIDS, SP.G., CONC.
AUTOMATIC
FEEDBACK
6AS OUTLET, SOLUTION OUTLET
•* PUMPS
SERVICE
NUMBER
94
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
9ELM«RVA POWER & LIGHT: DELAWARE CITY 3 (CONT.)
»• REHE'TER
YUM9ER
TYPE
HEATING
TEMPERATURE BOOST - C
»* THICKENER
TYPE
• • WATER LOOP
TYPE
»* BYPRODUCTS
BYPRODUCT KATURE
BYPRODUCT 8UANTITY - N T/H
BYPRODUCT QUALITY - X
DISPOSITION
•• TREATMENT
TYPE
«• DISPOSAL
NATURE
TYPE
HOT AIR INJECTION
FLUE GAS
27.8 (
NONE
CLOSED
SULFURIC ACID
11.3*
93.0
MARKETED
50 F)
{ 12.50 TPH)
NEUTRALIZATION
FINAL
LINED POND
.._ ... PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X R6.MOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/bO SYSTEM 100.0 100.0
•• PROBLEMS/SOLUTIOVS/COMMENTS
100.0
32.3
7*4 240 240
THE FGD SYSTEM BEGAN INITIAL AND COMMERCIAL OPERATIONS ON MAY 22, 1980.
NO MAJOR PROBLEMS WERE ENCOUNTERED DURING STARTUP OR THROUGH THE REST OF
THE MONTH.
SYSTEM 86.4 86.4
** PROBLEMS/SOLUTIONS/COMMENTS
86.4
86.4
720 720 622
REPAIRS WERE MADE TO A LEAK AND DAMAGED CHEVRON PACKING IN THE MIST ELIM-
INATOR DURING JUNE.
7/80 SYSTEM 95.3 95.3
•• PROBLEMS/SOLUTIONS/COMMENTS
95.3
95.3
744 744 709
SOME FGD SYSTEM OUTAGE TIME DURING THE MONTH WAS CAUSED BY LEAKS IN THE
MIST ELIMINATOR THAT NEEDED REPAIR.
AN ELECTRICAL FAILURE IN THE SHUTDOWN INSTRUMENTATION CAUSED THE FGD SYSTEM
TO BE OUT OF SERVICE PART OF THE MONTH.
J/80 SYSTEM 73.3 7J.3
** PROBLEMS/SOLUTIONS/COMMENTS
73.3
73.3
744 744 545
THE FGD SYSTEM HAS OUT OF SERVICE FOR PART OF THE MONTH TO REPAIR THE
PRESCRUBBER MIST ELIMINATOR.
J/80 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR SEPTEMBER 1980.
720
95
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NME
JNIT NUMBER
CITY
STATE
3ROSS UNIT GENERATING CAPACITY - Mw
1ET UNIT GENERATING CAPACITY W/FGD - M*
EQUIVALENT SCRUBBED CAPACITY - *H
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
A3SORBER SPARF COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»• TREATMENT
TYPE
•• DISPOSAL
TYPE
OUOUESNE LIGHT
ELRAMA
1-4
ELRAMA
PENNSYLVANIA
510.C
475.0
510.0
( 11350 BTU/LB)
COAL
2640J.
21.00
2.2C
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
RETROFIT
1.5
10/75
10/75
83.00
99.00
25.0
1.0
OPEN
CPU)
POZ-0-TEC
LANDFILL
.. _—PERFORMANCE DATA — —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
t REMOVAL PER BOILER F60 CAP
502 PART. HOURS HOURS HOURS FACTOR
12J79
101
201
301
401
501
SYSTEM
103.0
100.0
100.0
88.1
100.0
100.0
51.6
90.9
100.0
6?. 6
100.0
100,0
1C?.0
100.0
96.1
86.4
100.0
10P.O
48.5
85.5
100.0
64.5
100.0
98.7
744 700 734
1/8"
2/80
PROBLEMS/SOLUTIONS/COMMENTS
101
201
301
401
sm
SYSTEM
201
95. B
87.1
84.6
86.4
100.0
100.0
100.0
100.0
THERE WERE NO SCRUBBER-RELATED OUTAGES DURING THE SEPTEMBER THROUGH
DECEMBER PERIOD.
A NEW S02 MONITOR, WHICH WAS INSTALLED IN OCTOBER, HAS PLUGGED ONLY OUCE
SINCE INSTALLATION AND HAS REQUIRED ONLY FOUR HOURS OF MAINTENANCE PER
WEEK.
91.2
100.0
10P.O
55.6
100.0
130.0
85.4
100.0
94.8
87.1
84.6
77.1
100.0
100.0
100.0
105.0
75.2
87.1
84.6
45.8
100.0
98.2
6C.5
96.6
744 613
528
96
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
DJQUESKE LIGHT: ELRANA 1-4 (CONT.)
... . PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
SO? PART. HOURS HOURS HOURS FACTOR
301
(.01
501
SYSTEM
100.0
100.0
77.6
100.0
100.0
100. 0
56.8
100.0
100.0
100.0
64.0
100.0
10C.O
70.7
40.2
92.0
696
493
427
PROBLEMS/SOLUTIONS/COMMENTS
THE NEW S02 MONITOR IS STILL OPERATING WELL AND HAS LOGGED SIX MONTHS OF
OPERATION.
THE HIGH AVAILABILITIES ARE DUE TO THE 5TH MODULE BEING A TRUE SPARE.
AS OF FEBRUARY 1980 AND ARE STILL OPERATING WITHOUT ANY MAJOR PROBLEMS.
THE TWO RUBBER LINED UORMEN RECYCLE PUMPS HAVE NOW LOGGED 14,000 HOURS
S/bO
101
201
331
431
501
SYSTE"
103.3
73.7
100.0
78.1
103.0
100.0
100.0
73.7
48.4
7P.1
100.0
103.0
100.C
73.7
100.0
100.0
100.0
100.0
73.7
48.4
78.1
100.0
744
744
595
PROBLE*S/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH OF MARCH.
131
301
431
501
SYSTEM
40.3
72.3
87.3
100.0
100.0
99.4
72.3
67.3
130.D
100.0
99.4
40.0
72.3
87.3
100.0
100.0
100.0
40.0
72.3
87.3
100.0
100.0
99.4
720 720
572
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL THF 1C1 AND 201 RECYCLE PUMP IMPELLERS HAD TO BE REPLACED.
THIS CAUSED 8 HOURS OF OUTAGE TIME FOR THESE TWO MODULES. NO OTHER FGD
SYSTEM OUTAGES OCCURRED.
5/6r
101
2P1
501
SYSTEM
103.0
40.1
94.1
90.3
96.8
103. n
1CT.C
37.1
89.0
71.2
96.8
9R.5
100.0
3P.2
93.8
88.0
9f .8
100.0
100.0
37.1
89.0
71.2
96.8
98.5
744
744
586
•» PROaLEMS/SOLUTIOSS/COWENTS
CURHG "AY THE FGD SYSTEM WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH.
101
JD1
501
SYSTEM
100.3
103."
100.0
.0
100.0
100.0
97.8
96.7
100.0
98.6
100.0
100.0
100.0
.0
100.0
99.7
100.0
97.8
96.7
.0
100.0
98.6
720
720
710 61.6
*• PR08LEMS/SOLUTIONS/CCMMENTS
7/80
201
301
401
501
SYSTEM
100.0
100.0
98.?
75.8
35.5
10D.C
DURING JUNE MODULE 401 WAS CLEANED AND THE CEILCOTE LINER WAS REPLACED.
THIS IS THE FIRST TIME SINCE START UP (APPROXIMATELY 17,000 OPERATING
HOURS) THAT ANY MODULE NEEDED RELINED.
64.9
91.1
85.6
75.8
12.9
82.6
100.0
100.0
9".?
75.8
14.7
97.7
64.9
91.1
85.6
75.8
12.9
82.6
744 744
615 66.0
97
-------
EPA UTILITY FSD SURVEY: JULY - SEPTEMBER 1980
BJ8UESNE LIGHT: ELR»1A 1-4 (CONT.)
. . — . . ._ .—.. PERFORMANCE DATA— — -— ——...
PERIOD MODULF AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILED FED CAP ~
S03 PART. HOURS HOURS HOURS FACTOR
*• PROSLEMS/SOLUTIONS/COMMENTS
THE RELININ6 OF MODULE 401 CONTINUED INTO PART OF JULY.
3/80
101
201
351
401
531
SYSTEM
30.9
103.0
103.0
99.1
83.9
100.0
21.2
94.8
93.3
99.1
£2.5
97.7
23.5
100. C
100. 0
99.1
E3.7
1CO.O
21.2
94.8
93.3
99.1
82. 5
97.7
744
744
727 65.0
PROBLEMS/SOLUTIONS/COMMENTS
THE RELINING WITH CEILCOTE OK MODULE 501 COMMENCED IN JULY AND CONTINUED
FOR APPROXIMATELY 120 HOURS IN AUGUST.
THE RELININ6 OF MODULF 101 WITH CEILCOTE STARTED IN AUGUST ACCOUNTING
FOR THE LOW AVAILABILITY DURING THE MONTH.
»/8f» SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE MONTH OF SEPTEMBER IS NOT AVAILABLE AT THIS TIME.
98
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
J1JT
CITY
STATE
SRGSS UNIT GENERATING CAPACITY - Mw
HET UNIT GENERATING CAPACITY U/FGD - My
EQUIVALENT SCRUBBED CAPACITY - My
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT » Z
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEH/RETROF1T
ENERGY CONSUMPTION - X
IVIT1AL START-UP DATE
COMMERCIAL STIRT-UP DATE
S32 DESIGN REMOVAL EFFICIENCY - X
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• TREATMENT
TYPE
• • DISPOSAL
TYPE
- X
( 11535 BTU/LB)
DUQUESNE LIGHT
PHILLIPS
1-6
SOUTH HEIGHT
PENNSYLVANIA
408.0
373.0
4G8.0
COAL
BITUMINOUS
26830.
16.?7
5.02
1.92
UET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
RETROFIT
3.4
7/73
6/74
83.00
99.00
.0
.0
OPEN
(*•*»* GPM)
POZ-0-TEC
LANDFILL
.. ... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
12/79
101
201
301
401
SYSTEM
.0
100. P
90.7
77.7
67.1
.0
99.6
89.6
72.9
65.3
.0
100.0
9T.6
76.6
66.8
.0
98.6
89.6
72.9
65.3
744 744 486
PROBLEMS/SOLUTIONS/COMMENTS
1/80 101
201
J01
431
SYSTEM
2/80 101
201
.0
95.1
100.0
97.6
73.9
13.7
91.6
PRESENTLY THE UTILITY HAS BEEN ADDING SODIUM THIOSULfATE TO THE LIKE TO
PREVENT SCALE FORMATION. THIS PROCESS HAS IMPROVED S02 COLLECTION AS
WELL.
THE SCRUBBER FAN HOUSING LINERS ARE BEING REPLACED.
THE MECHANICAL COLLECTORS ARE BEING UPGRADED TO IMPROVE THE 8UAL1TY OF
THE WET SLUDGE.
.0
93.3
99.0
95.8
72.0
13.7
91.6
.0
9P.O
10P.O
97.5
73.9
13.7
91.7
.0
93.3
99.0
95.8
72.0
13.7
91.6
744
744
536
99
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ttJQUFSNE LIGHT: PHILLIPS 1-6 (CONT.)
PERFORMANCE DATA
PERIOD MO&ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
r REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
351
O1
SYSTEM
86.3
94.2
71.4
£4.6
90.5
70.1
86.0
94.C
71.4
84.6
90.5
70.1
696 696
468
*• PROBLEMS/SOLUTIONS/COMMENTS
5/B?
SODIUM THIOSULFATE ADDITION CONTINUED THROUGH THE FIRST QUARTER RESULTING
IN A INCIDENCE OF SIGNIFICANTLY REDUCED HIST ELIMINATOR SCALING. 2000-
5000 HOURS OF OPERATION HAVE BEEN LOGGED WITHOUT MIST ELIMINATOR SCALE
ACCUMULATION. THE UTILITY REPORTED THAT S02 REMOVAL EFFICIENCY HAS
IMPROVED 3X DUE TO THE SODIUM THIOSULFATE ADDITION. THE UTILITY IS LOOKING
INTO SODIUM THIOSULFATE ADDITION AT ELR»MA.
THE FAN RUBBER LINERS HAVE BEEN A CONTINUAL PROBLEM. TWO FANS WILL BE
REPLACED WITH INCONEL THE NEXT TIME THE RUBBER LINERS FAIL.
THE PHILLIPS FGD SYSTEM HAD A SYSTEM AVAILABILITY OF 71.81 FOR THE YEAR
1979.
84.0
53.9
4C.3
95.3
54.7 744 744 407
101
2D1
301
401
SYSTEM
94.7
59. 0
4S.4
95.4
60.3
84.3
5T.9
4C.3
95.3
54.7
94.?
56.8
47.8
99.8
73.6
«* PROBLEMS/SOLUTIOSS/COWENTS
PROBLEMS WERE ENCOUNTERED WITH THE MODULE 101 ID FAN.
TAKEN OFF LINE SO THE ID FAN COULD BE BALANCED.
THE MODULE WAS
PROBLEMS WERE ENCOUNTERED WITH THE HUB BOLTS ON THE ID FAN OF MODULE 201,
CAUSING THE MODULE TO COME OFF LINE FOR 11 DAYS.
THE RUBBER LINING ON THE 1C FAN HOUSING OF MODULE 301 NEEDED REPAIR DURING
MARCH.
MODULE 401 WAS TAKEN OFF LINE FOR APPROXIMATELY 2 HOURS SO REPAIRS COULD
BE MADE ON THE SCRUBBER MAKE-UP VALVES.
4/80 101
201
J01
401
SYSTEM
92.6
14.2
99.2
95. R
96.9
89.4
1P.O
99.0
94.6
73.3
92.4
10.5
99.f
98.6
75.6
89.4
10.0
99.0
94.6
73.3
720 720
527
PROBLEMS/SOLUTIONS/COMMENTS
ON APRIL 5 MODULE 101 WAS TAKEN OFF LINE DUE TO ID FAN BEARING PROBLEMS.
LATER IN THE "ONTH THE MODULE WAS SHUTDOWN DUE TO AN IB FAN INSTRUMENTATION
PRESSURE SWITCH PROBLEM.
TOWARDS THE LATTER PART OF APRILt MODULE 2u1 WAS SHUTDOWN DUE TO ID FAN
SEARING PROBLEMS. THIS PROBLEM WAS CORRECTED BY BALANCING THE FAN.
MODULE 301 WAS REMOVED FROM OPERATION ON APRIL 11 DUE TO AN ID FAN MOTOP
MALFUNCTION.
THE RECYCLE PUMP PACKING ON MODULE 401 NEEDED TO 8E REPLACED OUR1N6 THE
MONTH.
101
201
301
401
SYSTEM
67.5
81.6
91.7
92.2
83.2
53.9
69.0
77.1
75.9
6?.0
6?. 3
78.9
89.?
9^.6
60.2
53.9
69.0
7?.1
75.9
68.0
744 744
506
100
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
JUQUESNE LIGHT: PHILLIPS 1-6 (CONT.)
— _ — . . „___- PERFORMANCE OAT*
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
»• PROBLEMS/SOLUTIONS/COMMENTS
NODULE 101 CAME OFF LINE IN MAY SO REPAIRS COULD BE MADE ON THE CONTROL
DAMPER AND TO INSTRUMENTATION.
DURING MAY MODULE 201 EXPERIENCED PROBLEMS WITH THE MIST ELIMINATOR AND
THE 10 FAN. THE MODULE WAS TAKEN OFF LINE FOR APPROXIMATELY TWO OAYS TO
WASH THE MISTELIMINATOR INTERNALS AND ONE DAY TO REPAIR THE ID FAN BEARING.
MODULE 301 EXPERIENCED ID FAN PROBLEMS AND WAS TAKEN OFF LINE WHILE THE
ID FAN WAS BALANCED.
MODULE 401 MAS SHUTBOWN APPROXIMATELY 58 HOURS SO THAT THE 10 FAN CONTROL
DAMPERS COULD BE INSPECTED.
6/6"
101
201
3D1
401
SYSTEM
97.1
100.0
75.5
100.0
93.2
8C.5
76.2
64.8
71.4
7?.2
96.5
100.0
72.6
100.0
91.5
80.5
76. 2
64.8
71.4
73.2
720 720
527 55.3
•* PROBLEMS/SOLUTIOtS/COMMENTS
THE MODULE 101 MIST ELIMINATOR WAS CLEANED DURING JUNE.
7/80
1C1
231
331
431
SYSTEM
94.0
100.0
94.7
91.1
94.9
86.3
94.7
84.1
85.5
87.1
93.5
100.0
94.0
90.?
94.5
86.2
94.7
84.1
83.5
87.1
744
744
648 71.4
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THE RECYCLE PUMP IMPELLERS WERE REPLACED ON ALL THE NODULES
EXCEPT FOR MODULE 2"1.
J/B;
1D1
251
301
401
SYSTE"
91.1
96.9
87.6
92.3
92. C
72.9
85.8
85.J
86.1
82.5
90.6
96.5
89.6
91.8
91.5
72.9
85.8
85.5
86.1
82.5
744
744
614 58.5
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING AUGUST MODULE 401 EXPERIENCED PACKING PROBLEMS WITH THE RECYCLE
PUMP.
DURING THE PERIOD OF JUNE THROUGH AUGUST THE RUBBER LININGS ON THE FAN
HOUSINGS WERE REPAIRED.
9/60 SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE MONTH OF SEPTEMBER IS NOT AVAILABLE AT THIS TIME.
101
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNJT NUM3ER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
tET JN1T GENERATING CAPACITY U/FGD - MW
EBUIVALENT SCRUBBED CAPACITY - MW
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUP CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• « GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
SEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
502 DESIGN RE"OVAL EFFICIENCY - X
PARTICULATE DFSIGN REMOVAL EFFICIENCY
A9SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
- X
INDIANAPOLIS POKER & LIGHT
PETERSBURG
3
PETERSBURG
INDIANA
532.3
515.0
532.3
( 10750 BTU/LB)
COAL
BITUMINOUS
25004.
3.25
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
2.4
12/77
12/77
85.00
99.30
.0
.0
CLOSED
55.6
POZ-0-TEC
( 682 GPM)
DISPOSAL
TYPE
LANDFILL
.. _. . . PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8C' SYSTEM
2/80 SYSTEM
S/bO SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
t/80 SYSTE"
5/80 SYSTEM
i/80 SYSTEM
DURING THE FIRST QUARTER OF 1980, THE ENTIRE SCRUBBER PACKING BED WAS LOST
DUE TO EXCESSIVE WEAR OF THE NEOPRENE FOAM PACKING BALLS. THE UNIT
WILL BE TAKEN OFF LINE IN APRIL TO ACCOMOOATE NECESSARY REPAIRS AND
REPLACEMENT OF THE HALLS.
BYPASS DAMPER FAILURES ALSO OCCURRED AND ARE REPORTED TO BE A CONTINUAL
PROBLEM. MODIFICATIONS WERE MADE TO THE GULLOTINE TYPE DAMPERS DURING
THE PERIOD.
7?0
744
730
102
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
IVD1ANIPOLIS POWER K LIGHT: PETERSBURG 3 (CONT.)
.... PERFORMANCE DATA - ————
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 1 REMOVAL PER BOILER F6t> CAP.
502 PART. HOURS HOURS HOURS FACTOR
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION UAS AVAILABLE FOR THE PERI06 APRIL 1980 THROUGH JUNE
1980.
7/80 SYSTEM 744
3/80 SYSTEM 744
9/80 SYSTEM 7ZO
•• PROBLfcMS/SOLUTIONS/CONMENTS
THE OPERATIONAL DATA FOR THE THIRD QUARTER 19SC MERE NOT AVAILABLE FOR
PUBLICATION.
103
-------
EPA JTUITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAUE
JN1T NUM3ER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
YET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - r*l
KANSAS CITY POWER R LIGHT
HAWTHORN
3
KANSAS CITY
MISSOURI
90.0
E5.0
90.0
»• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - X
«* GENERAL EMISSION CONTROL SYSTEM DATA
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
...
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
ID/79
11/79
12/79
1 /bO
2/80
5/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.
100.
100.
10P.
ior.
100.
0
0
0
0
0
0
91
38
91
93
100
100
.0
.1
.9
.0
.0
.0
74*
720
744
744
696
744
677
274
684
692
696
744
677
274
684
692
696
744
PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE 1 COX OF THE TIKE THE BOILER OPERATED. NO
PROBLEMS WERE ENCOUNTERED.
4/80 SYSTE"
5/60 SYSTEM
4/80 SYSTEM
68.0
60.0
66.0
720
744
720
490
446
475
104
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
KANSAS CITY POWER * LIGHT: HAWTHORN 3 (CONT.)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
*• PROBLEIS/SOLUTICm/CONMENTS
THE UNIT 3 BOILER EXPERIENCED SUPERHEATER AND ECONOMIZER LEAKS DURIN6 THE
APRIL-JUNE PERIOD ACCOUNTING FOR THE LOW SCRUBBER UTILIZATION FIGURES.
7/80 SYSTEM 100.0 65.0 744 484 484 45.0
** PROBLENS/SOLUTIONS/COMWENTS
THE OUTAGE TIME DURING JULY HAS CAUSED BY BOILER TUBE LEAKS. NO FGD-
RELATED PROBLEMS WERE ENCOUNTERED.
3/80 SYSTEM 744 64Z 49.4
•• PROBLEIS/SOLUTIONS/COM^ENTS
THE UTILITY REPORTED THAT THE F6D SYSTEM IS NOW CERTIFIED, THEREFORE THE
SCRUBBER OPERATING HOURS ARE NO LONGER RECORDED.
THE FGD SYSTEM WAS SHUT DOWN FOR 10 HOURS DURING AUGUST TO REPAIR REHEATER
TUBE LEAKS.
?/bC SYSTEM 720 248 13.9
•• PKOBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER BOILER OPERATION WAS LIMITED DUE TO A SCHEDULED OVERHAUL.
DURING THE MONTH 67 HOURS OF SCRUBBER OUTAGE TIME WERE DUE TO REQUIRED
CLEANING OF THE SCRUBBER MODULES.
105
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FED SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
KANSAS CITY POWER ( LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
90.0
65.0
90.0
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
( 9800 BTU/LB)
COAL
BITUMINOUS
22795.
11.00
.60
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
8/7?
** / **
70.00
99.00
.0
.0
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
(**•»• GPM)
•* TREATMENT
TYPE
FLYASH STABILIZATION
•• DISPOSAL
TYPE
POND
.. PERFORMANCE DATA — ——-—— ____
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
13/79
11/79
12/79
1/80
2/60
3/80
SYSTEM 100.0
SYSTEM 10C.O
SYSTEM 100.0
SYSTEM
SYSTEM
SYSTEM
91.0
38.1
91.9
.0
.0
.0
744
720
744
744
696
744
677
274
684
0
0
0
677
274
684
0
0
0
.0
.0
.0
*• PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT REMAINED OFF LINE THROUGH THE FIRST QUARTER OF 1980 BECAUSE OF A
TURBINE GENERATOR OVERHAUL.
4/80 SYSTEM
*• PROBLEMS/SOLUTIONS/CONMENTS
65.0
720
468
LOW APRIL SCRUBBER UTILIZATION FIGURES OCCURRED BECAUSE THE BOILER WAS OUT
OF SERVICE FOR SCHEDULED MAINTENANCE DURING PART OF THE MONTH.
S/80 SYSTEM
4/80 SYSTEM
90.1
98.1
744
720
670
706
106
-------
EPA UTILITY F6D SURVEY: JULT - SEPTEMBER 1980
KANSAS CITY POWER « LIGHT: HAWTHORN 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RFLIAPILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
503 PART. HOURS HOURS HOURS FACTOR
•* PR03LE1S/SOLUTIONS/COHMENTS
THE UTILITY REPORTED THAT NO UNUSUAL FGB SYSTEM PROBLEMS OCCURRED DURIN6
MAY AND JUNE.
7/BO SYSTEM 10r.O 78.C 744 580 580 55.0
** PROBLEMS/SOLUTIONS/COMMENTS
NECESSARY REPAIRS TO THE GENERATOR COLLECTOR RING CAUSED SYSTEM OUTA6E
TIME DURING JULY.
A 53 HOUR OUTAGF WAS DUE TO THE REPLACIN6 OF THE UNDER BED SPRAY HEADERS
ON THE 4A MODULE. THIS UAS THE ONLY FGD-RELATED PROBLEM DURING JULY.
3/80 SYSTEM 744 569 47.4
•* PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE FGD SYSTEW IS SOW CERTIFIED. THEREFORE THE
SCRUBBER OPERATING HOURS ARE NO LONGER RECORDED.
DURING AUGUST APPROXIMATELY 66 HOURS WERE NECESSARY TO PERFORM GENERAL
MAINTENANCE ON THE SYSTEM.
J/B" SYSTEM 720 111 9.4
** PROBLE»S/SOLUTIONS/COHMENTS
LOW BOILER UTILIZATION DURING SEPTEMBER WAS DUE TO A LACK OF DEMAND.
NO FGD SYSTEM PROBLEMS WERE REPORTED FOR THE MONTH OF SEPTEMBER.
107
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAMF
PLANT NAME
JN1T NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
»ET UNIT GENERATING CAPACITY W/FGD -
EQUIVALENT SCRUBBED CAPACITY - MW
KANSAS CITY POWER 8 LIGHT
LA CYGNE
1
LA CYGNE
KANSAS
820.0
820.0
sza.o
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - i
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULAR DESIGN REMOVAL EFFICIENCY
ABSORBER SPARF CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
COAL
SUBDITUMINOUS
2191}.
24.36
?.60
5.39
.03
WET SCRUBBING
LIMESTONE
BABCOCK K WILCOX
NEW
2.9
2/73
6/73
80.00
99.50
.0
< 9*21 BTU/LB)
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
72.3
( 1148 EPPO
DISPOSAL
TYPE
UNLINED POND
PERFORMANCE DATA
»ERIO» MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79 SYSTEM -0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
744
.0
THE BOILER WENT DOWN FOR AN OVERHAUL ON OCTOBER 19 AND WAS OUT OF SERVICE
THROUGH DECEMBER.
EXTENSIVE MAINTENANCE WORK BEGAN ON THE FGD SYSTEM LATE IN OCTOBER CAUSING
THE SYSTEM TO BE UNAVAILABLE DURING NOVEMPI.R AND DECEMBER. SOME ITEMS
INCLUDED IN THE MAINTENANCE bERE:
THE INSTALLATION OF TWO NEW SPRAY HEADERS IN SIX OF THE MODULES, RE-
PLACEMENT OF THE ABSORBER SIOEWALLS, R&PLACEMENT OF THE MODULE OUTLET
DUCTS AND DAMPERS, AND VARIOUS DUCTWORK PATCHING.
1/80 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
744
.0
THE BOILER AND FGD SYSTEM REMAINED UNAVAILABLE DURING JANUARY DUE TO THE
ON-GOING GENERATOR/TURBINE OVERHAUL AND THE EXTENSIVE FGD SYSTEM MOD-
IFICATIONS BEING PERFORMED.
2/60 A
B
C
D
E
F
98.2
98.2
97.4
99.1
98.2
99.1
84.1
58.3
66.2
45.9
93.0
91.7
95.7
92.9
89.7
92.3
97.3
97.3
2P.O
13.2
14.9
10.3
21.0
20.7
108
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
KANSAS CITY POWER * LIGHT: LA CYCNE 1 (CONT.)
. PERFORMANCE DATA — — —-——— — —
PERIOD MODULE AVAILABILITY OPERABlLITt RELIABILITY UTILIZATION * REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6 99.1 91.7 97.3 20.7
H 99.6 92.4 97.J 20.8
SYSTEM 98.6 77.7 95.3 17.5
696
157
122
10.9
** PROBLEMS/SOLUTIONS/COMMENTS
3/80
THE TURBINE/GENERATOR OVERHAUL WAS COMPLETED IN FEBRUARY AND THE BOILER
AND F6D SYSTEM RETURNED TO SERVICE ON FEBRUARY 20. THE FGD SYSTEM VAS
AVAILABLE FOR OPERATION MOST OF THE MONTH.
4.3
4.3
4.3
4.3
4.0
2.3
1.3
.0
3.1 744 32 23
A
B
C
D
f.
f
G
H
SYSTE"
94.6
96.2
96.1
96.1
95.8
94.7
93.3
95.7
95.3
100.0
100.0
10C.O
100.0
9?. 8
53.1
31.3
.0
72.3
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
1.7
• * PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM HAS OPERATED FOR ONLY 23 HOURS IN MARCH AS A RESULT OF
GENERATOR/TURBINE PROBLEMS. SOME ROUTINE CLEANING AND INSPECTIONS OF THE
FGD SYSTEM WERE PERFORMED DURING THE OUTAGE TIME.
4/80
5/80
i/80
A
B
C
D
e
F
G
H
SYSTEM
A
B
C
D
E
F
G
H
SYSTEM
A
B
C
D
E
F
G
H
SYSTEM
96.3
95.1
95.0
96.7
95.3
92.5
97.0
97.0
95.6
96.4
94.6
95.7
95.9
96.1
96.5
96.1
96.8
96.0
98.2
9S.1
97.4
98.1
98.1
98.3
98.8
99.3
98.1
** PROBLEMS/SOLUT
7/80
A
a
c
D
E
F
G
H
SYSTEM
89.7
97.8
97.3
98.1
98.2
96.6
98.1
97.7
96.9
94.1
78.4
97.5
93.6
86.0
76.3
68.4
62.9
82.2
89.4
87.9
88.3
83.9
84.4
89.3
96.0
82.3
87.7
69.5
9C.3
96.8
92.5
87.6
91.1
88.2
87.3
90.4
IONS/COMMENTS
MO MAJOR FGD
86.9
97.6
96.9
98. 0
97.6
9?. 6
97.9
96.9
96.3
94.5
91.4
92.9
94.8
92.3
87.2
93.9
93.4
92.6
96.0
93.9
95.2
95.1
95.3
96.2
94.Q
96.2
95.5
97.2
96.8
96.7
9P.C
97.9
98.5
97.3
98.6
98.9
RELATED PROBLEMS
87.1
97.3
96.6
97.7
97.8
98.3
97.6
97.1
96.2
61.7
51.4
63.9
61.4
56.4
5C.O
44.9
41.3
53.9
84.1
82.7
83.1
78.9
79.4
84.0
90.3
77.4
82.5
46.0
46.4
49.7
47.5
45.0
46.8
45.3
44.9
4t.4
WERE
69.9
7R.5
77.9
7F.8
7P.4
79.3
78.7
77.9
77.4
720
472
388 37.6
744
700
614 49.9
720 37C
334 35.5
REPORTED FOR THE SECOND QUARTER OF 1980,
744
598
576 60.9
109
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
KANSAS CITY POWER t LIGHT: LA CYGNE 1 (CONT.)
. ».—— .... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/80
•• PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR FGD-RELATED PROBLEMS HERE REPORTED FOR JULY.
S/80 A
C
D
E
F
e
H
SYSTEM
94.6
97.9
98.1
97.7
97.2
98.7
97.6
97.3
97.4
92.7
97.3
97.3
96.8
96.2
97.2
96.9
96.4
96.4
93.9
97.2
97.3
97.4
96.7
98.1
96.7
96.3
96.7
66.9
70.3
70.3
69.9
69. 5
70.2
69.9
69.6
69.6
744 537
518 54.7
•• PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS HERE ENCOUNTERED DURING THE
MONTH OF AUGUST.
A
B
C
D
E
F
6
H
SYSTEM
98.9
98.6
97.8
94.9
98.6
99.2
99.2
98.8
98.2
90.4
91.1
90.7
84.8
91.1
93.0
93.0
90.2
90.7
98.0
97.5
96.0
90.8
97.5
98.5
98.5
97.7
97.0
53.9
54.3
54.0
50.6
54.3
55.4
55.4
53.8
54.0
720 429 389 43.3
PROBLEKS/SOLUTIONS/COMMENTS
THE FGD SYSTEM UAS TAKEN OFF LINE SEVERAL TIMES FOR A TOTAL OF 118 HOURS
BECAUSE OF BOILER TUBE LEAKS.
THE BOILER WENT DOUN ON SEPTEMBER 27, 1980 FOR A SCHEDULED MAINTENANCE
OVERHAUL. THE FGD SYSTEM VAS AVAILABLE DURING THIS TINE.
110
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 19&0
SECTION J
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL DOMESTIC F6D SYSTEMS
NAME
PLANT NAME
JNIT NUM3ER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
»ET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
• • FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
»• GENERAL EMISSION CONTROL SYSTEM DATA
6ENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
IHITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A9SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
.. WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/&
•* DISPOSAL
TYPE
- X
KANSAS PO*ER t LIGHT
JEFFREY
1
MANEGO
KANSAS
720.0
660.0
540.0
( 8125 BTU/LB)
COAL
18899.
5.80
28.00
.32
.01
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
NEW
8/78
**/ **
80.00
99.00
20.0
1.0
CLOSED
35.1
POND
S&7 GPMJ
— PERFORMANCE DATA — -——_———.
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER fGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
Z/80 SYSTEM
5/gO SYSTEM 100.0 100.0
•* PROBLEMS/SOLUTIONS/COMMENTS
100.0
67.7
744
696
744
504
504
THE BOILER WENT OFF LINE FOR TEN DAYS IN MARCH FOR A SCHEDULED INSPECTION.
DURING THE BOILER OUTAGE GENERAL MAINTENANCE HAS PERFORMED ON THE FGD
SYSTEM. OTHER THAN THIS OUTAGE, THE FGD UMIT OPERATED 100X OF THE TIME
IN MARCH.
k/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
720
744
720
720
744
720
720
744
720
• * PROBLEMS/SOLUTIONS/COMMENTS
DURING THE APRIL THROUGH JUNE PERIOD THE F6» SYSTEM OPERATED 100X OF THE
TIME.
7/80 SYSTEM
100.0
100.0
100.0
69.1
744
S14
514 49.3
111
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 19?0
CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
** PRDBLEMS/SOLUTIONS/COMHENTS
DURING JULY A 230 HOUR OUTAGE OCCURRED DUE TO A REHEATER TUBE LEAK IN
THE BOILER. NO FGD-RELATED PROBLEMS OCCURRED DURING THE MONTH.
S/89 SYSTE1 100.0 1CP.O 100.0 84.8 711 631 631 42.8
*» PROBLE"S/SOLUTIONS/COMMENTS
THE F6D SYSTEM WAS TAKEN OUT OF SERVICE FOR PART OF AUGUST SO REPAIRS
COULD BE CONDUCTED ON A BOILER REHEAT TUBE.
9/80 SYSTE* 100.0 10P.O 100.0 100.0 720 720 720 67.7
•* PROBLEflS/SOLUTIONS/COMHENTS
NO PROBLEMS WITH THE BOILER OR THE FGD SYSTEM WERE ENCOUNTERED DURING
SEPTEMBER.
11?
-------
EPA UTILITY F60 SURVEY: JUtY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC fGO SYSTEMS
COMPANY NAME
PLANT N»ME
JN1T NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NET PLANT GENERATING CAPACITY - MM
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGO - MU
EQUIVALENT SCRUBBED CAPACITY - MU
• * BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
HAXIMUN BOILER FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - «
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - 9TU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE P ROD UC M THROWAUA Y PRODUCT
SESERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LFVEL
NE./RETROFIT
502 DESIGN RE»OVAL EFFICIENCY - X
COHMERCIAL DATE
INITIAL START-UP
CONTRACT A*»RDED
KANSAS POUER fc LIGHT
JEFFREY
2
UAMEGO
KANSAS
0
(*
LB/MMBTU)
LB/MMBTU)
700.0
680.0
*** **.*
490.0
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
6/80
******** (....... ACFM)
******* (*•** F)
183. I 600 FT)
***.**• (....* FT)
COAL
*** **•
18841.
< 8100 BTU/LB)
5.80
7-8
.30
THROUAUAY PRODUCT
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
BLACK R VEATCH
FULL SCALE
NEW
60.00
1/80
4/bo
7/73
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TtXPFRATURE - C
PARTICULATE OUTLET LOAD - G/CU.M
• * PARTICLE SCRUBBER
TYPE
• * A3SOR3ER
TYPE
INITIAL START UP
SUPPLIER
BOILER LOAD/ABSORBER - X
L/G RATIO - L/CU.M
SOZ DESIGN REMOVAL EFFICIENCY - X
•* MIST ELIMINATOR
TYPE
COLD SIDE
COMBUSTION ENGINEERING
- X 98.6
13Z7.9 (?8140CO ACFM)
139.4 ( ?S3 F)
.07 ( .03 GR/SCF)
NONE
SPRAY TOWER
6/60
COMBUSTION ENGINEERING
11.7
4.1 ( 30.4 GAL/1000ACF)
60.3
CHEVRON
113
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
KANSAS POWER t LIGHT: JEFFREY 2 (CONT.)
SERVICE
•»**»»
** REHEATER
TYPE
TEMPERATURE BOOST - C
•* WATER LOOP
TYPE
»• TREATMENT
TYPE
»• DISPOSAL
MATURE
TYPE
LOCATION
TRANSPORTATION
NUMBER
»»•*
BYPASS
zs.o
CLOSED
45 F>
BOTTOM ASH STABILIZATION
FINAL
LINED POND
ON SITE
PUMPED
... ..........—.—PERFORMANCE DATA — -—.—...._
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
5/BO SYSTE"
•* PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
INITIAL OPERATIONS AT JEFFREY Z BEGAN IN JANUARY 1980. NO MAJOR PROBLEMS
HAVE BEEN ENCOUNTERED SINCE STARTUP.
t/80 SYSTEM 720
•* PROBLENS/SOLUTIONS/COMNENTS
DURING APRIL THE SYSTEM WAS STILL IN THE SHAKEDOUN/DEBUGGIN6 PHASE.
S/8P SYSTEM 100.0 100.0 100.0 100.0 744 744 744
S/80 SYSTEM 100.0 100.0 100.0 10C.O 720 720 720
•• PROBLEMS/SOLUTIOtS/COMPENTS
COMMERCIAL OPERATIONS BEGAN ON MAY 1, 1980. SINCE THEN THERE HAVE BEEN
NO PROBLEMS ENCOUNTERED WITH THE FGD SYSTEM. THE UNIT HAS OPERATED 100*
OF THE TIME.
7/8P SYSTEM 100.0 100.0
»* PROBLEMS/SOLUTIONS/COMMENTS
100.0
95.3
744
709
709 81.0
DURING JULY A 35 HOUR OUTAGE OCCURRED DUE TO A REHEATER TUBE LEAK IN THE
BOILER. NO FGD-RELATE6 OUTAGES OCCURRED DURING THE MONTH.
8/80 SYSTEM
»/80 SYSTEM
100.0 100.0 100.0 100.0
100. •) 100.0 100.0 100.0
•• PROBLENS/SOLUTIOMS/COMMENTS
744
720
744
720
744 80.1
720 73.5
NO PROBLEMS WERE ENCOUNTERED WITH THE BOILER OR THE FGD SYSTEM DURING THE
AUGUST AND SEPTEMBER PERIOD.
114
-------
FP* UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN «NO PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FCD SYSTEMS
COMPANY NAME
PLANT NAME
J*IT NUMBER
CITY
STATE
• ROSS UNIT GENERATING CAPACITY - MM
«ET UNIT GENERATING CAPACITY M/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - My
• * FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
• * WATER LOOP
TYPE
FRESH MAKE-UP MATER - LITER/S
.* TREATMENT
TYPE
•* DISPOSAL
TYPE
KANSAS POWER
LAMRENCE
4
LAMRENCE
KANSAS
U5.0
115.0
125.0
COAL
& LIGHT
( 10000 BTU/LB)
23260.
9.80
12.00
.55
.03
MET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
1/76
** / **
73.00
X 98.90
.0
.0
CLOSED
(****•* 6PM)
FORCED OXIDATION
POND
_...— ——— — — ———.—pERFORMANCE DATA — ——— ——
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTE"
100.0
10C.O
100.0
100.0
100.0
100.0
7*4 744
696 696
744 744
744
696
744
«. PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR PROBLEMS MERE REPORTED FOR THE LAWRENCE 4 SCRUBBER DURING
THE FIRST QUARTER 1980.
4/80 SYSTEM 100.0 100.0
*• PROBLEMS/SOLUTIONS/COMMENTS
100.0
80.0
720 576
576
THE BOILER WAS OFF LINE FOR SIX DAYS IN APRIL FOR A SCHEDULED INSPECTION.
DURING THE BOILER OUTAGE GENERAL MAINTENANCE MAS PERFORMED ON THE FGD
SYSTEM.
5/80 SYSTEM
4/&0 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
10C.O
100.0
744 744
720 720
744
720
115
-------
EP» UTILITY FGD SURVEY: JULY - SEPTEMBER 19*0
_
'ER10D MODULE AVAILABILITY OPERAfULlTY RELIABILITY UTILIZATION X REMOVAL PER BOILER F66 C*P.
S02 PART. HOURS HOURS HOURS FACTOR
•• PROBLE1S/SOLUTIOYS/COMMENTS
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED 100* OF THE TIHE IN
NAY AND JUNE.
7/&1 SYSTEM 96.8 96.8 96.P 96.8 74* 744 720 54.8
** PROBLtMS/SOLUTlONS/COMMENTS
A STORAGE TANK ERODED COMPLETELY THROUGH CAUSING A Tl>0 DAY OUTAGE IN
JULY.
3/80 SYSTE" 100.0 100.0 10^.0 100.0 744 744 744 SP.e
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED WITH THE F6D SYSTEM 01) THE BOILER DURING
AUGUST.
?/8? SYSTEM 96.9 100.0 100.C 40.3 720 290 290 16.4
•• PROBLEXS/SOLUTIOYS/CONMENTS
THE BOILER WAS OUT OF SERVICE FOR APPROXIMATELY 17 DAYS FOR A BOILER
INSPECTION.
ECONOMIZER WELD REPAIRS CAUSED THE SYSTEM TO REMAIN OUT OF SERVICE FOR
22 HOURS.
116
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
SET UNIT GENERATING CAPACITY H/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MH
.• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/&
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
cucDfv rnu^iiMPTirtM — ' y
t"t"OT tUPloUnr*lll)r
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
KANSAS POtfER I LIGHT: LAURENCE 5 (CONT.)
. .. ....... — PERFORMANCE DATA — —
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
•* PROBLEHS/SOLUTIONS/COMMENTS
A 29 HOUR OUTAGE OCCURRED AS A RESULT OF A REHEATER TUBE LEAK IN THE
BOILER. NO FED SYSTEM-RELATED PROBLEMS OCCURRED DURING JULY.
3/80 SYSTEM 100.0 100.0 100.0 81.5 744 606 606 43.3
•* PROBLENS/SOLUTIONS/COMMENTS
THE OUTAGE TIME IN AUGUST yAS DUE TO NECESSARY REPAIR OF A BOILER REHEAT
TUBE.
»/80 SYSTEM 100.0 100.0 100.0 95.7 7ZO 689 689 38.7
•• PROBLEMS/SOLUTIONS/COHMENTS
THE BOILER HAS OUT OF SERVICE FOR APPROXIMATELY 31 HOURS FOR A SCHEDULED
INSPECTION.
118
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAUE
JHIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - Mb
YET UNIT GENERATING CAPACITY W/FGD - My
E8UIVALENT SCRUBBED CAPACITY - »M
•• FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
t* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»« DISPOSAL
TYPE
KENTUCKY UTILITIES
GREEN RIVER
1-3
CENTRAL CITY
KENTUCKY
64.0
60.0
64.0
COAL
BITUMINOUS
35586.
13.40
12.10
4.00
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
3.1
9/75
6/76
80.00
99.50
.0
.0
( 11000 8TU/LB)
CLOSED
4.7
LINED POND
( 75 GPM)
— — —— —~ — PERFORMANCE DATA ..... — — ...—
•ERIOO MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGO CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
J/BO SYSTEM
100.0
100.0
100.0
.0
.0
.0
744
696
744
0
0
0
0
0
0
.0
.0
.0
*• PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED OUT OF SERVICE DUE TO BOILER REPAIRS.
EXPECTED TO BE OPERATING IN MAY.
THE UNIT IS
k/80 SYSTEM
5/80 SYSTEM
S/8P SYSTE*
100.0
100.0
100.0
.0
.0
.0
720
744
720
.0
.0
.0
• * PROBLEMS/SOLUTIONS/COMMENTS
7/80 SYSTEM
100.0
THE FGD SYSTEM REMAINED OFF LINE DURING THE SECOND QUARTER Of 1980 AS A
RESULT OF THE ON-GOING BOILER REPAIRS. COMPLETION OF THE BOILER REPAIRS
HAS BEEN DELAYED BY THE UNAVAILABILITY OF SOME NEEDED PARTS.
.0 744 0 0 .0
119
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19PC
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
YET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MM
.• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SDZ DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL fFFIClENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
fHESH MAKE-UP yATER - LITER/S
•» DISPOSAL
TYPE
- X
LOUISVILLE GAS & ELECTRIC
CANE RUN
4
LOUISVILLE
KENTUCKY
188.0
175.0
188.0
COAL
BITUMINOUS
26749.
17.10
9.00
J.75
.04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
1.6
8/76
8/77
85.00
99.00
.0
.0
( 11500 BTU/LB)
OPEN
6.3
LINED POND
( 10,0 6PM)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERA9IL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
Z/80 SYSTEM
$/80 SYSTEM
10C.O
99.8
80.5
95.6
66.7
74.3
744 711
696 465
744 687
711
464
553
•* PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS yERE REPORTED FOR THE FIRST QUARTER OF 19PO
rflTH EITHER THE BOILER OR THE FGD SYSTEM.
4/60 SYSTEM 99.0 98.8 9S.8 79.9 7?0 5P2 575
** PROBLcMS/SOLUTlONS/COMMENTS
DURING APRIL SPRAY PUMP PROBLEMS CAUSED SEVEN HOURS OF OUTAGE TIME.
5/80 SYSTEM 96.8 100.0 100.0 7.0 744 52 52
•* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS NOT NEEDED MOST Of MAY, THIS ACCOUNTS FOR THE LOW
UTILIZATION OF THE FGD SYSTEM.
ONE DAY OF OUTAGE TIME IN MAY yAS CAUSED BY A LEAK IN A SPRAY PUMP
SEAL.
SYSTE"
.0
.0
720 350
121
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
LOUISVILLE 6AS I ELECTRIC: CANE RUN I (CONT.)
... ... . . . PERFORMANCE DATA -—————«_..__
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/CONMENTS
DURING PART OF JUNE THE BOILER WAS ON RESERVE, IN WHICH TIME THE SCRUBBER
DUCTWORK AND LININGS WERE REPAIRED.
REPAIRS WERE WADE TO MODULE LININGS AND DUCTWORK. DUCTWORK REPAIRS/
REPLACEMENTS WERE MADE WITH 316 SS.
ALSO DURING THE DOWN TIME THE EXPANSION JOINT LOCATED AT THE DISCHARGE
OF THE BOOSTER PUMP WAS REPLACED.
7/80 A
a
SYSTEM
85.7
85.7
85.7
92.8
92.8
92.8
92.8
92.8
92.8
85.7
85.7
85.7
87.CO 99.00 74* 687 638
** PROBLEfS/SOLUTIONS/COMMENTS
PROBLEMS WERE ENCOUNTERED WITH THE OIL REHEAT SYSTEM DURING JULY.
SPRAY PUMP AND VALVE FAILURES ENCOUNTERED DURING THE MONTH ACCOUNTED FOR
SOME OF THE FGD SYSTEM DOWN TIME.
S/80 SYSTEM
7/80 SYSTEM
100.0
100.0
99.3
100.0
99.3
100.0
76.9
35.7
744
720
576
257
572 5C.O
257 50.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR OUTAGES OCCURRED DURING AUGUST AND
SEPTEMBER.
122
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFOR»ANCE DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
«ET UNIT GENERATING CAPACITY W/FGD - MM
EBUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 5!
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• • GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
SEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP BATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»* TREATMENT
TYPE
*« DISPOSAL
TYPE
- X
LOUISVILLE GAS fc ELECTRIC
CANE RUN
5
LOUISVILLE
KENTUCKY
200.0
192.0
( 11500 BTU/LB)
COAL
BITUMINOUS
26749.
17.10
9.00
3.75
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
1.5
12/77
7/78
85.00
99.00
.0
.0
OPEN
ttt•«*•
POZ-0-TEC
LINED POND
(***** 6PM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
SYSTEM 92.1 72.2 7*4 583 5S7
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY NO OPERATIONAL PROBLEMS WERE ENCOUNTERED.
SYSTEM 71.9 49.7 696 481 3*6
•• PROBLEMS/SOLUTIONS/COMMENTS
IN FEBRUARY THE UTILITY RAN OUT OF CARBIDE LIME CAUSING INTERRUPTION OF
THE FGD SYSTEM OPERATION. THE UNAVAILABILITY OF LIME HAS CAUSED BT FREEZE
UPS ENCOUNTERED BY AIRCO, THE LIME SUPPLIER.
5/80
SYSTEM 44.5
«• PROBLEMS/SOLUTIONS/COMMENTS
27.2
744
454
202
fc/80 SYSTEM
.0
REHEATER TUBE PROBLEMS WERE ENCOUNTERED IN FEBRUARY AND CONTINUED
THROUGH MARCH. THE UTILITY HOPES TO REPLACE THE TUBE BUNDLES IN THE
SUMMER.
.0 720 0 0
.0
123
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
L3U1SVILLE GAS fc ELECTRIC: C»NE RUN 5 (CONT.)
PERFORMANCE DATA —- —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•* PROBLE1S/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OFF LINE THE ENTIRE MONTH OF APRIL TO INSTALL
STAINLESS STEEL (316 SS) IN THE DUCTWORK AND IN THE MODULES.
5/60 SYSTEM 95.3 94.5
*• PROBLEMS/SOLUTIONS/COMWENTS
3/80
J/80
94.5
80.2
744
597
DURING "AY ONE DAY OF OUTAGE TIME WAS NECESSARY TO COMPLETE THE INSTALLA-
TION OF THE STAINLESS STEEL IN THE DUCTWORK AND MODULES.
A PUMP SEAL ON THE RECIRCULATION PUMP FMLED CAUSING APPROXIMATELY 10
HOURS OF OUTAGE TIME.
S/60 SYSTEM
78.8
74.4
74.4
61.8
720
598
44S
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SYSTEM HAD TO BE TAKEN OFF LINE FOR 153 HOURS DUE TO THE
POOR WELDS ON THE TUBE BUNDLES IN THE REHEATER. THE TUBE BUNDLES HAVE
BEEN A CONSTANT PROBLEM AND THE MANUFACTURER IS SCHEDULED TO REPLACE
THEM IN THE FALL.
7/80 SYSTEM 78.7 87.6
** PROBLEMS/SOLUTIONS/COMMENTS
87.6
78.7
85.00 99.00 744
669
586
DURING JULY THE REHEAT TUBE EXCHANGERS FAILED. TWO NEW EXCHANGERS ARE
NOW ON SITE AND ARE SCHEDULED TO BE INSTALLED IN NOVEMBER OR DECEMBER 1980.
A THREE DAY OUTAGE OCCURRED IN JULY DUE TO A LIMESTONE ROCK DISABLING
THE THICKENER.
SYSTEM
SYSTEM
49.6
87.2
5R.4
97.5
58.4
97.5
49.6
87.2
744
720
632
644
369 50.0
628 SO.O
*• PROBLEMS/SOLUTIONS/COMMENTS
THE OUTAGE TIME DURING AUGUST AND SEPTEMBER WAS CAUSED BY A REHEAT TUBE
BUNDLE FAILURE. THE BUNDLES ARE PRESENTLY BEING REPLACED IN BOTH MODULES.
124
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 5
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
«ET UNIT GENERATING CAPACITY W/FGD - My
E8UIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
SEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PtRTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBED SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LIUH/S
•* DISPOSAL
TYPE
I ELECTRIC
- X
( 11000 BTU/LBI
LOUISVILLE GAS
CANE RUN
6
LOUISVILLE
KENTUCKY
299.0
277.0
299.0
COAL
BITUMINOUS
25586.
17.10
9.00
4.80
.04
WET SCRUBBING
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
RETROFIT
1.0
4/79
*«/«*
95.00
99.00
20.0
.3
CLOSED
LANDFILL
(****» 6PM)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 49.D
»* PROBLEMS/SOLU1IOSS/COMMENTS
13.8
744
210
103
FGD SYSTEM OUTAGE TIME IN JANUARY HAS CAUSED BY A THICKENER FAILURE.
THE RAKF BECAME INOPERABLE BECAUSE OF HIGH SOLIDS AND THE THICKENER HAD
TO BE CLEANED OUT.
2/80
5/80
SYSTEM 64.7
SYSTE" 7C..3
*» PROBLEMS/SOLUTIONS/COMMENTS
47.0
64. 5
696
744
386
686
327
480
IN FEBRUARY AND MARCH OUTAGE TIME WAS CAUSED BY PROBLEMS WITH THE RECYCLE
PUMPS.
4/80
SYSTEM 93.8 91.5
*• PROBLEMS/SOLUTIONS/COMMENTS
97.7
73.9
95.00 99.CO 720 581
531
THE BOILER OUTAGES IN APRIL WERE A RESULT OF THE LOSS OF ONE OF THE BOILER
FEED PU«PS ASD BECAUSE THE LOAD WAS NOT NEEDED.
THE FGD OUTAGES WERE A RESULT OF HIGH BOOSTER FAN SUCTION TRIPS, REPAIRS
TO THE IUCS SYSTEM, REPAIRS TO THE THICKENER UNDERFLOW LINE AND A PLANNED
INSPECTION OF THE TRAYS. THE TRAY PLUGGING PROBLEM «AS SOLVED BY A
SLIGHT PH ADJUSTMENT IN THE REACTORS.
5/&C SYSTE"
99.
99.9
99.9
99.5
744
741
740
125
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
L3UISVILLE GAS I ELECTRIC: CANE RUN A (CONT.)
... _ PERFORMANCE DATA —— —-——.-.._
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
• * PROBLEKS/SOLUTIONS/COMMENTS
DURING MAY THE PRESSURE RELIEF VALVE ON THE BOOSTER FAN MALFUNCTIONED
FORCING THE FGD SYSTEM OUT OF SERVICE.
4/80 SYSTEM 99.9 99.8 99.9 88.9 720 642 640
•• PROBLEMS/SOLUTIONS/COMMENTS
A SPRAY PUMP MALFUNCTION CAUSED THE SYSTEM TO SHUTDOVN. APPROXIMATELY
ONE HOUR WAS NEEDED TO PUT THE SPARE INTO SERVICE.
THE BOILER WAS OFF FOR REPAIRS TO THE CLINKER GRINDER AND TO REPAIR A
BOILER TUBE LEAK.
IMPROVEMENTS TO T»E PH CONTROL CIRCUITRY HAVE LEAD TO IMPROVED CARBIDE
LIME UTILIZATION.
EXPERIMENTATION WITH A NEW FILTER CLOTH HAS SHOWN AN IMPROVEMENT IN SODA
ASH CONSUMPTION.
SULFUR DIOXIDE EMISSIONS AVERAGED LESS THAN 200 PPM FOR JUNE.
7/80 SYSTEM 99.9 99.9 99.7 82.9 744 618 617
•• PROBLEMS/SOLUTIO*S/COM»ENTS
DURING THE PERIOD FROM JULY 17 THROUGH JULY 28 AN ACCEPTANCE TEST WAS RUN.
DURING THE TEST THE FGD SYSTEM EXPERIENCED NO MAJOR PROBLEMS OR OUTAGE
TIME. THE AVERAGE SO? REMOVAL EFFICIENCY DURING THE TEST UAS 95.IX.
DURIKG NORMAL OPERATION IN JULY NO MAJOR FGD RELATED PROBLEMS WERE
ENCOUNTERED.
S/80 SYSTEM 99.5 94.6 94.6 84.5 744 665 628 50.0
»/80 SYSTEM 99.0 98.6 9».8 86.9 720 635 626 50.0
• • PROBLENS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS OCCURRED DURING THE MONTHS OF
AUGUST AND SEPTEMBER.
126
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
oROSS UNIT GENERATING CAPACITY - Mtt
YET UNIT GENERATING CAPACITY W/FGD - Mb
EQUIVALENT SCRUBBED CAPACITY - HW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
«* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»* TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
LOUISVILLE GAS t ELE.CTR1C
MILL CREEK
3
LOUISVILLE
KENTUCKY
442.0
420.0
COAL
BITUMINOUS
26749.
11.50
3.75
.04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
1.6
8/78
5/79
85.00
99.00
.0
.0
( 11500 BTU/LB)
OPEN
9.4
( 150 6PM)
FLYASH/LIME STABILIZATION
POND
.. PERFORMANCE DATA ——— ———
»ERIOD MODULE AVAILABILITY OPERABILIT1 RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/60
2/80
3/80
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
DURING THE OVERHAUL GENERAL SCRUBBER MAINTENANCE WAS DONE BUT NO MAJOR
MODIFICATIONS MERE MADE.
SYSTEM 36.1
• * PROBLEMS/SOLUTIONS/COMMENTS
26.6
696
512
185
THE UNIT CAME BACK ON LINE ON FEBRUARY 10 AFTER THE TURBINE OVERHAUL
WORK WAS COMPLETED.
SYSTEM 36.9
•• PROBLEMS/SOLUTIONS/COMMENTS
30.6
744
618
228
PROBLEMS ENCOUNTERED DURING FEBRUARY AND MARCH WITH THE F6D SYSTEM
OPERATION INCLUDED FROZEN WATER LINES AND WORN GASKETS BLOWING IN THE
REHEATER FLANGES.
4/80 SYSTEM
THE UTILITY IS IN THE PROCESS OF REPLACING THE REHEATER TUBES.
*2«* 42.5 42.5 42.2 85.00 99.40 720 715
304
.0
127
-------
EPA UTILITY fGD SURVEY: JULY - SEPTEMBER 1980
LDUISVILLE G»S & ELECTRIC: WILL CREEK 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AV«ILABILIT¥ OPERAPILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
«* PRQ,BLE«IS/SOLUTIONS/CON«ENTS
THE REHFATER TUBE REPLACEMENT CONTINUED INTO APRIL.
THE OTHER OUTAGE TIME ENCOUNTERED DURING APRIL WAS CAUSED BY A BLOWN
GASKET IN THE CONDENSATE PUMP.
5/80 SYSTEM 67.5 51.4 51.4 34.4 744 498 256
** PROBLE»S/SOLUTIONS/COMMENTS
DURING MAY THE PLASTIC MIST ELIMINATOR COMPONENTS WERE REPLACED WITH
STAINLESS STEEL. THIS KEPT THE SYSTEM OFF LINE FOR APPROXIRATELY 10 DAYS.
REHEATER TUBE LEAKS WERE ALSO ENCOUNTERED IN MAY.
4/80 SYSTEM 88.2 .0 .0 .0 720 85 0
** PROBLEHS/SOLUTIONS/COHMENTS
IN LATE MAY THE TURBINE LOST TWO BLADES CAUSING THE SYSTEM TO SHUTDOWN
UNTIL THE LATTER PART OF JUNE. DURING THE OUTAGE THE UTILITY DECIDED
TO REPLACE THE LIME STORAGE TANK LINES WITH LARGER ONES TO SERVICE THE
NEW UNITS. THE WORK WAS NOT COMPLETED WHEN THE BOILER WAS RETURNED
TO SERVICE; THUS, THE FGD UNIT DID NOT OPERATE DURING THE MONTH.
7/80 SYSTEM 92.0 91.3 91.3 83.9 744 684 625
•» PROBLEMS/SOLUTIOMS/COMMENTS
RECYCLE PUMP FAILURES CAUSED THE FGD SYSTEM TO SHUTDOWN FOR PART OF JULY.
J/80 SYSTEM 58.7 81.7 81.7 58.7 744 535 437 60.0
J/80 SYSTEM 57.2 60.4 60.4 57.2 720 682 412 60.0
*• PR03LEMS/SOLUT10NS/COMMENTS
DURING THE AUGUST THROUGH SEPTEMBER PERIOD THE PUMP HOUSE WAS FLOODED
DUE TO THE FAILURE OF THE BLEED PUMP FRP PIPE LINE. BECAUSE OF THIS
FAILURE, 23 PUMPS AND 23 PUMP MOTORS WERE DAMAGED.
128
-------
EPA UTILITY FGD SURVEI: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COHPMt NAME
PLANT NAME
UNIT MUM3ER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - My
til UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FJEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
.. GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEd/RETROFIT
ENER6Y CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S92 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
«• TREATMENT
TYPE
•* DISPOSAL
TYPE
- X
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
LOUISVILLE
KENTUCKY
72.0
67.0
72.0
t 11500 BTU/LB)
COAL
BITUMINOUS
26749.
11.50
2.50
WET SCRUBBING
LIKE
COMBUSTION ENGINEERING
RETROFIT
2.8
4/73
* * / **
90.00
99.10
.0
.0
CLOSED
3.1 ( SO GPM>
LIME STABILIZATION
POND
. «. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/6" SYSTE"
3/80 SYSTEM
.0
.0
.0
744
696
744
0
0
0
0
0
0
.0
.0
.0
* PROBLE*S/SOLUTIONS/CO«>"ENTS
THIS UNIT DID NOT OPERATE DURING THE FOURTH QUARTER OF 1979 OR THE FIRST
SUARTER OF 19FO DUE TO A LACK OF DEMAND. THIS UNIT IS USED AS A PEAKING
UNIT ANt> WILL BE RETIRED SOMETIME IN 1987.
4/8C SYSTE" 100.?
** PROBLi*S/SOLUTIONS/COM»ENTS
.0
720
.0
DURING APRIL THE FGD SYSTEM WAS AVAILABLE 10CX OF THE TIME BUT WAS NOT
OPERATED DUE TO A BOILER RELATE6 PROBLEM.
5/8C SYSTE1 100.3 86.6
• * PROBLfcMS/50LUTIONS/COM«lENTS
66.6
7.8
744
67
DURING MAY, NINF HOURS OF OUTAGE TIME RESULTED FROM THE UNAVAILABL1TY OF
THE LIME SLURRY.
i/8'
SYSTEM
'00.0
94.1
94.1
6.7
720
51
48
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
L9UISVILLE GAS I ELECTRIC: PADDY'S RUN 6 (CONT.)
_ ----- .. --------------- -PERFORMANCE DATA --------- - — — — — — - — ...... — ._._.__ __ _
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGft CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/80
3/80
9/60
** PROBLEMS/SOLUTIONS/COMMENTS
THE THREE HOURS THE SCRUBBERS DID NOT OPERATE IN JUNE WAS DUE TO THE FACT
THAT THE BOILER WAS BROUGHT ON LINE BEFORE THE SCRUBBER OPERATORS WERE
ON DUTY.
A
B
SYSTEM
100.0
100.0
100.0
.0
.0
.0
744
•* PROBLEMS/SOLUTIONS/COHMENTS
THE BOILER AND FGD SYSTEM DID NOT OPERATE DURING THE MONTH OF JULY DUE TO
A LACK OF DEMAND.
SYSTEM 100.0
SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
744
720
0
0
THE BOILER DID WOT OPERATE DURIN6 AUGUST AND SEPTEMBER. THE FGO SYSTEM
dAS AVAILABLE 100X OF THE TIME.
130
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AN6 PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUM3ER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
S02 MISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - Mw
SRCSS UNIT GENERATING CAPACITY - My
MET JNIT GENERATING CAPACITY W/FGD - MM
YET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - »y
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
HAHIIUM BOILER FLUE GAS FLOW - Cu.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
• * FJEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - 3TU/LD
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
R«NGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLOKIDE CONTENT - X
»• GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROiiAUAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIR"
CONSTRUCTION FIRM
DEVELOPMENT LFVEL
NEW/RETROFIT
PART1CULATE DESIGN REMOVAL EFFICIENCY
so2 DESIGN REMOVAL EFFICIENCY - x
INITIAL START-UP
CINSTRUCT I ON COMPLETION
CONSTRUCTION INITIATION
LETTER OF INTENT SIGNED
STARTED REQUESTING BIDS
STARTED PBELI»INAV DESIGN
** ESP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE. DROP - KPA
PARTICULATE OUTLET LOAD - G/CU.M
•• PARTICLE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
SHELL MATERIAL
LINING MATERIAL
MINNESOTA POWER I LIGHT
CLAY BOSWtLL
COHASSET
MINNESOTA
B
43.
516.
10CO.O
554.0
504.0
511.0
t .1CC LB/MMPTU)
( 1.COO LP/MMPTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
2/60
1086.40
148.9
163.
11.3
ACFM)
( 3PCj F)
< 6PO FT)
( 37.0 FT)
< 8887 BTU/LB)
7509 - 9923
COAL
SU8BITUMINOUS
19276.
9.4C
4.81 - 15.99
21.50
20.3D - 26.31
.94
0 - 4.55
.01
0 - O.C7
THROWAWAV PRODUCT
WET SCRUBBING
LIME/ALKALINE FLYASH
NONE
PEABODY PROCESS SYSTEMS
EBASCO
PEABOOY PROCESS SYSTEMS
FULL SCALE
NEW
- X 99.7J
£4.55
4/8?
2/60
5/78
2/77
4/76
6/75
1
HOT SIDE
JOY
X 99.7
94.4
398.9
.07
( 200000 ACFM)
( 750 F)
(••«.» IN-H20)
( .02 GR/SCF)
RADIAL VENTURI VARIABLE THROAT
PEABODY PROCESS SYSTEMS
1
STAINLESS STEEL
RUBBER
131
-------
EPA JT1LITY FGO SURVEY: JULY - SEPTEMBER 1980
"UNNESOTA POWER S LIGHT: CLAY BOSWELL 4 (COM.)
I ETERNAL "ATE RIAL
NUMBER OF NOZ7LES
TYPF OF NOZZLES
30ILER LOAD/SCRUBBEP - X
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
LI3UID 9ECIRCULATION RATf - LITEfi/S
L/G RATIO - LITER/CU.1
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - N&/J
PARTICULATfc OUTLET LOAD - NG/J
PARTICULATE DFSIGN REMOVAL EFFICIENCY - X
S02 INLET CONCENTRATION - NG/J
S02 DESIGN RE«OVAL EFFICIENCY - X
•• A3SOR3ER
N U ,1 8 E R
TYPF
INITIAL START UP
SUPPL IER
NUMBER OF STARES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
NUMBER OF NOZZLES
NOZZLE TYPt
3DILER LOAD/ABSORBER - X
iAS FLOW - CU.M/S
3»S TEMPERATURE - C
LIQUID RECIRCULATION RATE - UTER/S
L/G RATIO - L/CU.M
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE; INLET LOAD - NG/J
PARTICULATE. OUTLET LOAD- G/CU.M
PARTICULATE OUTLET LOAD - NG/J
502 OUTLET CONTRATION - PPM
Sit OUTLET CONCENTRATION- NG/J
SOI DESIGN REMOVAL EFFICIENCY - X
A3SORBER SPARF CAPACITY INDF.X - X
SPARF COMPONENT INDEX
•• FANS
NUM9E R
TYPF
CONSTRUCTION "ATERIALS
SERVICE - uET/DRY
CAPACITY - CU.M/S
•• VIST ELIMINATOR
TYPE
•* ^IST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION "ATE»1AL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
DEPTH - M
SPACING - CM
ANGLES
rfASH SYSTEM
SUPERFICIAL GAS VELOCITY - «/S
PRESSURE DROP - KPA
•• PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL RANGE
CONTROL MANNER
MODE
SENSOR LOCATION
STAINLESS STEEL
13
TANGENTIAL AND BULL NOZZLES
33.3
394.4 ( 835840 ACFM)
148.9 ( }CO F)
841.7 (1336C GPM)
2.7 (20.il GAL/100CACF>
******* (***»* IN-H20)
dZ.iOO LB/MMPTU)
( .IOC LB/MMBTU)
51 59.
43.
99.7
2752.
89.0
( 6.401 LB/MMBTU)
VENTUKI/SPRAY TOWER
5/e?
PEAeODY PROCESS SYSTEMS
4
DIA 35' HT 60'
CARbON STEEL
RUBBER LINED
STAINLESS STEEL, CARBON STEEL R RUBBER LINED
24
REFRAX NOZZLES
33.3
302.08
53.3
21C4.
6.7
5.
< 64C13C ACFM)
( 1C8 F)
(334CO GPM)
( 50.0 GAL/1000ACF)
(20.0 IN-H20)
( 12.0 FT/S)
( .030 GR/SCF)
( .IOC1 LB/MMBTU)
( .Q3C GR/SCF)
( .IOC
<*•*»« LB/MMBTU)
.0
3.7
.1
43.
.1
43.
345
*****
89.0
33.C
1.0
CENTRIFUGAL RADIAL TIP
INCONEL 6^5 R INCOLY 825
WET
JtO.33 ( 6788CO ACFM)
SIEVE TRAY
CHEVRON
NORYL PLASTIC
HORIZONTAL
1
3
1.52
.30
3.5
90
( 5.0 FT)
( 1.0 FT)
( 1.3.8 IN)
HOSE CONNECTION TO HEADER FOR MANUAL WASH
3.4 (11.0 FT/S)
.0 ( ,J 1N-H20)
PH-DENSITY IN RECYCLE TANKS
3-6 PH; 7-9X DENSITY
AUTOMATIC
FEE DBACK
RECYCLE TANKS
132
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
POUER S LIGHT: CLAY B05UELL 4 (CONT.)
PUMPS
SERVICE
ALKALI FEED
FLY ASH SLURRY FEED
VENTURI RECYCLE
ABSORBER RECYCLE
rfASH WATER
NUMBER
2
2
6
12
2
*** *
SERVICE
RECYCLE
ALKALI STORAGE
J«SH WATER
FLY ASH STORAGE
.* REHEATER
DUMBER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
• * WATER LOOP
TYPE
EVAPORATOR WATER LOSS - LITER/S
RECOVERED WATFR RETURN - LITER/S
FRESH MAKEUP WATER ADDITION - LITERS/S
•* REAGENT PREPARATION EQUIPMENT
NUMBER OF STORAGE HOPPERS
NUMBER OF SLAKERS
SLAKER CAPACITY - H T/H
REAGENT PRODUCT - t SLURRY SOLIDS
POINT OF ADDITION
•* DISPOSAL
MATURE
TYPE
LOCATION
TRANSPORTATION
DIMENSIONS
AREA - ACRES
CAPACITY - CU.M
NUMBER
4
1
1
1
4
BYPASS
FLUE GAS
14.4
CLOSED
23.9
188.1
56.4
5
4
.4
20.0
RECYCLE TANKS
26 F>
( 380 6PM)
< 298S GPM)
( 895 6PM)
.4 TPH)
FINAL
LINED POND
1 MILE WNW OF UNIT
PIPE
4000 X 3000 FT
300.0
9556522 < 7814.0 ACRE-FT)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/BO SYSTEM
7?0
•* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER BEGAN OPERATIONS ON FEBRUARY 26s 1980 AND FIRED OIL THROUGH THE
MONTH OF MARCH. INITIAL FGD SYSTEM OPERATIONS BEGAN IN EARLY APRIL KITH
THE BOILER FIRING COAL FOR TESTING PURPOSES. THE UNIT WAS SHUTDOWN IN
MID-APRIL TO RECTIFY MINOR SHAKEDOWN PROBLCMS. A TRIAL RUN OF THE FGD
SYSTEM IN AN INTEGRATED MODE OCCURRED IN LATE APRIL.
5/80 SYSTE"
5/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
7ZO
SHAKEDOWN OPERATIONS CONTINUED THROUGH THE SECOND CUARTER OF 1980. THE
FGD SYSTEM WILL BE FINE TUNED TO MEET DESIGN CRITERIA THROUGH JULY. TO
DATE THE UTILITY REPORTED THAT, ALTHOUGH MANY TYPICAL STARTUP PROBLEMS
ATTRIBUTABLE TO OPERATOR ERROR AS WELL AS MECHANICAL MALFUNCTIONS HAVE
OCCURRED, NO UNUSUAL PROBLEMS HAVE OCCURRED. THE COMPLIANCE TEST IS
SCHEDULED FOR EARLY SEPTEMBER.
13J
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
MINNESOTA POWER t LIGHT: CLAY BOSWELL 4 (CONT.)
.... ... .- — PERFORMANCE 6ATA
PERIOft MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/80
1
Z
3
4
SYSTEM
87.8
97.8
100.0
.0
96.1
100.0
100.0
100.0
100.0
86.8
96.7
10C.O
.0
95.0
720 712 684 79.0
S/8P 1
2
3
4
SYSTEM
7/80
1
2
3
t,
SYSTEM
71.8
75.5
29.*
49.7
75.5
71.6
89.6
14.7
65.1
80.5
100.0
10P.O
100.0
100.0
100.0
100.0
100.0
100.0
100.0
10P.O
62.9
66.1
25.8
45.5
66.1
n.o
88.7
14.5
64.5
79.6
744 652
744 737
*»2 61.7
592 73.7
•* PROBLEMS/SOLUTIONS/COMMENTS
THE FGO SYSTEM IS STILL IN THE DEBUGGING PHASE OF OPERATION. MUCH OF THE
EQUIPMENT IS STILL BEING WORKED ON AND TESTED.
134
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER i?80
SECTION 3
DESISN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JHlT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HFAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•» GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
$02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESISN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
»* HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
- X
MINNKOTA POWER COOPERATIVE
MILTON R. YOUNG
2
CENTER
NORTH DAKOTA
440.0
402.0
185.0
( 6500 BTU/LB)
COAL
LIGNITE
15119.
6.50
38.00
.70
.01
WET SCRUBBING
LINE/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
NEW
1.6
9/77
6/78
36.13
99.60
100.0
1.0
CLOSED
44.1
MINEFILL
( 700 6PM)
„__ — - — - — ——-PERFORMANCE DATA- ~— ......_..._.._..._.._..-.
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/gO A 7.1 10.5 7.1
B .0 .0 .0
SYSTEM 7.1 10.5 10.5 7.1
744 504 53 58.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY A COLD yEATHER CAUSED SOME PIPE LINES AND A BOOSTER
FAN ICE UP.
A HUH PERCENTAGE OF COARSE SOLIDS IN THE IHICKENER CAUSED SOME OUTAGE
TIME. THE WORM GEAR ON THE THICKENER FAILED ADDING TO THE OUTAGE TIME.
CLEANING AND REPAIR OF THE THICKENER HAS COMPLICATED BY SUB-ZERO AMBIENT
TEMPERATURES.
2/80 SYSTEM .0 .0
• » PROBLE1S/SQLUTIONS/COMMENTS
.0
696 696
0 97.1
PROBLEMS RELATED TO THE COLD HEATHER CONTINUED THROUGH FEBRUARY. ICE
ON THE BOOSTER FAN HAD TO BE MELTED BEFORE IT COULD BE OPERATED.
SHAFT SLEEVES ON SEVERAL SPRAY RECYCLE PUMPS WERE REPLACED DURING
FEBRUARY.
THE GEAR REDUCER FAILED ON THE B-SIDE ABSORBER AGITATOR PREVENTING SCRUB-
BER OPERATION.
THE ISOLATION DAMPER CHAINS BROKE DURING THE MONTH.
135
-------
EPA UTILITY fGO SURVEY: JULY - SEPTEMBER 198C
*INNK3TA POWER COOPERATIVE: "111 TON R. YOUNG 2 (CONT.)
. PERFORMANCE DATA . .
ȣRIOD MODULE AVAILABILITY OPERABILITY RELIAP1L1TY UTILIZATION I REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/80 A 22.6 22. 6 22.6
B 6.2 6.2 6.2
SYSTEM 28.9 28.8 28. B 28.8
744 743 214 89.1
t/80
5/80
PROBLE'S/SOLUTIONS/COMMENTS
DURING MARCH COLD HEATHER CONTINUED TO BE A PROBLEM.
THE TORQUE SWITCHES ON THE ISOLATION DAMPERS WERE REPLACED. THE DAMPER
PROBLEMS CAUSED THE BOOSTER FAN TO TRIP. THE OUTA6E TIME WAS EXTENDED
BECAUSE THE UTILITY HAD TO WAIT FOR THE SWITCHES TO BE DELIVERED.
AN EXCESSIVE AMOUNT OF COARSE PARTICLES IN THE THICrENER CONTINUED TO BE
A PROBLEM. PLUGGED BLEED LINES FROP THE ABSORBER TO THE THICKENER WERE
ALSO ENCOUNTERED.
THE A-SIDE ABSORBER AGITATOR ANCHOR BOLTS SHEARED DURING MARCH CAUSING
MODULE COWN TIME.
THE SHAFT SLEEVES ON THE SPRAY RECYCLE PUMPS WOULD NOT MOLD THE PUMP GLAND
PACKING. THE SHAFT SLEEVES ARE CURRENTLY BEING REPLACED.
A
B
SYSTEM
100.0
.0
100.P
.0
.G
.3
.0
.c
.0
.0
.0
720 154
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS DOWN FOR APPROXIMATELY 3 WEEKS FOR THE ANNUAL UNIT OUTAGE
DURING APRIL.
PLUGGED BLEED LINES AND THE REPLACEMENT OF THE SHAFT SLEEVES ON THE
RECYCLE PUMPS CAUSED THE F6D SYSTEM TO REMAIN OFF LINE DURING THE TIME
THE BOILER OPERATED.
A
B
SYSTEM
.0
47.2
47.2
.0
48.4
48.4
50.6
50.6
.0
45.6
45.6
744
700
339
•• PROBLEMS/SOLUTIONS/COMMENTS
MODULE B WAS OPERATED DURING MAY WHILE REPAIR WORK WAS BEING DONE ON MODULE
A .
THE REPAIRS ON MODULE A INCLUDED WORK ON THE SPRAY RECYCLE NOZZLE PIPING,
AND THE RECYCLE HEADER.
THE VALVES ON BOTH THE SPRAY RECYCLE PUMP AND THE DISCHARGE SPRAY CYCLE
PUMP WERE REPAIRED.
THE ABSORBER LINING HAS STARTED TO WEAR AND IS NOW BEING REPAIRED.
HIGH SOLIDS RESULTED IN THICKNER LINE PLUGGING. HIGH SOLIDS ALSO CAUSED
PROBLEMS WITH THE RAKE AND CONE. BOTH THE THICKNER AND THE CLARIFIER HAD
TO BE DRAINED AND CLEANED.
THE ABSORBER AGITATOR TUNNEL WAS ALSO CLEANED DURING THE MONTH.
A
B
SYSTEM
.0
41.B
41.8
.0
40.4
40.4
41.4
41.4
.0
39.3
39.3
720
701
283
.* PROBLEMS/SOLUTIONS/COMMENTS
MODULE B CONTINUED TO OPERATE THROUGH JUNE.
PROBLEMS WITH THE THICKNER CONTINUED THROUGH THE MONTH. HIGH SOLIDS CAUSED
PROBLEMS WITH THE RAKE MECHANISM AND THE LIMIT SWITCH.
136
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
4JNNKOTA POWER COOPERATIVE: MILTON R. YOUNG 2 CCONT.)
__ PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
TROUBLE WAS ENCOUNTERED DURING JUNE WITH THE VACUUM FILTER.
THE REPAIR UORK CONTINUED ON THE ABSORBER FLAKE LININGS.
NODULE A REPAIR WORK CONTINUED DURING JUNE.
r/eo A >o .0 .0
B 65.3 64.5 65.8 52.0
SYSTEM 65.3 64.5 65.8 52.0 7*4 600 387 60.0
*• PROBLEMS/SOLUTIONS/CONMENTS
PROBLEMS WITH THE RAKE MECHANISM AND UNDERFLOW PUMPS IN THE THICKENER CON-
TINUED IN JULY. HIGH SOLIDS IN THE THICKENER ARE CAUSED WHEN FLY ASH IS
ADDED TO THE LIME IN THE ABSORBER TOWER. THE ABSORBER REAGENT IS CHANGED
TO STRAIGHT LIME WHEN THIS OCCURS.
PROBLEMS WERE ENCOUNTERED WITH THE TWO VACUUM FILTER PUMPS. ONE WAS BEING
REBUILT WHILE THE OTHER FUNCTIONED POORLY.
REPAIRS WERE MADE TO THE LEAK IN THE ABSORBER TOWER.
PROBLEMS WERE REPORTED WITH THE MOTOR AND DISCHARGE VALVE ON THE TRAY
RECYCLE PUMPS.
THE FGD SYSTEM WAS NOT PLACED IN SERVICE WHEN THE BOILER WAS RUN AT REDUCED
LOAD DURING THE MONTH.
«/60 A 90.7 54.3 98.8 53.9
B 56.9 44.2 99.4 44.0
SYSTE" 99.2 9P.6 99.2 98.0 744 739 729 92.8
«• PROBLEMS/SOLUTIONS/COMMENTS
30TH MODULES WERE OPERATED DURING AUGUST.
DURING THE MONTH, MAINTENANCE UORK WAS DONE OH THE TEFLON PACKING OF THE
SPRAY RfCYCLE PUNPS. THE VACUUM FILTER DRUM, SPRAY NOZZLES, THE ABSORBER
AGITATOR, THE CLARIFJER CONE, AND THE THICKNER RAKE MECHANISM.
9/80 A 70.1 72.6 11-0.0 66.9
B 66.7 25.1 100.P 2'.2
SYSTEM 100.0 97.9 1G*.0 90.3 720 664 650 7P.5
• * PROBL£MS/SOLUT10NS/COM»ENTS
THE FGD SYSTE" WAS AVAILABLE DURING ALL OF SEPTEMBER.
BOTH MODULES WERE OPERATED DURING THE MONTH.
137
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
«ET UNIT 6ENERATIN6 CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - My
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
502 DESIGN REMOVAL EFFICIENCY - I
PARTICIPATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDFX - X
A3SORBER SPARE COMPONENTS INDEX
•• HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
NONONGAHELA POWER
PLEASANTS
1
8ELMONT
WEST VIRGINIA
618.0
580.0
618.0
COAL
BITUMINOUS
27912.
15.00
3.70
***•*•*»
WET SCRUBBING
LIME
BABCOCK t W1LCOX
NEW
( 12000 BTU/LB)
3/79
3/79
90.00
99.55
.0
.0
CLOSED
(.*.*• GPM)
. PERFORMANCE DATA — " ——— ———.__.
»E»IOO MODULE AVAILABILITY OPERABILIT* RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/60 SYSTEM
2/80 SYSTE"
3/80 SYSTE"
** PROBLEMS/SOLUTIONS/COMMENTS
74*
690
7*4
NO INFORMATION WAS AVAILABLE ON THE OPERATIONS AT PLEASANTS 1 FOR THE
FIRST QUARTER OF 198C.
SYSTE* 720
5/80 SYSTEM 7*4
S/6? SYSTEM 720
t* PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS UNAVAILABLE FOR THE SECOND QUARTER 1980 REPORT PERIOD.
7/80 SYSTEM 7*4
S/80 SYSTEM 7*4
J/8P SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE MONTHS OF AUGUST AND SEPTEMBER IS NOT AVAILABLE AT
THIS TIME.
138
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
*ONONG»HELA POWER: PLEASANTS 1 (CONT.)
... PERFORMANCE DATA
ȣRIOO NODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION * RtKOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
AN EIGHT WEEK BOILER AND FGD SYSTEM SCHEDULED OUTAGE BEGAN DURING THE WEEK
OF AUGUST 11. THE FGD SVSTEH MAS EXPECTED TO BE DOWN FOR 8-12 WEEKS.
139
-------
£PA JTHITY fGO SURVEY: JULY - SEPTEMBER 19RC
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
NAME
PLANT NAME
JNIT XU»3ER
CITY
STATE
3HOSS IWT GENERATING CAPACITY - MW
NET JNIT GENERATING CAPACITY W/FGD -
EOUIVALENT SCRUBBED CAPACITY - "fc
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
MONTANA POWER
COLSTRIP
1
COLSTRIP
"ION TANA
360.0
332.0
I6P.D
COAL
SUB6ITUMINOUS
20569.
9.60
2*.90
.77
.01
< ?843 BTU/LB)
•• GENERAL EMISSION CONTROL SYSTEM DATA
4ENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COM»ERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
A9SORBER SPARE COMPONENTS INDEX
- X
WET SCRUBBING
LIME/ALKALINE FLYASH
COMBUSTION EBUIP ASSOCIATES
NEW
3.3
9/75
11/75
60.00
99.50
20.0
.5
•* WATER LOOP
TYPF
FRtSH MAKE-UP WATER - LITER/S
CLOSED
23.3
( 370 6PH)
•• DISPOSAL
TYPE
POND
PERFORMANCE DATA
»ERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER FED CAP
S02 PART. HOURS HOURS HOURS FACTOR
12/79 SYSTEM
1/80 SYSTEM
Z/80 SYSTEM
3/SO SYSTEM
95.9
96.5
97.4
95.4
744
744
696
744
PROBLEMS/SOLUTIONS/COMMENTS
TOTAL SYSTEM AVAILABILITY CONTINUES TO BE HIGH WITH NO MAJOR F&D SYSTEM
PROBLEMS REPORTED DURING THE FIRST QUARTER OF 1980.
W6C SYSTEM 99.8
•» PROBLEMS/SOLUTIONS/COMMENTS
720
MO MAJOR PROBLEMS WITH THE F6D SYSTEM WERE REPORTED BY THE UTILITY DURING
APRIL.
5/80 SYSTEM
•» PROBLEMS/SOLUTIONS/COMMENTS
744
6/80 SYSTEM
NO AVAILABILITY DATA HERE REPORTED BY THE UTILITY BECAUSE OF A SCHEDULED
BOILER AND FGO SYSTEM OUTAGE FOR ROUTINE MAINTENANCE.
720
140
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
ONTANA POWER: COLSTRIP 1 (CONT.)
. -PERFORMANCE OAT*
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
PERFORMANCE INFORMATION FOR THE MONTH OF JUNE HAS NOT AVAILABLE.
7/80 SYSTEM 74*
S/80 SYSTEM 7*4
9/60 SYSTEM 720
•• PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE THIRD QUARTER OF 1980 HAS NOT AVAILABLE.
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
YET UNIT GENERATING CAPACITY W/FGD - MU
EBUIVALENT SCRUBBED CAPACITY - MW
MONTANA POWER
COLSTRIP
2
COLSTRIP
MONTANA
360.0
332.0
360.0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - *
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
A3SORBER SPARE COMPONENTS INDEX
- X
COAL
SUBBITUMINOUS
20569. ( 8843 BTU/LB)
a.60
23.90
.77
.01
WET SCRUBBING
LINE/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
NEW
3.3
5/76
10/76
60.00
99.50
20.0
.5
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
23.3
( 370 6PM
•* DISPOSAL
TYPE
POND
.. fc PERFORMANCE DATA ———>-..-._..
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79
1/80
2/6P
5/60
SYSTEM
SYSTEM
SYSTEM
SYSTEM
95.8
92.7
98. 1
9B.2
744
744
696
744
PROBLEMS/SOLUTIONS/COMMENTS
TOTAL FGD SYSTEM AVAILABILITY CONTINUES TO BE HI6H WITH NO MAJOR PROBLEMS
REPORTED FOR THE FIRST QUARTER OF 1980.
t/80 SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
720
NO AVAILABILITY DATA WERE REPORTED BY THE UTILITY BECAMSE OF A BOILER AND
FGD SYSTEM OUTAGE THAT WAS SCHEDULED FOR ROUTINE MAINTENANCE.
5/80 SYSTEM 93.5
«• PROBLEMS/SOLUTIONS/COMMENTS
744
NO MAJOR PROBLEMS WITH THE F6D SYSTEM WERE REPORTED BY THE UTILITY DURING
MAY.
S/8C1 SYSTEM
720
142
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
ONTANA POWER: COLSTRIP 2 (COM.)
1. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
*• PROBLEWSfSOlUTIONS/COMMENTS
PERFORMANCE INFORMATION FOR THE MONTH OF JUNE WAS NOT AVAILABLE.
7/80 SYSTEM 744
3/80 SYSTEM 744
j/80 SYSTEM 720
•* PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE THIRD QUARTER OF 1980 WAS NOT AVAILABLE.
143
-------
EPA JTILITY FGD SURVEY: JULY - SEPTEMBER 19?C
SECTION 3
DESIGN »N£> PERFOR"ANCE CATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
NAME
PLANT
JIIJT
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MH
NET U1IT GENERATING CAPACITY y/FGD - M*
EQUIVALENT SCRUBBED CAPACITY - »W
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE MEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFU" CONTENT - X
AVERAGE CHLORIDE CONTENT - T
•• GENERAL EMISSION CONTROL SYSTEM CATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A9SORBE* SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• DISPOSAL
TYPE
NEVADA POyER
REID GARDNER
1
MOAPA
NEVADA,
125.0
110.0
125.0
COAL
BITUMINOUS
28959.
8.00
5.50
.50
.05
WET SCRUBBING
SODIUM CARBONATE
COMBUSTION EfiUIP ASSOCIATES
RETROFIT
( 12*50 BTU/LB)
3/74
4/74
90.00
X 97.00
.0
.0
CLOSED
9.8
LINED POND
( 155 6PM)
PERFORMANCE DATA — _——. _
PERIorMoi)iJLF~AVAILABILITY QPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 100.0 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
10C.O
100.0
744 744 744
THE BOILER AND FGD SYSTEM OPERATED THE ENTIRE MONTH WITH NO OUTAGES.
2/BO SYSTEM 100.0 1QO.O 100.C 100.0 696 696 696
•• PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY, NO OUTAGES OCCURRED.
i/80 SYSTEM 93.8 83.3 84.4 33.6 744 300 250
«• PROBLEMS/SOLUTICm/COMMENTS
DURING THE FIRST OF MARCH THE F6D SYSTEM WAS OFF LINE FOR A SCHEDULED
OVERHAUL.
THE fGD UNIT WAS FORCED OUT OF SERVICE ONCE 10 REPAIR THE VENTURI PUMP
AND SIX OTHER TIMES DUE TO LOW VENTURI FLOW.
4/80 SYSTEM 97.3 96.4
•• PROBLEMS/SOLUTIONS/COMMENTS
96.8
82.7
720 618 596
LEAKS IN THE VENTURI LINE FORCED THE FGD SYSTEM OUT OF SERICE TWICE
DURING APRIL.
144
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
HEVAOA POWER: REID 6ARDNER 1 (CONT.)
. _ — PERFORMANCE 6ATA .——
PERIOD MODULE AVAILABILITY OPtRABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FG6 CAP.
SO? PART. HOURS HOURS HOURS FACTOR
A THERMOCOUPLE SHORTED OUT DUE TO HIGH VENTURI GAS OUTLET TEMPERATURES.
THIS FORCED THE FGD SYSTEM OUT OF SERVICE FOR SEVERAL HOURS.
THE BOILER WAS OUT OF SERVICE FOR 11? HOURS DUE TO BOILER TUBE LEAKS.
5/80 SYSTEM 97.7 93.9 97.4 84.7 7*4 672 630
•• PROBLEMS/SOLUTIONS/COMKENTS
THE FGD SYSTEM WAS DOUN THREE TIMES IN MAY BECAUSE OF LOU FLOW THROUGH THE
VENTURI.
A BOILER TRIP CAUSED THE FGD SYSTEM TO BE OUT APPROXIMATELY 97 HOURS.
6/80 SYSTEM 92.1 92.7 92.7 88.3 720 686 636
*» PROBLEMS/SOLUTIONS/COMMENTS
THE NOZZLES IN THE VENTURI RACE TRACK HAD TO BE CLEANED SEVERAL TIMES THIS
MONTH. TOTAL OUTAGE FOR THIS WAS APPROXIMATELY 48 HOURS.
THE FGD SYSTEM WAS FORCED OUT OF SERVICE WHEN THE EMERGENCY SPRAY SYSTEM
FAILED.
THE FGD SYSTEM WAS OUT OF SERVICE TWICE DURING JUNE DUE TO BOILER OUTAGES.
7/80 SYSTEM 87.1 94.9 86.7 84.0 744 658 625
*• PROBLtMS/SOLUTlONS/COMMENTS
THE FGD SYSTEM WAS RETURNED TO SERVICE ON JULY 3, 1980 AFTER THE BOILER
TRIPPED THE SYSTEM OFF LINE. THE GUILLOTINE DAMPER HAD TO BE REPAIRED
BEFORE THE FGD SYSTEM COULD RETURN TO SERVICE.
THE FGO SYSTEM WAS OFF LINE FOR SEVERAL HOURS TO UNPLUG THE VENTURI TRAY
AND RACETRACK. MAINTENANCE MORK WAS ALSO DONE ON THE VENTURI LINE.
A SCHEDULED BOILER OUTAGE CAUSED THE FGD SYSTEM TO BE OFF LINE FOR ONE
DAY.
THE FGD SYSTEM WAS FORCED OUT OF SERVICE WHEN THE EMERGENCY SPRAY SYSTEM
FAILED. THE ASH SLUICE PUMP SHAFT WAS REPAIRED DURING THIS TIME.
8/80 SYSTEM 86.1 85.5 83.7 71.5 744 622 532
*» PR08LEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM HAS OUT OF SERVICE FOR ALMOST 60 HOURS FOR ROUTINE CLEANING
AND MAINTENANCE.
LOSS OF EMERGENCY SPRAY KEPT THE FGD SYSTEM OFF LINE FOR SEVERAL HOURS.
BOILER RELATED OUTAGES CAUSED THE FGD SYSTEM NOT TO OPERATE FOR OVER 10C
HOURS.
THE TRAY SPRAY PUMP BELTS WERE REPAIRED.
A DAMPER THAT FAILED TO CLOSE TRIPPED THE FGD SYSTEM OFF LINE DURING THE
MONTH.
>/80 SYSTEM 91.3 91.0 91.1 89.6 72C 709 645
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGO SYSTEM WENT OFf LINE SEVERAL TIMES IN SEPTEMBER FOR ROUTINE CLEAN-
ING AND MAINTENANCE. THIS ROUTINE WORK INCLUDED CLEANING THE TRAYS AND
REPAIRING VENTURI, ASH. AND EFFLUENT LINES.
U5
-------
EPA JTUITT F60 SURVET: JUL» - SEPTEMBER 1980
NEVADA POKER: REID GARDNER 1 (CONT.)
...———-—__————.——. ——.-PERFORMANCE DATA——— ——— -.————.—_.__._
PERIOD MODULE AVAILABILITY OPERABILITr RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
A BOILER OUTA6E KEPT THE FGD SYSTEM OFF LINE FOR SEVERAL HOURS.
1*6
-------
cru uiiLlTY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 5
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F60 SYSTEMS
COMPANY NAME
PLANT NANE
JNIT NUK3ER
CITY
STATE
5ROSS UNIT 6ENERAT1N6 CAPACITY - MW
»ET UNIT GENERATING CAPACITY W/F6D - MU
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DAT*
FUEL TYPE
FUtL GfUOE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTEXT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETKOFIT
ENERGY CONSUMPTION - X
1HIT1AL START-UP DATE
COMMERCIAL START-UP DATE
S32 DESIGN REMOVAL EFFICIENCY - X
PJRTICULATE DESIGN REMOVAL EFFICIENCY
A3SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
NEVADA POWER
REID GARDNER
2
MOAPA
NEVADA
125.0
110.0
125.0
COAL
BITUMINOUS
28S59.
8.00
5.50
.50
.05
WET SCRUBBING
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
RETROFIT
( 12450 6TU/LB)
4/74
**/ **
90.00
X 97.00
.3
.0
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER'S
CLOSED
9.8
C 155 GPM)
* DISPOSAL
TYPE
LINED POND
.,_-— — — — — —— — PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION T REMOVAL PER BOILER FGC CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 97.4 9*.5
*• PROBLEMS/SOLUTIONS/COHMENTS
96.9
81.6
744
642
607
DURING JANUARY THE SCRUBBER WENT OFF LINE WITH THE BOILER TO REPLACE THE
REBUILT BOILER HIGH PRESSURE HEATER. THIS OUTAGE LASTED APPROXIMATELY
112 HOURS.
REPAIRS MERE NEEDED ON THE LEFT HAND INTERCEPT VALVE ON THE TURBINE CAUSING
THE SCRUBBER TO COME OFF LINE WITH THE BOILER.
THE CLEANING OF THE VENTURI RACE TRACK NOZZLES CAUSED TWO SCRUBBER OUTAGES.
THE SCRUBBER WENT OFF LINE SO MAINTENANCE COULD BE PERFORMED ON THE ID
FAN DAMPER CONTROLS.
Z/80 SYSTEM 96.9 96.9
•• PROBLEMS/SOLUTIONS/COMMENTS
96.9
96.9
696 696
675
THE SCRUBBER WAS TAKEN OFF-LINE TWICE 6URIN6 FEBRUARY DUE TO A MALFUNCTION
OF THE ID FAN CONTROLS. THE PRESSURE SENSING LINES WERE ALSO CLEANED
DURING THE OUTAGE.
THE SCRUBBER RACE TRACK NOZZLES HAD TO BE CLEANED TWICEt CAUSING APPROX-
IMATELY 4 HOURS OUTAGE TIME.
THE DISCHARGE VALVE ON THE VENTURI RECYCLE PUMP WAS REPLACED DURING
FEBRUARY.
147
-------
EPA t/MLITy fGt> SURVEY: JULY - SEP7EHPEP
NEVADA POrfER: REID GARDNER 2 (CONT.)
PERFORMANCE DATA —_
»E9IOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
REPAIRS MERE «IAD£ ON THE SCRUBBER EMERGENCY SPRAY LINE CAUSING ABOUT 4
HOURS OUTAGE TIME.
THE SCRUBBER HAD TO BE SHUT DOWN SO REPAIRS ON THE ID FAN DAMPER CONTROLS
COULD BE 1ADE.
3/80 SYSTE* 98.4 97.5 97.5 97.5 7*4 74* 725
** PROBLEMS/SOLUT IONS/COMMENTS
DURING MARCH THE SCRUBBER WAS TAKEN OFF LINE DUE TO THE UNAVAILABILITY OF
THE EMERGENCY SPRAY SYSTEM. DURING THIS TIME MAINTENANCE WAS DONE ON THE
A AND B ASH SLUICE PUMPS.
LATER IN THE MONTH AN OUTAGE WAS CAUSED BY A LEAK IN THE EMERGENCY SPRAY
LINE.
LOW VENTURI FLOW ALSO WAS A PROBLEM DURING MARCH.
4/80 SYSTEM 99.0 99.0 99.0 93.5 720 680 673
*• PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS UNAVAILABLE FOR 7 HOURS TO UNPLUG THE VENTURI RACE
TRACK.
THE BOILER WAS OUT OF SERVICE FOR *0 HOURS DUE TO BOILER TUBE LEAKS.
5/80 SYSTE* 100.0 8*.3 .0 14.3 7*4 124 107
«* PROBLEMS/SOLUTIONS/COMMENTS
THE FGD OVERHAUL WAS COMPLETED EARLY IN MAY.
A BOILER OVERHAUL WAS STARTED AND COMPLETED DURING MAY. THIS OUTAGE LASTFtt
ALMOST 23 DAYS. '"
S/80 SYSTE- 99.6 97.5 9'-5 ".* '20 5*1 5Z8
•• PR08LEMS/SOLUTIOYS/COMMENTS
THE BOILER WAS OUT OF SERVICE SEVERAL TIMES. DURING JUNE. THIS CAUSED THE
FGD SYSTEM TO BE OUT APPROXIMATELY 80 HOURS.
VENTURI RACE TRACK NOZZLES NEEDED TO BE UNPLUGGED CAUSING THE FGD SYSTEM
OUT OF SERVICE FOR SEVERAL HOURS.
7/80 SYSTEM 88.1 77.2 86.2 74.5 7*4 718 55*
** PROBLEMS/SOLUTIONS/COMMENTS
BOILER RELATED OUTAGES KEPT THE FGD SYSTEM OUT OF SERVICE FOR OVER 100
HOURS DURING JUNE. OVER HALF OF THIS OUTAGE TIME WAS A RESULT OF CONTROL
PROBLEMS WITH THE BOILER AND FGD SYSTEM. THE BOILER WAS RUN WITHOUT THE
FGO SYSTEM IN ORDER TO DETERMINE IF THE CONTROL PROBLEMS HERE FGD OR BOILER
RELATED. PROBLEMS WERE REPAIRED IN BOTH CONTROL SYSTEMS. THIS ALSO CAUSED
OVER 60 HOURS OF FGD SYSTEM RELATED DOWN TIME.
PROBLEMS WITH THE BOTTOM HOPPER SEALS CAUSED THE FGD SYSTEM TO GO DOWN.
THE FGD SYSTEM NEEDED TO BE OFF LINE FOR 1} HOURS FOR INSTRUMENT CHECKS
AND MAINTENANCE.
THE FGD SYSTEM WAS FORCED OUT OF SERVICE WHEN THE EMERGENCY SPRAY SYSTEM
FAILED. THE ASH SLUICE PUMP SHAFT WAS REPAIRED DURING THIS TIME.
S/80 SYSTEM 97.0 96.S 96.4 79.7 744 613 591
U8
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
1EVADA POJER: REID GARDNER 2 (CONT.)
PERFORMANCE DATA
•ER10D MODULE AVULAB1L1TY OPERABILITV RELIABILITY UTILIZATION X R&KOVAL PER BOILER FSB CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLE«tS/SOLUTIONS/COni"ENTS
LOSS OF EMERGENCY SPRAY KEPT THE F6D SYSTEM OFF LINE FOR ALMOST 20 HOURS.
BOILER RELATED OUTAGES CAUSED THE FGD SYSTEM NOT TO OPERATE FOR OVER 130
HOURS.
9/EO SYSTEM 100.0 .0 720 D 0
•* PROBLEIS/SOLUTIONS/CCmWENTS
THE FGD SYSTE* WAS 1COX AVAILABLE DURING A SCHEDULED BOILER OVERHAUL IN
SEPTEMBER.
149
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19«0
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY MAKE
PLANT NAME
U«IT NUMBER
CITY
STATE
SUOSS UNIT GENERATING CAPACITY - My
«ET UNIT GENERATING CAPACITY W/FGD - Mw
EflUIVALENT SCRUBBED CAPACITY - MW
•» FUEL DATA
fUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*» GENERAL EMISSION CONTROL SYSTEM DATA
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ASSOR8ER SPARE COMPONENTS INDEX
»• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
- X
( 12450 BTU/LB)
NEVADA PQyER
REID GARDNER
3
MOAPA
NEVADA
125.0
110. 3
125.0
COAL
BITUMINOUS
28959.
8.90
9.00
.SO
.05
WET SCRUBBING
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
NEW
*******
6/76
7/76
85.00
99.00
.0
.0
CLOSED
9.8
LINED POND
( 155 6PM)
.. — PERFORMANCE DATA
»ERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG» CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/BO
SYSTEM 1DO.O 99.8
*• PROBLEMS/SOLUTIONS/COHMENTS
100.0
91.4
744
681
680
DURING JANUARY THE SCRUBBER AND BOILER WERE OFF LINE FOR APPROXIMATELY
64 HOURS TO REPAIR AND BALANCE THE BOILER ID FAN.
2/6?
SYSTEM 1CO.O 9P.1
•* PROBLEMS/SOLUTIONS/COMMENTS
10C.C
77.9
696
552
542
DURING FEBRUARY TWO OUTAGES WERE NECESSARY SO THE ID FAN COULD BE BALANCED.
THE SCRUBBER AND BOILER WENT OFF LINE SO THAT THE COAL LEAKS ON THE
BURNER LINES COULD BE REPAIRED.
HIGH FURNACE PRESSURE CAUSED THE SCRUBBER AND BOILER TO TRIP OFF.
S/8P SYSTE" 100.0 99.6 10".0 60.3 744 450 448
•• PROBLE1S/SOLUTIONS/COHMENTS
THE UNIT AND SCRUBBER WENT DOWN TWICE DURING MARCH. THE FIRST OUTAGE WAS
TO BALANCE THE ID FAN. LATER IN THE MONTH THE ID FANS AND THE
PRECIPITATORS HAD TO BE REPAIRED.
4/8C SYSTEM
100. il
.0
720
150
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
POrfER: REID GARDNER 3 (COM.)
...... . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERARILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER EGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEIS/SOLUTIONS/COMNENTS
THE FGD SYSTEI" WAS AVAILABLE 10CX DURING APRIL, HOWEVER, DID NOT OPERATE
DUE TO THE OVERHAUL OF BOTH THE DUST COLLECTOR AND THE ID FAN.
5/80 SYSTEM .0 .0 .0 .0 74* 462 0
*• PROBLEHS/SOLUTIOHS/COHHENTS
THE FGD SYSTEM WAS DOWN THE ENTIRE MONTH FOR THE OVERHAUL OF THE FGD ID
FANS. BECAUSE OF THIS, THE SYSTEM AVAILABILITY WAS ZERO FOR MAY.
i/80 SYSTEM 75.2 81.4 81.4 72.2 720 639 520
*• PR03LE1S/SOLUTIONS/COM-ENTS
THE ID FAN OVERHAUL WAS COMPLETED EARLY IN JUNE.
THE BOILER WAS OUT OF SERVICE FOR 21 HOURS.
7/80 SYSTEM 95.7 96.4 95.7 95.2 744 735 721
** PROBLE^S/SOLUTIONS/COMHENTS
BOILER RELATED OUTAGES KEPT THE FGD SYSTEM OFF LINE FOR SEVERAL HOURS.
A HIGH VENTURl OUTLET TEMPERATURE FORCED THE FGD SYSTEM OFF LINE DURING
PART OF JULT.
A HIGH VENTURI OUTLET TEMPERATURE FORCED THE FGD SYSTEM OFF LINE DURING
3/80 SYSTEM 103.0 10P.O 101.0 100.0 744 744 744
*• PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE DURING ALL OF AUGUST.
9/gO SYSTEM 96.S 96.8 96.8 96.8 720 720 697
«* PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OUT OF SERVICE IN SEPTEMBER BECAUSE OF ROUTINE CLEANING
AND MAINTENANCE.
151
-------
EPA JT1LITY FGO SURVEY: JULY - SEPTEMBER 1VC
SECTION 3
DESIGN AND PERFORMANCE DATA TOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAWE
PLANT NAIE
JNIT NU"3ER
CITY
STATE
JROSS UNIT GENERATING CAPACITY - Mw
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ORTHERN INDIANA PUB SFRVICE: DEAN H. MITCHELL 11 (CONT.)
.. PERFORMANCE DATA
»ERIOO MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION J REMOVAL PER BOILER f6tt CAP.
SO? PART. HOURS HOURS HOURS FACTOR
3/8^ SYSTEM 75.4 20.4 24.9 U.5 744 529 108
•* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS OPERATIONAL ON MARCH 1 AFTER THE HYDROGEN LEAKS WERE
REPAIRED. THE BOILER WAS DOHN FROM MARCH 18 TO 23 SO THAT THE TURBINE
STOP VALVES COULD BE PULLED AND THE HYDROGE.N SEALS COULD BE INSPECTED.
THE FGD SYSTEM WAS FORCED OUT OF SERVICE WHEN A COMPRESSOR FAILED AND
AGAIN LATER AFTER AN INSTRUMENT MALFUNCTION. THERE WAS A COMPLETE POWER
IN THE FGD AREA WHICH FORCED THE SYSTEM DOHN FROM MARCH 26 THROUGH 27.
4/8? SYSTEM 63.3 52.6 53.4 50.3 720 702 362
«* PROBLEMS/SOLUTIONS/CONMENTS
FGD SYSTEM OPERATIONS DURING APRIL WERE INTERRUPTED BY SULFUR ACCUMULA-
TION AND BLOCKAGE IN THE CLAUS CONVERTER UNIT.
5/80 SYSTEM 62.B 23.5 26.4 15.5 744 490 115
«* PR08LEMS/SOLUTIONS/COMMENTS
THE FGO SYSTtM REGENERATION FACILITY EXPERIENCED A DRIVE MOTOR FAILURE ON
THE EVAPORATOR CIRCULATING PUMP DURING MAY.
<>/80 SYSTEM 53.7 .0 .0 .0 720 211 0
** PRD3LE*S/SOLUTIOKS/COMMENTS
THE BOILER WAS OFF LINE MOST OF JUNE DUE TO LOW SYSTEM POWER DEMAND.
THE AVAILABILITY OF THE FGD SYSTEM WAS LIMITED BY PROBLEMS WITH THE
BOOSTER BLOWER DRIVE AND LOOSENING OF A SUPPORT BEAM IN THE ABSORBER.
7/3° SYSTEM 103.C .0 .0 744 331 0
** PH09LtMS/SOLUTIONS/COM«EHTS
THE BOILER OPERATED ON LOW SULFUR COAL DURING JULY. THE BOILER WAS OFF
LINE FOR APPROXIMATELY 17 DAYS DUE TO LOW SYSTEM POWER DEMAND.
J/6T SYSTEM 83.9 65.6 65.6 31.0 744 352 251
*• PROBLEMS/SOLUIIONS/COM«ENTS
FROM AUGUST 1 TO AUGUST 13 THE BOILER FIRED LOW SULFUR COAL OR WAS
OPERATED AT LOW LOAD. FGD SYSTEM OPERATION W«S NOT NECESSARY DURING THIS
TIME.
FROM AUGUST 14 TO AUGUST 31, HIGH SULFUR COAL WAS FIRED MAKING FGD
SYSTE* OPERATION NECESSARY. PROBLEMS WITH THE BOOSTER BLOWER WERE
ENCOUNTERED »HEN THE UTILITY ATTEMPTED TO BRING THE SYSTEM ON LINE. THE
BLOWER EXPERIENCED LOW OIL PRESSURE CAUSING THE SYSTEM NOT TO BE OPERABLE
UNTIL AUGUST 19.
>/80 SYSTEM 68.6 5?.1 55.1 45.1 720 612 325
•• PROBLE«S/SOLUTIONS/COMMENTS
THE BOOSTER BLOWER REARING AND GOVERNOR REPAIRS ACCOUNTED FOR SOME OUTAGE
TIME DURING SEPTEMBER.
THE SULFUR CONDFNSERS IN THE S02 REDUCTION UNIT WERE AN ADDITIONAL PROBLEM
DURING SEPTEMBER.
153
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUM3ER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - *W
VET UNIT GENERATING CAPACITY W/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - MW
NORTHERN STATES POWER
SHERBURNE
1
BECKER
MINNESOTA
740.0
700.0
740.0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
P*RTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
COAL
SUBBITUMINOUS
19771. < 8500 BTU/Ld)
9.00
25.00
.80
.03
UET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
3/76
5/76
50.00
99.00
9.0
1.0
*• HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
CLOSED
*******
(****.* GPM)
•• TREATMENT
TYPE
FORCED OXIDATION
•• DISPOSAL
TYPE
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
SO? PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/81 SYSTEM
3/80 SYSTEM
97.0
97.0
98.0
74*
696
744
793
687
688
** PROBLEMS/SOLUTIONS/CONMENTS
9C.8
66.2
84.1
DURING THE FIRST QUARTER OF 1980 NO MAJOR PROBLEMS HERE ENCOUNTERED WITH
THE FGD SYSTEM.
WBO SYSTEM
S/BO SYSTEM
6/80 SYSTEM
97.0
96.0
96.0
FROM MID-SEPTEMBER TO MID-OCTOBER THE UTILITY HAS SCHEDULED A BOILER
OUTAGE AT WHICH TIME THE MARBLE BEDS WILL BE INSPECTED.
THE UTILITY HAS DECIDED TO CONVERT THE ENTIRE MARBLE BED SCRUBBING SYSTEM
TO A SPRAY TOWER SYSTEM BY REMOVING THE MARBLE BEDS AND MODIFYING THE SPRAY
ARRANGEMENT. TESTS CONDUCTED IN 1978 AND 1979 SHOW THAT MOST OF THE S02
IS COLLECTED IN THE VENTURI SECTION OF THE SCRUBBING TRAINS AND THAT
ALTHOUGH THE HARBLE BEDS IN THE ABSORBER SECTIONS IMPROVE INTIMATE S02/
SLURRY MIXING S02 REMOVAL EFFICIENCY OF THE SCRUBBING TRAINS IS NOT
MARKEDLY DIFFERENT WHEN MARBLE BEDS ARE REMOVED.
720
744
720
720
720
697
79.4
78.1
74.7
154
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
*JRTH£RN STATES POWER: SHERBURNE 1 (CONT.)
... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITT RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
«• PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED DURING THE SECOND ftUARTER
OF 1980.
7/81 SYSTE" 100.0 1CP.O 100.0 100.0 744 744 744 8?.1
** PROBLEMS/SOLUTIONS/COM-ENTS
NO OPERATIONAL PROBLEMS WERE ENCOUNTERED IN JULY.
3/80 SYSTEM 100.0 1CO.O 100.0 99.2 744 738 738 69.1
«* PROBLEMS/SOLUTIONS/COMMENTS
THERE WERE TWO SHORT TERM OUTAGES IN JULY DUE TO BOILER RELATED TRIPS.
J/bC SYSTE" 100.0 100.0 100.0 99.6 720 717 717 76.8
»* PROBLEMS/SOLUTIONS/COMMENTS
A BOILER RELATED PROBLEM CAUSED THE ONLY OUTAGE TIME IN SEPTEMBER.
155
-------
E»A JTILITY FGD SURVEY: JULY - SEPTEMBER 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
CONPANY NAME
PLANT NAME
J1IT YLH3ER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
»ET UNIT GENERATING CAPACITY W/FGD -
EBUIW«LF.WT SCRUBBED CAPACITY - PW
NORTHERN STATES POWER
SHERBURNE
2
BECKER
MINNESOTA
7*0.0
700.0
740.0
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DFSIGN REMOVAL EFFICIENCY
A9SORBEP SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
- X
COAL
SUBBITUMINOUS
19771. < 85CC BTU/LB)
9.00
as.oo
.80
.03
WET SCRUBBING
LIMESTONE/ALKALINE flYASH
COMBUSTION ENGINEERING
NEW
2.7
3/77
4/77
50.00
99.00
9.0
1.0
OPEN
(*•**• GPM)
•• TREATMENT
TYPE
»• DISPOSAL
TYPE
FORCED OXIDATION
LINED POND
.. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1L1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER
S02 PART. HOURS HOURS
FGO CAP.
HOURS FACTOR
1/80 SYSTEM
2/8C SYSTE"
J/80 SYSTE"
97.0
96.0
98.0
7*4 744
696 696
744 744
** PROBLEMS/SOLUTI01S/COMMENTS
91.8
91.9
DURING THE FIRST QUARTER OF 1980 THE FGO SYSTEM EXPERIENCED NO MAJOR
PROBLEMS.
A FOUR WEEK BOILER OUTAGE IS SCHEDULED FOR MAY AT WHICH TIME THE MARBLE
BEDS WILL BE REMOVED FROM THE FGD SYSTEM.
4/80 SYSTEM
96.0
THE UTILITY HAS DECIDED TO CONVERT THE ENTIRE MARBLE BED SCRUBBING SYSTEM
TO A SPPAY TOWER SYSTEM BY REMOVING THE MARBLE BEDS AND MODIFYING THE SPRAY
ARRANGEMENT. TESTS CONDUCTED AT UNIT 1 IN 1978 AND 1979 SHOW THAT HOST OF
THE SOZ IS COLLECTED IN THE VENTURI SECTION OF THE SCRUBBING TRAINS AND
THAT ALTHOUGH THE MARBLE BEDS IN THE ABSORBER SECTIONS IMPROVE INTIMATE
SD2/SLURRY MIXING S02 REMOVAL EFFICIENCY OF THE SCRUBBING TRAINS IS N01
MARKEDLY DIFFERENT WHCN MARBLE REDS ARE REMOVED.
720 704
6P.6
156
-------
EPA UTILITY rGO SURVEY: JULY - SEPTEMBER 1980
NORTHERN STATES POWER: SHERBURNE 2 CCONT.)
... PERFORMANCE DATA ~———— ——————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION S REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•* PROBLENS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS HERE ENCOUNTERED IN APRIL.
5/80 SYSTEM 96.0 744 214 2*.2
6/80 SYSTEM 100.0 720 SI 2.8
*• PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM HAS OUT OF SERIVE HOST OF HAY AND JUNE BECAUSE OF THE ANNUAL
BOILER AND TURBINE INSPECTION.
7/80 SYSTEM 100.0 100.0 100.0 82.7 744 615 615 63.8
** PROBLEMS/SOLUTIONS/COMMENTS
BOILER TUBE LEAKS CAUSED THE BOILER NOT TO OPERATE FOR 73 HOURS IN JULY.
BOTTOM ASH PLUGGING ALSO FORCED THE BOILER DOWN FOR 56 HOURS.
8/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 70.7
7/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 100.0
** PROBLEMS/SOLUTIONS/COMttENTS
THE BOILER AND FGD SYSTEM RAN CONTINUOUSLY THROUGH AUGUST AND SEPTEMBER
WITHOUT ANY PROBLEMS.
157
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FED SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MM
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SD2 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - .«
ABSORBER SPARE COMPONENTS INDEX
*• HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*• DISPOSAL
TYPE
PACIFIC POWER f
JIM BRIDGER
4
ROCK SPRINGS
WYOMING
550.0
507.8
550.0
LIGHT
( 9300 BTU/LB)
COAL
SUBBITUMINOUS
21632.
9.00
18.00
.56
.01
WET SCRUBBING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
NEW
.2
9/79
2/80
91.00
99.00
.0
.0
CLOSED
*******
LINED POND
(•**** 6PM)
...._.__,._—___-_._— .....—...... —PERFORMANCE DATA——
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
5/80 SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
1/80
744
696
744
THE UNIT IS STILL IN THE SHAKEDOWN PHASE OF OPERATIONS. A NUMBER OF
MECHANICAL PROBLEMS AND SOME CONTROL PROBLEMS HAVE BEEN ENCOUNTERED.
NO PROCESS-RELATED PROBLEMS HAVE OCCURRED.
41
42
45
SYSTEM
27.5
24.0
26.6
26.0
18.4
23.9
34.0
25.4
22.3
26.3
34.2
27.6
14.2
18.4
26.1
19.6
720 553
141
PROBLEMS/SOLUTIONS/COMMENTS
ALL THREE MODULES WERE OUT OF SERVICE THE FIRST 21 DAYS OF APRIL WHILE THE
UTILITY WAITED FOR DELIVERY OF NEW .SPRAY NOZZLES. SOME PLUGGING HAD OCCUR-
RED IN THE ORIGINAL NOZZLES. THE NEW NOZZLES HERE INSTALLED FOR TESTING
PURPOSES.
5/80 41
42
43
SYSTEM
95.2
72.4
100.0
89.2
46.0
75.1
81.6
67.6
9?.6
71.7
100.0
88.1
42.9
70.1
76.1
63.0
744 694
469
158
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
PACIFIC POWER K LIGHT: JIM BRIDGER 4 (CONT.)
_„___„_„--_-——_—-- — —------—----PERFORMANCE DATA——~————.-_.—————
PERIOD MODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COMNENTS
NODULE 42 WAS FORCED OUT OF SERVICE FOR EIGHT DAYS IN MAY WHILE A VORTEX
BREAKER WAS INSTALLED IN THE ABSORBER VESSEL. THE VESSEL HAS DRAINING
BEFORE REACHING DESIGN FLUID LEVELS.
VORTEX BREAKERS WERE INSTALLED IN MODULES 41 AND 43 AS WELL BUT INSTALLA-
TION IN THESE MODULES WAS NOT UNDERTAKEN DURING PERIODS WHEN MODULE SERVICE
WAS REQUIRED.
41 81.2 77.7 66.5 30.9
42 89.2 100.0 85.1 43.2
41 86.0 75.0 73.6 29.8
SYSTEM 85.5 87.1 75.4 34.6 744 296 258
** PROBLENS/SOLUUONS/COMMENTS
THE FGD SYSTEM WAS DOWN FOR 5 DAYS TO REPAIR A RECIRCULATION PUMP BREAKER
ON MODULE 41.
MODULES 41 AND 42 WERE UNAVAILABLE FOR A COMBINED TOTAL OF 6 DAYS DUE TO
THE REPLACING OF THE PH CONTROL PIPING.
7/80 41 97.3 67.2 96.0 64.8
42 97.4 91.2 97.1 87.8
4! 99.4 90.2 99.3 86.9
SYSTEM 98.0 82.9 97.6 79.8 744 717 594
*• PflOBLEHS/SOLUTIONS/COMMEMTS
NO MAJOR F6D-RELATED PROBLEMS WERE ENCOUNTERED IN JULY.
j/80 41 99.7 92.8 99.7 86.1
42 94.1 92.3 93.6 85.6
43 94.7 68.4 92.4 63.5
SYSTEM 96.2 84.5 95.2 78.4 744 690 583
•* PROBLtMS/SOLUTIONS/COMMENTS
NO FGD RELATED PROBLEMS HERE REPORTED FOR THE MONTH OF AUGUST.
J/80 SYSTEM 720
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR SEPTEMBER 1980.
159
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIEN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
J1IT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
MET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEM/RETROFIT
ENERCY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
• * WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• TREATMENT
TYPE
** DISPOSAL
TYPE
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPPINGPORT
PENNSYLVANIA
917.0
825.0
917.0
COAL
BITUMINOUS
26749.
12.90
7.00
3.00
< 11500 BTU/LB)
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
NEW
6.0
12/75
6/76
92.10
99.80
.0
.0
OPEN
CALCILOX
LANDFILL
(***«* 6PM)
———————————— ———PERFORMANCE DATA ——___
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 98.6 100.0 90.4 744 672 672
2/80 SYSTEM 9S.1 100.0 93.7 696 652 652
•* PROBLEMS/SOLUTIONS/COHMENTS
NO MAJOR F6D-RELATED PROBLEMS OCCURRED DURING JANUARY AND FEBRUARY.
3/80 SYSTEM 98.8 100.0 83.7 744 623 623
• * PftOBLEMS/SOLUTIONS/COHHENTS
THE BOILER HAS OUT OF SERVICE ONE WEEK IN MARCH DUE TO A PLUGGED AIR
PREHEATER. NO MAJOR F6D-RELATED PROBLEMS WERE REPORTED FOR MARCH.
4/80 SYSTEM 720
5/80 SYSTEM 744
4/80 SYSTEM 720
*• PROBLEHS/SOLUTIONS/COMMENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD HAS NOT AVAILABLE.
7/80 SYSTEM 744
160
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
PENNSYLVANIA POWER: BRUCE MANSFIELD 1 CCONT.)
... . ... PERFORMANCE DATA —
PERIOD NOtULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION t RHOVAL PER BOILER F6» CAP.
S02 PART. HOURS HOURS HOURS FACTOR
J/80 SYSTEM 7**
J/80 SYSTEM 720
• * PROBLEMS/SOLUTIONS/COHMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NO* YET AVAILABLE.
161
-------
EPA UTILITY f6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/FGD - NU
EQUIVALENT SCRUBBED CAPACITY - HW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - t
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•* TREATMENT
TYPE
»» DISPOSAL
TYPE
- X
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
SNIPPINGPORT
PENNSYLVANIA
917.0
825.0
917.0
< 11500 8TU/L8)
COAL
BITUMINOUS
26749.
12.90
7.00
3.00
UET SCRUBBING
LIME
CNEHICO DIVISION, EMVIROTECH
NEU
6.0
7/77
10/77
92.10
99.80
.0
.0
OPEN
*******
CALCILOX
LANDFILL
(***•* GPM)
....... ... .. —PERFORMANCE DATA ———— —...—————...____..
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 97.1 100.0 90.6 744 674 674
2/80 SYSTEM 94.7 100.0 99.8 696 694 694
*• PROBLEMS/SOLUTIONS/COHMENTS
THE FGD SYSTEM EXPERIENCED NO MAJOR PROBLEMS DURING JANUARY AND FEBRUARY.
5/80 SYSTEM 98.4 100.0 51.1 744 380 380
•» PROBLEMS/SOLUTIONS/COHMENTS
THE BOILER HAS OUT OF SERVICE 16 DAYS IN MARCH FOR A SCHEDULED BOILER
INSPECTION. NO MAJOR FGD-RELATED PROBLEMS HERE REPORTED.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
*• PROBLEMS/SOLUTIONS/CONHENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD HAS NOT AVAILABLE.
7/80 SYSTEM 744
162
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
PENNSYLVANIA POWER: BRUCE MANSFIELD 2 CCONT.)
................ ...—PERFORMANCE DATA— —— ___.__._.__.-.—————
NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FCO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
S/BO SYSTEM 7«4
7/80 SYSTEM 730
•* PROBLEMS/SOLUTIONS/COHNENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOT YET AVAILABLE.
163
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
'ARTICULATE EMISSION LIMITATION - N6/J
SO! EMISSION. LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MM
SROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
•* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.H/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
• • 6ENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEK/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
• • ESP
NUMBER
TYPE
»* PARTICLE SCRUBBER
TYPE
• * ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STA6ES
NUMBER OF NOZ7LES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - H/SEC
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENT INDEX
• • FANS
NUMBER
TYPE
- X
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
SHIPP1NGPORT
PENNSYLVANIA
D
32. (
258. (
2751.0
917.0
825.0
.075 LB/MMBTU)
.600 LB/MMBTU)
917.0
FOSTER WHEELER
PULVERIZED COAL
BASE
**/ **
1561.05
140.6
183.
(3308000 ACFM)
( 285 F>
( 600 FT)
(***** FT)
COAL
26749. ( 11500 BTU/LB)
11.500-11t950
12.50
11.5-13.5
7.00
5.5-8.5
3.00
1.75-3.75
********
******
THROUAUAY PRODUCT
WET SCRUBBING
LIME
MG PROMOTED
PULLMAN KELLOGG
GILBERT/COMMONWEALTH ASSOCIATES
FULL SCALE
NEW
95.00
92.20
6/80
6/80
COLD SIDE
NONE
SPRAY TOWER
4/80
PULLMAN KELLOGG
6
300
7.0 (28.0 IN-H20)
6.7 ( 22.0 FT/S)
2.5
1.0
CENTRIFUGAL RADIAL TIP
164
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
PENNSYLVANIA POWER: BRUCE MANSFIELD 3 CCONT.)
SERVICE - MET/DRY DRV
*• HIST ELIMINATOR
TYPE CHEVRON
•* PUMPS
SERVICE NUMBER
SLURRY RECIRCULATION •*•*
****** •***
•* TANKS
SERVICE NUMBER
REACTION •»•»
LIME SLURRY ****
** REHEATER
TVPE NONE
** THICKENER
NUMBER 1
*• TREATMENT
TYPE FLVASM STABILIZATION
__. ----- - — —————— ---------- _ ----- PERFORMANCE OAT* ------- — — — • -- --- - — — ---- -~ — — -- -
PERIOD NODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
PART. HOURS HOURS HOURS FACTOR
4/80 SYSTEM 720
•* PROBLEMS/SOLUTIONS/CONMENTS
INITIAL OPERATION OF THE F6D SYSTEM COMMENCED ON JUNE 9, 1980. THE
UTILITY REPORTED THAT IT IS PRESENTLY IN THE PROCESS OF DEBUGGING THE
SYSTEM.
7/80 SYSTEM 744
3/80 SYSTEM 744
9/80 SYSTEM 7ZO
•* PROBLEMS/SOLUTIONS/COHPENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOC YET AVAILABLE.
165
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/F6D - MU
EQUIVALENT SCRUBBED CAPACITY - MU
PUBLIC SERVICE
SAN JUAN
1
UATERFLOU
NEU MEXICO
361.0
314.0
361.0
OF NEU MEXICO
** FUEL »ATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
STSTEM SUPPLIER
NEU/RETIOFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
COAL
SUBBITUAINOUS
22795.
18.00
14.82
.80
.03
UET SCRUBBING
UELLHAN LORD
DAVY MCKEE
RETROFIT
4.4
4/78
4/78
90.00
99.80
100.0
2.0
( 9800 BTU/LB)
•• HATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
•• BYPRODUCT
3VPRODUCT NATURE
DISPOSITION
CLOSED
30.2
( 480 6PM)
ELEMENTAL SULFUR
MARKETED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/80
A
a
c
D
SYSTEM
A
B
C
D
SYSTEM
A
B
C
D
SYSTEM
81.0
96.0
.0
83.0
100.0
.0
99.0
3.0
99.0
67.0
.0
100.0
58.1
97.5
100.0
51.0
42.3
.0
79.3
86.3
.0
94.3
2.5
97.6
97.2
.0
50.4
82.8
85.5
100.0 100.0
41.8
34.7
.0
65.1
70.8 744 610 527
.0
85.9
2.3
88.9
88.6 696 634 616
.0
17.6
29.2
30.1
38.5 744 262 286 11. 0
*• PROBLEMS/SOLUTIONS/COMMENTS
SCRUBBER OPERATIONS AT UNIT ONE ARE STILL LIMITED TO TUO MODULES BECAUSE
OF THE CURRENT LACK OF REHEATER CAPACITY.
4/80 A
B
C
D
SYSTEM
.0
98.2
50.0
91.7
100.0
.0
71.5
7.2
71.5
75.1
100.0
.0
48.2
4.9
48.2
50.7
720
485
365 SS.8
166
-------
Cr« wTILITY F60 SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF NEW MEXICO: SAN JUAN 1 CCONT.i
... .— . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY QPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUT10NS/COMMENTS
ONLY TWO MODULES ARE NEEDED AT THE PRESENT TIME TO MEET CURRENT SOZ
EMISSION REGULATIONS CSEE COMMENTS FOR 00/78).
A TUBE WALL LEAK FORCED THE BOILER OUT OF SERVICE DURIN6 APRIL.
HIGH VIBRATIONS IN THE BOOSTER BLOWER IN MODULE D FOLLOWED AFTER THE UNIT
OUTAGE.
HIGH VIBRATIONS IN THE BOOSTER BLOWER CAUSED MODULE A TO BE UNAVAILABLE
THE ENTIRE MONTH.
REPAIR AND MAINTENANCE OF THE BOOSTER BLOU6R AND ISOLATION DAMPERS IN
MODULE C WERE PERFORMED DURING APRIL.
5/80 A 73.1 62.1 55.9
B 99.7 37.2 33.5
C 75.5 71.8 64.7
D 80.2 19.9 17.9
SYSTEM 100.0 95.5 100.0 86.0 7*4 670 640 87.4
•* PROBLEMS/SOLUTIONS/COMMENTS
BOOSTER BLOWER VIBRATIONS ARE CONTINUING IN ALL THE MODULES.
THERE WAS A UNIT OUTAGE SO THAT REPAIR WORK COULD BE UNDERTAKEN ON THE ESP.
A/BO
A
B
C
D
SYSTEM
2.8
96.9
82.5
.1
91.2
2.5
92.0
79.2
.2
87.0
2.1
75.6
65.0
.1
79.8 71.4
720 591 514 65.4
• • PROBLEMS/SOLUTIONS/COMMENTS
A BOILER TUBE LEAK FORCED THE UNIT OUT OF SERVICE IN JUNE.
REPAIR WORK WAS DONE ON THE ISOLATION DAMPBRS DURING JUNE.
7/80
A
B
C
D
SYSTEM
.0
30.4
89.2
82. 8
100. 0
.0
16.0
87.9
79.6
91.7
.0
16.0
87.9
79.6
91.7
744 744 683 91.7
*• PROBLEMS/SOLUTIONS/COMMENTS
NODULE A WAS UNAVAILABLE IN JULY BECAUSE OF REPAIRS MADE TO THE ISOLATION
DAMPER AND THE LOWER CHIMNEY SEAL.
MODULE B WAS FORCED OUT BECAUSE OF HIGH VIBRATIONS IN THE BOOSTER BLOWER.
VIBRATIONAL PROBLEMS ALSO KEPT MODULE D OFF LINE UNTIL JULY 4, WHEN THE
BOOSTER BLOWER WAS BALANCED.
8/80
A
B
C
D
SYSTEM
.0
21.5
91.1
94.4
100.0
.0
21.5
77.8
90.1
94.7
.0
21.5
77.8
90.1
93.2 94.7
744 744 704 82.0
*• PROBLEMS/SOLUTIONS/CONMENTS
NODULE A DID NOT OPERATE IN AUGUST BECAUSE OF REPAIRS HADE TO THE LOWER
CHIMNEY SEAL.
MODULE B WAS OUT OF SERVICE FOR OVER 3 WEEKS TO CLEAN, PAINT, AND BALANCE
THE BOOSTER BLOWER ROTOR.
167
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EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF NEW MEXICO: SAN JUAN 1 CCONT.)
....—__._ _ . PERFORMANCE DATA— —— ——————_.__.
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
CRACKED VELDS ON THE WATER INLET NOZZLES W6RE REPAIRED ON MODULE C.
.0
31.4
30.7
39.3
94.8 50.7 720 394 365 43.5
•* PROBLEMS/SOLUTIONS/COMMENTS
HI6H VIBRATIONS IN THE BOOSTER BLOWER CAUSED MODULE C TO SHUT DOWN FOR
PART OF SEPTEMBER.
THE F6D SYSTEM WAS DOWN FOR SEVERAL DAYS BECAUSE OF BOILER RELATED
PROBLEMS.
THE BOILER AND FGD SYSTEM WENT DOWN ON SEPTEMBER 18. 1980 FOR SCHEDULED
MAINTENANCE AND WERE UNAVAILABLE THE REST OF THE MONTH.
9/80
A
B
C
D
SYSTEM
.0
37.2
39.4
45.1
60.9
.0
57.4
56.1
71.8
92.7
168
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/F6D - MU
EDUIVALENT SCRUBBED CAPACITY - MU
• • FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
«• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
»* BYPRODUCT
1YPRODUCT NATURE
DISPOSITION
- X
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN
2
UATERFLOU
NEU MEXICO
350.0
306.0
350.0
COAL
SUBBITUMINOUS
22795.
18.00
U.82
.SO
.05
UET SCRUBBING
UELLMAN LORD
DAVY NCKEE
RETROFIT
4.6
8/78
8/78
90.00
99.SO
33.0
1.0
CLOSED
30.2
< 9800 BTU/LB)
( 480 GPM)
ELEMENTAL SULFUR
MARKETED
........ ....-.-.._.... . _ -PERFORMANCE DATA——
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
502 PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
1/80
E
F
G
H
SYSTEM
92.0
100.0
.0
.0
96.0
63.0
.0
.0
.0
31.5
62.4
.0
.0
.0
31.2
744 737
232
• * PROBLEMS/SOLUTIONS/COMMENTS
THE F-NODULE UAS AVAILABLE. HOWEVER, FGD SERVICE UAS NOT REQUIRED BECAUSE
A BOILER-RELATED POKER FAILURE FORCED THE BOILER TO OPERATE AT LOU LOAD.
2/60
3/80
E
f
G
H
SYSTEM
E
F
G
H
SYSTEM
97.0
22.0
.0
.0
59.5
87.0
8S.O
.0
.0
86.0
65.7
12.3
.0
.0
39.0
.0
93.6
.0
.0
46.8
64.5
12.1
.0
.0
38.3
.0
59.4
.0
.0
29.7
696 683
744 472
267
221 33.0
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER ONLY ONE ABSORBER COULD BE OPERATED DUE TO AN
ELECTRICAL PROBLEM. CURRENTLY, OPERATIONS ARE LIMITED TO TUO ABSORBERS
UNTIL NEU REHEATERS ARE INSTALLED. REHEATEJt INSTALLATION IS EXPECTED TO
169
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF NEW MEXICO: SAN JUAN l (CONT.)
PERIOD
4/80
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
E
F
G
H
SYSTEM
BE COMPLETED IN APRIL.
99.3 91.3 68.5
99.9 71.1 53.3
.0 .0 .0
44.2 58.5 43.9
100.0 90. 8 98.8 68.1
720 540 490 66.
3
•• PROBLEMS/SOLUTIONS/COMMENTS
MODULE G IS DOWN FOR MAJOR REPAIRS WHICH WERE
EARLIER IN THE YEAR.
A RESULT OF AN INTERNAL FIRE
A REGULATION CHANGE EFFECTIVE APRIL 18, NOW REQUIRES THAT THREE MODULES
OPERATE TO MEET S02 REGULATIONS (SEE COMMENTS FOR 00/76).
MODULE H WAS UNAVAILABLE IN THE BEGINNING OF THE MONTH.
5/80
E
F
&
H
SYSTEM
99.1 97.3 86.7
98.9 95.2 84.8
.0 .0 .0
98.9 91.9 81.9
99.0 94.8 100.0 84. 5
744 663 628 79.
1
*» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS DOWN FOR SEVERAL HOURS FOR MINOR MAINTENANCE AND BOILER TUBE
REPAIRS.
i/80
E
F
G
H
SYSTEM
89.2 72.4 56.0
89.6 74.1 57.4
.0 .0 .0
88.8 83.8 64.9
89.2 76.7 98.3 59.4
720 557 428 69.
6
•* PROBLEMS/SOLUTIONS/COMMENTS
7/80
E
F
G
H
SYSTEM
AN ELECTRICAL CABLE FAILURE PREVENTED MODULES
SIMULTANEOUSLY. AUXILIARY POWER COULD ONLY BE
97.6 55.4 49.1
96.9 85.0 75.3
.0 .0 .0
98. 9 91.0 80.6
97.8 77.1 68.3
E AND F FROM OPERATING
PROVIDED TO ONE MODULE.
744 659 508 79.
8
** PROBLEMS/SOLUTIONS/CONMENTS
THE BOILER WAS DOWN FOR SEVERAL DAYS IN JULY TO REPAIR TUBE LEAKS.
THE POWER CABLE WHICH FAILED IN JUNE WAS REPAIRED THIS MONTH. THIS CABLE
PERMITS OPERATION OF THE E AND F MODULES WITH THE H MODULE.
J/80
E
F
G
H
SYSTEM
98.4 90.2 85.8
97.8 72.7 69.1
.0 .0 .0
98.3 92.6 88.0
98.2 85.2 100.0 81.0
744 707 602 88.
7
•* PROBLEMS/SOLUTIONS/COHMENTS
»/80
E
F
G
H
SYSTEM
TUBE LEAK REPAIRS IN THE BOILER CAUSED THE FGD
TWO DAYS.
99.0 56.1 51.9
99.3 56.1 51.9
•0 .0 .0
97.6 56.2 52.1
98.6 56.1 62.5 51.9
SYSTEM NO TO OPERATE FOR
720 667 374 85.
5
170
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF NEV MEXICO: SAN JUAN Z (CONT.)
. . PERFORMANCE DATA ——
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F60 CAP.
$02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
ESP PROBLEMS CAUSED ERRATIC OPERATION OF THE F6D SYSTEM FOR SEVERAL DAYS
IN SEPTEMBER.
THE F6D SYSTEM WAS NOT OPERATED DURING A SCHEDULED OUTAGE OF THE CHEMICAL
PLANT. THE SYSTEM MAS AVAILABLE DURING THIS TIME.
NODULE 6 HAS UNAVAILABLE IN SEPTENBER BECAUSE OF ONGOING REPAIR OF FIRE
DAMAGE.
171
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EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
OESI6N AND PERFORMANCE DATA
SECTION 3
FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
WATERFLOW
NEW MEXICO
534.0
468.0
534.0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - S
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
COAL
SUBBITUMINOUS
18641.
22.45
14.82
.80
.07
WET SCRUBBING
WELLMAN LORD
DAVY NCKEE
NEW
3.6
12/79
**/ **
90.00
99.50
.0
.0
< 8>00 BTU/LB)
»• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
SULFURIC ACID
MARKETED
PERFORMANCE DATA ——.—. -•.._
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
M
SYSTEM
86.0
86.0
54.4
54.4
41.5
41.5
744
568
309
PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM FIGURES REFLECT THE OPERATION OF A SINGLE MODULE. ONLY ONE
MODULE WILL BE NEEDED UNTIL MAY 1982 TO MEET CURRENT 502 EMISSION
REGULATIONS.
2/80
3/80
M
SYSTEM
M
SYSTEM
98.0
98.0
85.5
85.5
13.6
13.6
78.3
78.3
79.6
79.6
1.0
1.0
56.7
56.7
696
44
744 539
*22 53.0
*• PROBLEMS/SOLUTIONS/COMMENTS
THE ONE NODULE CURRENTLY OPERATIONAL AT SAN JUAN 3 OPERATED WITHOUT ANY
MAJOR PROBLEMS DURING THE FIRST QUARTER OF 1980. THE BOILER HAS OFF LINE
FOR APPROXIMATELY 24 DAYS IN FEBRUARY DUE ffO AN ELECTRICAL PROBLEM.
4/80
N
SYSTEM
92.1
92.1
82.7
82.7
90.1
90.1
71.8
71.8
720 625
517 77.0
*• PROBLEMS/SOLUTIONS/COMMENTS
MINOR REPAIR WORK WAS DONE TO THE BOILER THIS MONTH. FGD SYSTEM AVAILABIL-
ITY WAS OVER 90S.
5/80
N
SYSTEM
100.0
100.0
78.1
78.1
100.0
100.0
32.7
32.7
744
311
243 35.0
172
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF NEW MEXICO: SAN JUAN 3 (CONT.)
_._...— ........ PERFORMANCE 6ATA —
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6» CAP.
$02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER HAS OUT OF SERVICE FOR A SCHEDULED MAINTENANCE OUTAGE.
j/80 M 49.0 43.3 39.2 27.6
SYSTEM 49.0 43.3 39.2 27.6 720 460 127 $5.0
•* PROBLEMS/SOLUTIONS/COMHENTS
MINOR REPAIR AND MAINTENANCE OF THE BOILER CAUSED SYSTEM OUTA6E TIME.
THE F6D SYSTEM DID NOT OPERATE AFTER JUNE *9 DUE TO FAILURE OF THE HIST
ELIMINATOR MESH PADS AND BOTTOM BALLAST TRAY.
7/80 * 75.5 89.B 89.8 74.5
SYSTEM 75.5 89.8 89.8 74.5 744 617 544 66.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS RETURNED TO SERVICE ON JULY STH AFTER BOILER AND FGD
SYSTEM REPAIRS HERE MADE.
1/80 H 83.2 81.6 82.7 80.2
SYSTEM 83.2 81.6 82.7 80.2 744 732 597 81.9
•» PROBLENS/SOLUTIONS/COMNENTS
BEARINGS ON THE CIRCULATING PUMP MERE REPLACED DURING AUGUST.
A PUMP DISCHARGE VALVE WAS REPLACED DUE TO LEAKAGE.
9/80 N 96.7 59.4 59.1 45.7
SYSTEM 96.7 59.4 59.1 45.7 720 549 329 61.6
** PROBLEMS/SOLUTIONS/CONMENTS
THE FGD SYSTEM HAS DOWN FOR SEVERAL DAYS IN SEPTEMBER BECAUSE OF BOILER
TUBE LEAKS.
THE FGD SYSTEM WAS NOT OPERATED DURING A SCHEDULED OUTAGE OF THE CHEMICAL
PLANT. THE SYSTEM WAS AVAILABLE DURING THIS TIME.
173
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/F6D - MW
EBUIVALENT SCRUBBED CAPACITY - MU
»• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/B
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - t
AVERAGE CHLORIDE CONTENT - X
•» GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• DISPOSAL
TYPE
- X
SALT RIVER PROJECT
CORONADO
1
ST. JOHNS
ARIZONA
350.0
350.0
280.0
COAL
SUBBITUMINOUS
19306.
25.00
16.00
1.00
( 8300 BTU/LB)
UET SCRUBBING
LIMESTONE
PULLMAN KELLOGG
NEW
4.3
11/79
13/79
66.00
99.87
.0
.0
OPEN
17.0
LINED POND
( 270 GPM)
.... .... . PERFORMANCE DATA ————————.._. .
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP
SO? PART. HOURS HOURS HOURS FACTOR
1/BO
2/BO
3/80
4/80
5/80
6/80
SYSTEM
SYSTEM
SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
DURING THE PERIOD STACK EMISSION TESTS WERE COMPLETED.
INFORMATION HAS AVAILABLE.
NO OPERATIONAL
SYSTEM
SYSTEM
SYSTEM
• • PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
7/80
J/80
9/60
SYSTEM
SYSTEM
SYSTEM
ALTHOUGH FGD SYSTEM PERFORMANCE DATA ARE BEING LOGGED. THE UTILITY REPORTED
THAT THE INFORMATION IS UNAVAILABLE FOR RELEASE AT THIS TIME.
744
744
720
174
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SILT RIVER PROJECT: CORONAOO 1 (CONT.)
... . f PERFORMANCE DATA— —
PERIOD NODULE AVAILABILITY OPERA8ILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FG0 CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
«_.._ — — — ^• — •— • "•••••—••• • *«*«••__._•. .»•.•*___«»•«« »—*«»*»• — — -. •• ••••» »••» •••««•• ••••• •••»••
•» PROBLEHS/SOLUTIONS/COHMENTS
THE UTILITY WILL HOT AUTHORIZE THE RELEASE OF F«D PERFORMANCE DATA AT
THIS TIME, BUT NOTED THAT THE SYSTEM IS TO SHUT BOHN ON NOVEMBER 1, 19SO
FOR A MAJOR OVERHAUL.
175
-------
EPA UTILITY f60 SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
CROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATIN6 CAPACITY W/FGD - MW
MET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
»* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOW - CU.H/S
FLUE 6AS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - N
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM 6ATA
SALEABLE PRODUCT/THROUAUAV PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 BESX6N REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
• • ESP
NUMBER
TfPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICULATE OUTLET LOAD - G/CU.M
•• PARTICLE SCRUBBER
TYPE
•* ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
- X
SALT RIVER PROJECT
CORONADO
2
ST. JOHNS
ARIZONA
D
43. C
700.0
350.0
350.0
365.0
260.0
RILEY STOKER
PULVERIZED COAL
BASE
4/80
1226.94
404.4
152.
5.8
.,100 LB/MHBTU)
.800 LB/MMBTU)
C2600000 ACFB)
( 760 F)
< 500 FT>
( 19.0 FT)
COAL
SUBBITUMINOUS
19306.
25.00
19-35
16.00
12-20
1.00
0.4-1.0
********
I 8300 BTU/LB)
t,000-11,000
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
NONE
PULLMAN KELLOGG
BECHTEL
BECHTEL
FULL SCALE
NEW
99.87
66.00
10/80
7/80
11/79
5/77
6/76
HOT SIDE
WESTERN PRECIPITATION
X 99.8
1321.3 (2800000' ACFH)
404.4 ( 760 F)
******* <**•*.* 1N-H20)
.00 ( .00 GR/SCF)
NONE
SPRAY TOWER
1/80
PULLMAN KELLOGG
176
-------
EPA UTILITY F6D SURVEY.: JULY - SEPTEMBER 1980
SALT RIVER PROJECT: CORONADO 2 (CONT.)
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
INTERNAL MATERIAL
NUMBER OF NOZZLES
BOILER LOAD/ABSORBER - X
SIS FLOW - CU.K/S
GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
L/E RATIO - L/CU.N
PRESSURE DROP - KPA
S02 INLET CONCENTRATION - PPM
S92 OUTLET CONTRATION - PPM
S02 OUTLET CONCENTRATION- N6/J
502 DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENT INDEX
•* FANS
NUMBER
TYPE
SERVICE - WET/DRY
CAPACITY - CU.M/S
** MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
DEPTH - M
VANE SPACING - CM
riASH SYSTEM
SUPERFICIAL GAS VELOCITY - M/S
*• PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL RANGE
CONTROL MANNER
HOOF.
SENSOR LOCATION
•* PU1PS
SERVICE
SLURRY RECIRCULATION
SLUDGE DISPOSAL
SLURRY PURGE
ALKALI MAKEUP
PROCESS MATER
SEAL UATER
HI6H PRESSURE SEAL UATER
MIST ELIMINATOR WASH
******
** TANKS
SERVICE
REACTION MIX
PROCESS UATER
MIST ELIMINATOR
SEAL UATER
LIMESTONE SLURRY STORAGE
SLUDGE STORAGE
** REHEATER
TYPE
TEMPERATURE BOOST - C
•» THICKENER
NUMBER
TYPE
DIAHETER - M
OUTLET SOLIDS - X
120 L X 28 U X 17 H
CARBON STEEL
POLYESTER RESIN
14*
40.0
25.48
46.1
630.
3.3
1000
180
.4
t 54000 ACFIO
t 115 F)
(10000 GPM>
( 25.0 6AL/1000ACF)
C 1.5 IN-H20)
82.0
.0
.0
SCRUBBER Fc
DRV
304.52
(***«* LB/MMBTU)
C 644880 ACFM)
CHEVRON
HEIL NORVL E-265
VERTICAL
1
3
8.84
.21
3.2
MAKEUP UATER SPRAY
(29.0 FT}
( .7 FT)
( 1.25 IN)
4.6
( 15.0 FT/S)
S02 INLET CONCENTRATION GAS FLOU, PH
0-1000 PPM S02, 0-500,000 SCFM, 4-8 PH
AUTOMATIC AND MANUAL
FEED FORUARD
INLET DUCT, FIRST AND FOURTH STAGES (PH)
NUMBER
10
4
4
1
2
1
2
2
*** *
NUMBER
*•**
2
2
1
1
1
BYPASS
27.8 ( 50 F)
1
CENTER FEED UELL
32.0 (105 FT)
30.0
177
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SALT RIVER PROJECT: CORONADO 2 CCONT.)
•» WATER LOOP
TYPE
EVAPORATOR HATER LOSS - LITER/S
SLUDGE VATER LOSS - LITER/S
POND WATER LOSS - LITER/S
PURGE WATER LOSS - LITER/S
OTHER HATER LOSSES - LITER/S
RECOVERED WATER RETURN - LITER/S
FRESH MAKEUP WATER ADDITION - LITERS/S
** REAGENT PREPARATION EQUIPMENT
NUMBER OF STORAGE HOPPERS
NUMBER OF BALL MILLS
NUMBER OF SLAKERS
BALL MILL CAPACITY- M T/N
REAGENT PRODUCT - X SLURRY SOLIDS
POINT OF ADDITION
•» DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
AREA - ACRES
OPACITY - CU.H
OPEN
13.2
3.8
.0
.0
.0
.0
17.0
210 GPM)
60 GPM)
0 GPM)
0 6PM)
0 GPM)
0 6PM)
270 6PM)
1
2
0
11.8 ( 13.0 TPH)
20.0
REACTION MIX TANK BENEATH EACH ABSORBER TRAIN
FINAL
LINED POND
ON SITE
PIPE
28.0
4525100 C 3700.0 ACRE-FT)
... .__ _—.... PERFORMANCE DATA ———....-._.__
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/80 SYSTEM
S/80 SYSTEM
9/80 SYSTEM
•• PROBLEMS/SOLUTIONS/COMMENTS
744
744
720
INITIAL OPERATION OF THE F6D SYSTEM AT THE CORONADO 2 STATION COMMENCED
IN JULY, 1980.
DURING THE THIRD QUARTER 1980 A BEARING INSPECTION HAS CONDUCTED. THE UNIT
IS PRESENTLY IN THE PROCESS OF BEGINNING COMMERCIAL OPERATION.
178
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MU
MET UNIT GENERATING CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL OATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
*» WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
it DISPOSAL
TYPE
- X
SOUTH CAROLINA PUBLIC SERVICE
UINVAH
2
GEORGETOWN
SOUTH CAROLINA
280.0
258.0
140.0
COAL
BITUMINOUS
26749.
13.50
1.70
********
WET SCRUBBING
LIMESTONE
BABCOCK I WILCOX
NEW
1.1
7/77
**/ *»
45.00
99.40
.0
.0
( 11500 BTU/LB)
OPEN
6.3
< 100 6PM)
POND
...————————————— -PERFORMANCE DATA—————-—— —— —__
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
2/80
5/80
4/8C
5/80
6/80
SYSTEM
SYSTEM
SYSTEM
*• PROBLEMS/SOLUTIONS/CONMENTS
744
696
744
DURING THE FIRST QUARTER Of 1980 NO MAJOR FGD RELATED PROBLEMS WERE
REPORTED.
SYSTEM 100.0 100.0 100.0
SYSTEM 95.8 94.9 94.9
** PROBLEMS/SOLUTIONS/COMMENTS
85.3
77.7
720
744
614
609
614 60.2
578 61.9
THE FGD SYSTEM WAS OFF LINE THROUGH PART OF MAY TO HASH DOWN THE ABSORBER
MODULES.
SYSTEM 100.0 100.0
•* PROBLENS/SDLUTIONS/COMMENTS
100.0
99.6
720 718
718 76.6
NUMEROUS LEAKS IN THE FGD SYSTEM WERE REPAIRED THROUGHOUT THE PERIOD WHILE
THE BOILER AND SCRUBBER WERE IN SERVICE. NO MAJOR OPERATIONAL PROBLEMS
WERE REPORTED FOR APRILt MAY, OR JUNE.
7/80 SYSTEM
100.0
100.0
100.0
100.0
744
744
744 75.3
179
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SOUTH CAROLINA PUBLIC SERVICE: WINYAH 2 (CONT.)
... __.—.—. —PERFORMANCE DATA —————————..____„
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COMMENTS
NO OPERATIONAL PROBLEMS WERE REPORTED DURING JULY.
B/80 SYSTEM 99.7 99.7 99.7 88.3 7*4 659 657 74.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE GRIT SEPARATOR PLUGGED CAUSING A TWO HOUR OUTAGE. THE FGD SYSTEM
MAS AVAILABLE THROUGH ALL OF AUGUST EXCEPT FOR THIS SHORT OUTA6E.
»/8P SYSTEM 94.5 100.0 100.0 87.2 720 629 629 73.4
•• PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND FGD SYSTEM WENT DOWN FOR A SCHEDULED MAINTENANCE OVERHAUL
OH SEPTEMBER 30, 1980. WORK SCHEDULED TO BE DONE INCLUDED INSTALLING A
SECOND TRAY IN THE ABSORBER MODULE, RENEWING DEMISTER WASH SYSTEM WITH
ALLOY 20 PIPING, AND CLEANING SCALE DEPOSITS FROM SUENCHER THROAT.
180
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
SOZ EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
CROSS UNIT GENERATING CAPACITY - MU
«ET UNIT GENERATING CAPACITY W/FGD - NU
NET UNIT GENERATING CAPACITY UO/FGO - HV
EQUIVALENT SCRUBBED CAPACITY - MW
*• BDILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
NAX1NUM BOILER FLUE GAS FLOW - CU.H/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - N
STACK TOP DIAMETER - M
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - I
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROUAHAV PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
MEM/RETROFIT
SOZ DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION INITIATION
• * ESP
NUMBER
SUPPLIER
•* PARTICLE SCRUBBER
TYPE
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
$02 DESIGN REMOVAL EFFICIENCY - X
»* MIST ELIMINATOR
TYPE
•* PU1PS
SERVICE
SOUTH CAROLINA PUBLIC SERVICE
UINYAH
3
GEORGETOWN
SOUTH CAROLINA
B
****** (•*»»** LB/MHBTU)
****** (•***** LB/MMBTU)
*******
280.0
252.0
2S8.0
280.0
RILEY STOKER
PULVERIZED COAL
BASE
**/**
********
*******
******
*******
COAL
******
26749.
********
(•**•*** ACFN)
<•*** M
(***•* ft)
C***«* FT>
< 11500 BTU/LB)
*•«*.*•
******
1.70
THROWAWAY PRODUCT
UET SCRUBBING
LIMESTONE
BABCOCK I WILCOX
BURNS I ROE
FULL SCALE
NEW
90.00
6/80
5/80
3/79
RESEARCH-COTTRELL
NONE
SPRAY TOWER
5/80
BABCOCK t WILCOX
90.0
CHEVRON
NUMBER
****
181
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SOUTH CAROLINA PUBLIC SERVICE: WIN-YAH 3 (CONT.)
** REHEATER
TYPE HOT AIR INJECTION
HEATING MEDIUM STEAM
• • WATER LOOP
TYPE CLOSED
.. . . PERFORMANCE DATA — _
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/80 SYSTEM 60.0 60.0 60.0 46.6 720 559 336 59.5
•• PROBLEMS/SOLUTIONS/CONMENTS
INITIAL FGD OPERATIONS BEGAN JUNE 3, 1980.
THE INLET DAMPER LOCKED UP FORCING THE FGD SYSTEM OUT OF SERVICE FOR PART
OF JUNE.
THERE HAVE BEEN CONTINUING PROBLEMS WITH THE THICKENER SUMP RESULTING FROM
IT'S LOCATION. THESE PROBLEMS FORCED THE FGD SYSTEM OUT OF SERVICE FOR
APPROXIMATELY 7 DAYS.
7/80 A 12.8 12.8 12.8 12.8
B 12.8 12.8 12.8 12.8
SYSTEM 12.8 12.8 12.8 12.8 744 744 95 79.8
•* PROBLENS/SOLUTIONS/COMMENTS
THE THICKNER RAKE DRIVE MECHANISM HAS REPAIRED DURING JULY.
THE LARGE BELT DRIVEN PUMP HAS BEGUN TO SHOW SIGNS OF RAPID WEAR.
THE F6C SYSTEM WAS OUT OF SERVICE BECAUSE OF COMPUTER LOGIC PROBLEMS CAUSED
BY A BAD CABLE.
THE THICKNER SUMP PUMP AND MIXER MOTORS WERE FLOODED OUT CAUSIN6 THE FGD
SYSTEM TO GO DOWN.
3/80 A 18.0 20.4 20.4 18.0
B 18.0 20.4 20.4 18.0
SYSTEM 18.0 20.4 20.4 18.0 744 658 134 79.4
•• PROBLEMS/SOLUTIONS/COMMENTS
THE THICKNER SUMP PUMP AND MIXER MOTORS CONTINUED TO HAVE PROBLEMS BECAUSE
OF THE FLOODING LAST MONTH.
THE SCRUBBER OUTLET DAMPER WOULD NOT CLOSE PROPERLY WHICH REQUIRED WORK
DURING AUGUST.
THE ABSORBER TRAY STRAP WAS BROKEN IN SEVERAL AREAS AND REQUIRED REPAIR
WORK DURING THE MONTH.
9/80 A .0 .0 .0 .0
B »0 .0 .0 .0
SYSTEM .0 .0 .0 .0 720 647 0 84.6
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OUT OF SERVICE THROUGH ALL OF SEPTEMBER BECAUSE OF
REPAIRS BEING MADE ON THE THICKNER.
182
-------
EPA UTILITY F60 SURVEY: JULT - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT 6EMERATING CAPACITY - MW
WET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SD2 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
»• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
.* TREATMENT
TYPE
»* DISPOSAL
TYPE
SOUTH MISSISSIPPI ELEC
R.D. MORROW, SR.
1
HATTISBUR6
MISSISSIPPI
200.0
180.0
124.0
PWR
( 12000 BTU/LB)
- X
COAL
BITUMINOUS
27912.
15.00
6.50
1.30
.01
WET SCRUBBING
LIMESTONE
ENVIRONEERING, RILEV STOKER
NEW
5.5
8/78
8/78
52.70
99.60
.0
.0
CLOSED
*******
{**••* 6PM>
FLVASH STABILIZATION
LANDFILL
____—.—.. ............—..... .......PERFORMANCE
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F66 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
SYSTEM .0
«• PROBLEMS/SOLUTIONS/COMMENTS
.0
7*0
.0
THE UNIT REMAINED OFF LINE DURING JANUARY AS RELINING OF THE SCRUBBERS
WAS COMING TO COMPLETION.
THE PRESATURATOR AREAS, BYPASS DUCTS, AND THE SECTIONS OF DUCT FROM
ABSORBER EXITS AT POINTS WHERE BYPASSED GAS MIXES WITH WET GAS ALL THE
WAY TO THE STACK ARE BEING LINED WITH HASTtLLOY G (A I/ft INCH LINING IS
BEING WELDED TO THE EXISTING CARBON STEEL).
THE MAIN BODY OF THE ABSORBER MODULES IMMEDIATELY ABOVE THE PRESATURATOR
SECTIONS ALL THE WAV TO THE ABSORBER EXIT LS BEING LINED WITH CHLOROBUTVL
RUBBER CON THE EXISTING CARBON STEEL).
Z/80
J/80
k/80
SYSTEM
SYSTEM
.0
41.5
95.1
.0
100.0
.0
39.5
696
744
0
309
0
294
• • PROBLEMS/SOLUTIONS/COMNENTS
DURING MARCH THE UNIT 1 FGD SYSTEM RETURNED TO SERVICE OPERATING 294 HOURS.
SYSTEM 100.0 99.0 100.0 99.0 80.00 720 720 713
183
-------
EPA UTILITY FSO SURVEY: JULY - SEPTEMBER 1980
S3UTH H1SSISSIPPI ELEC PUR: R.D. MORROW, SR. 1 (CONT.)
------------------------------------------ PERFORMANCE DATA ----------------- - — -- — - ------------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X R6.MOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THERE WERE NO OPERATIONAL PROBLEMS RELATED TO THE FGD SYSTEM DURING APRIL.
FOUR INSPECTIONS WERE PERFORMED WHICH REOUIREO THE FGD SYSTEM TO BE OUT
OF SERVICE FOR SEVEN HOURS.
5/80 SYSTEM 99.7 99. B
*• PROBLEMS/SOLUTIONS/COMMENTS
100.0
88.7
80.00
744
660
658
THE BOILER WAS SCHEDULED TO BE OUT OF SERVICE FOR 84 HOURS TO CLEAN THE
AIR PREHEATERS. THE BOILER OPERATED THE REMAINING HOURS IN MAY.
THE FGD SYSTEM WAS SCHEDULED TO BE OUT OF SERVICE FOR 1.5 HOURS FOR ROU-
TINE MODULE INSPECTION. THE FGD SYSTEM WAS AVAILABLE 99. 7X DURING HAY.
6/80 SYSTEM
99.?
97.0
99.0
93.0
90. 00
720 690
668 68.9
PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE OPERATIONS CAME TO A HAULT FOR APPROXIMATELY SIX HOURS TO CLEAN
THE MIST ELIMIMTORS. OTHER OUTAGE TIME DURING THE MONTH HAS CAUSED
BY BOILER-RELATED PROBLEMS.
7/60 SYSTEM 94.1 99.3
«• PROBLEfS/SOLUTIONS/COMMENTS
99.3
94.1
90.00
744
705
700 67.3
DURING JULY THE SCRUBBER WAS INSPECTED FOR SCALE ACCUMULATION AND A TRIP
TEST WAS CONDUCTED ON THE SCRUBBER CONTROLS TO CHECK ON EARLIER MODIFICA-
TIONS.
THE MAJORITY OF OUTAGE TIME WAS CAUSED BY A MALFUNCTION OF THE BALL HILL.
THIS RESULTED IN A LOSS OF LIMESTONE SUPPLY IN THE STORAGE TANK.
A LEAK IN THE FEED WATER LINE CAUSED ADDITIONAL OUTAGE TINE DURING THE
MONTH.
3/80 SYSTEM 100.0 100.0 100.0 100.0 80.00
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE MONTH OF AUGUST.
>/80 SYSTEM 99.2 99.6 99.6 99.2 720
• * PROBLEMS/SOLUTIONS/COMMENTS
744 744
717
744 77.7
714 70.3
DURING SEPTEMBER THE SCRUBBER WAS INSPECTED CAUSING TWO HOURS OF
OUTAGE TIME.
A BRIEF FGD OUTAGE OF 12 MINUTES WAS CAUSED BY AN ELECTRICAL SHORT.
THE UNIT AND FGD SYSTEM WERE OUT OF SERVICE FOR APPROXIMATELY 3 1/2 HOURS
DUE TO ESP PROBLEMS.
184
-------
EPA UTILITY FCD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
(ROSS UNIT EENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
.* TREATMENT
TYPE
.* DISPOSAL
TYPE
SOUTH MISSISSIPPI ELlEC PUR
R.D. MORROW, SR.
2
HATTISBURG
MISSISSIPPI
200.0
180.0
124.0
( 12000 BTU/LB)
- X
COAL
BITUMINOUS
27912.
IS.00
6.50
1.30
.01
UET SCRUBBING
LIMESTONE
ENVIRONEERINGt RILEV STOKER
NEU
5.5
6/79
6/79
52.70
99.60
.0
.0
CLOSED
*******
(**».* 6PK>
FLVASH STABILIZATION
LANDFILL
„_ . PERFORMANCE DATA —-
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
744 743
0 75.4
2/80
3/80
4/80
SYSTEM
SYSTEM
SYSTEM
THE UNIT REMAINED OFF LINE DURING JANUARY UHILE SCRUBBER LINER REPAIRS
CONTINUED.
THE PRESATURATOR AREAS, BYPASS DUCTS, AND THE SECTIONS OF DUCT FROM
ABSORBER EXITS AT POINTS WHERE BYPASSED GAS MIXES UITH WET GAS ALL THE
HAY TO THE STACK ARE BEING LINED UITH HASTBLLOV G CA 1/8 INCH LINING IS
BEING WELDED TO THE EXISTING CARBON STEEL).
THE MAIN BODY OF THE ABSORBER MODULES IMMEDIATELY ABOVE THE PRESATURATOR
SECTIONS ALL THE WAY TO THE ABSORBER EXIT IS BEING LINED UITH CHLOROBUTYL
RUBBER (ON THE EXISTING CARBON STEEL).
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.00
.00
696
744
720
698
486
0
75.0
*• PROBLENS/SOLUTIONS/COMNENTS
THE FGD SYSTEM REMAINED OFF LINE THROUGH APRIL AS SCRUBBER LINER REPAIRS
CONTINUED. THE UNIT IS EXPECTED BACK ON LINE AT THE END OF MAY.
5/80 SYSTEM
2.4
14.2
14.2
2.4
85.00
744
127
18
185
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SDUTH MISSISSIPPI ELEC PUR: R.O. MORROW, SR. 2 (CONT.)
..........—___.....-......-.— ———PERFORMANCE DAT*-——— —— ... ——_._.._
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X RBHOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT REMAINED OFF LINE DURING MOST OF HAT TO COMPLETE SCRUBBER AND
STACK LINING MODIFICATIONS.
THE BOILER OPERATED 127 HOURS IN NAY; HOWEVER, THE F6D SYSTEM OPERATED
ONLY 18 HOURS BECAUSE OF COMPUTER CONTROL PROBLEMS.
6/80 SYSTEM 99.3 90.0 99.1 78.0 90.00 720 625 561 68.9
*« PROBLEMS/SOLUTIONS/COHHENTS
THE FED SYSTEM COMPUTER LOST POWER DURING JUNE CAUSING THE UNIT TO
BE SHUT DOWN FOR 25 MINUTES.
DURING JUNE OPERATIONS CANE TO A HAULT FOR APPROXIMATELY FIVE HOURS TO
CLEAN THE HIST ELIMINATORS. OTHER OUTAGE MHE DURING THE MONTH HAS CAUSED
BY BOILER RELATED PROBLEMS.
7/80 SYSTEM 79.8 80.7 80.7 79.8 85.0ft 7*4 736 594 73.8
»* PR08LEHS/SOLUTIONS/COMHENTS
DURING JULY BALL HILL REPAIRS ACCOUNTED FOR THE MAJOR PORTION OF THE FGD-
RELATED OUTAGE TIME.
THE SCRUBBER WAS INSPECTED FOR SCALE ACCUMULATION AND A TRIP TEST WAS
CONDUCTED ON THE SCRUBBER CONTROLS TO CHECK ON EARLIER MODIFICATIONS.
THE SCRUBBING SYSTEM WENT OFF LINE DUE TO AN ALARM TRIGGERED BY HIGH
TEMPERATURE, WHICH WAS DETERMINED TO BE A FALSE ALARM.
A POSSIBLE TUBE LEAK SHUT THE BOILER DOWN ON JULY 27. THE UNIT WENT BACK
ON LINE WITHOUT FINDING THE LEAK. THE BOILER WAS THEN TAKEN OFF LINE ON
JULY 28 TO FIND THE LEAK AND MAKE THE NECESSARY REPAIRS.
PROBLEMS WITH THE BURNER HANAGEHENT CONTROL SYSTEH ALSO CAUSED A BOILER-
RELATED OUTAGE.
8/80 SYSTEM 98.8 99.$ 99.5 98.8 80.00 744 739 735 74.3
** PROBLEHS/SOLUTIONS/COHNENTS
THE BOILER WAS OUT OF SERVICE APPROXIMATELY FIVE HOURS DURING AUGUST DUE
TO A BOILER TUBE LEAK.
AFTER THE REPAIRS TO THE BOILER TUBE AN ADDITIONAL FOUR HOURS OF OUTAGE
TIME WAS NECESSARY TO START UP THE FGD SYSTEH.
a/80 SYSTEM 98.8 99.5 99.5 98.8 80.00 744 739 735 74.3
• • PROBLEMS/SOLUTIONS/COHMENTS
DURING AUGUST THE FGD SYSTEM HAS SHUT DOWN FOR FOUR HOURS FOR REPAIR OF A
TUBE LEAK,
9/80 SYSTEM 99.8 99.} 99.5 88.3 720 639 636 62.4
*• PROBLENS/SOLUTIONS/COHMENTS
DURING SEPTEMBER THE BOILER WAS TAKEN OUT OF SERVICE FOR APPROXIMATELY
SI HOURS DUE TO A TUBE LEAK.
A BOILER INSPECTION AND AN ELECTRICAL SHORT IN THE CONTROLS CAUSED THE
FED SYSTEM TO SHUT DOWN WITH THE BOILER FOR APPROXIMATELY 1 1/2 HOURS.
186
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESI6N AND PERFORMANCE OAT* FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
(ROSS UNIT GENERATING CAPACITY - MM
WET UNIT 6ENERATIN6 CAPACITY W/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/S
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
.. MATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER'S
•• TREATMENT
TYPE
»• DISPOSAL
TYPE
- X
SOUTHERN ILLINOIS
MARION
4
MARION
ILLINOIS
173.0
161.0
173.0
POWER COOP
COAL/REFUSE
BITUMINOUS
23841.
16.69
17.20
3.75
.10
WET SCRUBBING
LIMESTONE
BABCOCK t UILCOX
NEW
2.3
5/79
6/79
89.40
.00
38.0
.6
( 10250 BTU/LB)
CLOSED
(*•**•* 6PM)
FLVASH STABILIZATION
LANDFILL
— — ———PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
13/79
11/79
12/79
SYSTEM
SYSTEM
SYSTEM
100
100
.0
.0
26
71
.0
.7
.0
74*
720
744
0
192
528
0
192
528
.0
** PROBLEMS/SOLUTIONS/COMNENTS
THE UNIT HAS DOWN FROM OCTOBER 1 THROUGH NOVEMBER 17 FOR A BOILER/TURBINE
INSPECTION. NO MAJOR FGD RELATED PROBLEMS HERE ENCOUNTERED DURING THE
FOURTH QUARTER OF 1979 OTHER THAN SOME FREEZE-UPS CAUSED BY THE WINTER
HEATHER.
1/80
2/60
J/BO
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
10.0
31.0
48.4
744
696
744
72
216
360
72
216
360
•» PROBLEMS/SOLUTIONS/COMMEMTS
DURING JANUARY THE LOU BOILER AND SCRUBBER HOURS HERE A RESULT OF AN
18 DAY BOILER OUTAGE NEEDED FOR CORRECTION OF TUBE PROBLEMS. BOILER
OUTAGES DUE TO TUBE PROBLEMS HERE ALSO EXPERIENCED IN FEBRUARY AND MARCH.
THE ONLY REPORTED FGD-RELATED PROBLEM DURING THE FIRST QUARTER OF 1980 WAS
187
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
S3UTHERN ILLINOIS POKER COOP: MARION 4 (CONT.)
------------------------------------------ PERFORMANCE DATA ------------------------------- -— ------- .
PERIOD NODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
$02 PART. HOURS HOURS HOURS FACTOR
i/80
MAINTAINING THE BELT ALIGNMENT IN THE SLUDGE DISPOSAL SYSTEM.
SYSTEM 66.7 66.7 66.7 66.7 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
480 81.3
SHAFT BREAKAGE UITHIN THE RECLAIM WATER PUMP CAUSED FGD SYSTEM OUTAGE TINE
DURING APRIL.
58. 8
32.3
744
408
240 49.6
5/80 SYSTEM 77.4 58.8
• * PROBLEMS/SOLUTIONS/COMMENTS
A BOILER OUTAGE CAUSED THE FGD SYSTEM NOT (TO OPERATE FOR TWO WEEKS.
SHAFT BREAKAGE UITHIN THE WATER RECLAIM PUMP CONTINUED THROUGH HAY.
6/80 SYSTEM 50.0 50.0 50.0 50.0 720 720 360 82.3
*• PROBLEMS/SOLUTIONS/COMMENTS
SHAFT BREAKA6E WITHIN THE WATER RECLAIM PUMP CONTINUED TO CAUSE FGD
OUTAGE TIME. A SOLUTION HAS BEEN PROPOSED TO SIPCO BY THEIR ENGINEERING
CONSULTANT FOR CONSIDERATION.
7/80 SYSTEM 96.7 100.0
** PROBLEMS/SOLUTIONS/COMRENTS
100.0
95.9
744
714
714 82.0
AFTER REVIEW OF THE PROPOSED SOLUTION OF THE SHAFT BREAKAGE PROBLEM WITHIN
THE RECLAIM WATER PUMP, SIPCO AUTHORIZED THEIR CONSULTANT TO PROCEED
WITH THE WORK TO CORRECT THE PROBLEM.
S/80 SYSTEM 100.0 100.0
** PROBLENS/SOLUTIONS/CONMENTS
100.0
90.5
744 673
673 89.6
PROBLEMS WITH THE SHAFT BREAKAGE IN THE RECLAIM WATER PUMPS CONTINUED
THROUGH AUGUST. A REPLACEMENT PUMP HAS BEEN PURCHASED TO SOLVE THE
PROBLEM.
9/80
A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
720 720 7ZO 100.0
*• PROBLEMS/SOLUTIONS/COMMENTS
SUMMARY OF GENERAL PROBLEMS TO DATE
THE MAJOR CAUSES OF SCRUBBER OUTAGES HAVE CENTERED AROUND COLD WEATHER-RE-
LATED CONVEYOR BELT AND PIPING PROBLEMS, PU6 MILL BEARING FAILURES, AND
RECLAIM WATER PUMP SHAFT FAILURES. OTHER PROBLEMS HAVE BEEN RELATED TO
PROCESS CHEMISTRY CONTROL. THE UTILITY REPORTED THAT NUMEROUS SMALL PRO-
BLEMS ALSO HAVE OCCURRED BUT HAVE GENERALLY BEEN CORRECTED SOON AFTER THEIR
DISCOVERY. DETAILS OF THE PRIMARY SCRUBBER PROBLEMS ARE OUTLINED BELOW:
COLD WEATHER PROBLEMS
THE MOST SEVERE FREEZING PROBLEM CONCERNS THE SLUDGE CONVEYOR SYSTEM.
WHEN THE AMBIENT TEMPERATURE DROPS BELOW 30 F THE CONVEYOR SYSTEM BE-
COMES INOPERABLE. THE UTILITY HAS ATTEMPTED TO REMOVE THE FROZEN SLUDGE
USING VARIOUS COMMERCIAL AND COMPANY-BUILT SCRAPERS WITH LITTLE SUCCESS.
THE UTILITY ALSO INSTALLED HEATERS AT THE VARIOUS TRANSFER POINTS TO
THAW THE SLUDGE. THIS PROVED UNSUCCESSFUL AS WELL. THE PROBLEM HAS NOT
YET BEEN SOLVED.
AN ADDITIONAL PROBLEM WITH THE CONVEYOR SYSTEM HAS BEEN THE FAILURE OF
THE BELT TO TRACK CORRECTLY. ON SEVERAL! OCCASIONS THE BELT HAS TOUCHED
THE STRUCTURAL STEEL SUPPORTS RESULTING IN BELT DAMAGE. HOWEVER, BY RE-
188
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SOUTHERN ILLINOIS POWER COOP: MARION 4 (CONT.)
.... — PERFORMANCE DATA-——— ———— " ~
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
DUCIN6 THE CONVEYOR SPEED THE UTILITY HAS INCREASED THE ESTIMATED BELT
LIFE FROM FIVE TO 10 YEARS.
THE OTHER COLD HEATHER PROBLEM IS RELATED TO THE SCRUBBER VESSEL PIPING
SYSTEM. ON SEVERAL OCCASIONS MATER LINE FREEZE UPS HAVE RESULTED IN
SCRUBBER OUTAGES. WHEN THE PROBLEM HAS DISCOVERED, THE UTILITY IN-
STALLED EXTENSIVE HEAT TRACING ON EXPOSED HATER LINES. ALTHOUGH THERE
HAS BEEN NO COLD HEATHER SINCE THE HEAT TRACING INSTALLATION. THE
UTILITY BELIEVES THAT THE PROBLEM IS SOLVED.
PUG MILL PROBLEM
SEVERAL BEARING FAILURES HAVE OCCURRED ON THE PUG MILL. THE UTILITY
HAS INCREASED THE MAINTENANCE ON THE MILL SYSTEM TO LESSEN THE LIKELI-
HOOD OF ANOTHER FAILURE. THE UTILITY REPORTED THAT IF THIS PROCEDURE
MODIFICATION DOES NOT INCREASE THE PUG MILL RELIABILITY TO AN ACCEPTABLE
LEVEL OTHER ACTION HILL BE TAKEN.
RECLAIM HATER PUMP SHAFT FAILURE
THE RECLAIM WATER PUMPS PRODUCE A VERY F.LAT OUTPUT PRESSURE CURVE BUT
THET FEED A SYSTEM COMPOSED OF MANY AUTOMATICALLY CONTROLLED DIAPHRAGM
VALVES. THE OPENING AND CLOSING OF THESE VALVES EXPOSES THE PUMPS TO
A HIDE VARIABILITY IN HATER REQUIREMENTS. MOTOR SHAFT FATIGUE RESULTS
VHEN THE PUMPS ATTEMPT TO RESPOND TO THE. VARIABLE DEMAND. THE SYSTEM
SUPPLIER IS CURRENTLY SUPPLYING THE UTILITY UITH INFORMATION ON THE
OPERATION OF THE DIAPHRAGM VALVES. THE UTILITY'S CONSULTANT ENGINEERING
FIRM HILL REVIEU THE MATERIAL AND SUGGEST POSSIBLE CONTROL VALVE
CHANGES. THE UTILITY REPORTED THAT IF IHIS IS NOT POSSIBLE OR DOES NOT
WORK, A DESIGN CHANGE TO A DIFFERENT PUMP TYPE HILL BE CONSIDERED.
WHILE THE PROBLEM CONTINUES, THE UTILITY. IS KEEPING A COMPLETE SHAFT AND
IMPELLER ON SITE.
PROCESS CHEMISTRY
THE UTILITY HAS LOST CONTROL OF THE PROCESS CHEMISTRY SEVERAL TIMES.
THE SLURRY SOLIDS LEVEL HAS CONSEQUENTLY INCREASED TO THE POINT THAT
THE THICKENER RAKE HAS BECOME INOPERABLE. TO SOLVE THE PROBLEM THE
UTILITY HAS BEEN IMPROVING THE CHEMISTRl MONITORING SYSTEM. IN THE
INTERIM, WHERE EXISTING MONITORS ARE OUT OF SERVICE, LAB PERSONNEL
PERFORM MANUAL TESTS TO MAINTAIN PROCESS CHEMISTRY CONTROL.
THE BOILER AND THE FGD SYSTEM OPERATED THE ENTIRE MONTH OF SEPTEMBER HITH
NO PROBLEMS.
189
-------
EP* UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
EftOSS UNIT GENERATING CAPACITY - MW
NET UNIT 6ENERATIN6 CAPACITY U/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• • GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
$02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•* TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
SOUTHERN INDIANA 6A9 > ELEC
A.B. BROWN
1
WEST FRANKLIN
INDIANA
265.0
2SO.O
265.0
COAL
BITUMINOUS
25819.
9.40
13.30
3.35
.05
WET SCRUBBING
DUAL ALKALI
FMC
NEW
.8
3/79
4/79
85.00
99.50
20.0
.3
CLOSED
*******
NONE
LANDFILL
( 11100 BTU/LB)
(***** 6PM)
---——————————————-PERFORMANCE DATA--
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 A 99.0 96.5 99.1 96.4
B 99.0 99.0 99.1 99.0
SYSTEM 99.0 98.0 99.1 97.7
744 744 727 65.8
** PROBLEMS/SOLUTIONS/COMMENTS
SEVEN HOURS OF FGD SYSTEM FORCED OUTAGE TIME DURING JANUARY WERE CAUSED
BY A THICKENER RAKE STALL.
2/80
A
B
SYSTEM
99.1
98.4
98.8
70.3
70.0
70.2
98.8
97.8
98.3
69.4
68.7
69.1
696 687
75.5
** PROBLEMS/SOLUTIONS/COMMENTS
SOME OUTAGE TIME IN FEBRUARY RESULTED FROM A WET SLUDGE PRODUCT.
CHEMICAL IMBALANCE CAUSED THE SLUDGE PROBLEM.
3/80
A
B
SYSTEM
98.7
99.2
99.0
64.8
51.6
58.2
95.2
94.3
95.8
26.5
21.1
23.8
744
304
177 23.8
190
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SOUTHERN INDIANA G«S t ELEC: A.B. BROUN 1 (CONT.)
_____— _____——__ —-PERFORMANCE DATA———- ——————— ——
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLENS/SOLUTIONS/COMMENTS
DURING MARCH, BOILER DOWN TIME WAS DUE TO A SCHEDULED UNIT OUTAGE* DURING
WHICH TIME MAINTENANCE HAS PERFORMED ON THE SCRUBBER.
4/80
A
8
SYSTEM
100.0
100.0
100.0
96.8
99.7
98.3
100.0
100.0
100.0
92.9
95.7
94.3
7?0 691
679 58.6
PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL, THERE HERE NO OPERATIONAL PROBLEMS WITH THE FGD SYSTEM.
SYSTEM VAS AVAILABLE 100X OF THE TIME.
THE
5/80
A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
82.8
82.8
82.8
744 604
616 53.7
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING KAY NO FORCED OUTAGES WERE EXPERIENCED WITH THE FGD SYSTEM. THE
BOILER WAS OFF LINE FOR 140 HOURS DURING THE MONTH FOR GENERAL MAINTENANCE,
DURING WHICH TIME SOME GENERAL FGD SYSTEM MAINTENANCE WAS ALSO PERFORMED.
4/80
A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
98.2
98.2
98.2
720 706
707 55.4
*• PROBLEMS/SOLUTIONS/COMMENTS
NO FGD RELATED PROBLEMS WERE REPORTED FOR THE MONTH OF JUNE.
SYSTEM OPERATED 100X OF THE TIME THE BOILER WAS ON LINE.
THE FGD
7/80
A
B
SYSTEM
98.1
86.8
92.4
97.9
87.7
92.8
97.9
87.7
92.8
92.5
82.9
87.7
744 703
653 62.6
•• PROBLEMS/SOLUTIONS/COMMENTS
THE B NODULE RECIRCULATION PUMPS WERE THE MAJOR CAUSE OF DOWNTIME. TWO
PIECES OF THE CHEVRON MIST ELIMINATOR FELL CAUSING THE SUCTION LINES TO
PLUG.
ADDITIONAL PROBLEMS WITH THE PUMP WERE CAUSED BY THE THRUST BEARING.
WAS CORRECTED BY THE MANUFACTURER.
THIS
THE UNAVAILABILITY OF THE VACUUM FILTERS AND ASSOCIATED EQUIPMENT REQUIRED
THE SCRUBBER TO SHUTDOWN TO AVOID A STOPPAGE OF THE THICKENER RAKE. THIS
SITUATION ACCOUNTED FOR APPROXIMATELY 15 HOURS OF SYSTEM OUTAGE TIME
DURING JULY.
3/80
A
B
SYSTEM
94.5
94.8
94.6
94.5
94.8
94.6
94.5
94.8
94.6
94.5
94.8
94.6
744 744
704 61.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE MAJOR CAUSE OF UNAVAILABLITY FOR AUCUSI WAS PROBLEMS WITH SOLIDS
DISPOSAL, INCLUDING PROBLEMS WITH PRIMARY LIQUID-SOLID SEPARATION UP TO
AND INCLUDING FINAL LANDFILLING.
9/80
A
B
SYSTEM
100.0
100.0
100.0
99.6
99.6
99.6
99.6
99.6
99.6
99.6
99.6
99.6
720 720
717 $9.8
191
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SOUTHERN INDIAN* GAS I ELEC: A.B. BROWN 1 CCONT.)
... PERFORMANCE BATA — . ——__
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP."
S02 PART. HOURS HOURS HOURS FACTOR
»* PROBLE1S/SOLUTIONS/COMHENTS
SLUDGE DISPOSAL REMAINS THE HOST PREVALENT PROBLEM DUE TO MECHANICAL
BREAKDOWN OF THE DISPOSAL TRUCKS AND UNDERFLOW PUMPS, IN ADDITION TO THE
HIGH MAINTENANCE REQUIREMENTS OF THE ROTARY VACUUM FILTERS.
THE MONTH OF SEPTEMBER ALSO SAW AN EXTREMELY HIGH RATE OF FAILURE OF
RECIRCULATION PUMPS, WITH DAMAGE TO THE RUBBER LINED CASINGS AND IMPELLERS
THE CAUSE OF THIS PROBLEM IS UNKNOWN TO THE UTILITY AT THIS POINT.
192
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EPA UTILITT F60 SURVEY: JULT - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUM3ER
CITY
STATE
5R05S UNIT GENERATING CAPHCITY - MM
*ET JNIT GENERATING CAPACITY U/FGD - Mb
EBUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP BATE
COHHERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A3SORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
»* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•* DISPOSAL
TYPE
- X
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
SPRINGFIELD
MISSOURI
194.0
173.0
194.0
( 11500 BTU/LB)
COAL
BITUMINOUS
26749.
13.00
9.00
3.50
.30
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
4.6
4/77
9/77
eo.oo
99.70
20.0
.3
CLOSED
LANDFILL
(*..«* GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 S-1
S-2
SYSTEM
54.5
68. 7
61.6
38.7
72.6
55.7
47.9
73.1
60.5
36.3
68.1
52.2
744
698
388 65.4
«• PROBLEMS/SOLUTIONS/COMMENTS
2/80
S-1
S-2
SYSTEM
36.7
73.8
55.3
AT THE BEGINNING OF JANUARY AN S-1 ID FAN EXPANSION JOINT FAILED.
BOILER WAS SHUTDOWN SOON AFTER FOR BOILER-RELATED PROBLEMS.
THE
DURING THE LATTER PART OF THIS PERIOD THE S-1 MIST ELIMINATOR AND TRAP OUT
TRAY HEADER FROZE. AFTER REPAIRS WERE MADE BOTH MODULES WERE PUT ON LINE.
BOTH WERE KEPT RUNNING UNTIL JANUARY 20 WHEN A FLANGE BROKE LOOSE ON THE
HIST ELIMINATOR HEADER.
AFTER MIST ELIMINATOR REPAIRS WERE COMPLETED THE S-1 MODULE OPERATED UNTIL
JANUARY 27 WHEN FREEZING AIR LINES TO THE BALL MILLS PREVENTED THE USE OF
BOTH MODULES DUE TO THE LACK OF SLURRY.
THE S-2 MODULE WAS ON LINE AT THE BEGINNING OF THE MONTH BUT DEVELOPED
PRESATURATOS SPRAY NOZZLE PROBLEMS. WHILE THIS WAS BEING REPAIRED THE
UNIT WAS TAKEN OFF LINE. APART FROM THIS IIME THE MODULE WAS ON LINE.
2P.1
71.7
5".4
31.5
73.2
52.4
29.1
71.6
5C.4
696 695
350 59.9
193
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SPRINGFIELD CITY UTILITIES: SOUTHWEST 1 (CONT.)
PERFORMANCE OAT A
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•* PROBLEMS/SOLUTIONS/COMMENTS
THE S-1 MODULE WAS OUT OF SERVICE IN THE FIRST PART OF FEBRUARY OUE TO
FROZEN AND BROKEN LINES. THE SUPERNATE LINE BROKE IN SEVERAL PLACES TAKING
BOTH MODULES OUT OF SERVICE FOR SEVERAL DAYS. ONCE THIS HAS REPAIRED BOTH
MODULES WERE IN SERVICE AS REQUIRED BY LOAD EXCEPT FOR A FEU MINOR TRIPS.
THE S-2 MODULE WAS EITHER IN SERVICE OR AVAILABLE FOR HOST OF THE MONTH.
5/80
S-1
S-2
SYSTEM
64.5
22.0
43. 3
64.1
5.8
35.0
64.4
6.9
35.7
64.1
5.8
35.0
7*4
744
260 57.7
• * PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE S-1 MODULE WAS OUT FOR 11 DAYS TO CLEAN THE ABSORBER
SECTION.
THE S-2 MODULE WAS OUT OF SERVICE FOR CLEANING THE ABSORBER SECTIONS AND
MIST ELIMINATORS FOR NEARLY ALL THE PERIOD BUT WAS AVAILABLE ON MARCH
25. IT WAS NOT OPERATED, HOWEVER, BECAUSE OF LOU UNIT LOAD DEMANDS.
4/80 S-1
S-2
SYSTEM
78.2
15.1
46.7
69.1
6.9
37.9
37.9
59.6
6.0
32.8
720
621
236 42.4
*• PROBLEMS/SOLUTIONS/COMMENTS
THE S-1 MODULE EXPERIENCED SHORT OUTAGES DURING APRIL CAUSED BY SLURRY
DRAW-OFF PUMP FAILURES AND MIST ELIMINATOR AND PRESATURATOR SPRAY SYSTEM
PROBLEMS.
THE S-2 MODULE EXPERIENCED RECURRING HIGH FLUE GAS TEMPERATURE-RELATED
PROBLEMS DURING THE MONTH. THIS WAS CORRECTED BY REPAIRING THE SCRUBBER
INLET SCREEN.
5/80 S-1
S-2
SYSTEM
72.9
43.6
58.3
60.7
30.7
45.7
69.1
35. 2
52.2
60.6
30.7
45.7
74*
744
340 56.7
»* PROSLEMS/SOLUTIONS/COMMENTS
DURING MAY THE S-1 SCRUBBER KEQUIRED CLEANING.
PUMP AND PUMP CONTROL PROBLEMS ON THE S-1 SCRUBBING TRAIN OCCURRED
DURING THE PERIOD.
THE S-2 MODULE WAS OFF LINE SEVERAL DAYS BECAUSE OF RECYCLE PUMP AND
RECYCLE SYSTEM REPAIRS.
4/80 S-1
S-2
SYSTEM
FLUE GAS OUTLET DUCT REPAIRS WERE REQUIRED ON THE s-2 MODULE IN MAY.
85.6 85.5 84.9
6.8 7.2 6.8
45.8 47.4 45.8 720 720 330 66.6
*« PROBLEMS/SOLUTIONS/COMMENTS
85.4
12.8
49.2
THE S-1 MODULE WAS IN CONTINUOUS SERVICE DURING JUNE WITH SHORT DURATION
OUTAGES FOR CLEANING, CONTROL SYSTEM DAMAGE CAUSED BY LIGHTNING, AND OTHER
MINOR MISCELLANEOUS PROBLEMS.
THE S-2 MODULE HAS OUT OF SERVICE FOR APPROXIMATELY 23 DAYS IN JUNE BECAUSE
OF A BROKEN SLURRY HOLD TANK AGITATOR SHAFT.
IN ADDITION TO THE OUTAGE CAUSED BY THE BROKEN SHAFT, THE S-2 MODULE HAD
SHORT DURATION OUTAGES CAUSED BY RECYCLE PUMP AGITATOR PROBLEMS, CONTROL
SYSTEM PROGRAMMING, AND OTHER MINOR MISCELLANEOUS PROBLEMS.
194
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SPRINGFIELD CITY UTILITIES: SOUTHWEST 1 (CONT.)
. --- "PERFORMANCE DATA ——
»ERIOD NODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/BO S-1
S-2
SYSTEM
80.5
57.0
68.7
69.6
39.0
54.3
69. 5
39.0
54.3
72.4 54.3 744 743 404 80.6
** PROBLE1S/SOLUTIONS/COM«ENTS
DURING JULY THE S-1 MODULE WAS CLEANED AND THE SPHERES WERE REPLACED.
THE S-1 MODULE DUCTWORK NEEDED REPAIR DURING JULY CAUSING SOME OUTAGE TIME.
THE SLUDGE DEWATERING FILTER BELT AND THE HOLD TANK BEARING FAILED
ACCOUNTING FOR SOME OF THE S-1 MODULE DOWNTIME.
THE S-1 MODULE SPRAY CONTROL VALVE FAILED ADDING TO THE OUTAGE TIME.
HIGH FLUE GAS TEMPERATURE CONDITIONS RESULTED IN A SHUTDOWN OF BOTH THE
FGD MODULES.
THE S-2 MODULE AGITATOR SHAFT IN THE HOLD TANK FAILED CAUSING THE MODULE
TO COME OFF LINE.
PROBLEMS WERE ENCOUNTERED WITH THE SLURRY DRAW OFF PUMP, SUPERNATANT PUMP
AND THE RECYCLE PUMP CAUSING THE S-2 MODULE TO SHUTDOWN.
A POWER SUPPLY EflUIPMENT FAILURE RESULTED IN A S-2 MODULE OUTAGE.
AN EXPANSION JOINT FAILURE OCCURRED ON THE S-2 MODULE SEAL AIR FAN.
A HIGH LEVEL CONDITION IN THE DRAW OFF SUMP WAS ALSO A CAUSE OF THE
S-2 MODULE LOW AVAILABILITY. THE PROBLEMS EXPERIENCED WITH THE CONTROL
SYSTEM CONTRIBUTED ALSO.
3/80 S-1
S-2
SYSTEM
73.7
71.9
72.8
67.4
55.4
61.4
62.4
67.4
55.4
61.4
744
744
457 86.2
*• PR03LEMS/SOLUTIONS/COMMENTS
THICKENER PROBLEMS ENCOUNTERED DURING AUGUST CAUSED BOTH MODULES TO
SHUT DOWN FOR PART OF THE MONTH.
THE OUTLET DUCT EXPERIENCED LEAKAGE CAUSING SOME SYSTEM DOWN TIME.
THE S-1 MODULE DAMPER DRIVE FAILED CAUSED ADDITIONAL OUTAGE TIME.
THE LIMESTONE FEEDER FOR MODULE S-2 FAILED CAUSING THE S-2 MODULE TO
SHUT DOWN FOR PART OF THE MONTH.
THE FGD SYSTEM WAS SHUT DOWN DURING PART Of THE MONTH SO THAT VALVE REPAIRS
COULD BE MADE.
PROBLEMS WERE ENCOUNTERED WITH THE S-2 MODULE RECYCLE PUMP.
?/80 S-1
S-2
SYSTEM
78.5
57.5
68.0
85.8
.6
43.2
87.4
.2
43.8
78.5
.2
39.4
720 658
283 80.3
»• PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER, THE SCRUBBER OUTLET DUCTS EXPERIENCED LEAKING CAUSING
THE SYSTEM TO SHUTDOWN FOR PART OF THE MONTH.
THE S-1 NODULE EXPERIENCED INLET DAMPER PROBLEMS.
THE RECYCLE SPRAY NOZZLES ON THE S-2 MODULE PLUGGED CAUSING ADDITIONAL
OUTAGE TIME.
195
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFOR"ANCE DATA FOB OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
5ROSS UNIT GENERATING CAPACITY - MW
NET JNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
ST. JOE ZINC
G.F. WEATON
1
MONACA
PENNSYLVANIA
60. 0
60.0
60.0
COAL
BITUMINOUS
29075.
11.50
*»******
2.00
.20
WET SCRUBBING
CITRATE
MORRISON t KNUDSEN/U.S,
RETROFIT
( 12500 BTU/LFJ)
B.M.
11/79
1/80
90.00
X 99.60
.3
.0
•« WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
CLOSED
(«»*.* GPM)
ELEMENTAL SULFUR
. . -PERFORMANCE DATA —
PERIOD HODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/60 SYSTEM
2/80 SYSTEM
5/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE SYSTEM IS STILL GOING THROUGH THE DEBUGGING PHASE OF OPERATION. SOME
EQUIPMENT PROBLEMS HAVE OCCURRED, ESPECIALLY WITH THE HYDROGEN SULflDE
GENERATOR AND HEAT EXCHANGERS, ONE OF WHICH HAD TO BE REMOVED AND RETURNED
TO THE MANUFACTURER. NO OPERATING HOURS WERE LOGGED DURING THE FIRST
QUARTER OF 1980 BRINGING THE TOTAL SYSTEM OPERATING HOURS TO 42 IN 1979.
WBO SYSTEM
5/30 SYSTEM
4/80 SYSTEM
•« PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE GEORGE F. UNEATON STATION HAS BEEN OPERATING AT A REDUCED LOAD OF 2P
TO 30 MW SINCE DECEMBER, 1979 DUE TO THF SHUTDOWN OF THE ST. JOE ZINC co.
SMELTER. ALTHOUGH A NUMBER OF TRIAL RUNS OF THE CITRATE DEMONSTRATION
PLANT HAVE BEEN MADE DURING THE PAST SIX MONTHS, MECHANICAL BREAKDOWNS OF
EQUIPMENT AND PROBLEMS RELATED TO LOU TEMPERATURE OPERATION HAVE PREVENTED
CONTINUOUS OPERATION TO OBTAIN MEANINGFUL DATA. ST. JOE IS ATTEMPTING TO
196
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
ST. JOE ZINC: G.F. WEATON 1 (CONT.)
„__ PERFORMANCE DATA — —~ ~ —
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
SO? PART. HOURS HOURS HOURS FACTOR
NEGOTIATE A POWER SALES AGREEMENT THAT WILL PERMIT FULL UTILIZATION OF THE
STATION CAPACITY AND ALSO PROVIDE DESIGN FLUE GAS QUANTITIES TO THE DEMON-
STRATION PLANT. OPERATION OF THE POWER PLANT AT THE DESIGN RATES IS RE-
QUIRED FOR ACCEPTANCE AND DEMONSTRATION TESTING.
7/80 SYSTEM 7*4
5/80 SYSTEM 74*
** PROBLtMS/SOLUTIONS/COHMENTS
THE CITRATE PROCESS DID NOT OPERATE DURING THE MONTHS OF JULY AND AUGUST
1980.
NEGOTIATIONS TO PERMIT THE POUER PLANT TO OPERATE AT HIGHER RATES AND
ALLOW THE DEMONSTRATION PLANT TEST PROGRAM TO PROCEED AS PLANNED ARE
CONTINUING.
9/80 SYSTEM 720
•* PROBLEMS/SOLUTIONS/COMMENTS
NEGOTIATIONS MENTIONED EARLIER CONTINUED THROUGH SEPTEMBER. MINIMAL
F&D OPERATIONS WERE REPORTED FOR THE MONTH.
197
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
OESI6N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - NU
1ET UNIT GENERATING CAPACITY V/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - *U
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
HEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A9SORBER SPARE CAPACITY INDFX - X
ABSORBED SPARE COMPONENTS INDEX
•• HATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
- X
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
PADUCAH
KENTUCKY
10.0
10.0
19.0
COAL
BITUMINOUS
2.90
« (»***.* BTU/LB)
UET SCRUBBING
LIME/LIMESTONE
AIR CORRECTION DIVISIONt OOP
RETROFIT
4/72
»*/ **
90.00
.3
.0
CLOSED
(»***-* 6PM)
.—_.- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
3/60 SYSTEM
*» PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR SHAWNEE 10B.
198
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/FGD - NW
EQUIVALENT SCRUBBED CAPACITY - MW
• * FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
• • WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10B
PADUCAH
KENTUCKY
10.0
10.0
10.0
COAL
BITUMINOUS
(****«* BTU/LB)
2.90
********
WET SCRUBBING
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
RETROFIT
4/72
**/**
90.00
********
.0
.0
CLOSED
(•***• 6PM)
_.__„_——--—--—— —PERFORMANCE DATA—-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
SO? PART.
PER BOILER F6D CAP.
HOURS HOURS HOURS FACTOR
|/80 SYSTEM
2/80 SYSTEM
3/60 SYSTEM
«• PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
DURING THE FIRST QUARTER OF 1980, ONLY THE VENTURI/SPRAV TOMER SYSTEM UAS
OPERATED. THE TCA SYSTEM CONTINUED TO OPERATE DURING THE QUARTER ON DOWA
BASIC ALUMINUM SULFATE PROCESS UNDER EPRI/UOP/TVA SPONSORSHIP.
THE LIMESTONE/ADIPIC ACID TEST SERIES ON THE VENTURI/SPRAY TOWER SYSTEM,
WHICH HAD BEEN INITIATED IN MID-DECEMBER TO INVESTIGATE THE RELATIONSHIP
BETWEEN THE SLURRY PH AND THE ADIPIC ACID CONSUMPTION {DEGRADATION) RATE,
UAS COMPLETED IN MID-FEBRUARY. THE TESTS WERE CONDUCTED WITHOUT FORCED
OXIDATION AND WITH A SINGLE HOLD TANK. AT THE SCRUBBER INLET PH OF 4.6
TO 5.0, ESSENTIALLY ALL OF THE ADIPIC ACID ADDED WAS ACCOUNTED FOR IN
THE LIQUID PHASE Of THE WASTE SLUDGE DISCHARGED FROM THE SYSTEM. AT THE
SCRUBBER INLET PH 5.25 AND 5.5, THE ADIPIC ACID UNACCOUNTED FOR WERE
6X AND 26X , RESPECTIVELY. THEREFORE. IT APPEARS THAT THE ADIPIC
ACID COR CARBOXYLIC ACID) DEGRADATION TAKES PLACE AT SCRUBBER INLET
PH ABOVE ABOUT 5.1 UNDER CONDITIONS ASKED.
A SERIES OF LIMESTONE/ADIPIC ACID TESTS WERE CONDUCTED FROM MID-FEBRUARY
TO EARLY MARCH USING THE VENTURI SCRUBBER ONLY WITH A SINGLE TANK AND
WITHOUT FORCED OXIDATION TO INVESTIGATE THE S02 REMOVAL CAPABILITY OF THE
VENTURI AT 5.1 INLET PH AND HIGH ADIPIC ACID CONCENTRATION. AT 4000 PPM
ADIPIC ACID. L/G OF 21 GAL/MCf, AND 8.3 INCHES H20 PRESSURE DROP, S02
REMOVAL WAS 65X WITH 2200 PPM INLET S02 CONCENTRATION.
FORCED OXIDATION USING A SINGLE TANK WITH LIMESTONE/ADIPIC ACID SLURRY ON
THE VENTURI/SPRAY TOWER SYSTEM BEGAN IN MID-MARCH. AS IN THE CORRESPONDING
TEST SERIES CONDUCTED ON TCA IN APRIL 1979, LIMESTONE BLINDING BY CALCIUM
SULFITE OCCURRED. SOLUTION OF THE PROBLEM CAN BE EXPECTED BY USING TWO
199
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19PO
TENNESSEE VALLEY AUTHORITY: SHAWNEE 1CB (CONT.)
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
TANKS IN SERIES WITH FORCED OXIDATION IN THE FIRST TANK AND LIMESTONE
ADDITION IN THE SECOND. THIS MODE IS PLANNED ON BEING DEMONSTRATEB NEXT
QUARTER.
W80 SYSTEM "0
S/gn SYSTEM 744
4/80 SYSTEM 720
• * PROBLEMS/SOLUTIOHS/COMMENTS
THE VENTURI/SPRAY TOMER SYSTEM (TRAIN 100) WAS SHUT DOUN FROM HAY 28
THROUGH JUNE 17 FOR CONVERSION TO A SPRAY TOWER-ONLY SYSTEM BY THE PHYSICAL
REMOVAL OF THE VENTURI SECTION. THE SPRAY TOWER-ONLY TESTING BEGAN
JUNE 17 ON A SERIES OF LIMESTONE FACTORIAL TESTS, BOTH WITH AND WITHOUT
FORCED OXIDATION, TO CHARACTERIZE THE EFFECTS OF LIQUID-TO-6AS RATIO AND
SLURRY PH ON SO? REMOVAL IN THE SPRAY TOWER (THE FIRST SPRAY TOWER-ONLY
TESTING AT SHAWNEE).
7/80 SYSTEM 7*4
S/80 SYSTEM 7*4
J/80 SYSTEM 720
•• PROBLEMS/SOLUTIONS/COMMENTS
TRAIN 100 WAS AGAIN SHUT DOWN FROM AUGUST 11-38 FOR MODIFICATION OF THE
SLURRY PIPING AND INTERNAL HEADERS TO INCREASE THE SLURRY FLOW CAPACITY
FROM 1600 TO 2400 GPM. TESTING RESUMED ON AUGUST 28 ON ANOTHER
LIMESTONE FACTORIAL TEST SERIES WITH AND WITHOUT FORCED OXIDATION, BUT AT
HIGHER LIQUID-TO-GAS RATIOS (UP TO 150 6AL/.MCF AT 20,000 ACFM AT 300 F GAS
RATE ANO 2400 GPM MAXIMUM SLURRY fLOW fUTEJ. THIS TEST SERIES IS EXPECTED
TO BE COMPLETED BY MID OCTOBER.
TESTING OF THE TCA SYSTEM (TRAIN 200) RESUMED ON JULY 15 AFTER THE SYSTEM
HAD BEEN RESTORED FRO1* THE DOHA PROCESS OPERATING MODE. AS PART Of THE
EPA FULL-SCALE ADIPIC ACID DEMONSTRATION PROGRAM, THE SYSTEM HAD BEEN USED
THROUGHOUT THE THIRD QUARTER TO SIMULATE THE OPERATION OF THE FULL-SCALE
TCA UNITS OPERATING WITH LIMESTONE/ADIPTIC ACID SLURRY AT THE SOUTHWEST
STATION OF THE SPRINGFIELD CITY UTILITIES. AT SPRINGFIELD MISSOURI. TESTS
HAVE BEEN CONDUCTED BOTH WITH ANO WITHOUT FORCED OXIDATION TO GENERATE
INFORMATION USEFUL FOR THE FULL-SCALE DEMONSTRATION.
200
-------
EPA UTIL1TT F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - Mw
VET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
• * FUEL DATA
FUEL TYPE
FJEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
A3SORBER SPARE COMPONENTS INDEX
•* DISPOSAL
TYPE
- X
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
BRIDGEPORT
ALABAMA
550.0
516.0
550.0
( 10000 BTU/LB)
COAL
* ** ***
23260.
25.oo
10.00
3.70
********
WET SCRUBBING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
RETROFIT
4.7
5/77
1/78
70.00
99.50
.0
.0
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2/80
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
A
B
C
D
SYSTEM
70.4
83.5
100.0
28.3
70.6
79.8
100.0
100.0
54.7
83.6
39.2
56.3
55.5
26.9
44.5 83.60
744 366 331 23.9
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE UNIT 8 BOILER EXPERIENCED LOW AVAILABILITY, CAUSING THE
FORCED OXIDATION TESTS TO BE DISCONTINUED UNTIL AFTER THE SCHEDULED
MAINTENANCE OUTAGE WHICH WILL BEGIN IN SEPTEMBER 1980. THE FORCED
OXIDATION TESTS ARE EXPECTED TO RESUME IN JANUARY 1981.
A
B
C
D
SYSTEM
80.0
86.5
91.1
87.6
86.3
83.6
9C.2
97.6
9R.2
93.7
72.7
74.0
80.0
80.6
76.8
84.00
696 571
535 43.6
*• PROBLEMS/SOLUTIONS/COMMENTS
3/80
A
3
C
D
SYSTEM
93.6
93.0
71.9
93.3
86.C
BY FEBRUARY 27, 1980, THE DIFFERENTIAL PRESSURE ACROSS THE TRAIN C ABSORB-
ER HAD REACHED 19 INCHES WATER GAGE. THE HIGH ABSORBER DIFFERENTIAL
PRESSURE WAS CAUSED BY PLUGGING OF TURBULENT CONTACT ABSORBER (TCA)
SPHERES WHICH WERE INSTALLED DURING SCRUBBED OPTIMIZATION TESTS. 1HE TCA
SPHERES WILL BE REMOVED IN MARCH.
88.3
5C.6
73.!
63.9
79.0
85.4
87.9
71.1
62.0
76.6
62.60
744
722
570 50.4
£01
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
TENNESSEE VALLEY AUTHORITY: WIDOWS CREEK 8
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
TENNESSEE VALLEY AUTHORITY: WIDOWS CREEK 8 (CONT.)
—-— — — PERFORMANCE DATA —.- —--—--
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
302 PART. HOURS HOURS HOURS FACTOR
** PR08LEHS/SOLUTIONS/COMMENTS
INFORMATION FOR THE MONTHS OF AUGUST AND SEPTEMBER IS NOT AVAILABLE AT
THIS TIME.
203
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19*0
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - MW
YET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
MEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
C3MMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
A9SORBER SPARE CAPACITY INDEX - X
A3SORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•» TREATMENT
TYPE
•• DISPOSAL
TYPE
- X
TEXAS UTILITIES
MARTIN LAKE
1
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
3J.OO
.90
7380 BTU/LBJ
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
1.3
4/77
10/78
71.00
99.40
.0
.0
CLOSED
34.6
C 550 GPH>
FLYASH STABILIZATION
LANDFILL
. ..—.. ..... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
503 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
J/80 SYSTEM
«• PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/80 SYSTEM
5/80 SYSTEM
4/80 SYSTEM
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER OF 1980, PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR SECTION. THE
HIST ELIMINATOR PLUGGING WAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
WATER FOR HIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
THE FRP STRUCTURAL WORK IS BECOMING A PROBLEM.
WORK WAS REPLACED WITH STAINLESS STEEL.
MUCH OF THE FRP SUPPORT
THE UTILITY HAS PLANS TO INSTALL TWO NEW SCRUBBING TOWERS IN EARLY 1982.
THE NEW TOWERS HAVE BECOME NECESSARY DUE TO THE INCREASING LIGNITE
SULFUR CONTENT AND THE NEED FOR SPARE SCRUBBER CAPACITY.
720
744
720
204
-------
EPA UTILITY FGD SURVEY: JUtY - SEPTEMBER 1980
TEXAS UTILITIES: MARTIN LAKE 1 (CONT.i
.————— .. «—....—-PERFORMANCE DATA—— ——— ————————
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•* PROBLEMS/SOLUTIONS/COMMENTS
HIGH MAINTENANCE PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
THE SECOND QUARTER OF 1980. THE ABSORBERS ARE STILL EXPERIENCING PLUGGING
PROBLEMS.
7/80 SYSTEM 744
•• PROBLEMS/SOLUTIONS/COMMENTS
CORROSION IN THE SCRUBBER NODULES WAS A PROBLEM DURING JULY.
THE FOUNDATION FOR THE TWO NEW SCRUBBING TOUERS WAS COMPLETED DURING THE
MONTH.
J/80 SYSTEM 744
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE FGO SYSTEM OPERATED WITHOUT ANY MAJOR
PROBLEMS DURING AUGUST AND SEPTEMBER.
205
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
WET UNIT GENERATING CAPACITY M/FGD - HW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• * GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
*• WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
** TREATMENT
TYPE
•* DISPOSAL
TYPE
- X
TEXAS UTILITIES
MARTIN LAKE
2
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
33.00
.90
********
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
1.3
5/78
**/**
71.00
99.40
.0
.0
C 7380 BTU/LB)
CLOSED
34.6
( 550 GPM)
FLYASH STABILIZATION
LANDFILL
............ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
fc/80
5/80
6/ao
SYSTEM
SYSTEM
SYSTEM
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER OF I960, PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR SECTION. THE
MIST ELIMINATOR PLUGGING WAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
MATER FOR MIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
THE FRP STRUCTURAL WORK IS BECOMING A PROBLEM.
WORK WAS REPLACED WITH STAINLESS STEEL.
MUCH OF THE FRP SUPPORT
THE UTILITY HAS PLANS TO INSTALL TWO NEW SCRUBBING TOWERS IN EARLY 1983.
THE NEW TOWERS HAVE BECOME NECESSARY DUE TO THE INCREASING LIGNITE SULFUR
CONTENT AND THE NEED FOR SPARE SCRUBBER CAPACITY.
720
744
720
206
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
fEMAS UTILITIES: HARTIN LAKE 2 UONT.)
. .... . . PERFORMANCE DATA —
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION i REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
o» PROBLE^S/SOLUTIOIS/COMHEMTS
HIGH MAINTENANCE PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
THE SECOND QUARTER OF 1980. THE ABSORBERS ARE STILL OPER1EWCIN6 PLU66IN6
PROBLEMS.
f/80 SYSTER 7*4
oo PftOBLEnS/SOLUTIONS/COnnENTS
CORROSION IN THE SCRUBBER MODULES bAS A PROBLEM DURING JULY.
THE FOUNDATION FOR THE 2 NE« SCRUBBING TOUS.RS HAS COMPLETED DURING THE
RONTH.
J/BO SYSTEM 744
J/BO SYSTEH 720
0* PROSLEnS/SOLUTIONS/COMWENTS
THE UTILITY REPORTED THAT THE FGD SYSTEH OPERATED HITHOUT ANY HAJOB
PROBLEMS DURING AUGUST AND SEPTEMBER.
207
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EBUIVALENT SCRUBBED CAPACITY - My
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SOZ DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - t
ABSORBER SPARE COMPONENTS INDEX
•* TREATMENT
TYPE
•• DISPOSAL
TYPE
TEXAS UTILITIES
MARTIN LAKE
3
TATUM
TEXAS
793.0
750.0
595.0
COAL
LIGNITE
17166.
8.00
J3.00
.90
< 7380 BTU/LB)
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
1.3
2/79
**/ **
71.00
- X 99.40
.0
.0
FLYASH STABILIZATION
LANDFILL
. _ — .. .... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
7*4
696
74*
*• PROSLEMS/SOLUTIONS/COMMENTS
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER OF 1980, PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR SECTION. THE
MIST ELIMINATOR PLUGGING WAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
WATER FOR MIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
THE FRP STRUCTURAL WORK IS BECOMING A PROBLEM.
WORK WAS REPLACED WITH STAINLESS STEEL.
MUCH OF THE FRP SUPPORT
1/80 SYSTEM
S/BO SYSTEM
S/80 SYSTEM
THE UTILITY HAS PLANS TO INSTALL TWO NEW SCRUBBING TOWERS IN EARLY 1983.
THE NEW TOWERS HAVE BECOME NECESSARY DUE TO THE INCREASING LIGNITE SULFUR
CONTENT AND THE NEED FOR SPARE SCRUBBER CAPACITY.
720
744
720
208
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
TEXAS UTILITIES: MARTIN LAKE 3 (CONT.)
---————————— ————PERFORMANCE DATA—— ————————
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH MAINTENANCE PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
THE SECOND QUARTER OF 1980. THE ABSORBERS ARE STILL EXPERIENCING PLUGGING
PROBLEMS.
7/80 SYSTEM 7**
•• PROBLEMS/SOLUTIONS/COMMENTS
CORROSION IN THE SCRUBBER MODULES WAS A PROBLEM DURING JULY.
THE FOUNDATION FOR THE 2 NEW SCRUBBING TOWERS WAS COMPLETED DURING THE
MONTH.
5/80 SYSTEM 744
9/80 SYSTEM 720
*• PROBLENS/SOLUTIONS/COMffENTS
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED WITHOUT ANY MAJOR
PROBLEMS DURING AUGUST AND SEPTEMBER.
209
-------
EPA UTILITY F6D SURVET: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
(ROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/F6D - MU
EOUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - S
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* MATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
•• TREATMENT
TYPE
*• DISPOSAL
TYPE
- X
TEXAS UTILITIES
MONTICELLO
3
NT. PLEASANT
TEXAS
800.0
750.0
aoo.o
(••**.** BTU/L61
COAL
LIGNITE
18.90
31.90
1.50
.04
UET SCRUBBING
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
NEU
*******
5/78
10/78
74.00
99.50
.0
.0
CLOSED
( 5*6 GPM)
FLYASH STABILIZATION
LANDFILL
....„...__„„.._ — -...__.. . —PERFORMANCE DATA — — ——"—————
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FSD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS UERE ENCOUNTERED DURING THE FIRST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
*• PROBLEMS/SOLUTIONS/COMMENTS
THE MONTICELLO 3 SCRUBBING SYSTEM PERFORMED UELL THROUGHOUT THE SECOND
BUARTER OF 1980. THE TEXAS AIR CONTROL BOARD REPORTED THAT IT HAD RECEIVED
VERY FEU EXCESS EMISSIONS REPORTS FROM THE STATION DURING THE APRIL-JUNE
PERIOD.
7/80 SYSTEM
744
210
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER I960
TEXAS UTILITIES: MONTICELLD 3 (CONT.)
—PERFORMANCE DATA-- — —————-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGO CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
•* PROBLENS/SOLUTIONS/COMMENTS
NO MAJOR FGD-RELATED PROBLEMS WERE ENCOUNTERED CURING JULY.
S/80 SYSTEM 7*4
»/BO SYSTEM 720
«• PROBLEMS/SOLUTlONS/COfmENTS
THE UTILITY REPORTED THAT THE RECYCLE PUMP LININGS HAVE BEEN A CONTINUAL
PROBLEM DURING AUGUST AND SEPTEMBER. AT ONE TIME DURING THE TWO MONTH
PERIOD THREE RECYCLE PUMP LINERS FAILED.
THE FGD SYSTEM CONTINUES TO PERFORM WELL AND IS IN COMPLIANCE MORE THAN
95Z OF THE TIME.
Z11
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIG-N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
•ROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGO - MU
EQUIVALENT SCRUBBED CAPACITY - My
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - I
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
CONtERCIAL START-UP DATE
S52 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP VATER - LITER/S
UTAH POWER K LIGHT
HUNTER
1
CASTLE DALE
UTAH
400.0
400.0
360.0
( 12500 BTU/LR)
COAL
BITUMINOUS
29075.
10.00
6.50
.55
.00
WET SCRUBBING
LIME
CHEMICO DIVISION. ENVIROTECH
NEW
5/79
5/79
80.00
X 99.50
.0
.0
OPEN
*******
(»***« GPM)
•• TREATMENT
TYPE
»* DISPOSAL
TYPE
FLYASH STABILIZATION
POND
PERFORMANCE DATA .—....—.——.
»Ef»IOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
13/79
11/79
12/79
1/80
2/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.
100.
100.
100.
100.
0
0
0
0
0
95
91
98
95
86
.6
.1
.2
.9
.8
7*4
720
744
744
696
711
656
731
715
604
711
6S6
7J1
713
604
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THERE WERE NO MAJOR FGD PROBLEMS ENCOUNTERED
FROM OCTOBER 1979 THROUGH FEBRUARY 1980.
5/80 SYSTEM 57.8
»* PROBLEMS/SOLUTIONS/CONMENTS
56.9
744 732
423
THE FGD SYSTEM HAS FORCED OF SERVICE IN MARCH BECAUSE THE THICKENER RAKE
SHAFT FAILED AND THE TANK HAD TO BE DRAINED. THIS OUTAGE KEPT THE SYSTEM
DOVN FOR APPROXIMATELY 309 HOURS.
4/80 SYSTEM
5/80 SYSTEM
100.0
100.0
60.1
64.0
720 433
744 476
433
476
212
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
UTAH POWER I LIGHT: HUNTER 1 CCONT.)
PERFORMANCE DATA —-— ———-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE LOU FGD HOURS DURING APRIL AND MAT RESULTED FROM THE ANNUAL OUTAGE
FOR GENERAL FGD SYSTEM MAINTENANCE.
5/80 SYSTEM 100.0 97.9 720 70S 705
*• PROBLEMS/SOLUTIONS/COMMENTS
NO FGD SYSTEM PROBLEMS UERE REPORTED FOR JUNE.
7/80 SYSTEM 100.0 100.0 7** 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR F6D-RELATED PROBLEMS UERE REPORTED DURING JULY.
9/80 SYSTEM 100.0 744 744
9/80 100.0
SYSTEM 720 713
*• PROBLE1S/SOLUTIONS/COHMENTS
THE UTILITY REPORTED THAT NO MAJOR FGD PROBLEMS UERE ENCOUNTERED DURING
THE MONTHS OF AUGUST AND SEPTEMBER.
213
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - N6/J
NET PLANT 6ENERATIN6 CAPACITY - MU
6ROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MW
NET UNIT GENERATING CAPACITY UO/FGD - MU
E3UIVALENT SCRUBBED CAPACITY - MU
UTAH POWER t LIGHT
HUNTER
2
CASTLE DALE
UTAH
B
43.
516.
*******
400.0
400.0
*******
360.0
( .100 LB/MNBTU)
( 1.COO LB/MHBTU)
*• BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOU - CU.H/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK TOP DIAMETER - M
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
RANEE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANEE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROUAUAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEU/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY - X
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
4/80
******** (***«*** ACFM)
******* (**•* F)
****** !*•*» FT>
******* (****• FT)
COAL
******
29075.
10.00
9-12
6.50
******
.55
******
********
( 12500 BTU/LB)
12,COO - 12.700
THROUAUAY PRODUCT
UET SCRUBBING
LIME
CHEMICO DIVISION, EHVIROTECH
STEARNS-ROGER
FULL SCALE
NEU
99.50
80.00
6/80
6/80
ESP
NUMBER 1
SUPPLIER BUELL
FLUE GAS CAPACITY - CU.M/S 886.2
FLUE GAS TEMPERATURE - C 127.8
(1878000 ACFM)
( 262 F)
*• PARTICLE SCRUBBER
TYPE
•* A3SOR3ER
TYPE
INITIAL START UP
SUPPLIER
•* MIST ELIMINATOR
TYPE
NONE
SPRAY TOUER
6/80
CHEHICO DIVISION, ENVIROTECH
CHEVRON
*• REHEATER
TYPE
•• REHEATER
TYPE
HOT AIR INJECTION
BYPASS
214
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
UTAH POWER t LIGHT: HUNTER 2 (CONT.)
»• HATER LOOP
TYPE
** TREATMENT
TYPE
*• DISPOSAL
NATURE
TYPE
LOCATION
OPEN
FLTASH STABILIZATION
FINAL
POND
ON SITE
...—... ... -. PERFORMANCE DATA — —
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
6/BO SVSTEN 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
99.5
720 717 717
INITIAL AND COMMERCIAL OPERATIONS AT HUNTER 2 BEGAN IN JUNE. NO MAJOR
STARTUP PROBLEMS WITH THE F6D SYSTEM HERE ENCOUNTERED.
98.9
74* 736 736
7/80 SYSTEM 100.0
*• PROBLEMS/SOLUTIOVS/COHNENTS
NO MAJOR FGD-RELATED PROBLEMS HERE REPORTED DURING JULY.
8/80 SYSTEM 99.7 74* 7*3
9/80 SYSTEM 100.0 730 720
• * PROBLENS/SOLUTIONS/CONMENTS
THE UTILITY REPORTED THAT NO MAJOR FGD PROBLEMS HERE ENCOUNTERED DURING
AUGUST AND SEPTEMBER.
215
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
VET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENER6Y CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PHRTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
•* WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
•• TREATMENT
TYPE
•• DISPOSAL
TYPE
t LIGHT
( 12500 BTU/LB)
UTAH POWER
HUNTINGTON
1
PRICE
UTAH
430.0
400.0
366.0
COAL
BITUMINOUS
29075.
10.00
6.50
.55
WET SCRUBBING
LIME
CHEHICO DIVISION. ENVIROTECH
NEW
1.6
5/78
5/78
80.00
99.50
.0
.0
CLOSED
18.9
( 300 6PM)
FLYASH STABILIZATION
LANDFILL
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
ID/79 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
744 497
ON OCTOBER 15 FGD OPERATIONS WITH LJMESTON& WERE INITIATED FOR TESTING
PURPOSES. IF THE FGD SYSTEM OPERATIONS ARE ADEQUATE WITH LIMESTONE THE
UTILITY WILL STUDY THE ECONOMIC TRADEOFFS OF LIME VS LIMESTONE SUCH AS
PUMP WEAR ETC. IF THE RESULTS FAVOR LIMESTONE THE HUNTINGTON 1 FGD SYSTEM
NAY BE SHIFTED FROM LIME TO LIMESTONE.
11/79 SYSTEM
12/79 SYSTEM
1/80 SYSTEM
720
744
744
28
642
668
•* PROBLEMS/SOLUTIONS/COMMENTS
DUE TO A LACK OF RECORDS, DATA CONCERNING THE FGD SYSTEM OPERATIONS WAS
UNAVAILABLE FOR THE MONTHS OF OCTOBER 1979 THROUGH JANUARY 1980. IN
NOVEMBER THE BOILER WAS DOWN MOST OF THE MONTH FOR A SCHEDULED UNIT
OVERHAUL.
2/80 SYSTEM
i/80 SYSTEM
100.0
100.0
87.0
89.2
696 60S
744 664
605
664
216
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
UTAH POWER ( LIGHT: HUNTIN6TON 1 (CONT.)
. . ... ....... .. . -PERFORMANCE DATA ———-— .——-———
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION I REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/80 SYSTEM 98.1 92.1 720 676 663
** PROBLENS/SOLUTIONS/COMMENTS
THE FED SYSTEM OPERATED ALONG WITH THE BOILER DURING FEBRUARY AND MARCH
WITH NO MAJOR PROBLEMS.
5/80 SYSTEM 100.0 99.7 74* 742 742
S/BO SYSTEM 100.0 99.2 720 714 714
•• PROBLEMS/SOLUTIONS/CONMENTS
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER DURING THE APRIL THROUGH
JUNE PERIOD EXCEPT FOR A FEW HOURS IN APRIL. THE UTILITY REPORTED THAT
NO MAJOR PROBLEMS OCCURRED DURING THIS TIME.
7/80 SYSTEM 100.0 87.2 744 649 649
*• PROBLEKS/SOLUTIONS/COMMENTS
NO MAJOR F6D-RELATED PROBLEMS WERE REPORTED CURING JULY.
3/80 SYSTEM 100.0 744 695
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED IN AUGUST.
J/80 SYSTEM .0 7?0 0
•* PROBLE1S/SOLUT10NS/COMMENTS
THE FGD SYSTEM AND BOILER WERE DOWN THROUGHOUT SEPTEMBER FOR A SCHEDULED
MAINTENANCE OVERHAUL.
217
-------
EPA UTILITY F6D SURVEYS JULY - SEPTEMBER 1980
SECTION 4
SUMMARY OF F6D SYSTEMS BY COMPANY
TOTAL
COMPANY NAME
ALABAMA ELECTRIC COOP
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
ATLANTIC CITY ELECTRIC
BASIN ELECTRIC POWER COOP
BIG RIVERS ELECTRIC
CAJUN ELECTRIC POWER COOP
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CENTRAL POWER t LIGHT
CINCINNATI 6AS K ELECTRIC
COLORADO UTE ELECTRIC ASSN
COLUMBUS t SOUTHERN OHIO ELEC
CON10NWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
OELHARVA POWER t LIGHT
DESERET GEN t TRANS COOP
DUBJESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT K PWR
HOOSIER ENERGY
HOUSTON LIGHTING t POWER
INDIANAPOLIS POWER I LIGHT
IOWA ELECTRIC LIGHT t PWR
JACKSONVILLE ELEC AUTHORITY
KANSAS CITY POWER ft LIGHT
KANSAS POWER t LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LANSING BOARD OF WATER R LIGHT
LOS ANGELES DEPT OF WTR ft PWR
LOUISVILLE GAS I ELECTRIC
MAR8UETTE BOARD OF LIGHT S PWR
MICHIGAN SO CENTRAL PWR AGENCY
KIDDLE SOUTH UTILITIES
MINNESOTA POWER t LIGHT
NINNKOTA POWER COOPERATIVE
NONONGAHELA POWER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
HUSCATINE POWER t WATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POWER
NEW YORK STATE ELEC t GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
PACIFIC G*S I ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC G ( T COOP
PLATTE RIVER POWER AUTHORITY
PUBLIC SERVICE INDIANA
PU3LIC SERVICE OF NEW MEXICO
PWR AUTHORITY OF STATE OF NY
SALT RIVE« PROJECT
SAN MIGUEL ELECTRIC COOP
SENINOLE ELECTRIC
SIKESTON BRD OF MUNICIPAL UTIL
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
NO.
2
2
8
1
1
5
4
1
2
1
1
1
2
3
t
1
2
4
2
2
3
6
1
2
3
5
1
2
3
4
1
1
1
4
10
1
1
6
1
1
2
4
1
1
1
10
1
1
3
3
2
4
3
3
1
1
1
4
1
3
1
2
1
5
2
MW
358.
196.
2598.
670.
330.
2590.
1364.
540.
866.
617.
600.
720.
1300.
1294.
1572.
450,
654.
730.
820.
918.
1800.
3880.
65.
882.
1992.
3012.
720.
1200.
1000.
1575.
64.
364.
160.
3280.
3554.
44.
55.
5340.
475.
185.
1236.
2120.
440.
166.
650.
3215.
625.
100.
957.
1590.
1600.
2203.
2751.
724.
233.
279.
650.
1779.
700.
P40.
400.
1240.
235.
1700.
248.
OPERATIONAL
NO.
2
2
5
0
0
1
1
0
1
1
0
0
0
1
2
1
2
3
0
2
0
0
0
0
0
1
0
0
3
4
1
0
0
0
5
0
0
0
1
1
1
2
0
0
0
3
0
0
1
2
0
1
3
0
0
0
0
3
0
2
0
0
0
2
2
NW
358.
196.
962.
0.
0.
570.
242.
0.
416.
617.
0.
0.
0.
400.
822.
450.
654.
180.
0.
918.
0.
0.
0.
0.
0.
532.
0.
0.
1000.
1575.
64.
0.
0.
0.
1201.
0.
0.
0.
475.
185.
618.
720.
0.
0.
0.
375.
0.
0.
115.
1480.
0.
550.
2751.
0.
0.
0.
0.
1245.
0.
560.
0.
0.
0.
420.
248.
CONSTRUCTION CONTRACT
AWARDED
NO.
0
0
1
1
0
3
1
0
0
0
0
0
1
1
0
0
0
0
0
0
1
0
1
2
1
1
0
0
0
0
0
1
0
0
3
0
0
0
0
0
1
2
1
0
0
0
0
1
0
1
0
0
0
2
0
0
1
1
0
0
1
0
1
1
0
MW
0.
0.
ie6.
670.
0.
1580.
242.
0.
0.
0.
0.
0.
650.
447.
0.
0.
0.
0.
0.
0.
500.
0.
65.
882.
492.
530.
0.
0.
0.
0.
0.
364.
0.
0.
1203.
0.
0.
0.
0.
0.
618.
14QC.
440.
0.
0.
0.
0.
100.
0.
110.
0.
0.
0.
574.
0.
0.
650.
534.
0.
0.
400.
0.
235.
280.
0.
NO.
0
0
2
0
0
0
2
0
0
0
0
0
0
1
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0
0
2
0
0
0
0
1
1
1
0
0
0
0
0
2
0
2
0
MW
0.
0.
1510.
0.
0.
0.
880.
0.
0.
0.
0.
0.
0.
447.
0.
0.
0.
0.
410.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
55.
0.
0.
0.
0.
0.
0.
166.
0.
0.
0.
0.
842.
0.
0.
0.
0.
150.
233.
279.
0.
0.
0.
0.
0.
1240.
0.
1000.
0.
PLANNED
NO.
0
0
0
0
1
1
0
1
1
0
1
1
1
0
2
0
0
1
1
0
2
6
0
0
2
3
1
2
0
0
0
0
1
4
2
1
0
6
0
0
0
0
0
0
1
7
1
0
0
0
2
3
0
0
0
0
0
0
1
1
0
0
0
0
0
MW
0.
0.
0.
0.
330.
440.
0.
540.
450.
0.
600.
720.
650.
0.
750.
0.
0.
sso.
410.
0.
1300.
3880.
0.
0.
1500.
1950.
720.
1200.
0.
0.
0.
0.
160.
3280.
1150.
44.
0.
5340.
0.
0.
0.
0.
0.
0.
650.
2840.
625.
0.
0.
0.
1600.
1650.
0.
0.
0.
0.
0.
0.
700.
280.
0.
0.
0.
0.
0.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED, HEQUESTING/EVALUTING BIDS,
AND CONSIDERING ONLY FGD SYSTEMS
218
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
C01PANY NAME
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS & ELEC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT t PWR
ST. JOE ZINC
SUNFLOWER ELECTRIC COOP
TA^PA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER & LIGHT
TEXAS UTILITIES
TUCSON ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER S LIGHT
WEST PENN POWER
WEST TEXAS UTILITIES
NO.
2
1
3
1
1
1
1
1
7
1
3
8
2
1
6
1
1
MW
473.
265.
2160.
194.
205.
60.
347.
475.
3153.
400.
1882.
5585.
740.
50.
2216.
JOO.
720.
OPERATIONAL
NO.
1
1
0
1
0
1
0
0
3
0
0
4
0
0
3
0
0
MW
173.
265.
0.
194.
0.
60.
0.
0.
570.
0.
0.
2585.
0.
0.
1086.
0.
0.
CONSTRUCTION
NO.
0
0
0
0
1
0
0
0
3
1
1
0
0
1
1
0
0
MW
0.
0.
0.
0.
205.
0.
0.
0.
1983.
4QO.
382.
0.
0.
SO.
330.
0.
0.
CONTRACT
AWARDED
NO.
0
0
2
Q
0
0
1
1
1
0
2
1
2
0
2
1
0
MW
0.
0.
1440.
0.
0.
0.
347.
475.
600.
0.
1500.
750.
740.
0.
800.
300.
0.
PLANNED
NO.
1
0
1
0
0
0
0
0
0
0
0
3
0
0
0
0
1
MW
3CC.
0.
720.
Q.
C.
0.
C.
0.
0.
0.
0.
2250.
0.
0.
0.
0.
720.
TOTALS
208 94737.
76 25832.
39 16442.
30 14164.
63 38299.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED, REOUESTIN6/EVALUTING BIDS*
AND CONSIDERING ONLY FGD SYSTEMS
219
-------
EPA UTILITY FSB SURVEY: JULY - SEPTEMBER 1980
SECTION 5
SUMMARY OF FED SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTEM SUPPLIER/PROCESS
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTONE
SODIUM CARBONATE
TDTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK I WILCOK
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
BUELL DIVISION, ENVIROTECH
DUAL ALKALI
TOTAL -
CHEMICO DIVISION, ENVIROTECH
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LIMESTONE
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
TOTAL -
COMBUSTION EOUIP ASSOCIATES
DUAL ALKALI
LIME
LIME/ALKALINE ILYASH
SODIUM CARBONATE
TOTAL -
DAVY MCKEE
riELLMAN LORD
TOTAL -
ENV1RONEERIN6, RILEY STOKER
LIMESTONE
MAGNESIUM OXIDE
TOTAL -
DUAL ALKALI
TOTAL -
JOY MFE/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
NO.
2
5
1
2
1C
6
1
7
4
8
2
14
1
1
8
8
3
1
20
6
9
2
2
19
1
1
5
3
10
8
8
3
1
4
3
3
6
6
2
2
MW
822.
2616.
10.
880.
4328.
1673.
280.
1953.
1951.
2467.
1017.
5435.
617.
617.
4138.
5000.
579.
10.
9727.
1160.
3575.
1480.
654.
6869.
299.
500.
2305.
375.
3479.
2074.
2074.
664.
600.
1264.
1107.
1107.
1916.
1916.
882.
882.
OPERATIONAL
NO.
?
3
1
1
7
4
0
4
1
4
0
5
1
1
7
1
3
1
12
4
4
2
2
12
1
n
3
3
7
7
7
3
0
3
1
1
0
0
0
0
MU
822.
1176.
10.
550.
2558.
936.
0.
936.
618.
1413.
9.
2031.
617.
617.
3838.
800.
579.
10.
5227.
452.
1575.
1480.
654.
4161.
299.
0.
905.
375.
1579.
1540.
1540.
664.
0.
664.
265.
265.
0.
0.
0.
0.
CONSTRUCTION
NO.
0
0
c
1
1
2
1
3
3
1
1
7
0
C
0
3
0
0
3
2
3
0
0
5
0
1
2
0
3
1
1
0
0
0
0
0
2
2
2
2
MW
0.
0.
0.
330.
330.
737.
280.
1017.
1333.
999.
570.
2902.
0.
0.
0.
1900.
0.
0.
1900.
708.
1357.
0.
0.
2065.
0.
500.
1400.
0.
1900.
534.
534.
0.
0.
0.
0.
0.
550.
550.
882.
882.
CONTRACT
AWARDED
NO.
0
2
0
0
2
0
0
0
0
1
1
2
0
0
1
4
0
0
5
0
2
0
0
2
0
0
0
0
G
0
0
0
1
1
2
2
4
4
0
0
MU
0.
1440.
0.
0.
1440.
0.
0.
0.
0.
55.
447.
502.
0.
0.
300.
2300.
0.
0.
2600.
0.
643.
0.
0.
643.
0.
0.
0.
0.
c.
0.
0.
0.
600.
600.
842.
842.
1366.
1366.
0.
0.
220
-------
EPA UTILITY FSB SURVEY: JULY - SEPTEMBER 1980
SECTION 5
SUMMARY OF F60 SYSTEMS BY SYSTEM SUPPLIER
TOTAL
SYSTEM SUPPLIER/PROCESS
MORRISON t KNUDSEN/U.S.B.M.
CITRATE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOG
LIMESTONE
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCM-COTTRELL
LIMESTONE
LIME/LIMESTONE
LIME/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
UHEELA8RATQR-FRYE/R.I.
SODIUM CARBONATE/SPRAY DRYING
TOTAL -
NO.
1
1
8
1
9
2
2
1
4
5
14
1
1
16
1
1
1
1
2
3
5
1
1
MU
60.
60.
3445.
475.
3920.
880.
880.
917.
1880.
2797.
5281.
475.
50.
5806.
100.
100.
550.
550.
1510.
724.
2234.
440.
440.
OPERATIONAL
NO.
1
1
3
1
4
0
0
1
2
3
8
0
0
8
0
0
1
1
0
0
0
0
0
MU
60.
60.
758.
475.
1233.
0.
0.
917.
560.
1477.
2934.
0.
0.
2934.
0.
0.
550.
550.
0.
0.
0.
0.
0.
CONSTRUCTION
NO.
0
0
1
0
1
0
0
0
2
2
4
0
1
5
1
1
0
0
0
2
2
1
1
MU
0.
0.
447.
0.
447.
0.
0.
0.
1320.
1320.
1431.
0.
50.
1481.
100.
100.
0.
0.
0.
574.
574.
440.
440.
CONTRACT
AUARDED
NO.
0
0
4
0
4
2
2
0
0
0
2
1
0
3
0
0
0
0
2
1
3
0
0
MU
0.
0.
2240.
0.
2240.
880.
880.
0.
0.
0.
916.
475.
0.
1391.
0.
0.
0.
0.
1510.
150.
1660.
0.
0.
TOTAL -
145 56438.
76 25832.
39 16442.
30 14164.
221
-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
SECTION 6
SUMMARY OF FCD SYSTEMS BY PROCESS
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PLANNED
PROCESS
NO.
RU
NO.
MU
NO
nu
NO.
MU
NO.
KU
AQUEOUS CARBONATE/SPRAY DRYING
CITRATE
LIMESTONE
LIME/LIMESTONE
MAGNESIUM OXIDE
WELLNAN LORD
1
1
3
1
4
8
100.
60.
1766.
475.
1324.
2074.
0
1
0
0
0
7
0.
60.
0.
0.
0.
1540.
1
0
0
0
2
1
100.
0.
0.
0.
574.
534.
0
0
1
1
2
0
0.
0.
166.
475.
7-50.
0.
0
0
2
0
0
0
0.
0.
1600.
0.
0.
0.
SUBTOTAL - SALEABLE PRODUCT 18 5799.
8 1600.
4 1208.
4 1391.
2 1600.
DUAL ALKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLVASH
LIME/LIMESTONE
LINE/SPRAY DRVIN6
PROCESS NOT SELECTED
SODIUM CARBONATE
SODIUM CARBONATE/SPRAY DRYING
SUBTOTAL - THROUAWAY PRODUCT
TOTALS
SALEABLE PRODUCT PROCESS
X OF TOTAL MU
5
34
73
2
11
2
10
12
9
1
159
177
2023.
15951.
32569.
1480.
4013.
20.
3027.
7020.
3155.
440.
69698.
75497.
8
3
19
29
2
9
2
0
0
4
0
68
76
1181.
7583.
10430.
1480.
2613.
20.
0.
0.
925.
0.
24232.
25832.
6
0
8
19
0
2
0
4
0
1
1
35
39
0
3278
8616
0
1400
0
1170
0
330
440
15254
16442
7
»
•
•
•
•
•
9
•
•
*
•
•
2
3
15
0
0
0
5
0
0
0
25
29
842.
1810.
7588.
0.
0.
0.
1813.
0.
0.
0.
12053.
13444.
10
0
4
10
0
0
0
1
12
4
0
31
33
0.
3280.
5935.
0.
0.
0.
44.
7020.
1900.
0.
18179.
19779.
8
NOTE: 31 UNITS ARE UNDECIDED AND ARE NOT INCLUDED IN THIS TABLE
222
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 7
SUMMARY OF OPERATIONAL F6D SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CITRATE
6.F. MEATON
DUAL ALKALI
A.B. BROUN
CANE RUN
NEUTON
LIME
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELRAMA
GREEN
6REEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTER
HUNTIN6TON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
CORONADO
CORONADO
CRAI6
DUCK CREEK
JEFFREY
JEFFREY
LA CVGNE
LARAMIE RIVER
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
POWERTON
R.D. HORROUt SR.
R.D. MORROW, SR.
SOUTHWEST
TDMBI6BEE
TOMBI6BEE
WIDOWS CREEK
WINVAH
WINYAH
UNIT NO.
1
1
6
1
1
2
3
4
5
5
6
1-4
1
1-3
3
4
1
2
1
3
6
1-6
1
2
3
1
2
1
2
2
1
1
2
1
1
4
5
4
1
2
3
3
3
51
1
2
1
2
3
8
2
3
CAPACITY
nw
60.
60.
26S.
299.
617.
1181.
917.
917.
917.
188.
200.
411.
411.
510.
242.
64.
90.
90.
360.
360.
366.
442.
72.
408.
618.
7583.
98.
98.
119.
264.
280.
280.
400.
416.
540.
490.
820.
570.
125.
420.
173.
595.
595.
595.
800.
532.
450.
124.
124.
194.
179.
179.
550.
140.
280.
INITIAL
STARTUP
11/79
3/79
4/79
9/79
12/7.5
7/77
6/80
8/76
12/77
1/77
6/78
10/75
12/Z9
9/75
11/72
8/72
5/79
6/80
5/78
8/78
4/7.3
7/73
3/79
8/78
6/19
10/73
4/78
11/79
7/&0
12/359
7/76
8/78
4/80
2/73
7/80
1/76
11/71
5/79
4/77
5/78
2/79
5/78
12/77
4/80
8/78
6/79
4/77
9/78
6/79
5/7-7
7/77
5/&0
COMMERCIAL
STARTUP
1/80
4/79
O/ 0
12/79
6/76
10/77
6/80
8/77
7/78
2/77
7/78
10/75
12/79
6/76
O/ 0
O/ 0
5/79
6/80
5/78
3/79
O/ 0
6/74
3/79
1/79
4/79
12/73
6/78
12/79
10/80
5/80
8/78
O/ 0
1/80
6/73
7/80
O/ 0
O/ 0
6/79
10/78
O/ 0
O/ 0
10/78
12/77
6/81
8/78
6/79
9/77
9/78
6/79
1/78
O/ 0
6/80
10430.
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
223
-------
EPA UTILITY FSO SURVEY: JULY - SEPTEMBER 1980
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
UNIT NO.
CAPACITY
MW
INITIAL
STARTUP
COMMERCIAL
STARTUP
LIMESTONE/ALKALINE FLVASH
SHERBURNE 1
SHERBURNE 2
LIME/ALKALINE FLYASH
CLAY BOSWELL 4
COAL CREEK 1
COAL CREEK 2
COLSTRIP 1
COLSTRIP 2
FOUR CORNERS 1
FOUR CORNERS ?
FOUR CORNERS 3
1ILTON R. YOUNG 2
LIME/LIMESTONE
SHAWNEE 10A
SHAHNEE 10B
SODIUM CARBONATE
JIM BRID6ER 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
WELLMAN LORD
DEAN H. MITCHELL 11
DELAWARE CITY 1
DELAWARE CITY 2
DELAWARE CITY 3
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
740.
7*0.
14?0.
475.
327.
327.
360.
360.
175.
17S.
229.
185.
2613.
10.
10.
20.
550.
125.
125.
125.
925.
3/76
3/77
4/80
7/79
7/80
9/75
5/76
11/79
11/79
11/79
9/77
4/72
4/72
9/79
3/74
4/74
6/76
5/76
4/77
01 0
8/79
9/80
11/75
10/76
01 0
O/ 0
01 0
6/78
O/ 0
O/ 0
2/80
4/74
01 0
7/76
115.
60.
60.
60.
361.
350.
534.
7/76
5/80
5/80
5/80
4/78
8/78
12/79
6/77
5/80
5/80
5/80
4/78
8/78
O/ 0
1540.
TOTAL
25832.
224
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FED SYSTEMS
99 nr EC c t
r » UU c a 9 /
JKIT NAME
CITRATE
E.F. riEATDN
»UAL ALKALI
».B. SROUN
CANE RUN
ME W TON
LIME
JRUCE MANSFIELD
JRUCE MANSFIELD
3RUCE MANSFIELD
CANE RUN
CANE RUN
C3NESVILLE
CONESVILLE
ELRA*»
SREEN
5REEN RIVER
DAWTH3RN
HAWTHORN
HUNTER
HUNTER
HJNTI1STON
1ILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANT;
UNIT NO
1
1
6
1
1
2
3
4
5
5
6
1-4
1
1-3
3
4
1
2
1
3
6
1-6
1
... ... . ...... .............. ..
STABILIZED UNSTABILIZED TYPE DISPOSITION
ELEMENTAL. SULFUR
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND
POND
POND
LANDFILL
LINED POND
POND
POND
POND
POND
LANDFILL
POND
POND
LANDFILL
LIMESTONE
»P«CME
APACHE
CHOLLA
CHOLLA
C3RONADO
CORONADO
CRAIG
»JCK CREEK
JEFFREY
JEFFREY
LA CVGNE
LARAMIE RIVER
LAURENCE
LAWRENCE
IARION
4ARTIM LAKE
4ARTIN LAKE
4ARTIN LAKE
15NTICELLO
PETERSBURG
P3WERTON
t.D. MORROU, SR.
«.». MORROW, SR.
SOUTHJEST
F3MBI&BEE
rSMBICBEE
WIDOWS CREEK
«INYAH
JIMVAH
I
3
1
2
1
2
2
1
1
2
1
1
4
5
4
1
2
3
3
3
51
1
2
1
2
3
8
2
3
POND
LINED POND
LANDFILL
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND
POND
POND
POND
UNLINED POND
LINED POND
LINED POND
MINEFILL
LINED POND
UNLINED POND
LANDFILL
POND
POND
LIMESTONE/ALKALINE FLVASH
SNERBURNE
SHERBURNE
LINED POND
LINED POND
225
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL F6D SYSTEMS
PROCESS/
UNIT NAME
THROUAUAY
UNIT NO STABILIZED UNSTABILIZED
-BYPRODUCT-
DISPOSITION
LIKE/ALKALINE FLVASH
CLAY BOSUELL 4 LINED POND
COAL CREEK 1 LINED POND
COAL CREEK 2 LINED POND
COLSTRIP 1 POND
COLSTRIP 2 POND
FOUR CORNERS 1
FOUR CORNERS 2
FOUR CORNERS 3
HILTON R. YOUNG 2 MINEFILL
LINE/LIMESTONE
SHAWNEE IDA
SNANNEE 108
SODIUM CARBONATE
JIN BRID6ER 4 LINED POND
»EIO GARDNER 1 LINED POND
REID GARDNER 2 LINED POND
«EIP GARDNER 3 LINED POND
HELLMAN LORD
ftEAN H. RITCHELL 11
ftELAWARE CITY 1 LINED POND
DELAWARE CITY 2 LINED POND
DELAWARE CITY 3 LINED POND
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
ELEMENTAL SULFUR
SULFUR 1C ACID
SULFURIC ACID
SULFURIC ACID
ELEMENTAL SULFUR
ELEMENTAL SULFUR
SULFURIC ACID
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
226
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COHPAMY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMBI6BEE 2
ALABAMA ELECTRIC COOP
T01BIGBEE 3
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
CHDLLA 1
ARIZONA PUBLIC SERVICE
CHDLLA 2
ARIZONA PUBLIC SERVICE
F9UR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BASIN ELECTRIC POWER COOP
LARA'IE RIVER 1
BIS RIVERS ELECTRIC
GREEN 1
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEKTON 1
COLORADO UTE ELECTRIC ASSN
CRAIG 2
COLUMBUS K SOUTHERN OHIO ELEC
CDXESVILLE 5
COLUMBUS 1 SOUTHERN OHIO ELEC
CONESV1LLE 6
COMMONWEALTH EDISON
POriERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELNARVA POWER t LIGHT
DELAWARE CITY 1
OELNARVA POWER t LIGHT
DELAWARE CITY 2
DELNARVA POWER I LIGHT
DELAWARE CITY 3
DUBUESNE LIGHT
ELUAHA 1-4
DUBUESNE LIGHT
PHILLIPS 1-6
NEW OR (
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
IAPACITY
NW
179.0
179.0
98.0
98.0
119.0
264.0
175.0
175.0
229.0
570.0
242.0
416.0
617.0
400.0
411.0
411.0
450.0
327.0
327.0
60.0
60.0
60.0
510.0
408.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODV PROCESS SYSTEMS
LIMESTONE
RESEARCH-COYTRELL
LIMESTONE
RESEARCH-COT-TRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COT-TRELL
LIME/ALKALINE FLYASH
CHEHICO DIVISION, ENVIROTECH
LIME/ALKALINE FLYASH
CHEMICO DIVISION. ENVIROTECH
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COTTRELL
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEV STOKER
DUAL ALKALI
BUELL DIVISION. ENVIROTECH
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME/ALKALINE FLVASH
COMBUSTION KNGINEERING
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY NCKEE
WELLMAN LORD
DAVY MCKEE
LIME
CHEMICO DIVISION, ENVIROTECH
LINE
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/76
11/79
11/79
11/79
7/80
12/79
7/76
9/79
12/79
1/77
6/78
4/80
7/79
7/80
5/80
5/80
5/80
10/75
7/73
227
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTI-ON 9
SUMMARY OF FGO SYSTEMS IN OPERATION
COMPANY NAME/
LIMIT NAME UNIT NO.
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
KANSAS CITY POWER 8 LIGHT
HAWTHORN 3
KANSAS CITY POWER S LIGHT
HAWTHORN 4
KANSAS CITY POWER K LIGHT
LA CY6NE 1
KANSAS POWER 8 LIGHT
JEFFREY 1
KANSAS POWER I LIGHT
JEFFREY 2
KANSAS POWER & LIGHT
LAWRENCE 4
KAMSAS POWER ( LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
6REEN RIVER 1-3
LOUISVILLE GAS & ELECTRIC
CANE RUN 4
LOUISVILLE GAS t ELECTRIC
CANE RUN S
LOUISVILLE GAS I ELECTRIC
CANE RUN 6
LOUISVILLE GAS t ELECTRIC
MILL CREEK 3
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
MINNESOTA POWER t LIGHT
CLAY BOSWELL t
MINNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONONGAHELA POWER
PLEASANTS 1
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP 2
NEVADA POWER
REID GARDNER 1
NEVADA POWER
REID GARDNER 2
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POWER
NEW OR
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
CAPACITY
MW
5J2.0
90.0
90.0
820.0
540.0
490.0
125.0
420.0
64.0
188.0
200.0
299.0
442.0
72.0
475.0
185.0
618.0
360.0
360.0
125.0
125.0
125.0
115.0
740.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK ft WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLVASH
PEABODV PROCESS SYSTEMS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
LIME
BABCOCK ( WILCOX
LIME/ALKALINE FLVASH
COMBUSTION BQUIP ASSOCIATES
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION fcQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION fcQUIP ASSOCIATES
WELLMAN LORD
DAVY MCKEE
LIMESTONE/ALKALINE FLYASH
START-UP
DATE
12/77
11/72
8/72
2/75
8/78
4/80
1/76
11/71
9/75
8/76
12/77
4/79
8/78
4/73
4/80
9/77
3/79
9/75
5/76
3/74
4/74
6/76
7/7'6
3/76
COMBUSTION ENGINEERING
228
-------
EPA UTILITY F6P SURVEY: JULY - SEPTEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER K LIGHT
Jit BRIDGED I
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
SALT RIVER PROJECT
CBRONAOO 1
SALT RIVER PROJECT
CORONADO 2
SOUTH CAROLINA PUBLIC SERVICE
UINVAH 2
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 3
SOUTH MISSISSIPPI ELEC PUR
R.D. SORROW, SR. 1
SOUTH MISSISSIPPI ELEC PUR
R.D. MORROW, SR. 2
SOUTHERN ILLINOIS POUER COOP
MARION 4
SOUTHERN INDIANA GAS I ELEC
A. 3. BROUN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
ST. JOE ZINC
G.F. iJ EATON 1
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10A
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10B
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
NEU OR (
RETROFIT
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEW
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEU
:APACITT
MU
740.0
S50.0
917.0
917.0
917.0
361.0
350.0
534.0
280.0
280.0
140.0
280.0
124.0
124.0
173.0
265.0
194.0
60.0
10.0
10.0
550.0
595.0
595.0
595.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
PULLMAN KELLOGG
UELLHAN LORD
DAVY MCKEE
UELLMAN LORD
DAVY MCKEE
UELLMAN LORD
DAVY MCKEE
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BABCOCK I UILCOX
LIMESTONE
BABCOCK 1 UH.COX
LIMESTONE
ENVIRONEERINC, RILEY STOKER
LIMESTONE
ENVIRONEERING, RILEV STOKER
LIMESTONE
BABCOCK S UILCOX
DUAL ALKALI
FHC
LIMESTONE
AIR CORRECTION DIVISION, UOP
CITRATE
MORRISON ( KNUDSEN/U.S.B.M.
LIME/LIMESTONE
AIR CORRECTION DIVISION. UOP
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
START-UP
DATE
3/77
9/79
12/75
7/77
6/80
4/78
8/78
12/79
11/79
7/80
7/77
5/80
8/78
6/79
5/79
1/79
4/77
11/79
4/72
4/72
5/77
4/77
5/78
2/79
229
-------
EPA UTILITY FSB SURVEY: JULY - SEPTEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/ NEW OR
UMIT NAME UNIT NO. RETROFH
TEXAS UTILITIES NEW
MONTICELLO 3
UTAH POWER & LIGHT NEW
HUNTER 1
UTAH POWER t LIGHT NEW
HUNTER 2
UTAH POWER I LIGHT NEW
HUNTINGTON 1
CAPACITY PROCESS/
r MW SYSTEM SUPPLIER
800.0 LIMESTONE
CHEHICO DIVISION, ENVIROTECH
360.0 LINE
CHEMICO DIVISION, ENVIROTECH
360.0 LIME
CHEMICO DIVISION, ENVIROTECH
366.0 LIME
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
5/78
5/79
6/80
5/78
TOTAL
25832.0
230
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 10
SUMMARY OF F6» SYSTEMS UNDER CONSTRUCTION
C01PANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
CHOLLA 4
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
BASIN ELECTRIC POKER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POWER COOP
LARA1IE RIVER 2
BASIN ELECTRIC POWER COOP
LARANIE RIVER 3
BI6 RIVERS ELECTRIC
GREEN ?
CINCINNATI 6AS I ELECTRIC
EAST 9END 2
COLORADO UTE ELECTRIC ASSN
CRAI6 1
EAST KENTUCKY POWER COOP
SPURLOCK Z
GRAND HAVEN BRD OF LIGHT t PWR
J.9. SINS 3
HOOSIER ENERGY
HERO* 1
HOOSIER ENERGY
MEROM Z
HOUSTON LIGHTING 1 POWER
U.A. PARISH 8
INDIANAPOLIS POWER t LIGHT
PETERSBURG 4
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE 6AS t ELECTRIC
HILL CREEK 1
LOUISVILLE GAS t ELECTRIC
MILL CREEK Z
LOUISVILLE GAS I ELECTRIC
MILL CREEK 4
MONONSAHELA POWER
PLEASANTS 2
MONTANA POWER
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
MONTANA-DAKOTA UTILITIES
COYOTE 1
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEV 66
NORTHERN STATES POWER
NEW OR CAPACITY
RETROFIT NW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEM
NEW
RETROFIT
RETROFIT
126.0
670.0
440.0
570.0
570.0
242.0
650.0
447.0
500.0
65.0
441.0
441.0
492.0
530.0
364.0
3S8.0
350.0
495.0
618.0
700.0
700.0
440.0
100.0
110.0
PROCESS/ START-UP
SYSTEM SUPPLIER DATE
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
PULLMAN KELLOC6
LIME/SPRAY DRYING
JOY HF6/NIRO ATOMIZER
LIMESTONE
RESEARCH-COfTRELL
LIME/SPRAY DRYING
BABCOCK * WILCOX
LIME
AMERICAN AIR FILTER
LIME
BABCOCK t WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
COMBUSTION EQUIP ASSOCIATES
LIME
BABCOCK t VILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COXTRELL
LIMESTONE
BABCOCK t WILCOX
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
BABCOCK ( WftLCOX
LIME/ALKALINE FLVASH
COMBUSTION EQUIP ASSOCIATES
LINE/ALKALINE FLVASH
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE/SPRAT DRYING
UHEELABRATOR-FR YE/R.I.
AQUEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
LIME/SPRAY DRYING
6/81
1/82
4/83
6/81
4/82
11/80
12/80
10/80
1/81
6/83
5/82
9/81
11/82
10/84
8/81
1/81
12/81
6/B2
10/80
5/83
3/84
3/81
4/82
11/80
JOY MFG/NIRO ATOMIZER
231
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 10
SUMMARY OF F6D SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
PHILADELPHIA ELECTRIC
EDDYSTONE 1
PHILADELPHIA ELECTRIC
EDDYSTONF. 2
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SIKESTON 3RD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 4
SPRINGFIELD WATER, LIGHT 8 PWR
DALLMAN 3
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER t LIGHT
SANDOW 4
UNITED POWER ASSOCIATION
STANTON 1A
UTAH POWER & LIGHT
NAJGHTON 3
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
240.0
334.0
650.0
534.0
400.0
235.0
280.0
205.0
704.0
704.0
575.0
400.0
382.0
50.0
330.0
PROCESS/
SYSTEM SUPPLIER
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
VELLKAN LORD
DAVY MCKEE
LIMESTONE
BABCOCK K W1LCOX
LIMESTONE
6ABCOCK K WI1COX
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
RESEARCH-COITRELL
LIMESTONE
CHEM1CO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
COMBUSTION 6N6INEERIN6
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
RESEARCH-COTTRELL
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
START-UP
DATE
12/82
12/82
0/82
6/82
11/80
3/81
7/81
10/80
3/82
6/82
9/81
1/82
11/80
6/82
6/81
TOTAL
16442.0
232
-------
EPA UTILITY f6D SURVET: JULY - SEPTEMBER 1980
SECTION 11
SUMMARY OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
BIG RIVERS ELECTRIC
D.B. WILSON 1
BIG RIVERS ELECTRIC
D.B. WILSON 2
COLORADO UTE ELECTIUC ASSN
CRAI6 3
OESERET GEN I TRANS COOP
MOON LAKE 1
MICHIGAN so CENTRAL PWR AGENCY
PROJECT 1
MUSCATINE POWER I HATER
MUSCATINE 9
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCMAHFER 18
PHILADELPHIA ELECTRIC
CRONBV 1
PLAINS ELECTRIC 6 K T COOP
PLAINS ESCALANTE 1
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
SEAINOLE ELECTRIC
SE1INOLE 1
SEMINOLE ELECTRIC
SENINOLE 2
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEV 1
SUNFLOWER ELECTRIC COOP
HOLCONB 1
TAMPA ELECTRIC
BI6 SEND 4
TENNESSEE VALLEY AUTHORITY
JOHMSONV1LLE 1-10
TEXAS POWER t LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
NEW OR (
RETROFIT
RETROFIi
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
APACITT
MW
755.0
755.0
(40.0
440.0
447.0
410.0
55. 0
166.0
421.0
421.0
150.0
233.0
279.0
620.0
620.0
500.0
500.0
720.0
720.0
347.0
475.0
600.0
750.0
750.0
PROCESS/
SYSTEM SUPPLIER
LIME
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOG
LIMESTONE
PULLMAN KELLOG
LIME/SPRAY DRYING
BABCOCK ( NU.COX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK I WILCOX
LIMESTONE
R£SEARCH-COTTRELL
DUAL ALKALI
FMC
DUAL ALKALI
FMC
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
JOY NFG/NIRO ATOMIZER
LIMESTONE
PEABODV PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODV PROCESS SYSTEMS
LIMESTONE
PEABOOY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/SPRAY DRYING
JOY MF6/NIRO ATOMIZER
LINE/LIMESTONE
RESEARCM-COTTRELL
MAGNESIUM OXIDE
ENVIRONEERING, RILEY STOKER
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
0/82
0/82
7/S4
1/86
0/82
9/84
6/82
9/82
6/83
6/85
5/83
12/83
12/83
3/83
3/85
1/85
11/83
0/86
12/84
9/83
12/84
12/81
8/84
8/85
233
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
SECTION 11
SUMMARY Of CONTRACT AWARDED F6D SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
TEXAS UTILITIES
MARTIN LAKE 4
TUCS»N ELECTRIC POWER
SPRIMSERVILLE 1
TUCSON ELECTRIC POWER
SPRINGERVILLE 2
UTAH POWER « LIGHT
HUNTER 3
UTAH POWER t LIGHT
HUNTER 4
WEST PENN POWER
MITCHELL 33
NEW OR
'RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
750.0
370.0
370.0
400.0
400.0
300.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
RESEARCH-COiTTRELL
LIME/SPRAY DRYING
JOY NFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
CHEHICO DIVISION, ENVIROTECH
LIMESTONE
CHEHICO DIVISION, ENVIROTECH
LIME
CHEHICO DIVISION, ENVIROTECH
START-UP
DATE
0/85
1/85
5/87
6/83
6/85
8/82
TOTAL
14164.0
234
-------
EPA UTILITY FG6 SURVEY: JULY - SEPTEMBER 1980
SECTION 12
SUMMARY OF PLANNED F60 SYSTEMS
COMPANY NAME/
UNIT NINE UNIT NO.
NEW OR
RETROFIT
CAPACITY
MW
PROCESS/
SYSTEM SUPPLIER
START-UP
DATE
LETTER OF INTENT SIGNED
MIDDLE SOUTH UTILITIES
ARKANSAS LI6NITE 5
MIOOLE SOUTH UTILITIES
ARKANSAS LIGNITE 6
HI DOLE SOUTH UTILITIES
UNASSIGNED 1
MIDDLE SOUTH UTILITIES
UNASSIGNED 2
MIDDLE SOUTH UTILITIES
WILTON 1
MIDDLE SOUTH UTILITIES
UILTON 2
NEVADA POWER
REID 6ARDNER 4
TOTAL
REQUESTING /EVALUATING
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
DESERET GEN I TRANS COOP
MOON LAKE 2
GENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
SEWARD 7
HOUSTON LIGHTING t POKER
LI1ESTONE 1
HOUSTON LIGHTING t POKER
LI'ESTOttE 2
IOWA ELECTRIC L16HT t PUR
GUTHRIE CO. 1
LOUISVILLE GAS ( ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS ( ELECTRIC
TRIMBLE COUNTY 2
MARQUETTE BOARD OF LIGHT C PHR
SMIRAS 3
NEVADA POWER
WARNER VALLEY 1
NEVADA POWER
WARNER VALLEY 2
NEK YORK STATE ELEC ( GAS
SOMERSET 1
PACIFIC POWER t LIGHT
JIM BRIDGES 1
NEW
NEW
NEW
NEW
NEW
NEW
NEW
BIDS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
890.0
890.0
890.0
890.0
890.0
890.0
250.0
890.0
440.0
450.0
410.0
690.0
690.0
750. 0
750.0
720.0
575.0
575.0
44.0
295.0
295.0
625.0
550.0
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
SODIUM CARBONATE
COMBUSTION 80UIP ASSOCIATES
LINE/SPRAY DRYING
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME/SPRAY DRYING
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT (ELECTED
LIMESTONE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
0/90
0/92
0/89
0/93
0/88
0/91
4/83
10/85
1/86
0/88
5/91
5/87
12/84
12/85
11/84
7/85
7/88
10/82
6/85
6/86
6/84
0/88
235
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
PACIFIC POWER * LIGHT
JH 9RID6ER 2
PACIFIC POWER t LIGHT
lit BRIDGES 3
TEXAS UTILITIES
FOREST GROVE 1
TOTAL
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
CAPACITY
MW
SSO.O
550.0
750.0
440.0
PROCESS/
SYSTEM SUPPLIER
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
START-UP
DATE
0/84
0/86
0/87
CONSIDERING FGD SYSTEMS
ATLANTIC CITY ELECTRIC
CUMBERLAND 1
CAJUN ELECTRIC POWER COOP
BIS CAJUN III 1
CENTRAL MAINE POKER
SEARS ISLAND 1
CENTRAL POWER ft LIGHT
COLETO CREEK 2
CINCINNATI 6AS 1 ELECTRIC
EAST BEND 1
COLUMBUS 1 SOUTHERN OHIO ELEC
POSTON 5
COLUMBUS I SOUTHERN OHIO ELEC
POSTON 6
DELMARVA POWER 1 LIGHT
VIENNA 9
EAST KENTUCKY POWER COOP
J.K. SMITH 1
EAST KENTUCKY POWER COOP
J.K. SMITH 2
GENERAL PUBLIC UTILITIES
COAL 1
GENERAL PUBLIC UTILITIES
COAL 2
GENERAL PUBLIC UTILITIES
COAL 3
GENERAL PUBLIC UTILITIES
COAL 4
INDIANAPOLIS POWER I LIGHT
PATRIOT 1
INDIANAPOLIS POWER t LIGHT
PATRIOT 2
INDIANAPOtIS POWER t LIGHT
PATRIOT 3
JACKSONVILLE ELEC AUTHORITY
NEW PROJECT 1
JACKSONVILLE ELEC AUTHORITY
NEW PROJECT 2
LANSING BOAR» OF WATER t LIGHT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
330.0
540.0
600.0
720.0
650.0
375.0
375.0
550.0
650.0
650.0
62S.O
625.0
625.0
625.0
650.0
650.0
650.0
600.0
600.0
160.0
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
1/88
0/8S
1/89
9/86
10/87
8/86
0/89
6/87
1/85
1/87
12/92
5/94
12/95
5/97
0/87
O/ 0
O/ 0
12/85
6/87
1/87
VENDOR NOT SELECTED
236
-------
EPA UTILITY F66 SURVEY: JULY - SEPTEMBER 1980
SECTION 12
SUMMARY OF PLANNED fGO SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
LOS ANGELES DEPT OF UTR ( PUR
IMTERHOUNTAIN 1
LOS ANGELES DEPT OF WTR 1 PUR
INTERNOUNTAIV 2
LOS ANGELES DEPT OF WTR I PUR
INTERNOUNTAIN 3
LOS ANGELES DEPT OF WTR 1 PUR
INTERHOUNTAIN 4
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
NEVADA POUER
HARRY ALLEN 1
NEVADA POUER
HARRY ALLEN 2
NEVADA POUER
HARRY ALLEN 3
NEVADA POUER
HARRY ALLEN *
PACIFIC GAS t ELECTRIC
NONTEZUMA 1
PACIFIC GAS t ELECTRIC
MONTEZUHA Z
PtfR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONADO 3
SOUTHERN ILLINOIS POUER COOP
MARION 5
SOUTHWESTERN ELECTRIC POUER
OOLET HILLS 2
TEXAS UTILITIES
HILL CREEK 1
TEXAS UTILITIES
HILL CREEK 2
UEST TEXAS UTILITIES
OKLAUNION 1
NEU OR
RETROFIT
NEW
NEU
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEU
NEW
NEW
NEW
NEW
NEW
CAPACITY
NU
820.0
820.0
820.0
820.0
650.0
500.0
500.0
500.0
500.0
800.0
800.0
700.0
280.0
300.0
720.0
750.0
750.0
720.0
PROCESS/
SYSTEM SUPPLIER
LIME
VENDOR NOT SELECTED
LINE
VENDOR NOT SELECTED
LINE
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
START-UP
DATE
0/86
0/87
0/88
0/89
3/87
6/86
6/87
6/88
6/89
6/89
6/90
4/87
0/89
0/88
0/88
0/85
0/86
12/86
TOTAL
330.0
237
-------
EPA UTILITY FG6 SURVEY: JULY - SEPTEMBER 1980
SECTION 13
TOTAL F60 UNITS AND CAPACITY INSTALLED BY YEAR
YEAR
1968
1969
1971
1972
197J
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
198S
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1997
UNDEFINED
NEV I
NO.
1
0
1
6
4
?
6
8
10
13
20
20
13
22
12
12
15
11
14
9
a
2
2
2
1
1
1
1
9
9N LINE
MU
140.
0.
420.
485.
1419.
250.
2018.
2824.
4464.
4553.
6300.
7383.
5169.
9523.
4405.
6946.
8411.
6340.
8540.
5095.
5065.
1690.
1580.
1515.
890.
625.
625.
625.
3262.
TERM
NO.
0
1
0
0
1
3
3
3
1
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1NATED
RW
0.
140.
0.
0.
175.
340.
1637.
850.
47.
0.
143.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
TOTAL
NO.
1
0
1
7
10
9
12
17
26
39
57
77
90
112
124
136
151
162
176
185
193
195
197
199
200
201
202
203
ON LINE
NU
140.
0.
420.
905.
2149.
2059.
2440.
4414.
8831.
13384.
19541.
26924.
32093.
41616.
46021.
52967.
61378.
67718.
76258.
81353.
86418.
88108.
89688.
91203.
92093.
92718.
93343.
93968.
238
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 1*
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - HU
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - HU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
HEM/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
TYPE
COMMONWEALTH EDISON
UILL COUNTY
1
ROMEOVILLE
ILLINOIS
167.0
137.0
COAL
»»****
22260.
7.40
1.50
WET SCRUBBING
LIMESTONE
BAB COCK t UILCOX
RETROFIT
( 9S70 BTU/L8)
4/72
2/73
76.00
98.00
1
COLD SIDE
VENTURI
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
12/79
A
B
SYSTEM
77.0
64.9
77.0
99.5
100.0
99.5
57.5
57.8
57.5
744 431
4Z8
** PROBLEHS/SOLUTIONS/COMMENTS
ON DECEMBER 4i UNIT 1 CAME OFF LINE SO THAT THE AID HEATER HOPPERS AND
PRECIPITATOR HOPPERS COULD BE EMPTIED OF CARBON CARRY-OVER AND DEBRIS.
DURING THIS OUTAGE THE SHOP REPAIRED A LEAK IN THE POND RETURN LINE.
ON DECEMBER 10, THE A-NODULE DEVELOPED A SERIOUS STEAM LEAK (25,000 MAKE-
UP) IN A LOWER REHEAT BUNDLE. THE LEAKING BUNDLE HAD TO BE REMOVED AND
REPLACED. THIS RESULTED IN A TUO DAY FORCED OUTAGE. LATER IN THE MONTH
THE A-MOOULE BLEU ANOTHER REHEATER TUBE FORCING THE BOILER OFF FOR AN
ADDITIONAL 25 HOURS AND 12 MINUTES.
THE A-MODULE WAS REMOVED FROM THE GAS PATH ON DECEMBER 29, FOR THREE HOURS
TO ALLOW THE MAINTENANCE SHOP TO WELD A LEAKING REHEATER FLANGE.
THE S02 PLANT FORCED THE BOILER OFF TWICE THIS MONTH. TOTAL FORCED OUTAGE
TIME ATTRIBUTED TO THE SCRUBBER WAS 54 HOURS AND 39 MINUTES.
1/80 A
B
SYSTEM
91.0
88.6
88.6
87. 5
84.1
84.1
63.0
60.6
60.6
744 536
451
«* PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST SIX DAYS OF JANUARY, UNIT 1 BOILER WAS OFF THE SYSTEM BECAUSE
OF A SLAG SCREEN TUBE LEAK. THE UNIT RETURNED TO SERVICE ON JANUARY 7.
ON JANUARY 16, THE UTILITY HAD TO DERATE UNIT 1 TO 50 MW BECAUSE THE RE-
239
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA--
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
HEATER SECTIONS ON A AND B MODULES WERE PLUGGING. ON JANUARY 17, THE
MODULES WERE TAKEN OUT OF THE GAS PATH TO BEGIN REMOVING AND CLEANING THE
REHEATER SECTIONS WITH A HIGH PRESSURE (4000 PSD WATER SPRAY. UNIT 1
BOILER WAS LEFT ON TO PROVIDE STABILITY FOR THE 138 KV SYSTEM.
IN THE PAST, ALL 42 BUNDLES CONSISTING OF SEVEN TUBES PER BUNDLE.
HAD TO BE TAKEN OUTSIDE TO BE CLEANED ON A CONCRETE SLAB. IN THIS CASE
SINCE TIME WAS THE MOST IMPORTANT FACTOR. A DIFFERENT APPROACH WAS USED.
ONLY THE MIDDLE SIX BUNDLES ON EACH MODULE WERE REMOVED. THIS PROVIDED A
LARGE ENOUGH SPACE SO THAT A LANCE WITH AN EXTENSION ON IT COULD BE USED
TO CLEAN THE BOTTOM OF THE TWO TOP BUNDLES AND THE TOP OF THE TWO BOTTOM
BUNDLES. THERE ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
OF THE REHEATER. USING THIS METHOD, ONLY 12 OR THE 42 BUNDLES WERE
REMOVED. IN THE PAST, THIS JOB HAS TAKEN AS LONG AS TWO WEEKS TO
COMPLETE. USING THE NEW METHOD. ALL THE REHEATER BUNDLES WERE CLEANED IN
20 HOURS.
THE B-MODULE WAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY. BOTH
THESE OUTAGES WERE CAUSED BY THE REHEATER (A COIL LEAK AND A FLANGE LEAK)
TOTALING 18 HOURS AND 24 MINUTES.
2/80
A
B
SYSTEM
79.7
78.6
74.1
90.5
89.2
84.2
79.7
78.6
74.1
696 613
516
** PROBLEMS/SOLUTIONS/COMPENTS
SCRUBBER PROBLEMS IN FEBRUARY WERE CAUSED FROM LEAKS IN THE VENTURI SPRAY
HEADER. THESE LEAKS DEVELOP WHERE THE RUBBER LINING INSIDE THE VENTURI
PIPING HAS WORN AWAY SO THAT THE BARE METAL IS EXPOSED. THIS EXPOSED METAL
IS THEN SUBJECT TO ERROSION/CORROSION. THE LINING IS HOST LIKELY TO WEAR
AT THE HELD HEAD OF THE SPRAY NOZZLE TO THE MAIN HEADER. ALL THE VENTURI
SPRAY PIPING I.S BEING REPLACED.
TUBE LEAKS IN THE STEAM COIL REHEAT SYSTEM CAUSED SCRUBBER PROBLEMS THIS
MONTH. MODULE A WAS FORCED OUT ONCE AND MODULE B MAS FORCED OUT THREE
TIMES. THESE TUBES WILL BE REPLACED DURINC THE NEXT OUTAGE.
3/80
A
A
SYSTEM
83.9
83.9
83.9
744
•* PROBLEMS/SOLUTIONS/COMHENTS
THE BOILER WAS OUT OF SERVICE FOR ALL OF MA.RCH DUE TO BOILER TUBE LEAKS IN
THE REHEAT SECTION OF THE BOILER.
4/80
A
B
SYSTEM
100.0
87.7
93.9
71.0
71.0
71.4
17.3
17.3
17.3
720 175
125
** PROBLEMS/SOLUTIONS/COMMENTS
5/80 SYSTEM
DURING THE FIRST 15 DAYS OF APRIL THE BOILER WAS OUT OF SERVICE DUE TO
TUBE LEAKS IN THE AIR PREHEATER.
WHEN ATTEMPTS WERE MADE TO BRING THE BOILER ON'LINE ON THE 16 THE
B-HODULE OF THE S02 SYSTEM DEVELOPED REHEAJER TUBE LEAKS. THIS CAUSED
A FORCED OUTAGE OF 53 HOURS AND 40 MINUTES.
WHEN ATTEMPTS WERE MADE TO RETURN THE BOILER TO SERVICE AGAIN, THE AUXIL-
IARY LOW PRESSURE GOVENOR DEVELOPED AN OIL LEAK CAUSING A FOUR DAY OUTAGE,
FOLLOWED BY ANOTHER REHEATER TUBE LEAK OUTAGE ON THE B MODULE. THIS
OUTAGE LASTED 35 HOURS. THE UNIT RETURNED TO SERVICE ON APRIL 24 AND
WAS AVAILABLE FOR THE REST OF APRIL.
744
240
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 CCONT.)
— -------------- - ------------- - ---- —— -PERFORMANCE DATA- --- — --- - --- — —————— ---------
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION » REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COHMENTS
INFORMATION UAS NOT AVAILABLE FOR THE MONTH OF HAY.
6/80
A
B
SYSTEM
86. 5
86.5
86.5
100.0
100.0
100.0
81.2
81. Z
81. Z
720 584
584
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM FORCED THE BOILER OUT OF SERVICE FROM JUNE 6 TO
JUNE 10. THE OUTAGE HAS CAUSED BY PLUGGED REHEATERS ON BOTH MODULES.
THIS UAS THE ONLY FORCED OUTAGE EXPERIENCE* DURING JUNE.
7/80
A
B
SYSTEM
87.8
87.8
87.8
78.3
78.3
78.3
55.0
S5.0
55.0
744
522
409
** PROBLEMS/SOLUT IONS/COMMENTS
DURIN6 THE MONTH OF JULY THERE HERE NO FORCED SCRUBBER OUTAGES.
TWO SLAG LINE OUTAGES. ONE FORCED DRAFT FAN AND ONE BOILER SCREEN HALL
TUBE OUTAGE OCCURRED. THIS ACCOUNTED FOR 193 HOURS OF BOILER-RELATED
OUTAGE TIME DURING THE MONTH.
ON NINE OCCASIONS IN JULY THE SCRUBBER MAS BY-PASSED SO THAT THE BOILER
COULD CARRY MAXIMUM LOAD (163 MH>. THE UNIT HAS LIMITED TO 13S MU AFTER
A RECENT STACK EMISSION TEST.
B/80 SYSTEM
»/80 SYSTEM
*• PROBLEMS/SOLUTIONS/COMMENTS
744
720
NO INFORMATION HAS AVAILABLE FOR THE MONTHS OF AUGUST AND SEPTEMBER.
241
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 1*
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT 6ENERATIN6 CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DATA
FUEL TYPE
FUEL 6RADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*» GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
STSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** ESP
• * MECHANICAL COLLECTOR
•* PARTICLE SCRUBBER
NUMBER
TYPE
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHIGAN
260.0
130.0
COAL
SUBBITUMINOUS
22330.
4.00
22.60
.35
( 9600 BTU/LB)
WET SCRUBBING
LIMESTONE
PEABODV PROCESS SYSTEMS
RETROFIT
6/75
9/75
90.00
99.70
2
VENTURI
_——_. PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
744
696
744
*• PROBLEMS/SOLUTIONS/COMMENTS
4/80 SYSTEM
THE SCRUBBING SYSTEM OPERATED WITH BETTER THAN SOX AVAILABILITY DURING THE
FIRST QUARTER OF 1980.
THE SCRUBBER ID FAN FAILED. THE BOLTS HOLBIN6 PART OF THE SHROUDING
IN PLACE SHEERED CAUSING THE PLATE TO FALL ONTO THE SHAFT.
BECAUSE OF ADDITIONAL PROBLEMS WITH THE A-S-H SUMP PUMPS. THE DENVER PUMPS
INSTALLED TO ASSIST THE A-S-H PUMPS NOW CARRY THE ENTIRE LOAD. THE A-S-H
PUMPS DRIVES HAVE BEEN DISCONNECTED. THE SLURRY CIRCULATES THROUGH THE
THE NON-OPERATING A-S-H PUMPS TO THE DENVER PUMPS.
THE CONTINUAL PROBLEMS WITH THE LOUVER BY PASS DAMPERS WAS SOLVED BY DIS-
CONNECTING THE EXTREME LOUVER AT EITHER END. THE DAMPERS OPERATE NOW WITH
12 OF THE 14 LOUVERS. THE UTILITY IS PLEASED WITH RECENT DAMPER
OPERATIONS.
SOME RECENT SCRUBBER OUTAGES RESULTED FROM THE OCCASIONAL UNAVAILABILITY
OF LIMESTONE.
720
242
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
...—_ . .-..---..-.-.._.-__._.-.—PERFORMANCE DATA —— — — ...... ...
PERIOD MODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION t REMOVAL PER BOILER F6t CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS OUT OF SERVICE THROUGH APRIL WHILE REPAIRS CONTINUED ON
THE SCRUBBER ID FAN HOUSING. BECAUSE BOILER OPERATED AT LOW LOAD THE
SCRUBBER SERVICES WERE NOT REQUIRED IN APRIL.
5/80 SYSTEM 74*
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS OUT OF SERVICE UNTIL MAY 21 WHEN THE FAN HOUSING REPAIR
WAS COMPLETED. THE SCRUBBER WAS SHUT DOWN AGAIN ON MAY 25 WITH A SCRUBBER
ID FAN BEARING FAILURE.
6/80 SYSTEM 720
• • PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS NOT OPERATED THROUGH JUNE BECAUSE PARTS FOR THE SCRUBBER
IB FAN HAD NOT ARRIVED AT THE PLANT. SCRUBBER SERVICE WAS NOT REQUIRED
BECAUSE OF LOW BOILER LOAD.
SCRUBBER REPAIRS AT ST CLAIR REQUIRE MORE OUTAGE TIME THAN ONE WOULD EXPECT
BECAUSE THE UTILITY DOES NOT STOCK A GREAT DEAL OF PARTS FOR THE SCRUBBER.
THE ST CLAIR 6 SCRUBBER IS SCHEDULED TO BE PERMANENTLY REMOVED FROM SERVICE
IN SEPTEMBER 1981 WHEN THE NEW 100X CAPACITY ESP FACILITY CURRENTLY UNDER
CONSTRUCTION IS COMPLETE. AT PRESENT SOX OF THE FLUE GAS IS SCRUBBED AND
SOX PASSES THROUGH THE ESP. DURING LOW LOA.D PERIODS EITHER THE SCRUBBER OR
ESP CAN BE SHUT DOWN.
7/80 SYSTEM 7**
8/80 SYSTEM 74*
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM DID NOT OPERATE DURING THE JULY THROUGH SEPTEMBER
PERIOD. THE UTILITY IS WAITING ON A UNIT OUTAGE TO PERFORM THE NECESSARY
REPAIRS ON THE BOOSTER FAN AND TO REPAIR SOME MINOR SCRUBBER INTERNAL
PROBLEMS.
243
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
KENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
*• FABRIC FILTER
NUMBER
TYPE
•* ESP
NUMBER
•* MECHANICAL COLLECTOR
NUMBER
«• PARTICLE SCRUBBER
NUMBER
TYPE
MINNESOTA POWER t LIGHT
CLAY BOSWELL
3
COHASSET
MINNESOTA
364.0
347.1
350.0
( 8400 BTU/LB)
COAL
SUBBITUMINOUS
19538.
9.00
26.00
.92
.01
WET SCRUBBING
ALKALINE FLVASH
KREBS ENGINEERS
NEW
.8
1/73
5/73
.00
98.70
0
NONE
0
0
1
SPRAY IMPINGEMENT TOWER
.... -._._—.__________ „.. —PERFORMANCE DATA —.. ....... ........_
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION J REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
5/80 SYSTEM
•* PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
** PROBLEHS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM
8/80 SYSTEM
100.0
100.0
100.0
100.0
90.3
78.0
720 650
744 580
650 60.2
580 52.3
244
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
MINNESOTA POWER * LIGHT: CLAV BOSWELL 3 CCONT.)
---— PERFORMANCE DATA — —— —.........
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
9/80 SYSTEM 100.0 100.0 84.0 744 625 625 54.8
** PROBLEMS/SOLUTIONS/COMMENTS
NO OPERATIONAL PROBLEMS WERE REPORTED FOR THE JULY THROUGH SEPTEMBER
PERIOD.
245
-------
EPA UTILITY FED SURVET: JULY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
BROSS UNIT 6ENERATIN6 CAPACITY - MW
NET UNIT GENERATING CAPACITY U/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MW
MINNESOTA POWER ( LIGHT
SVL LASKIN
1
AURORA
MINNESOTA
62.0
57.3
58.0
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** FABRIC FILTER
NUMBER
TYPE
• * ESP
NUMBER
TYPE
•• MECHANICAL COLLECTOR
NUMBER
TYPE
*• PARTICLE SCRUBBER
NUMBER
TYPE
( 8800 BTU/LB)
COAL
SUBBITUMINOUS
20469.
9.00
26.70
1.00
.01
WET SCRUBBING
ALKALINE FLYASH
KREBS ENGINEERS
RETROFIT
1.1
6/71
6/71
.00
98.70
0
NONE
0
NONE
0
NONE
1
SPRAY IMPINGEMENT TOWER
__—.....—-—....—........ PERFORMANCE DATA—- —————————...._._.__.
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
•• PROBLEMS/SOLUTIONS/COMNENTS
744
696
744
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST GUARTER OF 1980.
4/80
5/80
6/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEHS/SOLUTIONS/COMNENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80
8/80
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
56.6
19.0
744
744
421
140
421
140
25.2
12.0
246
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
MINNESOTA POWER 8 LIGHT: SVL LASKIN 1 CCONT.)
—_—_—PERFORMANCE DATA——— ——————— ——— -
PERIOD MODULE AVAILABILITY OPERABUITY RELIABILITY UTILIZATION t REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEHS/SOLUT10NS/COMMENTS
THE UTILITY REPORTED THAT NO BOILER OR FCC-RELATED PROBLEMS HERE ENCOUNTER-
ED DURING JULY AND AUGUST. LOW UTILIZATION FACTORS WERE DUE TO A LACK
OF POWER DEMAND.
9/80 SYSTEM 100.0 100.0 100.0 t.4 720 33 33 1*9
** PROBLEMS/SOLUTIONS/COMMENTS
NO SCRUBBER OUTAGES OCCURRED »URIN6 SEPTEMBER. THE LOW UTILIZATION FACTOR
WAS AGAIN THE RESULT OF A LACK OF DEMAND FOR POWER.
2*7
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY" W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MW
MINNESOTA POWER ft LIGHT
SYL LASKIH
2
AURORA
MINNESOTA
63.0
57.3
58.0
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
»* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
COAL
SUBBITUMINOUS
20469.
9.00
26.70
1.00
.01
WET SCRUBBING
ALKALINE FLVASH
KREBS ENGINEERS
RETROFIT
1.1
6/71
6/71
.00
98.70
< 8600 BTU/LB)
•* FABRIC FILTER
NUMBER
TYPE
0
NONE
•* ESP
NUMBER
TYPE
•• MECHANICAL COLLECTOR
NUMBER
TYPE
•* PARTICLE SCRUBBER
NUMBER
TYPE
0
NONE
0
NONE
1
SPRAY IMPINGEMENT TOWER
_ ..—PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/fcO SYSTEM
744
2/80 SYSTEM
J/80 SYSTEM
696
744
PROBLEMS/SOLUTIONS/COMMENTS
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
720
744
720
•* PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DUR1N6 1HE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LI6HT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM
100.0
100.0
100.C
24.5
744 182
182 12.3
248
-------
EPA UTILITY FGO SURVEY.: JULY - SEPTEMBER 1980
MINNESOTA POWER 8 LI6HT: STL LASKIN 2 (CONT.)
.... . ——PERFORMANCE DATA-—-—-—-..——— ..............
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION I REMOVAL PER BOILER FGO CAP.
502 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER DID NOT OPERATE MOST OF JULY CUE TO A BOILER INSPECTION. NO
PROBLEMS WERE ENCOUNTERED WITH THE F6D UNIT.
B/80 SYSTEM 100.0 100.0 100.0 15.0 7*4 115 115 5.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER OPERATED ONLY 115 HOURS DURING AUGUST DUE TO A LACK OF DEMAND.
9/80 SYSTEM 100.0 100.0 100.0 5.2 720 39 39 2.4
«» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORT THAT NO SCRUBBER OUTACCS OCCURRED DURINC SEPTEMBER.
THE LOW UTILIZATION FACTOR RESULTED FROM A LACK OF DEMAND FOR
POWER.
249
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - My
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEU/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL $02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** MECHANICAL COLLECTOR
NUMBER
TYPE
MONTANA-DAKOTA UTILITIES
LEWIS > CLARK
1
SIDNEY
MONTANA
55.1
50.3
55.1
COAL
LIGNITE
15003.
7.80
36.20
.61
.03
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
RETROFIT
2.2
»«/•»
12/75
.00
98.00
1
MULTICLONES
f 6450 BTU/LB)
PARTICLE SCRUBBER
TYPE
VENTURI
PERFORMANCE DATA—-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/60 SYSTEM
3/80 SYSTEM
• • PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/80 SYSTEM
5/80 SYSTEM
DURING THE JANUARY THROUGH MARCH PERIOD THE SCRUBBER HAS AVAILABLE MORE
THAN 95X OF THE TIME.
THE EROSION PROBLEM MENTIONED DURING NOVEMBER CONTINUED. SECTIONS OF THE
LINED CARBON STEEL COLUMN WALL SUPPORTING tHE FLOODED DISC HERE RUPTURING,
FILLING THE INNER CHAMBER WITH SLURRY AND ULTIMATELY RENDERING THE DISC
MOVEMENT MECHANISM INOPERATIVE. THE UTILITY HAS MANAGED TO KEEP THE
SCRUBBER OPERATING AS A STOP-GAP MEASURE BETWEEN UNIT SHUTDOWNS BY INSERT-
ING A GARDEN HOSE IN THE COLUMN HOLES AND CONTINUALLY FLUSHING THE INNER
CHAMBER. THE UTILITY HAS HAD SOME SUCCESS IN OTHER EROSION AREAS BY
MAKING REPAIRS WITH A HASTELLOY MATERIAL. PLANS ARE BEING MADE TO JACKET
THE ENTIRE DISC SUPPORT COLUMN WITH HASTELLOY 6.
720
6/80 SYSTEM
•• PROBLEHS/SOLUTIONS/COHMENTS
744
720
THE BOILER WAS SHUT DOWN FOR TWO WEEKS IN HAY.
CREWS INSPECTING THE SCRUBBING SYSTEM DISCOVERED THAT THE NINE FOOT SCRUB-
BER LINER SECTION AT THE BOTTOM OF THE CYCLONIC MIST ELIMINATOR WAS SEVERE-
250
-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
MONTANA-DAKOTA UTILITIES: LEWIS t CLARK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F66 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
LY ERRODED. THE LINER HAS LASTED THREE YEARS. THE UTILITY CONSIDERS THIS
A NORMAL MAINTENANCE PROBLEM. AT ONE TIME LINERS IN THIS SECTION HERE RE-
PLACED EVERY SIX MONTHS. REPLACEMENT UORK ON THE LATEST FAILURE IS EXPECT-
ED TO BE6IN BY JULY 21.
THE ENTIRE SCRUBBER COLUMN SUPPORTING THE DISC WHICH HAS ERODING AS REPORT-
ED DURING THE PREVIOUS TWO QUARTERS HAS BEEN CLAD WITH HASTELLOY C.
THE UTILITY REPORTED THAT THE SCRUBBER HAS EXPERIENCED PLUGGING AT WET/DRY
INTERFACES WITHIN THE STRUCTURE. IT APPEAR* THAT THIS IS RELATED TO COAL
SULFUR CONTENT. WHEN THE SULFUR CONTENT IS RELATIVELY HIGH (0.7 TO 1.OS AT
LEWIS AND CLARK) THE PLUGGING DOES NOT OCCUR. LIMESTONE IS ADDED AS RE-
QUIRED TO PREVENT THE OCCURRANCE OF LOW PH LEVELS. WHEN THE SULFUR CONTENT
FALLS TO THE O.W RANGE THE PH RISES AS A RESULT OF THE ALKALINE CONSTITU-
ENTS IN THE FLY ASH UNTIL SOFT SCALE PLUGGING RESULTS. THE UTILITY HAS
CONSIDERED ADDING ACID TO STABILIZE THE PH WHEN THE COAL SULFUR CONTENT
DROPS.
7/80 SYSTEM 7**
«• PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY TWO WEEKS OF DOWN TIME WAS NECESSARY TO REPLACE THE HIST
ELIMINATOR LINER.
THE PROBLEM WITH THE FLOODED DISC BUILDUP MENTIONED EARLIER CONTINUED.
THE UTILITY PERFORMS THE NECESSARY REPAIRS IN THREE TO FOUR HOURS WHEN
THIS OCCURS.
8/80 SYSTEM 7*4
»/80 SYSTEM 7?0
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH SCRUBBING
OPERATIONS DURING THE MONTHS OF AUGUST AND SEPTEMBER.
251
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
WET UNIT GENERATING CAPACITY y/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MU
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - t
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** PARTICLE SCRUBBER
NUMBER
TYPE
PACIFIC POWER S LIGHT
DAVE JOHNSTON
I
GLENROCK
WYOMING
330.0
326.5
330.0
( 7430 BTU/LB)
COAL
SUBBITUMJNOUS
17282.
12.00
26.00
.50
.04
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, EMVIROTECH
RETROFIT
1.1
4/72
**/ **
********
VENTURI
— _ ........—.. . _—PERFORMANCE DATA ——— ............
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILEJ) FSO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
•* PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION HAS AVAILABLE FOR THE FIRST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
*• PROBLEMS/SOtUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS OCCURRED DURIN6 THE SECOND
QUARTER OF 1980.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COHMENTS
NO INFORMATION WAS AVAILABLE FOR THE THIRD QUARTER OF 1980.
252
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MU
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL SOZ REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
•* ESP
TYPE
•• PARTICLE SCRUBBER
TYPE
POTOMAC ELECTRIC POWER
DICKERSON
1
DICKERSON
MARYLAND
190.0
183.0
COAL
******
27214.
14.00
*•***•**
2.00
UET SCRUBBING
RETROFIT
( 11700 BTU/LB)
**/ «*
0/78
99.00
COLD SIDE
VENTURI
.. . . -PERFORMANCE DATA — — ...———
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
1/80
2/80
J/8C
SYSTEM
SYSTEM
SYSTEM
100.
94.
100.
0
3
0
100.
95.
100.
0
8
0
100.
94.
100.
0
3
0
744
696
744
744
685
744
744
656
744
•* PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 ONLY ONE SCRUBBER OUTAGE OCCURRED. IN
FEBRUARY OUTAGE TIME WAS NECESSARY TO REPAIR A SLURRY RECYCLE LINE LEAK.
4/80
5/80
6/8C
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
7/80
3/80
9/80
SYSTEM
SYSTEM
SYSTEM
DICKERSON 1 SCRUBBER DEPENDABILITY FACTORS WERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD. THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
REPORT. THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED THE ENTIRE
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS WERE REPORTED.
744
744
720
253
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 1 (CONT.)
....... . . PERFORMANCE DATA ——.—.-..
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•* PROBLEBS/SOLUT10NS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
254
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME POTOMAC ELECTRIC POWER
PLANT NAME DICKERSON
UNIT NUMBER Z
CITY DICKERSON
STATE MARYLAND
GROSS UNIT GENERATING CAPACITY - Hy 190.3
YET UNIT GENERATING CAPACITY W/SCRUBBER - MU 183.3
EQUIVALENT SCRUBBED CAPACITY - MU *******
•• FUEL DATA
FUEL TYPE COAL
FUE.L GRADE ******
AVERAGE HEAT CONTENT - J/G 27214. ( 11700 BTU/LB)
AVERAGE ASM CONTENT - X 14.00
AVERAGE MOISTURE CONTENT - T ********
AVERAGE SULFUR CONTENT - X 2.00
AVERAGE CHLORIDE CONTENT • X ********
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE UET SCRUBBING
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEy/RETROFIT RETROFIT
ENERGY CONSUMPTION - X *******
INITIAL START-UP DATE **/*«
COMMERCIAL START-UP DATE 0/78
TYPICAL S92 REMOVAL - X ********
PARTICLE DESIGN REMOVAL EFFICIENCY - X 99.00
«* ESP
TYPE COLD SIDE
** PARTICLE SCRUBBER
TYPE VENTURI
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
2/80
5/80
4/80
5/80
6/80
SYSTEM 95.4 96.4
** PROBLEMS/SOLUTIONS/COMMENTS
95.4
744
736
710
IN JANUARY THE SCRUBBER WAS DOWN FOR THREE HOURS TO REPAIR A SLURRY
RECYCLE LINE LEAK.
31 HOURS OF THE OUTAGE TIME IN JANUARY UAS NECESSARY TO REPAIR A RECYCLE
PUMP.
SYSTEM 100.0 100.0
SYSTEM 96.9 96.9
•• PROBLEMS/SOLUTIONS/COMMENTS
100.0
96.9
696
744
696
744
696
721
IN MARCH THE SCRUBBER UAS DOUN FOR A SCRUBBER LINING WARRANTY INSPECTION.
NO REPAIR WORK UAS NECESSARY.
SYSTEM
SYSTEM
SYSTEM
• * PROBLEMS/SOLUTIONS/COMMENTS
720
720
7/80 SYSTEM
DICKERSON 2 SCRUBBER DEPENDABILITY FACTORS MERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD. THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
REPORT. THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED THE ENTIRE
SECOND OUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS UERE REPORTED.
744
Z55
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19?C
POTOMAC ELECTRIC POWER: DICKERSON 2 (CONT.)
p£PfONMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PEP BOILER fGO C»P.
SO? PART. HOURS HOURS HOURS FACTOR
B/60 SYSTEM 744
9/80 SYSTEM 7?0
•* PROBLEHS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENOA6ILITY FIGURES AS YtT.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY HAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
256
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION U
DESI6N AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/SCRUB8ER - HU
EQUIVALENT SCRUBBED CAPACITY - MU
•• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTEXT - X
AVERAGE CHLORIDE CONTENT - X
*• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
• • ESP
NUMBER
TYPE
• * PARTICLE SCRUBBER
NUMBER
TYPE
POTOMAC ELECTRIC POWER
DICKERSON
3
DICKERSON
MARYLAND
190.0
183.0
*******
COAL
BITUMINOUS
27214.
14.00
********
2.00
WET SCRUBBING
RETROFIT
( 11700 BTU/LB)
9/75
**/ •*
.00
99.3C
COLD SIDE
1
VENTURI
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
2/80
3/80
4/80
5/8C
6/80
SYSTE" 78.7 88.2 7?.7 744 664 586
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE SCRUBBER HAS DOWN TO REPAIR THE FLAKEGLASS LINING.
SYSTEM 100.0 100.0 100.0 696 696 696
SYSTEM 100.0 10C.O 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED UITH NO MAJOR PROBLEMS.
SYSTE* 720
SYSTEM 744
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT 3 SCRUBBER EXPERIENCED SOME DOWN TIME DURING THE APRIL-JUNE PERIOD
AS A RESULT OF THE CONTINUING DETERIORATION OF THE SCRUBBER FLAKEGLASS
LINING. THE UTILITY REPORTED THAT MAINTENANCE CREWS ARE PATCHING OLD
PATCHES. A STUDY WILL BEGIN IN LATE JULY iTO ESTABLISH THE OPTIMUM LINEP
MATERIAL AND APPLICATION STRATEGY FOR THE UNIT 3 SCRUBBING SYSTEM.
7/80
8/BO
9/80
SYSTEM
SYSTEM
SYSTEM
744
744
720
257
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 3 CCONT.)
—— — — PERFORMANCE DATA————— —.———. —_.._.__._..
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER FGt CAP.
502 PART. HOURS HOURS HOURS FACTOR
** PROBLENS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS VET.
THE UTILITY REPORTED HAVIN6 MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED TO 1/2 LOAtt DURING PART OF THE PERIOD DUE
TO THE NECESSARY PATCHING OF THE SCRUBBER LINING. THE UTILITY IS PRESENTLY
STUDYING THE POSSIBILITY OF REPLACING THE PLAKEGLASS LINER WITH A RUBBER
LINER.
258
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/SCRUBBER - MU
EQUIVALENT SCRUBBED CAPACITY - MU
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEK/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL SOZ REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** FABRIC FILTER
NUMBER
TYPE
• • ESP
NUMBER
• * MECHANICAL COLLECTOR
NUMBER
•* PARTICLE SCRUBBER
NUMBER
TYPE
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
113.0
109.8
112.0
( 10200 BTU/LB)
COAL
SUBBITUNINOUS
33725.
9.30
13.70
.95
.01
MET SCRUBBING
ALKALINE FLVASH
AIR CORRECTION DIVISION, UOP
RETROFIT
*******
9/73
**/ **
********
0
NONE
1
MOBILE PACKED TOWER
PERFORMANCE DATA
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
502 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
5/80 SYSTEM
** PROBLEWS/SOLUTIONS/COMMENTS
744
696
744
4/80 SYSTEM
THE MODULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST QUARTER OF 1980.
USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED. THE PROGRAM FOR RE-
PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY. THE UNIT IS SHUTDOWN
yHEN MAJOR SCRUBBER PROBLEMS OCCUR.
REHEATER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS. THE SIX STEAM COILS
ON THIS IN-LINE REHEAT SYSTEM, TWO OF WHICH ARE 316SS AND FOUR OF WHICH
ARE CARBON STEEL, ARE EXPERIENCING CORROSION PROBLEMS. A SOLUTION TO THE
PROBLEM HAS NOT VET BEEN DETERMINED.
IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER BALLS AND GRIDS. THE OLD
BALLS WERE REPLACED WITH THE NEW HOLLOW HARD PLASTIC-WALLED BALLS WITH
NOTCHED SEAMS. THE GRIDS WERE ORIGINALLY 116L SS, CERAMIC, POLYPROPYLENE,
AND RUBBER LINED CARBON STEEL, BUT HAVE BEEN REPLACED WITH 317L SS GRIDS.
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER EXCEPT FOR THE
BALL AND GRID REPLACEMENT DOWNTIME.
100.0
100.0
720 720
720
259
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
PERFORMANCE DATA . .._
PERIOD MODULE AVAILABILITY OPERABILITr RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
$02 PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 100.0 100.0 7*4 7*4 744
6/80 SYSTEM 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMKENTS
BOTH BOILER AND SCRUBBERS OPERATED THE ENTIRE APRIL-JUNE PERIOD.
THE ISOLATION DAMPERS ARE STILL EFFECTIVELY. INOPERABLE AND A REPLACEMENT
PLAN AS YET HAS NOT BEEN REESTABLISHED.
THE UTILITY REPORTED THAT THE REHEATER TUBE LEAK PROBLEM CONTINUED THROUGH
THE SECOND QUARTER. THE TUBES WILL BE ENTIRELY REPLACED WITH NEW 316L SS
BUNDLES DURING THE NEXT SCHEDULED OUTAGE IM NOVEMBER AND DECEMBER. DURING
THE SECOND QUARTER MORE TUBES WERE BLANKED OFF AFTER STEAK LEAKS OCCURRED.
TO DATE ROUGHLY SOX OF THE TUBES ARE SEALED OFF AND ARE OUT OF SERVICE
BECAUSE OF LEAKS THAT OCCURRED OVER THE PAST MONTHS.
7/80 SYSTEM
8/80 SYSTEM
9/80 SYSTEM
100.0
100.0
100.0
10C.O
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
7*4
7*4
720
7*4
744
720
744
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBERS OPERATED ACCEPTABLY DURING THE JULY-SEPTEMBER PER-
IOD. NO PLANS HAVE BEEN MADE TO REPAIR THi ISOLATION DAMPERS. THE FAULTY
REHEATER TUBES WILL BE REPLACED DURING THE SCHEDULED OUTAGE NOW SET FOR THE
FIRST THREE KEEKS Of DECEMBER.
260
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING CAPACITY - HU
NET UNIT GENERATING CAPACITY W/SCRUBBER - HU
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE NEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - T
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** FABRIC FILTER
NUMBER
TYPE
• * ESP
NUMBER
** MECHANICAL COLLECTOR
NUMBER
•• PARTICLE SCRUBBER
NUMBER
TYPE
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
115.0
100.0
102.2
( 10100 BTU/LB)
COAL
BITUMINOUS
23493.
12.50
11.30
.65
.01
WET SCRUBBING
ALKALINE FLYASH
AIR CORRECTION DIVISION, UOP
RETROFIT
4.3
6/73
• */ «»
0
NONE
MOBILE PACKED TOWER
...... — ....... ...... . — PERFORMANCE DATA •
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
2/60
3/80
SYSTEM
SYSTEM
SYSTEM
IOC.
100.
1CC.
c
0
o
100
100
ion
.0
.0
.0
744
696
744
744
696
744
744
696
744
** PROBLEMS/SOLUTIONS/COMPENTS
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE FIRST QUARTER OF 198C.
THE ISOLATION DAMPERS HAVE NOT CAUSED ANY PROBLEMS BECAUSE MODULE
ISOLATION HAS NOT REQUIRED DURING THE PERIOD.
THE FANS ARE STILL EXPERIENCING EROSION PROBLEMS.
IN MARCH A BOILER/SCRUBBER OVERHAUL BEGAN. DURING THIS TIME THE CARBON
STEEL ISOLATION DAMPERS WILL BE REPLACED WITH 316 SS. THE NEW FANS
WILL BE INSTALLED IN THE OLD HOUSINGS. THE NEW HIGH STRENGTH CARBON STEEL
FANS WILL BE EQUIPPED tolTH REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE
TIPS.
4/EO SYSTEM
5/80 SYSTEM
6/60 SYSTEM
720
744
720
261
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 1 UONT.>
......... ........ ——PERFORMANCE DATA——————— —————....
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION f REMOVAL PER BOILER FED CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
«* PROBLEMS/SOLUTIONS/COMHENTS
THE 1B 10 FAN UAS SEVERELY ERRODEO. THE F*N WAS REBUILT DURING THE OUTAGE.
THE OLD CARBON STEEL ISOLATION DAMPERS UER8 REPLACED WITH 316 SS DAMPERS
DURING THE CONTINUING MAY-JULY OUTAGE.
7/8C SYSTEM 74*
3/60 SYSTEM 744
9/80 SYSTEM 730
•* PROBLEMS/SOLUTIONS/COMMENTS
SHAFT BEARING FAILURES ON THE RECIRCULATION PUMP CAUSED SCRUBBER SYSTEM
PROBLEMS THROUGHOUT THE JULY-SEPTEMBER PERIOD.
26Z
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/SCRUBBER - MV
EBUIVALENT SCRUBBED CAPACITY - MW
•• FUEL DATA
FUEL TYPE
FULL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - I
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
• • GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL SOZ REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** FABRIC FILTER
NUMBER
TYPE
• * ESP
NUMBER
• « MECHANICAL COLLECTOR
NUMBER
** PARTICLE SCRUBBER
NUMBER
TYPE
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
375.0
350.0
356. 4
( 10100 BTU/LB)
COAL
BITUMINOUS
23493.
12. 50
11.30
.65
.01
WET SCRUBBING
ALKALINE FLVASH
AIR CORRECTION DIVISION, UOP
RETROFIT
6.7
7/74
**/**
********
********
0
NONE
MOBILE PACKED TOWER
DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
J/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
THE OUTLET DUCT WORK IS BEING REBUILT INTERNALLY WITH FIBERGLASS FOR
STRUCTURAL SUPPORT AND ACID RESISTANCE. WITH REGULAR MAINTENANCE THE
UTILITY EXPECTS THIS TO PROVE TO BE A PERMANENT SOLUTION TO THE EROSION/
CORROSION PROBLEM.
THE OLD FANS ARE BEING REPLACED WITH HIGH STRENGTH CARBON STEEL FANS HAVING
REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE TIPS.
720
744
720
263
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
SO? PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
PROBLEMS/SOLUTIONS/COMMENTS
THE NEW FANS DESCRIBED DURIN6 THE LAST REPORT PERIOD HERE INSTALLED IN ONE
OF THE FOUR MODULES. NEW FANS WILL BE INSTALLED IN THE OTHER THREE MODULES
DURING A SCHEDULED LATE SEPTEMBER OUTAGE UNLESS THE UTILITY HAS AN OPPOR-
TUNITY TO MAKE THE REPLACEMENTS SOONER.
7/80 SYSTEM
7*4
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER RETURNED TO SERVICE IN MID JULY AFTER A TWO WEEK OUTAGE.
DURING THIS TIME, THE FIBERGLASS INSIDE THC DUCTVORK WAS REPLACED, AND A
VERTICAL GRID WAS INSTALLED ON THE SECOND LEVEL OF THE MOBILE BED TOUER TO
IMPROVE SYSTEM PERFORMANCE.
8/80 SYSTEM
>/80 SYSTEM
** PR08LEMS/SOLUTIONS/COMMENTS
74*
720
THE BOILER AND FGO SYSTEM WENT DOUN ON SEPTEMBER 15, 1980 FOR A SCHEDULED
OVERHAUL. CURING THIS TIME, FANS HERE INSTALLED ON MODULES A, C, AND 0.
THE UTILITY IS CURRENTLY EVALUATING THE VERTICAL GRID ON THE SECOND LATER.
IF THE GRID IMPROVES SYSTEM PERFORMANCE. THEY WILL INSTALL ANOTHER ONE
ON THE THIRD LEVEL.
264
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE OAT* FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MU
PUBLIC SERVICE
VALMONT
5
VALHONT
COLORADO
166.0
157.0
166.0
Of COLORADO
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - t
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL S02 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - t
.* FABRIC FILTER
NUMBER
TYPE
COAL
SUBBITUMINOUS
25121.
6.00
15.00
.70
( 1080C BTU/LB)
WET SCRUBBING
LIMESTONE/ALKALINE FLVASH
UOP/PUBLIC SERVICE OF COLORADO
RETROFIT
3.6
11/71
10/74
85.00
95.00
0
NONE
• * ESP
NUMBER
TYPE
»* MECHANICAL COLLECTOR
NUMBER
1
COLD SIDE
1
* PARTICLE SCRUBBER
NUMBER
TYPE
MOBILE PACKED TOWER
— . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1T1 RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 A
B
SYSTEM
Z/BO A
B
SYSTEM
98.5
98.5
98.5
84. *
94.9
89.7
7*4
696
3/8C
A
B
SYSTEM
90.8
87.7
89.0
74*
615
•« PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980, NO MAJOR PROBLEMS HERE ENCOUNTERED WITH
THE SCRUBBER.
A
B
SYSTEM
88.1
88.1
88.1
720 716
*• PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS SHUT DOWN ON APRIL U FOR A WEEK TO MAKE REPAIRS TO A HOLE
IN THE SCRUBBER RUBBER LINING, RECYCLE PUMP LININGS AND A STEAM REGULATOR
ON ONE OF THE REHEATERS.
265
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
-PERFORMANCE DATA-- — -.___.
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
5/80
A
B
SYSTEM
96.8
100.0
98.4
7** 74*
•« PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE REPORTED FOR MAY.
6/80 A 8.0
B 8.0
SYSTEM 8.0 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER WAS FORCED OUT OF SERVICE WHEN AN INBOARD FAN
PEOISTLE BEARING FAILED. THE BEARING SECTION WAS REBUILT.
WHILE fAN REPAIRS WERE IN PROGRESS EXTENSIVE MAINTENANCE WAS PERFORMED ON
THE SCRUBBER. MAINTENANCE WORK INCLUDED COMPLETE BALL REPLACEMENT, ADDI-
TIONAL REPAIR WORK ON THE SCRUBBER LINER, REPAIR OF HOLES IN THE TOWER
SHELL AND OF A RUPTURED MIST ELIMINATOR WASH LINE AND THE REHEATER WAS
CLEANED.
DAMPER JAMMING AT VALMONT HAS OCCURRED PERIODICALLY. SOMETIMES DAMPERS 00
NOT READILY CLOSE. THE OPERATOR MUST MOVE THE DAMPER UP AND DOWN UNTIL THE
GUILLOTINE SEATS. BECAUSE OF CONTINUOUS FLY ASH ACCUMULATION IT APPEARS
THAT THE DAMPERS MUST BE EXERCISED FREOUEN.TLY TO PREVENT JAMMING.
7/80 5A 4g.3 46.6
SB 48.3 46.6
SYSTEM 48.3 *6.6 744 719 347
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER SYSTEM WAS SHUT DOWN BECAUSE OF SCRUBBER BOOSTER FAN
BEARING FAILURE.
8/80 5A 87.5 84.8
58 95.6 92.6
SYSTEM 91.5 87.7 7*4 721 660
•* PROBLEMS/SOLUTIONS/COMMENTS
THE RECIRCULATION PUMP MOTOR BEARING FAILED CAUSING SOME MINOR OUTAGE
TIME IN AUGUST.
9/80 SYSTEM .0 720 0 0
•* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBER WERE SHUT OOVN DURING SEPTEMBER FOR SCHEDULED
MAINTENANCE.
266
-------
EPA UTILITY F€0 SURVEY: JUtY - SEPTEMBER 1980
SECTION U
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - HU
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - *W
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL SOE REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - %
• • ESP
NUMBER
TYPE
• * PARTICLE SCRUBBER
NUMBER
TYPE
SOUTHWESTERN PUBLIC SERVICE
HARRINGTON
1
AMARILLO
TEXAS
360.0
320.0
360.0
COAL
SUBBITUMINOUS
19538.
5.00
27.10
.42
( 8400 6TU/LB)
UET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
NEW
4/77
**/ **
50.00
99.00
COLD SIDE
MOBILE PACKED TOWER
. ......... .................—.......pERfORMANCE DATA——
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER fGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
*• PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THROUGH DECEMBER, TUO SPRAY PUMP MOTORS FAILED.
THE FRP FLUSH PIPING HAS FAILED CAUSING SOME LEAKING.
PLUGGING IN ONE MARBLE BED WAS ENCOUNTERED WHEN THE CHEMISTRY CONTROL U*S
TEMPORARILY LOST.
THE CONE SHAPED EXPANDED METAL (316L SS) SCREENS COVERING THE BED DRAIN
PIPES HAVE ERODED AWAY FROM BALL MOVEMENT. THE MARBLE BALLS HAVE BEEN
DROPPING INTO THE RECYCLE TANK. WHERE THE UTILITY HAS REPLACED THE METAL
SCREEN WITH EXPANDED PLASTIC SCREEN, EROSION HAS NOT OCCURRED.
744
696
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
•* PROBLENS/SOLUTIONS/COMPENTS
744
DURING THE FIRST QUARTER OF 1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
CAUSING PLUGGING IN SCRUBBERS 4 AND 5. THE UTILITY PLANS TO REPLACE
ALL FRP PIPING WITH STEEL. THE RUPTURE ON NO. 5 ALSO DAMAGED THE MATER
SUPPLY HEADER.
267
-------
EPA UTILITT F6D SURVEY: JULY - SEPTEMBER 1980
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
THE WARBLE BED PLUGGING REPORTED DURING THE LAST QUARTER IS NOT YET
COMPLETELY CLEARED. THE SOFT SCALE IS GRADUALLY GOING BACK INTO THE
SOLUTION. THF PLATE AREA IS CLEAN.
THE DUCT BENEATH THE REHEATEK TUBING ON ONE OF THE MODULES HAS CORRODED TO
THE POINT THAT HOLES HAVE FORMED. SCALE AND MOISTURE WERE FOUND ON THE
PLATE WHERE THE CORROSION FORMED. THE PLATE WAS REMOVED AND A NEW CARBON
STEEL PLATE yAS WELDED IN. NO OTHER REHEATER DUCTS HAVE EXPERIENCED ANY
SCALE OR MOISTURE ACCUMULATION.
SYSTEM
«* PROBLcMS/SOLUTIONS/COMPIENTS
A PUMP LINER FAILURE OCCURRED IN APRIL.
PAIRED AND REPLACED.
s/e:
SYSTEM
720
THE IMPELLER SHAFT LINER WAS RE-
7(4
PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN A F£W DAYS IN LATE APRIL AND 12 TO U DAYS IN
EARLY MAY FOR AIR PREHEATER REPAIRS.
DURING APRIL AND MAY THE SCRUBBING SYSTEM EXPERIENCED AGITATOR PROBLEMS.
THE RECENT PROBLEMS HAVE BEEN RELATED TO BEARING FAILURE. HOWEVER, THE
SEALS HAVE BEEN LEAKING AS WELL. THE AGITATORS AT THIS FACILITY ARE SIDE
MOUNTED. THE AGITATOR SHAFT ENTERS THE TANK AT ROUGHLY 12 FT BELOW THE
FLUID SURFACE. IT APPEARS THAT THE SEAL LEAKING MAY BE ATTRIBUTABLE TO
FAULTY INSTALLATION.
6/80 SYSTEM 92.1
*» PROBLEMS/SOLUTIONS/COMMENTS
720
696
79.3
7/80 SYSTEM
8/80 SYSTEM
9/8P SYSTEM
DURING JUNE THE SCRUBBER EXHIBITED AN AVAILABILITY OF 92.U. THERE WAS
GREATER SCRUBBED CAPACITY AVAILABLE THAN REQUIRED BY THE BOILER. NO
PROBLEMS WERE REPORTED FOR JUNE.
DAMPER PROBLEMS REPORTED PREVIOUSLY HAVE PEEN ELIMINATED. THE OLD OPERATOR
MECHANISMS WERE REPLACED WITH OPERATORS SUPPLIED BY ANOTHER MANUFACTURER.
ONE OF THE MARBLE BEDS IS STILL PARTIALLY PLUGGED. THE MATERIAL SEEMS TO
BE HARD CALCIUM SULFATE SCALE. THE SCALE WILL PROBABLY NOT CLEAR FURTHER
THROUGH DISSOLUTION DURING NORMAL SCRUBBER OPERATIONS AS HAD BEEN HOPED.
ALTHOUGH THE MODULE MUST OPERATE AT LOWER 1HAN DESIGN GAS FLOW SCRUBBER
OPERATIONS ARE NOT HAMPERED OVERALL BECAUSE THE SYSTEM HAS SOME DESIGN
SPARE CAPACITY.
THE REHEATER PROBLEM REPORTED PREVIOUSLY HAS OCCURRED ON THREE REHEATERS
NOW. THE FAILURE OF THE REHEATER DUCT BOTITOM PANELS KAY BE A RESULT OF AN
UNDERSIZED DEFLECTION SHIELD BENEATH THE TUBE BANKS. IT IS ALSO POSSIBLE
THAT THF DUCTING WAS IMPROPERLY WELDED.
744
744
720
PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR SCRUBBING SYSTEM PROBLEMS OCCURRED
DURING THE THIRD QUARTER 1980.
THE PROBLEM REPORTED EARLIER WITH THE HIST ELIMINATOR WASH PIPING IS
PRESENTLY BEING SOLVED BY REPLACING THE PIPING WITH CARBON STEEL.
268
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION IS
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAHE
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - Mw
*• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* F6D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
$02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MIKE-UP WATER - LITER/S
•« BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
CHU60KU ELECTRIC
SHIMONOSEKI
1
SHIMONOSEKI
JAPAN
175.0
175.0
175.0
- X
( 10768 BTU/LB)
COAL
******
25046.
24.60
2.30
.59
.04
WET SCRUBBING
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
RETROFIT
5/79
7/79
85.00
.0
OPEN
6.8
GYPSUM
( 108 6PM)
... — ........ . PERFORMANCE DATA — —
PERIOD MODULE AVAILABILITY OPERAPILITT RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
2/80
SYSTEM
SYSTEM
100.0
55.2
100
100
.0
.0
10C
55
.0
.2
100
55
.0
.2
744
696
744
384
744
384
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY AND THE FIRST HALF OF FEBRUARY THE F6D UNIT OPERATED WITH
NO PROBLEMS. THE BOILER WAS TAKEN OFF-LIN6 ON FEBRUARY 8 FOR SCHEDULED
MAINTENANCE.
.0
744
J/80 SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED DOWN THROUGH MARCH FOR ANNUAL MAINTENANCE.
4/80 SYSTEM 100.0 100.0
** PROBLEMS/SOLUTIONS/COHMENTS
10C.O
83.1
720 598
S98
DURING THE ANNUAL MAINTENANCE THE SCR (SELECTIVE CATALYTIC REDUCTION OF
NOX) UNIT WAS CONNECTED BETWEEN THE BOILER AND AIR PREHEATER. AFTER THE
STARTUP ON APRIL 6, COAL ONLY HAS BEEN USED (BEFORE FEBRUARY, COAL AND
OIL WERE USED 50:50). EXCEPT FOR A 2 HOUR SHUTDOWN FOR A TURBINE TEST ON
APRIL 7, THE FGD SYSTEM HAS OPERATED CONTINUOUSLY WITH NO PROBLEMS.
5/80 SYSTEM
100.0
100.0
100.0
90.3
744 672
672
269
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
CMUGOKU ELECTRIC: SHIMONOSEKI 1 (CONT.)
...... .... ....... .—.—-PERFORMANCE DATA ..... _
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED CONTINOUSLV WITH NO PROBLEMS. A THREE DAY
SHUTDOWN FOR INSPECTION OF THE SCR UNIT FROM HAY 16 TO MAY 19 HAS THE
ONLY DOWN TIME EXPERIENCED DURING MAY.
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
*• PROBLEMS/SOLUTIONS/COMPENTS
THE FGD SYSTEM OPERATED CONTINOUSLV WITH NO PROBLEMS DURING JUNE.
7/80 SYSTEM 744
8/80 SYSTEM 744
»/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOiT VET AVAILABLE.
270
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREICN FED SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
• * FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•• FGO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP HATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULAR DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO
ISOGO
1
YOKOHAMA
JAPAN
265.0
238.0
265.0
- X
COAL
*** **•
25956.
16.00
7.00
.60
WET SCRUBBING
LIMESTONE
IHI - CMEMICO
RETROFIT
*** **•*
12/75
3/76
90.00
96.70
.0
OPEN
22.3
GYPSUM
MARKETED
( 11160 BTU/LB)
< 354 6PM)
_.._...__..—..—.——.._——-_„—... PERFORMANCE DATA-———————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79 SYSTEM
5/79 SYSTEM
5/79 SYSTEM
7/79 SYSTEM
ft/79 SYSTEM
»/79 SYSTEM
ID/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
1/80 SYSTEM
2/80 SYSTEM
5/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
7*4
720
744
744
720
744
720
744
744
696
744
4/80 SYSTEM
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
100.0 10C.O 100.0 100.0 720 720 720
271
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 198C
ELECTRIC POWER DEVELOPMENT CO: ISOSO 1 (CONT.)
. PERFORMANCE DATA —
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
5/8P
ft/en
7/80
8/80
9/80
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER FOR THE ENTIRE MONTH OF
APRIL.
SYSTEM 100.0 100.0 100.0
SYSTEM 100.0 100.0 10C.O
»* PROBLE*S/SOLUTIONS/COMI«£NTS
51.6
13.3
744
720
384
96
384
96
THE BOILER WAS SHUT DOWN FROM MAY 17 TO JUNE 27 FOR ANNUAL MAINTEN-
ANCE. THE FGD SYSTEM WAS OPERATED DURING ALL OF THE BOILER OPERATION
IN MAY AND JUNE.
SYSTEM 744
SYSTEM 744
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOT YET AVAILABLE.
272
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1960
SECTION 15
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - My
EBUIVALENT SCRUBBED CAPACITY - MW
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* FSO SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEri/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP BATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPIRE COMPONENTS INDEX
• * WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO
I SO GO
2
YOKOHAMA
JAPAN
265.0
238.0
265.0
COAL
25958.
16.00
7.00
.60
*** *****
{ 11160 BTU/LFI)
WET SCRUBBING
LIMESTONE
IHI - CHENICO
RETROFIT
3.C
3/76
5/76
90.00
96.70
.0
OPEN
22.3
GYPSUM
MARKETED
( 554 GPM)
PERFORMANCE DATA .
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION i REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79 SYSTEM 7?0
5/79 SYSTEM 744
i/79 SYSTE" 720
7/79 SYSTEM 744
3/79 SYSTEM 744
9/79 SYSTEM 720
ID/79 SYSTEM 744
11/79 SYSTEM 720
12/70 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/60 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 1CO.O 33.3 720 240 240
273
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 2
-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAflE
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY V/F6D - MU
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STABT-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARF COMPONENTS INDEX
»* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
- X
ELECTRIC POWER DEVELOPMENT CO
TAKASAGO
1
TAKASAGO
JAPAN
250.0
230.0
250.0
COAL
******
25958.
22.00
7.00
1.80
********
WET SCRUBBING
LIMESTONE
MITSUI - CHEMICO
RETROFIT
3.2
2/75
**/ **
93.00
( 11,160 BTU/LB)
.0
OPEN
13.1
GYPSUM
( 208 GPM)
DATA ------ - --- - -------------------------------
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
t/79 SYSTEM 720
6/79 SYSTEM 720
7/79 SYSTEM 74<,
S/79 SYSTEM 744
9/79 SYSTEM 720
13/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
Z/80 SYSTEM 696
J/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 10?. 0 100.? 30.0 720 216 216
275
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 1 (COST.)
_ PERFORMANCE DATA ——
PERIOD NODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLE«IS/SOLUTIONS/COM«ENTS
THE BOILER WAS SHUTDOWN ON MARCH 29 FOR ANNUAL MAINTENANCE. THE UNIT
REMAINED OFF LINE THROUGH APRIL 21. WHEN OPERATIONS COMMENCED THE FGD
SYSTEM OPERATED WITH THE BOILER FOR THE REST OF THE MONTH.
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
«* PROBLEHS/SOLUTIONS/COMMENTS
THE FGD SYSTEM EXPERIENCED NO PROBLEMS DURING THE HAY-JUNE PERIOD.
7/80 SYSTEM 744
S/80 SYSTEM 744
9/80 SYSTEM 720
•• PROBLEMS/SOLUTIONS/COMMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOJ YET AVAILABLE.
276
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COBPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - fW
MET UNIT GENERATING CAPACITY W/FGD - My
EBUIVALENT SCRUBBED CAPACITY - MU
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - T
** F6D SYSTEM
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
•• WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
•• BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
- X
ELECTRIC POWER DEVELOPMENT CO
TAKASAGO
z
TAKASAGO
JAPAN
Z50.0
230.0
250.0
COAL
******
25958.
22.00
7.00
1.80
WET SCRUPBING
LIMESTONE
MITSUI - CHEMICO
RETROFIT
3.2
3/76
**/ **
93.PO
( 11160 BTU/LB)
.0
OPEN
17.1
GYPSUM
( 208 GPM)
PERFORMANCE DATA ---
PERIOD MODULE AVAILABILITY OPERARILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/79 SYSTE" 720
5/79 SYSTEM 74*
5/79 SYSTE" 720
7/79 SYSTEM 744
S/79 SYSTEM 744
?/79 SYSTEM 720
13/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/8T SYSTEM 744
2/80 SYSTEM 696
3/bC SYSTE" 744
•* PROBLEMS/SOLUTIONS/COWENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.fi 100.0 1CC.O 100.0 720 720 720
277
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASA60 2 (CONT.)
PERFORMANCE DATA --—--—__
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 100.0 10C.O 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL AND MAY THE UTILITY EXPERIENCED NO PROBLEMS WITH THE FGft
SYSTEM.
6/80 SYSTEM 100.0 100.0 100.0 4.4 7?0 32 32
•• PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUTDOWN FROM JUNE 3 TO JUNE 24 FOR ANNUAL MAINTENANCE.
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER THE REMAINDER OF THE TIME.
7/80 SYSTEM 744
9/BO SYSTEM 744
9/8C SYSTEM 720
*» PROBLtMS/SOLUTIONS/COMMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOT YET AVAILABLE.
278
-------
6PA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NINE
JNIT NUM9ER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - M*
MET UNIT GENERATING CAPACITY W/FGD - "U
EQUIVALENT SCRUBBED CAPACITY - My
*• FUEL DATA
FUEL TYPE
FUEL GRADE
HVESAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** F&D SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - %
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
«* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** PYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELECTRIC POWER DEVELOPMENT CO
TAKEHARA
1
MIHARA
JAPAN
Z50.0
231.0
250.0
- X
COAL
******
25130.
23.00
9.05
2.00
.05
WET SCRUBBING
LIMESTONE
BABCOCK - HITACHI
RETROFIT
3.2
2/77
2/79
94.20
91.70
.0
( 10804 BTU/LB)
OPEH
U.9
6YPSUH
MARKETED
( 237 6PM)
__ — — ——PERFORMANCE DATA—-—-————-.—.__..—.—.—...—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
SOJ PART. HOURS HOURS HOURS FACTOR
SYSTEM
5/79 SYSTEM
J/79 SYSTEM
7/79 SYSTEM
B/79 SYSTEM
9/79 SYSTEM
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
1/80 SYSTEM
2/80 SYSTEM
J/8P SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
7*4
720
744
744
720
744
720
744
744
696
744
4/80 SYSTEM
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
100.0 100.0 100.0 100.0 720 720 720
279
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 19?0
ELECTRIC POWER DEVELOPMENT CO: TAKEHARA 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/e?
6/80
SYSTEM
SYSTEM
100.0
100.0
IOC
100
.0
.0
100.
100.
0
0
100
100
.0
.0
744
720
744
720
744
720
** PROBLEMS/SOLUTIONS/COMKENTS
DURING THE APRIL, MAY AND JUNE PERIOD THE FGD SYSTEM OPERATED CONTINUOUSLY
WITHOUT APPRECIABLE TROUBLE.
7/80 SYSTEM 744
3/8C SYSTEM 744
J/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE THIRD QUARTER UPDATE INFORMATION IS NOT VET AVAILABLE.
280
-------
APPENDIX A
FGD SYSTEM COST DATA: OPERATIONAL AND NONOPERATIONAL SYSTEMS
A-l
-------
INTRODUCTION
The cost of flue gas desulfurization (FGD) systems for the
control of sulfur dioxide emissions is an area of intense inter-
est and substantial controversy. As a result, many computer
models have recently been developed to estimate capital and
annual costs. As part of an effort by the U.S. Environmental
Protection Agency to provide meaningful economic data concerning
FGD systems, reported economic data have been incorporated into
the EPA Utility FGD Survey report. This information has appeared
as a separate appendix of the report since October 1976. Until
January 1978, this cost appendix consisted entirely of data
reported by the utilities with little or no interpretation pro-
vided by PEDCo Environmental, Inc. Beginning with the May 1978
report, the format and content of the cost appendix were revised
to include reported and adjusted costs for the operational FGD
systems.
The rationale for including adjusted as well as reported
costs stems primarily from the lack of comparability of the
reported costs. Many of the reported cost figures, both capital
and operating, are largely site-sensitive values that cannot be
accurately compared because they refer to different FGD battery
limits and different years in which the expenditures were made.
As a result, an analysis of the cost data was made for the opera-
tional units since these systems offer the potential of having
complete and accurate economic data. The adjustments were made
to provide comparable, accurate cost data for the sulfur dioxide
portion of the emission control system. This, in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.
A-2
-------
In an attempt to promote further comparability of the
figures, the adjustment procedure was carried one step further
and standardized adjusted figures were developed. This was done
by modifying the fixed annual cost rates such that they would be
identical for each unit (i.e. cost of depreciation, interim re-
placement, taxes, insurance and capital costs). The newly ad-
justed total fixed annual cost rate was applied to the total ad-
justed capital cost in each case and a standardized adjusted
annual cost was obtained.
A-3
-------
APPROACH
In March 1978, each utility having at least one operational
FGD system was given a cost form containing all available cost
information then in the PEDCo files. The utility was asked to
verify the data and fill in any missing information called for
on the form. A follow-up visit by the PEDCo Environmental staff
was arranged to assist in data acquisition and to insure com-
pleteness and reliability of information. Results of the cost
analysis were forwarded to each participating utility for final
review and comment.
The cost data were treated solely to establish the accurate
costs for FGD systems, on a common basis, not to critique the
design or reasonableness of the costs reported by any utility.
Adjustments focused primarily on the following items:
0 All capital costs were adjusted to July 1, 1977, dol-
lars using the Chemical Engineering Index. All capital
costs, represented in dollars/kilowatt ($/kW), were
expressed in terms of gross megawatts (MW). Actual
costs were reported by utilities in dollar values for
years 1970 to 1980. These values are represented in
terms of the year of greatest capital expenditures.
0 Gross unit capacity was used to express all FGD capital
expenditures because the capital requirement of an FGD
system is dependent on actual boiler size before de-
rating for auxiliary and air quality control power
requirements.
0 Particulate control costs were deducted. Since the
purpose of the study was to estimate the incremental
cost for sulfur dioxide control, particulate control
costs were deducted using either data contained in the
cost breakdowns or as a percentage of the total direct
cost (capital and annual). The percentage reduction
varied depending upon system design and operation.
A-4
-------
The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, were included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).
Indirect charges were adjusted to provide adequate
funds for engineering, field expenses, legal expenses,
insurance, interest during construction, allowance for
startup, taxes, and contingency.
All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net megawatts
(MW) .
Net unit capacity was used to express all FGD annual
expenditures because the annual cost requirement of an
FGD system is dependent on the actual amount of kilo-
watt-hours (kWh) produced by the unit after derating
for auxiliary and air quality control power require-
ments.
All annual costs were adjusted to a common capacity
factor (65%).
Replacement power costs were not included since only a
few utilities reported such costs and these were pre-
sented using a variety of methods.
Sludge disposal costs were adjusted to reflect the
costs of sulfur dioxide waste disposal only (i.e.,
excluding fly ash disposal) and to provide for disposal
over the anticipated lifetime of the FGD system. This
latter correction was necessary since several utilities
reported costs for sludge disposal capacity that would
last only a fraction of the FGD system life. The
adjustments were based on a land cost of $2000/acre
with a sludge depth of 50 ft in a clay-lined pond (clay
is assumed to be available at the site).
A 30-year life was assumed for all process and economic
considerations for all new systems that were installed
for the life of the unit. A 20-year life was assumed
for all process -and economic considerations for retro-
A-5
-------
fit systems that were installed for the remaining por-
tion of the life of the unit.*
0 Regeneration and by-product recovery facility costs
were added for those regenerable systems not reporting
such costs.
To the extent possible, all cost adjustments were made using
the previous assumptions developed by PEDCo Environmental. When
cost data were inadequate, adjustments were made using process
design data in conjunction with the previous cost assumptions.
In some cases, no adjustments were possible because of in-
sufficient data.
The use of a 30-year service life for new units coincides with
the conclusion of the National Power Survey of the Federal
Power Commission which recognized this value as reasonable for
steam-electric plants. A 20-year service life was assumed for
all retrofit units even if the remaining life of the units is
less than this value. Thus, two different rates are used and
should be noted when making comparisons between new and retro-
fit systems.
A-6
-------
DESCRIPTION OF COST ELEMENTS
Capital costs consist of direct costs, indirect costs, con-
tingency costs, and other capital costs. Direct costs include
the "bought-out" cost of the equipment, the cost of installation,
and site development. Indirect costs include interest during
construction, contractor's fees and expenses, engineering, legal
expenses, taxes, insurance, allowance for start-up and shake-
down, and spares. Contingency costs include those costs result-
ing from malfunctions, equipment alterations, and similar un-
foreseen sources. Other capital costs include the nondepreciable
items of land and working capital.
Annual costs consist of direct costs, fixed costs, and over-
head costs. Direct costs include the cost of raw materials,
utilities, operating labor and supervision, and maintenance and
repairs. Fixed costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs include those of plant and payroll expenses. The
various capital and annual cost components are discussed and
defined in greater detail in the following paragraphs.
The direct capital costs include the following elements:
° Equipment required for the FGD system. Table A-l
provides a summary of the major process equipment used
in regenerable and nonregenerable systems.
° Installation of equipment, including foundations; steel
work for support, buildings, piping and ducting for
effluents, slurries, sludge, and make-up water, control
panels, instrumentation, insulation of ducting, buildings,
piping, and other equipment, painting and piling.
0 Site development may include clearing and grading,
construction of access roads and walkways, establish-
ment of rail, barge, and/or truck facilities, and
parking facilities.
A-7
-------
TABLE A-l. MAJOR FGD SYSTEM EQUIPMENT SUMMARY
Category
Description
Material handling-
raw materials
Feed preparation-
raw materials
Sulfur dioxide
absorption
Flue gas reheat
Gas handling
Sludge disposal
Utilities
By-product
handling
Equipment for the handling and transfer of
raw materials includes unloading facilities,
conveyors, storage areas and silos, vibrators,
atmospheric emission control associated with
these facilities, and related accessories.
Equipment for the preparation of raw material
to produce a feed slurry consists of feed
weighers, crushers, grinders, classifiers,
ball mills, mixing tanks, pumps, agitators,
and related accessories.
Equipment for treating the flue gas includes
absorbers, mist eliminators, hold tanks,
agitators, circulating pumps, pond water re-
turn pumps, and related accessories.
Equipment required includes air, steam, or
hot water heaters, condensate tanks, pumps,
soot blowers, fans, fuel storage facilities,
gas bypass equipment, and related accessories.
Equipment to handle the boiler flue gas in-
cludes booster fans, ductwork, flue gas by-
pass system, turning vanes, supports, plat-
forms, and related accessories.
Nonregenerable FGD systems require solids/
water separation equipment such as clarifiers,
vacuum filters, centrifuges, sludge fixation
equipment, and related accessories.
Equipment to supply power and water to the
FGD equipment consists of switch-gear, break-
ers, transformers, piping, and related
accessories.
Equipment for processing the by-product of
regenerable FGD systems may include a rotary
kiln, fluid bed dryer, conveyor, storage silo,
vibrator, combustion equipment and oil stor-
age tanks, waste heat boilers, hammer mills,
evaporators, crystallizers, strippers, tanks,
agitators, pumps, compressors, sulfuric acid
absorber and cooling, mist eliminator, pumps,
acid coolers, tanks, etc.
(continued)
A-8
-------
TABLE A-L. (continued)
Category
Description
Regeneration
Purge treatment
Auxiliary
Equipment for regeneration of the absorbing
medium of an FGD system may consist of re-
actor vessels, material handling system,
storage, weigh feeder, conveyor, rotary kiln,
fluid bed calciner, dust collector, storage
silo, vibrator, combustion equipment and oil
storage tanks, waste heat boiler, hammer
mill, evaporators, crystallizers, strippers,
tanks, agitators, pumps, compressors, sul-
furic acid absorber and cooling, mist elimi-
nator, pumps, acid coolers, tanks, etc.
Equipment for the removal of purge material
(e.g. sodium sulfate) includes refrigeration,
pumps, tanks, crystallizer, centrifuge,
dryer, dust collector, conveyors, storage,
and related equipment.
Equipment not directly related to the
FGD system, but which may require design or
modification to accommodate an FGD system
may include such items as existing fans,
ducts, or stack. If new fans, ducts, or
stacks are added to improve boiler perfor-
mance and accommodate the FGD systen, the
costs are prorated to the boiler and FGD
system.
A-9
-------
Indirect capital costs include the following elements:
0 Interest accrued on borrowed capital during construction,
0 Contractor's fee and expenses, including costs for
field labor payroll; field office supervision; person-
nel; construction offices; temporary roadways; railroad
trackage; maintenance and welding shops; parking lot;
communications; temporary piping and electrical and
sanitary facilities; safety security (fire, material,
medical, etc.); construction tools and rental equip-
ment; unloading and storage of materials; travel ex-
penses; permits; licenses; taxes; insurance; overhead;
legal liabilities; field testing of equipment; start-
up; and labor relations.
0 Engineering costs, including administrative, process,
project, and general; design and related functions for
specifications; bid analysis; special studies; cost
analysis; accounting; reports; consultant fees; pur-
chasing; procurement; travel expenses; living expenses;
expediting; inspection; safety; communications; model-
ing; pilot plant studies (if required because of pro-
cess design or application novelty); royalty payments
during construction; training of plant personnel; field
engineering; safety engineering; and consultant ser-
vices.
0 Legal expenses, including those for securing permits,
rights-of-way/ etc.
0 Taxes, including sales, and excise taxes.
0 Insurance covering liability for equipment in transit
and at site; fire, casualty, injury, and death; damage
to property; delay; and noncompliance.
0 Allowance for start-up and shakedown includes the cost
associated with system start-up.
0 Spare parts including pumps, valves, controls, special
piping and fittings, instruments, spray nozzles, and
similar items.
Other capital costs include the following elements:
0 Land required for the FGD process, waste disposal, re-
generation facility, and storage.
0 Working capital, including the total amount of money
invested in raw materials and supplies in stock,
finished products in stock, and unfinished products
A-10
-------
in the process of being manufactured; accounts re-
ceivable; cash kept on hand for payment of operating
expenses such as salaries, wages, and raw materials
purchases; accounts payable; and taxes payable.
Annual cost of an FGD system includes the following direct,
fixed and overhead charges:
° Direct Charges
Raw materials, including those required by the FGD
process for sulfur dioxide control, absorbent regenera-
tion, sludge treatment, sludge fixation, flocculants,
etc.
Utilities, including water for slurries, cooling and
cleaning; electricity for pumps, fans, valves, lighting
controls, conveyors, and mixers; fuel for reheating of
flue gases; and stream for processing.
• Operating labor, including supervisory, skilled, and
unskilled labor required to operate, monitor, and
control the FGD process.
Maintenance and repairs, consisting of both manpower
and materials to keep the unit operating efficiently.
The function of maintenance is both preventive and
corrective to keep outages to a minimum.
Byproduct Sales: credit from the sale of byproducts
regenerable FGD processes (e.g. sulfur, sulfuric acid)
is a negative charge deducted from the annual direct
cost to obtain the net annual direct cost of the FGD
system.
0 Fixed Charges
Depreciation - the annual charge to recover direct and
indirect costs of physical assets over the life of the
asset.
• Interim, replacement - costs expended for temporary or
provisional replacement of equipment that has failed or
malfunctioned prematurely.
Insurance, including the costs of protection from loss
by a specified contingency, peril, or unforeseen event.
Required coverage could include losses due to fire,
personal injury or death, property damage, explosion,
lightning, or other natural phenomena.
A-ll
-------
Taxes, including franchise, excise, and property taxes
levied by a city, county, state, or Federal government.
* Interest on borrowed funds.
0 Overhead
Plant and administrative overhead is a business expense
that is not charged directly to a particular part of a
project, but is allocated to it. Overhead costs in-
clude administrative, safety, engineering, legal and
medical services; payroll? employee benefits; recrea-
tion; and public relations.
Table A-2 provides a summary of the means used to determine
the missing cost elements if the costs were not reported or
insufficient information prevented their actual determination.
The assumptions and cost bases for determining the capital and
annual costs of FGD systems were developed by the PEDCo staff
based upon previous economic studies conducted for the U.S. EPA
(Flue Gas Desulfurization Process Cost Assessment, May 1975;
Simplified Procedures for Estimating Flue Gas Desulfurization
System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur
Dioxide Emission Control Costs for Large Coal-Fired Boilers,
March 1978, EPA-600/7-78-032).
A-12
-------
TABLE A-2. COST ELEMENT FACTORS
Category
Value
Indirect capital costs:
Interest during
construction
Field overhead
Contractor's fee and
expenses
Engineering
Taxes
Spares
Shakedown allowance
Other capital costs:
Contingency
Direct annual costs:
Raw materials:
Fixation chemicals
Lime
Limestone
Magnesium oxide
Sodium carbonate
Salt cake (credit)
Sulfur (credit)
Sulfuric acid (credit)
Utilities:
Electricity
Water
Steam
Operating labor:
Direct labor
Supervision
10% of total direct capital costs
10% of total direct capital costs
5% of total direct capital costs
10% of total direct capital costs
2% of total direct capital costs
1% of total direct capital costs
5% of total direct capital costs
20% of total direct and indirect
capital costs
$2/ton
$40/ton
$10/ton
$150/ton
$80/ton
$50/ton
$65/ton
$25/ton
25 mills/kWh
$0.20/103 gal
$0.80/106 Btu
$8.50/man-hour
15% of direct labor costs
Contingency costs are used only when the cost data supplied are
incomplete (such as equipment costs or direct costs only) and a
contingency cost must be factored in to give an accurate estimate
of the total capital cost.
(continued)
A-13
-------
TABLE A-2. (continued)
Category
Value
Maintenance:
Labor and materials
Supplies
Overhead:
Plant
Payroll
Fixed annual costs:
Depreciation
Interim replacement
Taxes
Insurance
Capital costs
4% of total direct capital costs
15% of labor and materials costs
50% of operation and maintenance costs
20% of operating labor costs
3.33% or 5% (new or retrofit)
0.7% or 0.35%
4%
0.3%
9%
Some system components have life spans less than the expected
service life of the system. Interim replacement is an allow-
ance factor used in estimating annual revenue requirements to
provide for the replacement of these short-lived items. An
average allowance of 0.35% of the total investment is normally
provided and used for systems with an expected service life of
20 years or less. A higher allowance of 0.70% of the total
investment is provided and used for systems with an expected
service life of 30 years or more.
A-14
-------
DEFINITION OF COST ELEMENTS
The costs displayed in Appendix A are accompanied by a
series of alphabetic characters summarizing data presented for
each FGD system. These relate to the cost elements described
earlier in this section and identify what has been included and
excluded for reported and adjusted capital and annual costs. The
alphabetic characters, along with their titles, are briefly de-
scribed in Table A-3.
A-15
-------
TABLE A-3. DESCRIPTION OF COST
Code
Title
Description
L
M
N
0
Particulate control (required for FGD pro-
cess) included in capital cost.
Particulate control (included in FGD
process) included in capital cost.
Total direct capital costs included.
Partial direct capital costs included.
Total indirect capital costs included.
Partial indirect costs included.
Chemical fixation of sludge included in
capital cost.
Dry sludge disposal included in capital
cost.
Off-site landfill area included in
capital cost.
Sludge pond included in capital cost.
Additional sludge disposal capacity
added for life of system.
Stack included in capital cost.
Modifications to stack, ducts, and/or
fans included in capital cost.
Total regeneration facility cost included
in capital cost.
Partial regeneration facility cost in-
cluded in capital cost.
R & D costs included in capital cost.
Particulate precollection device (ESP,
fabric filter, venturi) prior to FGD
system required for proper operation of
SO- control system.
Particulate collection equipment (venturi
scrubber) is included in the FGD system.
Complete cost of all FGD equipment, the
labor and materials required for equip-
ment installation, and interconnecting
the system is included in the total
capital cost.
One or a number of direct cost items, or
the cost associated with one or a number
of direct cost items, are excluded from
the total capital cost.
Complete cost of all the indirect cost
elements, including interest during con-
struction, contractor's fees, engineer-
ing, legal expenses, taxes, insurance,
allowance for start-up, and spares, is
included in total capital cost.
One or a number of indirect cost items,
or the cost associated with one or a
number of indirect cost items, are ex-
cluded from the total capital cost.
The cost of a chemical fixation process
which stabilizes the flue gas cleaning
wastes prior to disposal is included in
the total capital cost.
The coat of a secondary dewatering or
treatment method, such as filtration, cen-
trifugation, or forced oxidation, which
ultimately produces a dry sludge cake
for final disposal, is included in the
total capital cost.
The cost of an off-site area used as a
landfill for flue gas cleaning wastes is
included in the total capital cost.
The cost of an on-site disposal area for
ponding of treated or untreated flue gas
cleaning wastes is included in the total
capital cost.
The cost of additional SO. waste disposal
capacity required for FGD system operation
over the anticipated service life of the
unit is included in the total capital cost.
The cost of the stack is included in the
total capital cost.
Modifications to existing equipment (stack,
fans, ducts, etc.) which are required be-
cause of inclusion of an FGD system.
Complete cost of entire regeneration
facility included in total capital cost.
Part of the cost associated with the ret
generation facility included in the total
capital cost.
Bench scale or pilot plant studies to de-
termine process and design characteristics.
(continued)
A-16
-------
TABLE A-3. (continued)
Code
Title
Description
w
X
losts underwritten by system supplier in-
:luded in capital cost.
Excess reagent supply costs included in
capital cost.
Total direct annual costs included.
Partial direct annual costs included.
Total fixed annual costs included.
Partial fixed annual costs included.
Overhead cost included in total annual
cost.
Particulate control costs included in
direct annual cost.
Sludge disposal service costs (contract)
included in direct annual cost.
Replacement energy costs included in
total annual costs.
Capital expenditures underwritten by the
system supplier for system repairs or
modifications for optimization of perfor-
mance or R S D programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items, are excluded
from the total annual cost.
Complete cost of all fixed cost elements,
including depreciation, interim replace-
ment, insurance, taxes, and interest, is
included in the total annual cost.
One or a number of fixed annual cost items,
or the cost associated with one or a
number of fixed annual cost items, are ex-
cluded from the total annual cost.
Plant and payroll overhead costs are in-
cluded in the total annual cost.
The cost of operating particulate collection
equipment included in the FGD system is in-
cluded in the total annual cost.
The treatment and disposal of flue gas
cleaning wastes that are handled by an
outside firm.
The cost of additional power-generating
capacity required to compensate for power
used by the PGD system.
A-17
-------
RESULTS OF COST ANALYSIS
The results of the operational FGD system survey are summarized
in Table A-4 and Section A-l. Table A-4 produces a summary of a
categorical analysis of the reported and adjusted capital and
annual costs for the operational FGD systems addressed in the
survey. Included in this categorical analysis are the ranges,
means, and standard deviation for all the various types and
categories of FGD systems examined. Section A-l summarizes the
reported and adjusted capital and annual costs for all the oper-
ational FGD systems that were addressed in the cost study
(Section A-2 summarizes available cost data for nonoperational
FGD systems).
A-18
-------
TABLE A-4. CATEGORICAL RESULTS OF THE REPORTED AND ADJUSTED/
CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS
3=>
I
CATEGORY
ALL
MEU
RETROFIT
TNROUAUAT PROOUCT
SALEAILE PROIUCT
LINESTONE
LINE
•UAL ALKALI
LINE/ALKALINE FLTASM
SOIIUN CARIONATE
UELLNAN LORI
LIHESTOHE/ALKALIHE FLTASN
REPORTEI - AIJUSTED
—CAPITAL. I/KU ANNUAL, NIILS/KUH-— CAPITAL. «/«J ANNUAL. HILLS/KIM
RAN6E AVG IEV RANGE AVB DEV RANGE AVG DEV RANGE AVO KV
29.2-189.0 79.7 38.4
3I.8H89.0 7V.3 38.7
29.2-154.9 80.1 38.5
2V.2-187.0 71.2 34.8
.1- 14.V 4.4 4.4 34.0-140.A 88.0
.1- 14.3 3.2 3.9 44.4-117.4 84.1
2.1- 14.V 4.5 4.3 54.0-140.4 90.0
.1- 14.3 4.1 4.0 56.0-140.4 14.2
127.9-134.9 137.4 13.7 14.V- 14.V 14.V
31.1-148.0 75.7 37.0 .V- 3.3 2.0
29.2-128.3 74.V 32.2
43.2-I8V.O V4.7 45.5
77.1- 85.V 80.0 4.1
42.V-120.0 7V.8 37.0
!27.V-154.V 137.4 13.7 14.V- 14.V 14.9
47.V- 47.V 47.V .0 2.0- 2.0 2.0
.0 134.8-134.8 134.8
.7 34.0-117.4 88.6
.1- 14.3 4.9 4.8 67.3-140.4 90.8
3.2- 3.2 3.2 .0 *•*•*- .0 .0
.3- .3 .3 .0 77.2- 93.0 82.3
2.1- 2.1 2.1 .0 60.9-I07.V 76.6
.0 134.BH34.8 134.8
.0 71.2- 71.2 71.2
23.4
17.8
28.1
21.9
.0
29.9
22.2
.0
7.4
22.2
.0
.0
2.4-
2.8-
2.6-
2.4-
12.4-
2.4-
2.7-
***•*-
4.1-
3.2-
12.4-
2.8-
12.4
1.7
12.4
8.7
12.4
4.6
8.7
.0
3.2
4.4
12.4
2.8
3.4 2.4
3.2 2.0
3.6 2.7
3.1 2.8
12.4 .8
4.4 1.6
6.4 2.8
.0 .8
4.3 .3
3.6 .6
12.4 .8
2.8 .0
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 19PO
SFCTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
J4IT DESCRIPTION
COST DESCRIPTION
REPORTED
---COST- —
ADJUSTED
STANDARDIZED
ADJUSTED
ALABAMA ELECTRIC COOP
T31BI&3EE
3
179.3 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
•*» 65
69.5(1978) •**•••(
******( 0) ******(
C.E.J
65
0) *••***(
0) ******(
0)
0)
ARIZONA ELECTRIC POKER COOP
APACHE
2
9fc.D HU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, WKW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
*« 65 65
35.9(1977) ******( 0) *•**»«( o>
2.1(1978) ******( 0) ****•*( oj
C,E,H,J,L,S,
U,W,Y,Z
ARIZONA ELECTRIC POWER COOP
APACHE
3
96.3 nw (NET)
CAPACITY FACTOR, *
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
44 65
31.8(1977) **••*•(
2.1(1978) ••*•»•(
C ,E,H,J,L,S,
U.W.Y.Z
65
0) •••««*(
0) •***•*{
0)
0>
ARIZONA PUBLIC SERVICE
CHOLLA
1
119.3 MU (N£T)
CAPACITY FACTOR, X 85 65 65
TOTAL CAPITAL. S/try (TEAR) 53.0(1973) 56.0(1977) 56.0(1977)
TOTAL ANNUAL, «ILLS/KMH(TEAR) 3.ZU976) ?.6(1977) 2.3(197?)
COST ELEMENTS B,C,E,S,U,X C,E.K,S,U,W C.E.K.S.U.W
ARIZON* PUBLIC SERVICE
CHOLLA
3
2S4.3 MU (NET)
CAPACITY FACTOR, X 65 65 65
TOTAL CAPITAL, $/KH(YEAR) 168.0(1978) **•*•*( 0) ******(
TOTAL ANNUAL, MILLS/KWH(YEAR) 1.5(1978) ***••*( 0) •••«•*<
COST ELEMENTS B,D,T,X
3ASIN ELECTRIC POWER COOP
LARA»IE RIVER
1
570.3 MW (NET)
CAPACITY FACTOR, X ••* 65 65
TOTAL CAPITAL, f/KU(YEAR) 56.0(1980) ****«*( 0) ***««.(
TOTAL ANNUAL, HILLS/KtfH(YEAR) .9(7800) •*•••«( 0) **».«.(
COST ELEMENTS C,E
0)
0)
sis RIVERS ELECTRIC
SHEEN
1
242.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, */KU(YEAR)
TOTAL ANNUAL, MILLS/HUM(YEAR)
COST ELEMENTS
•*• 65
43.2(1976) ******!
***•**< 0) ••»*••<
B,C
65
0) ••••**(
0) ******(
0>
0)
CENTRAL ILLINOIS LIGHT
DJCK CREEK
1
416.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
*•* 65
93.3(1978) •***••<
3.3(1976) ******(
65
0) •*•»*»(
0) •••«**<
0)
0)
CENTRAL ILLINOIS PUBLIC SERV
MEWTON
1
617.3 MW (NET)
CAPACITY FACTOR, X **» 65 65
TOTAL CAPITAL, $/KW(YEAR) 189.0(1979) ****»•< 0) •*•«•*(
TOTAL ANNUAL, MILLS/KUH(YEAR) •****•( 0) •*****< 0) »•*•**(
COST ELEMENTS C,E,6
INDICATES COST FIGURES NOT YET AVAILABLE
A- 20
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 198C
SECTION A-1
COSTS FGS OPERATIONAL fGD SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
COLORADO UTE ELECTPIC ASSN
CRAIG
2
400.3 MU (NET)
CAPACITY FACTOR, X **•
TOTAL CAPITAL, S/KW(YEAR) 73.7(1979)
TOTAL ANNUAL, M 1LLS/KWH(YEAR) *••*»»< C)
COST ELEMENTS A.C
65
65
0) ..••*•(
0) **»•*»(
C)
0)
COLUMBUS £ SOUTHERN OHIO E.LEC CAPACITY FACTOfc, X 48 65 65
C3NESV1LLE TOTAL CAPITAL, S/KW(YEAR) 55.5(1975) 7C.7(1977) 70.7(1977)
5 TOTAL ANNUAL, MILLS/K.WH(YEAR) 5.8(1978) 7.4(1977) 7.4(1977)
411.0 MW (NET) COST ELEMENTS P,C,J,M,$,U, C,E,J,M,S,U, C,E,J,",S,U,
W,X,Y U,Y V,t
COLUMBUS S SOUTHERN OHIO ELEC
C JNESVILLE
411.3 MW (NET)
COMMONWEALTH EDISON
P3WERTON
51
450.0 MW (NET)
CAPACITY FACTOR, X
COST ELEMENTS
CAPACITY FACTOR, 1
COST ELEMENTS
*e
Bft ,J9P,S ,Ut
»(>T,Y
*+ *
C.E.H.J
65
C,E, J
w,t
65
,M,S.U,
65
65
pjOUESNE LIGHT
1-4
510.3 MU (NET)
OPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, MI LLS/K.UH ( Y E AR )
COST ELEMENTS
64 65 65
113.4(1976) 127.1(19771 127.K1977)
8.6(1977)
7.8C1977)
7.5<1977>
R.D.F.I.J.M. C,E,I,J,M,S, C.E.l.J.M.S,
T,V,«^Y U,Y U,Y
OjauESNE LIGHT
PHILLIPS
1-6
498.0 MM (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, }/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH{YEAR)
COST ELEMENTS
70 65 65
106.9(1972) UO.6(1977) 140.6(1977)
7.8(1977) 8.6(1977) 8.2(1977)
e,D,F,I,J,H, C.E.l.J.M.S-, C.E.l.J.M.S,
T.V.X.Y U.Y u.Y
INDIANAPOLIS POWER S LIGHT
PETERSBURG
5
532.0 MH (NET)
CAPACITY FACTOR, X *** 65 65
TOTAL CAPITAL, S/KW(YEAR) 99.5(1976) 110.6(1977) 110.6(1977)
TOTAL ANNUAL, MILLS/KHH(YEAR) ••*»•*( 0) 6.6C1977) 7.411977)
COST ELEMENTS t.F.G.J.R C.E,6,J,H,S, C,E,6,J,M,S,
U,«,t U.W.t
CITY POWER 8 LIGHT
HAWTHORN
3
90.3 MW (NET)
CAPACITY FACTOR, »
TOTAL CAPITAL, */KW
TOTAL ANNUAL, MILLS/HWH(YEAR)
COST ELEMENTS
1* 65 65
29.2(1972) 87.3 87.2(1977)
8.4(1977) 4.3(1977) 4.4(1977)
9,D,F,T,X B.C.E.J.K.S, B,C,E.J,K,S,
U.U.X U.U.X
KANSAS CITY POWER * LIGHT
HAWTHORN
4
90.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL. MILLS/KWM(YEAR)
COST ELEMENTS
•«• 65 65
29.4(1972) 87.2(19771 87.2(1977)
8.4(1977) 4.3(1977> 4.4(1977)
e,0,F,T,I B.C.E.J.K.S. B.C.E.J.K.S.
U,W.X U.W.X
...... INDICATES COST FIGURES NOT YET AVAILABLE
A- 21
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION A-1
COSTS FOR OPERATIONAL F6D SYSTEMS
JSIT DESCRIPTION
COST DESCRIPTION
REPORTED
COST
ADJUSTED
STANDARDIZED
ADJUSTED
KANSAS CITY POWER K LIGHT
LA CYSNt
1
320. 3 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KU(YEAR)
TOTAL ANNUAL, M I LLS/KWH ( YE AR)
COST ELEMENTS
42 65 65
53.6(1972) 68.0(1977) 68.0(1977)
1.3(1978) 3.8(1977) 3.9(1977)
T C,E,J,K,S,U C,E,J,K,S,U
KANSAS POWER & LI6HT
JEFFREY
1
5*0. 0 MW (NET)
CAPACITY FACTOR, X ••* 65 65
TOTAL CAPITAL, t/KU(YEAR) 56.8(1978) *•*••*( 0) «**•••( 0)
TOTAL ANNUAL, HI LLS/ KWH( YEAR) ****•»{ 19 78) *****»( 0) ***•**( 0)
COST ELEMENTS B ,C
KENTUCKY UTILITIES
SHEEN RIVER
1-3
64.0 MM (NFT)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, HI LLS/KWH ( YEAR)
COST ELEMENTS
16 65 65
70.3(1975) 77.5(1977) 77.5(1977)
U. 3(1977) 2.7(1977) 5.2(1977)
B.C.E.J.S.U, C,E,J,S,U,y C.E.J.S.U.U
W
LOUISVILLE GAS & ELECTRIC
CANE RUN
I
188. 3 MW (NFT)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, MI LLS/KUH ( YEAR)
COST ELEMENTS
55 65 65
66.5(1975) 80.6(1977) 80.6(1977)
2.7(1977) 5.8(1977) 6.2(1977)
C,E,HI,JtQ,T C,E,H,J,K,0, C,E,H,J,K,0,
s.u.w s.u.w
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
200.0 MW (NET)
CAPACITY FACTOR, X •** 65 65
TOTAL CAPITAL, t/KW(YEAR> 62.4(1977) 67.5(1977) 67.5(1977)
TOTAL ANNUAL, HI LLS /KWH ( YEAR) *****»( 0) 5.6(1977) 5.6(1977)
COST ELEMENTS C.E.H.J C,E,H,J,K,S, C,E,H,J,K,S,
u.y u,u
LSU1SVILLE GAS & ELECTRIC
CANE RUN
i
299.3 HU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, f I LLS/KWM( YEAR)
COST ELEMENTS
*** 65
57.9(1977) ******(
3.2(1979) •*•**•(
C ,E ,H>,M ,S , V,
M
65
0) •*•***<
0) ***•**(
0)
0)
LOUISVILLE GAS I ELECTRIC
1ILL CREEK
]
«4?. 3 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, SyKU(VEAR)
TOTAL ANNUAL, H I LLS/KUH ( YE AR)
COST ELEMENTS
10 65
42.6(1978) «••*••(
1.3(1978) *••*•*(
c,s
65
0) •**...(
0) *****.(
Q)
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
72.0 MW (NET)
CAPACITY FACTOR, X ***
TOTAL CAPITAL, S/KU(VEAR) 52.8(1973)
TOTAL ANNUAL, M I LLS/KMN ( V EAR) •**«•*( 0)
COST ELEMENTS C,E C,E,S,U,W
65 65
76.4(1977) 76.4(1977)
6.5(1977) 6.4(1977)
C.E. S.U.W
H1NNKOTA POWER COOPERATIVE
HILTON R. YOUNG
2
195.3 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KV(YEAR>
TOTAL ANNUAL, HI LLS/KWN ( YEAR)
COST ELEMENTS
••* 65 65
85.SM976) 93.0(1977) 93.0(1977)
••**•*( 0) 5.2(1977) 5.2(1977)
C.E.H.P C.E.H.M.P.S, C.E.H.R.P.S.
U,U U.W
...... INDICATES COST FIGURES NOT YET AVAILABLE
A- 22
-------
EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
SECTION A-1
COSTS FOR OPERATIONAL F60 SYSTEMS
UNIT DESCRIPTION
40NONGAHELA POWER
PLEASANTS
1
618.0 MW (NET)
MONTANA POWER
COLSTRIP
1
360.0 MW (NET)
MONTANA POWER
CDLSTRIP
2
360.0 NW (NET)
NEVADA POWER
REID GARDNER
125.0 MW (MET)
COST DESCRIPTION
CAPACITY FACTOR, X
TOTAL ANNUAL, HI LLS/ KUH ( t EAR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, HI LLS/KWH ( YEAR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, S*tCW(YEAR>
TOTAL ANNUAL, MI LLS/KVH ( YEAR )
COST ELEMENTS
CAPACITY FACTOR. X
TOTAL CAPITAL, S/KW(YEAR>
TOTAL ANNUAL, MI LLS/KWH( YEAR)
COST ELEMENTS
REPORTED
65
2.8(1978)
B.C.J.S
76
77.1(1975)
.3(1977)
76
77.1(1975)
.3(1977)
B,C,F,J,P,T
67
42.9(1973)
2.1(1977)
B.D.E.P.S.U,
ADJUSTED
65
*•***•( 0)
65
77.2(1977)
4.1(1977)
U.W
65
77.2(1977)
4.1(1977)
C,E,J.K,P,S.
U.W
65
60.9(1977)
3.2(1977)
8,D,E,P,S,U,
STANDARDIZED
ADJUSTED
65
•«««•*( 0)
65
77.2(1977)
4.1(1977>
U.W
65
77.211977)
4.1(1977)
C.E.J.K.P.S.
U.W
65
60.9t1977>
3.4(1977)
B.D.E.P.S.U,
w.x
w.x
w.x
NEVADA POWER
REID GARDNER
I
125.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, NILLS/KUH(YEAR)
COST ELEMENTS
67 65 65
42.0(1973) 60.9(1977) 60.9(1977)
2.1(1977) 5.2(1977) 3.4<1977>
B.O.E.P.S.U. B.D.E.P.S.U, B.D.E.P.S.U,
W,X W,X U,K
NEVADA POWER
REID GARDNER
5
125.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
67 65 65
113.6(1975) 107.9(1977) 107.9(1977)
2.1(1977) 4.4(1977) 5.0(1977)
B,C,E,L,S,U, B.C.E.L.S.U. B.C.E.L.S.U,
w,x y.x w.i
NORTHERN INDIANA PUB SERVICE
»EAN H. MITCHELL
11
115.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
77 65 6S
156.0(1976) 134.8(1977) 1J4.8(1977>
14.9(1976) 12.4(1977) 11.0(1977)
B,C,Ei,L.N.S. C,E,L,N,S,U, C,E,L,N,S,U,
U,U,X,Z W,I U.Z
NORTHERN STATES POWER
SHERBURNE
1
740.3 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, &/KW(VEAR>
TOTAL ANNUAL. HILLS/KWH(YEAR)
COST ELEMENTS
73 65 65
47.9«1972) 71.2(1977) 71.2(1977)
2.0(1977) 2.8(1977) 3.3(1977)
B.C.j.S.U.X, C.E.J.K.S.U. C.E.J.K.S.U.
I W W
NORTHERN STATES POWER
SHERBURNE
740.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, SSKU(VEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
73
47.0(1972)
2.0(1977)
65
71.2(1977)
2.8(1977)
65
71.2(1977)
3.3(1977)
B,C,J,S,U,X, C.E.J.K.S.U, C.E.J.K.S.U,
.»***. INDICATES COST FIGURES NOT YET AVAILABLE
A- 23
-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMPf 198C
SECTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
JNIT DESCRIPTION
COST DESCRIPTION
REPORTED
-"COST-
ADJUSTED
STANDARDIZED
ADJUSTED
PACIFIC POWER 8 LIGHT
JI1 PRIDGER
4
550.3 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, PILLS/KWh{YEAR)
COST ELEMENTS
*** 65
120.0(1979) *••«**(
*****»( C) •*****(
C.E.J
65
C) ******( 0)
0) *****»( 0)
PENNSYLVANIA POWER
3RUC E 1ANSFIELD
1
J17.0 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
40 65 65
120.6(1975) 102.1(1977) 102.1C1P77)
14.3(1977) ?.7(1977) 1C.6(1977>
B,C,E,G,I,L, C.E.G.I.H.S, C,E.G.I,M.S.
S,U,Wi,X U,U U,W
PENNSYLVANIA POWER
3RUCF 1ANSFIELD
2
J17.3 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/K«H(YEAR)
COST ELEMENTS
40 65 65
120.6(1975) 102.1(1977) 102.1(1977)
14.3(1977> 8.7(1977) 10.8(1977)
B.C.E.G.I.L, C,E,G,I,H,S, C.E.G.I,M.S.
s.u.w.x u,. u,w
PJBLIC SERVICE OF NEW MEXICO
«
361 .D MW (NFT)
PJBLIC SERVICE OF NEU MEXICO
550. C MW (NET)
SALT RIVER PROJECT
CORONADO
280.3 MW (NET)
SALT RIVER PROJECT
280.3 MU (NET)
CAPACITY FACTOR, X *** 65
COST ELEMENTS A,C,E>.N
CAPACITY FACTOR, X *** 65
COST ELEMENTS A,C,E,N
CAPACITY FACTOR, X *•* 65
TOTAL CAPITAL, $/KW(YEAR) 74.0(1978) ****•*(
COST ELEMENTS C ,E
CAPACITY FACTOR, X *** 65
COST ELEMENTS C ,E
0)
0)
0)
0)
0)
0)
65
65
65
******(
65
0)
l»
0)
0)
0)
0)
p>
0)
SDUTH CAROLINA PUBLIC SERVICE CAPACITY FACTOR, X
4INYAH
2
140.0 HW (NET)
TOTAL CAPITAL, S/KW
COST ELEMENTS
80 65 65
47.4(1976) 66.4(1977) 66.4(1977)
1.6(1975) 2.9(1977) 3.2(1977)
C.F.J.M.S.V C.E.J,K.H.S, C,E,J,K,M,S.
u.w u,w '
SOUTH MISSISSIPPI ELEC PWR
R.D. lORROy, SR.
1
124.3 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KHCYEAR)
TOTAL ANNUAL, M I LLS/ KWH( YEAR >
COST ELEMENTS
*** 65
37.4(1975) *«****( 0)
****•*( 0) «*****( 0)
C.E
65
•*****(
«•«•«»(
0}
0)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 24
-------
EPA UTILITY F6D SURVFY: JUIY - SEPTEMBER 1980
SECTION A-1
COSTS FOP OPERATIONAL FGD SYSTEMS
UMIT DESCRIPTION
SOUTH 1ISSISSIPPI ELEC PYR
D. D. 10RROU t SR •
2
124.3 MU (NET)
SOUTHERN ILLINOIS POWER COOP
^AR ION
173.0 MU (NET)
SOUTHERN INDIANA GAS & ELEC
A. 8. BROWN
1
265. D MW (NET)
COST DESCRIPTION
CAPACITY FACTOR, X
COST ELEMENTS
CAPACITr FACTOR, X
COST ELEMENTS
CAPACITY FACTOR, X
COST ELEMENTS
REPORT? D
** *
C.E
65
B»C,T?X
** *
C,E,G
ADJUSTED STANDARDIZED
ADJUSTED
65 65
65 65
65 65
SPRINGFIELD CITY UTILITIES
SJUTHJEST
I
194.3 HW (NFT)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, HI LLS/ KWM ( YE AR )
COST ELEMENTS
**• 65 65
77.3(1974) 117.6(1977) 117.6(1977)
•*•*••( 0) 6.2(1977) 6.9(1977)
C,F,H,J,P C.E.H.J.K.P, C,E,H,J,r,P,
S.U.U S,U,U
TENNESSEE VALLEY AUTHOR!!
WIDOWS CREEK
J
550.3 MU (NET)
jTAH POWER & LIGHT
HUNTER
1
360. 3 MW (NET)
UTAH POKER 8 LIGHT
HUNTINGTON
1
366.3 MU (NET)
'Y CAPACITY FACTOR, X 60 65 65
TOTAL CAPITAL, J/KW(YEAR> 98.1(1976) 117.1(1977) 113.1(1077)
TOTAL ANNUAL, M I LLS/ KUM( Y EAR ) 3.0(1977) 5.3(1977) 5.1(1977>
U
CAPACITY FACTOR, X 65 65
TOTAL CAPITAL, */KW(YEAR) 91.1(1978) •***•«(
TOTAL ANNUAL, M I LL S/ kWH ( Y E AR ) .1(1978) *»••••(
COST ELEMENTS B,C,T,X
CAPACITY FACTOR, X ?C 65
TOTAL ANNUAL, M I LLS/KUH ( YEAR ) 1.4(1978) «***«»(
COST ELEMENTS B,C,T,X
65
65
0) ••••••( 0)
•*«*** INDICATES COST FIGURES NOT »ET AVAILABLE
A- 25
-------
£PA UTUITr FGO SURVEY: JULY - SEPTEMBER 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
REPORTED
COST
ADJUSTED
STANDARDIZED
ADJUSTED
9ASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
570.3 NU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, HILLS/KUH(YEAR)
COST ELEMENTS
... 65
56.0(1980) ****••(
.e<7800) •«•*••(
C,E
65
0) **«**•(
0) •*«.»«{
0)
0)
JOSTON EDISON
CYSTIC
6
150.3 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KV(VEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR>
COST ELEMENTS
• *• 65
63.4(1972) •«•**•(
3.0(1974) *•«*••(
B.C.E.N.Q
65
0) **«.*.(
0) •«««..<
QJ
CDLORA60 UTE ELECTRIC ASSM
CRAIG
I
447.0 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR>
TOTAL ANNUAL, MlLLS/KWH(YEAR)
COST ELEMENTS
**• 65
86.5(1979) **•*»•(
.....*< 0) ••**••{
B.D.E
65
0) »*•••»(
0) ••«•*•(
0)
0)
ILLINOIS POWER COMPANY
RIVER
110. 0 HW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
82.5(1972) •****•(
.....«( 0) ...*..(
6S
0) ***••*(
0) .»..*.(
0)
0)
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
120.0 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR>
TOTAL ANNUAL, HI LLS/KWH (YEAR )
COST ELEMENTS
•*« 65 65
156.7(1972) 233.2(1977) 233.2(1977)
2.0(1972) 13.0(1977) 12.4(1977)
D.F.N.P C.E.N.P C.E.N.P
•***•» INDICATES COST FIGURES NOT YET AVAILABLE
A- 26
-------
APPENDIX B
DEFINITIONS
B-l
-------
DEFINITIONS
Boiler Commercial Service Date
Byproduct
Commercial Service Date
(FGD System)
Company Name
Disposal
Efficiency:
Particulate Matter
SO,
Date when boiler and auxiliary
equipment (including FGD sys-
tem for new boilers) has met
initial supplier guarantees
and begins to contribute elec-
trical power to the power
grid.
The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product by systems that gen-
erate a saleable product.
Date when the FGD system suc-
cessfully completes compliance
testing and the utility is
satisfied that the system
meets supplier contractual
guarantees.
Name of corporation as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.
Disposal method for throwaway
product systems producing
sludge including: stabilized
or unstabilized sludge, inter-
im and final disposal sites
and disposal type (minefill,
landfill, etc.) as well as
disposal location.
The actual percentage of par-
ticulate matter removed by the
emission control system (me-
chanical collectors, ESP, or
fabric filter and FGD) from
the untreated flue gas.
The actual percentage of SC>2
removed from the flue gas by
the FGD system.
B-2
-------
FGD Viability Indexes
Availability Index
Reliability Index
Several parameters have been
developed to quantify the vi-
ability of FGD system technol-
ogy. Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
represent the operation of any
FGD system during a given per-
iod. The above-mentioned pa-
rameters are defined below and
discussed briefly. The objec-
tives of this discussion are
to make the reader aware that
several different definitions
are being used and to select
appropriate parameters that
can be used for reporting pur-
poses so that reasonably con-
sistent comparisons can be
made.
Hours the FGD system is avail-
able for operation (whether
operated or not) divided by
hours in period, expressed as
a percentage. This parameter
tends to overestimate the vi-
ability of the FGD system be-
cause it does not penalize for
election not to operate the
system when it could have been
operated. Boiler downtime may
tend to increase the magnitude
of the parameter because FGD
failures generally cannot oc-
cur during such periods.
Hours the FGD system was oper-
ated divided by the hours the
FGD system was called upon to
operate, expressed as a per-
centage. This parameter has
been developed in order not to
penalize the FGD system for
elected outages, e.g., periods
when the FGD system could have
been run but was not run be-
cause of chemical shortages,
lack of manpower, short dura-
tion boiler operations, etc.
The main problem in using this
B-3
-------
FGD Operability Index
FGD Utilization Index
End Product
Saleable
formula is the concise determi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod. In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .
Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage. This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time. The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable. In addi-
tion, an undefined value can
result when the FGD system is
not called upon to operate for
a given period (e.g., turbine
or boiler outage when FGD sys-
tem is available).
Hours that the FGD system op-
erated divided by total hours
in period. This parameter is
a relative stress factor for
the FGD system. It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The SO2 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
B-4
-------
Throwaway
Energy Consumption, %
Equivalent Scrubbed Capacity
(ESC)
FGD Status:
Category 1
Category 2
Category 3
Cateogry 4
Category 5
ammonium sulfate, sodium sul-
fate).
The SC-2 removed from the flue
gas is not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
products must be disposed in
an environmentally acceptable
fashion.
The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following equa-
tion:
[Net MW w/o FGD - Net MW w/FGD]/
Gross unit rating]
The effective scrubbed flue
gas in equivalent MW based on
the percent of flue gas scrubbed
by the FGD system.
Operational - FGD system is in
service removing SC>2 •
Under construction - ground
has been broken for installa-
tion of FGD system, but FGD
system has not become opera-
tional .
Planned, Contract Awarded -
contract has been signed for
purchase of FGD system but
ground has not been broken for
installation.
Planned, Letter of Intent
Signed - letter of intent has
been signed, but legal con-
tract for purchase has not
been awarded.
Planned, Requesting/Evaluating
Bids - bid requests have been
released but no letter of in-
tent or contract has been is-
sued.
B-5
-------
Category 6
Category 7
Category 8
Fuel Firing Rate - TPH
General Process Type
Initial Start-Up (FGD System)
New
Plant Name
Process Additives
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.
Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.
The manner in which the SC>2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.
Date when flue gas first
passes through any component
of the FGD system (or is
scheduled to do so).
FGD unit and boiler were de-
signed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.
Unit identification as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - or as indicated by
utility representative for in-
stallations in planning stages.
A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g., Mg, adipic
acid) to promote improved
process operation (e.g., scale
reduction, increased SC>2
removal efficiency).
B-6
-------
Process Type
Regulatory Class
Retrofit
Spare Capacity Index - %
Spare Component Index
System Supplier
Total Controlled Capacity
(TCC)
Company name if process is
patented. Generic name if
several companies have similar
processes (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .
A. New boiler constructed
subject to Federal New
Source Performance Stan-
dards (NSPS), 8/17/71.
B. Existing boiler subject
to State Standard that is
more stringent than the
NSPS, 8/17/71.
C. Existing boiler subject
to State Standard that is
equal to or less stringent
than NSPS, 8/17/71.
D. Other (unknown, undeter-
mined) .
FGD unit will be/was added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.
The summation of the individ-
ual component capacities (%)
minus 100%.
The equipment spare capacity
index (%) divided by the indi-
vidual component capacity (%).
A firm that fabricates and
supplies flue gas desulfuriza-
tion systems.
The gross rating (MW) of a
unit brought into compliance
with FGD, regardless of the
percent of flue gas treated at
the facility. In the case of
prototype and demonstration
FGD systems, this figure will
be identical to the Equivalent
Scrubbed Capacity rather than
B-7
-------
Unit Rating
Gross
New w/FGD
Net w/o FGD
the gross unit rating if the
system is not meant to bring
the facility into compliance
with S02 emission standards.
Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
B-8
-------
APPENDIX C
TABLE OF UNIT NOTATION
C-l
-------
TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Mass/Weight
Pressure
Temperature
Volume
English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Symbol
acre
ft*
gr/scf
ppm ,
lb/10 Btu
ft3/min
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
(actual)
Ib
t
in. H20
•r
ft3
Acre-ft
Survey Report
Notation
ACRE
SQ. FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
LB
T
IN. H20
F
CU.F
ACRE-FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Joules per
gram
Meter
Centimeter
Kilometer
Liters per cubic
meter
Kilogram
Megagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
M2
g/m3
ppm
ng/J
m3/s
liter/s
kg/s
M t/d
M t/h
J/q
m
cm
km
liter/m3
kg
Mg
kPa
•c
•j
Survey Report
Notation
SO.M
SQ.M
G/CU.M
PPM
NG/J
CU.M/S
LITER/S
KG/S
M T/D
M T/H
J/G
M
CM
KM
LITER/CU.M
KG
MG
KPA
C
CU.M
CU.M
o
I
-------
APPENDIX D
FGD PROCESS FLOW DIAGRAMS
0-1
-------
To Stack
o
i
ro
From
Precipitator
Mist Eliminator
Make
Flyash Silo
Reaction Tank
In-Tank
Strainer
Bleed
^ Pump
« *
lime Silo
«3i
Flyash Wet'G
Tank
Lime
Feed Pumps
Feeder
Lime
Feed Tank
To Disposal
Cooperative Power Association, Coal Creek 2
Simplified Process Flow Diagram
-------
[ TECHNICAL REPORT DATA
| (Plccsr read Instruction* on llii romi Ix/ort itnni>lrinifi
h. REPORT NO. 2
EPA-600/7-80-029d
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: July - September 1980
7. AUTHOR
------- |