&EPA
United States Industrial Environmental Research EPA-600/7-80-029c
Environmental Protection Laboratory July 1980
Agency Research Triangle Park NC 27711
EPA Utility FGD Survey:
April-June 1980
Interagency
Energy/Environment
R&D Program Report
-------
RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environmental
Protection Agency, have been grouped into nine series. These nine broad cate-
gories were established to facilitate further development and application of en-
vironmental technology. Elimination of traditional grouping was consciously
planned to foster technology transfer and a maximum interface in related fields.
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
effort funded under the 17-agency Federal Energy/Environment Research and
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
systems; and integrated assessments of a wide range of energy-related environ-
mental issues.
EPA REVIEW NOTICE
This report has been reviewed by the participating Federal Agencies, and approved
for publication. Approval does not signify that the contents necessarily reflect
the views and policies of the Government, nor does mention of trade names or
commercial products constitute endorsement or recommendation for use.
This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.
-------
EPA-600/7-80-029C
July 1980
EPA Utility FGD Survey:
April-June 1980
by
M. Smith, M. Melia, N. Gregory
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-01-4147
Task No. 143
Program Element No. INE828
EPA Project Officer: Norman Kaplan
Industrial Environmental Research Laboratory
Office of Environmental Engineering and Technology
Research Triangle Park, NC 27711
Prepared for
U.S. 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 third 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.
11
-------
USE OF THIS REPORT
This report is the second 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 June 1980, future
projections (December 1990) of controlled and uncontrolled gener-
ating 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 accomo-
date the revised New Source Performance Standards (6/79) and, as
a result, the categories will differ slightly from those of pre-
vious 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.
111
-------
ABSTRACT
This report is the second 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 operational domestic FGD systems show
73 systems in operation, 38 systems under construction, and 89
planned systems. Projected 1990 FGD controlled capacity in the
U.S. is 95,223 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 42
Alabama Electric
Tombigbee 2 42
Tombigbee 3 44
Arizona Electric Power
Apache 2 46
Apache 3 48
Arizona Public Service
Cholla 1 50
Cholla 2 52
Four Corners 1 53
Four Corners 2 54
Four Corners 3 55
Big Rivers Electric
Green 1 56
Central Illinois Light
Duck Creek 1 58
Central Illinois Public Service
Newton 1 61
Colorado Ute Electric Assn.
Craig 2 63
Columbus & Southern Ohio Electric
Conesville 5 65
Conesville 6 67
Commonwealth Edison
Powerton 51 69
Cooperative Power Association
Coal Creek 1 72
v
-------
CONTENTS (continued)
Delinarva Power & Light
Delaware City 1 74
Delaware City 2 77
Delaware City 3 80
Duquesne Light
Elrama 1-4 83
Phillips 1-6 85
Indianapolis Power & Light
Petersburg 3 88
Kansas City Power & Light
Hawthorn 3 90
Hawthorn 4 92
LaCygne 1 94
Kansas Power & Light
Jeffrey 1 96
Jeffrey 2 97
Lawrence 4 99
Lawrence 5 101
Kentucky Utilities
Green River 1-3 103
Louisville Gas & Electric
Cane Run 4 104
Cane Run 5 106
Cane Run 6 108
Mill Creek 3 110
Paddy's Run 6 112
Minnesota Power & Light
Clay Boswell 4 114
Minnkota Power Cooperative
Milton R. Young 2 118
Monongahela Power
Pleasants 1 121
Montana Power
Colstrip 1 122
Colstrip 2 123
Nevada Power
Reid Gardner 1 124
Reid Gardner 2 126
Reid Gardner 3 128
Northern Indiana Public Service
Dean H. Mitchell 11 130
Northern States Power
Sherburne 1 132
Sherburne 2 134
Pacific Power & Light
Jim Bridger 4 136
VI
-------
CONTENTS (continued)
Section 4
Section 5
Section 6
Section 7
Pennsylvania Power
Bruce Mansfield 1 138
Bruce Mansfield 2 140
Bruce Mansfield 3 142
Public Service Company of New Mexico
San Juan 1 144
San Juan 2 146
San Juan 3 148
Salt River Project
Coronado 1 150
South Carolina Public Service Authority
Winyah 2 151
Winyah 3 153
South Mississippi Electric
R.D. Morrow 1 155
R.D. Morrow 2 157
Southern Illinois Power Coop
Marion 4 159
Southern Indiana Gas & Electric
A.B. Brown 1 161
Springfield City Utilities
Southwest 1 163
St. Joe Zinc
G.F. Weaton 1 165
Tennessee Valley Authority
Shawnee 10A 167
Shawnee 10B 168
Widows Creek 8 170
Texas Utilities
Martin Lake 1 172
Martin Lake 2 174
Martin Lake 3 176
Monticello 3 178
Utah Power & Light
Hunter 1 179
Hunter 2 181
Huntington 1 183
Summary of FGD Systems by Company 185
Summary of FGD Systems by System Supplier 187
Summary of FGD Systems by Process 189
Summary of Operating FGD Systems by
Process and Unit 190
VI1
-------
CONTENTS (continued)
Section 8
Section 9
Section 10
Section 11
Section 12
Section 13
Section 14
Section 15
Page
Summary of End-Product Disposal
Practices for Operational FGD Systems 192
Summary of FGD Systems in Operation 194
Summary of FGD Systems Under Construction 198
Summary of Contract Awarded FGD Systems 200
Summary of Planned FGD Systems 202
Total FGD Units and Capacity (MW)
Installed by Year 205
Design and Performance Data for
Operational Particle Scrubbers 206
Commonwealth Edison
Will County 1 206
Detroit Edison
St. Clair 6 209
Minnesota Power and Light
Aurora 1 211
Aurora 2 213
Clay Boswell 3 215
Montana-Dakota Utilities
Lewis & Clark 1 217
Pacific Power and Light
Dave Johnston 4 219
Potomac Electric Power
Dickerson 1 220
Dickerson 2 221
Dickerson 3 223
Public Service of Colorado
Arapahoe 4 224
Cherokee 1 226
Cherokee 4 228
Valmont 5 230
Southwestern Public Service
Harrington 1 232
Design and Performance Data for
Operational Foreign FGD Systems 234
Chugoku Electric
Shimonoseki 1 234
Vlll
-------
CONTENTS (continued)
Page
Electric Power Development Company
Isogo 1 236
Isogo 2 238
Takasago 1 240
Takasago 2 242
Takehara 1 244
Appendix A FGD System Cost Data: Operational
and Nonoperational Systems A-l
Introduction A-2
Approach A-4
Description of Cost Elements A-7
Definition of Cost Elements A-15
Costs for Operational FGD Systems A-20
Costs for Nonoperational FGD Systems A-25
Appendix B Definitions B-l
Appendix C Table of Unit Notation C-l
Appendix D FGD Process Flow Diagrams D-l
IX
-------
TABLES
No. Page
I Number and Total Capacity of FGD Systems x^
II Summary of Changes, April - June 1980 xiii
III Performance of Operational Units,
April - June 1980 xv
FIGURE
No. Page
1 Computerized Data Base Structure Diagram
-------
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 June 1980. Table II lists the units that
have changed status during the second 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
73
38
29
7
15
38
200
Total
controlled
capacity, MW*
27,155
17,525
13,769
5,590
8,424
22,760
95,223
Equivalent
scrubbed .
capacity, MW
24,765
16,524
12,919
5,590
8,424
22,540
90,762
* 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
H-
H-
Figure 1. Computerized data base structure diagram.
-------
TABLE II. SUMMARY OF CHANGES
APRIL - JUNE 1980
FGD status report
March 31, 1980
Cajun Electric Power Coop.
Big Cajun 3
Colorado UTE Electric Assn.
Craig 3
Commonwealth Edison
Powerton 51
Delmarva Power & Light
Delaware City 1
Delaware City 2
Delaware City 3
General Public Utilities
Coal 4
Coho 1
Seward 7
Hoosier Energy
Merom 1
Houston Lighting & Power
W.A. Parish 8
Limestone 1
Limestone 2
Iowa Electric Light & Pwr.
Guthrie Co. 1
Jacksonville Elect. Authority
New Project 1
New Project 2
Kansas Power & Light
Jeffrey 2
Lansing Board of Water & Light
Erickson 2
Los Angeles Dept. of Wtr. & Pwr.
Intermountain 1
Intermountain 2
Intermountain 3
Intermountain 4
Marquette Board of Light & Pwr.
Shiras 3
Middle South Utilities
Arkansas Lignite 1
Arkansas Lignite 2
Unassigned 1
Unassigned 2
Wilton 1
Wilton 2
Operational
No.
65
+1
+1
+1
+1
+1
MWa
21,733b
450
60
60
60
490
Under
construction
No.
42
-1
-1
+1
+1
-1
MWa
18,343b
450
60
441
492
490
Contract
awarded
No.
23
+1
-1
-1
MWa
10,513b
447
441
492
Letter
of intent
No.
2
+1
+1
+1
H
+1
+1
MWa
842
890
890
890
890
890
890
Requesting/
eval. bids
No.
15
+ 1
+1
+1
+1
+1
+1
-1
-1
-1
-1
-1
-1
MWa
10,345b
690
690
750
750
720
44
890
890
890
890
890
890
Considering
FGD
No.
34
+1
-1
+1
-1
-1
+1
+1
+1
+1
+1
+1
+1
MW5
19,212b
540
447
625
690
690
600
eon
160
820
820
820
820
Total
No.
181
+1
+1
+1
+1
+1
+1
+1
+ 1
+ 1
+1
+1
+1
+1
+1
+1
MWa
80,938b
540
60
60
625
750
750
720
600
600
160
820
820
820
820
44
(Continued)
Xlll
-------
TABLE II (Continued)
FGD status report
Minnesota Power & Light
Clay Boswell 4
Nebraska Public Power District
Fossil III 1
Nevada Power
Reid Gardner 4
Warner Valley 1
Warner Valley 2
Northern Indiana Pub. Service
Schahfer 17
Schahfer 18
Pennsylvania Power
Bruce Mansfield 3
Philadelphia Electric
Eddystone 1A
Plains Electric G&T Coop.
Plains Escalante 1
Platte River Power Authority
Rawhide 1
Potomac Electric Power
Dickerson 4
South Carolina Public Service
Cross 1
Cross. 2
Winyah 3
Winyah 4
Sunflower Electric Coop.
Hoi comb 1
Tampa Electric
Big Bend 4
Utah Power & Light
Hunter 2
TOTAL
Operational
No.
+1
+1
-1
+1
+1
73
MWa
475
917
120
280
360
24,765
Under
construction
No.
-1
-1
-1
+1
-1
38
MWa
475
917
280
280
360
16,524
Contract
awarded
No.
+1
+1
+1
+1
+1
+1
-1
+1
+1
29
ma
421
421
233
275
500
500
280
347
475
12,919
Letter
of intent
No.
+1
-1
-1
7
MW3
250
421
421
5,590
Requesting/
eval . bids
No.
-1
+1
+1
-1
15
MWa
250
250
250
475
8,424
Considering
FGD
No.
+1
-1
-1
-1
38
MWa
650
250
250
800
22,540
Total
No.
+1
-1
+1
+1
-1
+1
+1
+1
200
MW°
650
120
233
275
800
500
500
347
90,762
a Equivalent scrubbed capacity.
This value was modified slightly due to a MW correction.
XIV
-------
TABLE III.
PERFORMANCE OF OPERATIONAL UNITS
APRIL - JUNE 1980
Plant
Tombigbee 2
Tonbigbee 3
Apache 2
Apache 3
Cholla 1
Choi la 2
Four Corners 1
Four Corners 2
Four Corners 3
Green 1
Duck Creek 1
Newton 1
Craig 2
Conesville 5
Conesville 6
Powerton 51
Coal Creek 1
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 5
Cane Run 6
Mill Creek 3
Paddy's Run 6
FGD system
capacity,
179
179
97
97
119
264
175
175
229
242
416
617
447
411
411
450
327
60
60
60
510
408
532
90
90
874
540
490
125
420
64
188
200
299
442
72
Flue gas
% scrubbed
70
70
49
49
100
100
100
100
100
100
100
100
100
100
100
100
60
100
100
100
100
100
100
100
100
100
75
70
100
100
100
100
100
100
100
100
FGD capacity
on line
during
"#*
179
179
97
97
242
416
617
447
411
411
450
327
60
60
60
510
408
90
90
874
540
490
125
420
188
200
299
442
72
No information
for this
period, MW
119
264
175
175
229
532
Shut down
throughout
period,
MWa
64
April 1980 r 0
Dependability %c>e
AVL
100
67
99
65
48
33
85
99
99
99
97
96
100
100
100
100
99
0
99
43
100
OPR
98
65
97
56
73
29
75
40
83
99
73
82
100
100
100
99
0
92
43
0
REL
65
97
79
89
29
100
100
76
93
100
100
100
99
0
98
43
0
UTL
97
0
61
31
45
48
29
70
17
31
99
73
68
65
54
100
80
100
0
80
0
74
42
0
Hay 1980
Dependability %t>e
AVL
100
96
91
0
74
42
5
40
91
97
88
100
83
96
100
100
100
100
100
97
95
100
68
100
OPR
97
8
91
0
76
65
5
38
85
46
51
99
68
88
100
100
100
100
100
95
100
51
87
REL
97
8
91
79
70
5
40
100
100
80
96
100
100
100
100
100
95
100
51
87
UTL
97
1
91
0
74
42
3
40
85
43
25
99
68
60
90
83
100
100
100
81
0
7
80
100
34
8
June 1980
Dependability tf'e
AVL
85
20
53
86
97
90
100
100
100
100
100
0
79
100
88
100
OPR
80
20
57
73
62
53
100
100
100
100
0
74
100
0
94
REL
84
20
59
100
100
100
100
100
0
74
100
0
94
UTL
80
20
53
73
62
53
66
98
100
100
100
100
0
0
62
89
0
7
(Continued)
-------
TABLE III (Continued)
Plant
Clay Boswell 4
Hilton R. Young 2
Pleasants 1
Colstrip 1
Colstrip 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell
Sherburne 1
Sherburne 2
Jim Bridger 4
Bruce Mansfield
Bruce Mansfield 2
Bruce Mansfield 3
San Juan 1
San Juan 2
San Juan 3
Coronado 1
Winyah 2
Winyah 3
R.D. Morrow 1
R.D. Morrow 2
Marion 4
A.B. Brown 1
Southwest 1
G.F. Weaton 1
Shawnee IDA
Shawnee 10B
Widows Creek 8
Martin Lake 1
Martin Lake 2
Martin Lake 3
Monticello 3
FGD system
capacity,
475
185
618
360
360
125
125
125
11 115
740
740
550
917
917
917
361
350
534
280
140
280
124
124
184
265
194
60
10
10
550
595
595
595
800
Flue gas
% scrubbed
85
42
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
80
50
100
62
62
100
100
100
N/Ad
N/Ad
N/Ad
100
75
75
75
100
FGD capacity
on line
during
"#*
475
185
125
125
125
115
740
740
550
361
350
534
140
280
124
124
265
194
60
550,
595
595
595
800
No information
for this
period, MW
618
360
360
917
917
917
280
184
10
10
Shut down
throughout
period,
April 1980
Dependability r>e
AVL
0
97
99
100
63
97
96
26
100
81
100
64
100
0
100
47
96
OPR
0
97
99
53
25
75
74
100
60
99
98
38
81
REL
0
97
99
53
28
100
80
100
60
100
100
38
UTL
0
81
94
0
50
20
51
55
85
50
99
0
94
33
46
May 1980
Dependability % '
AVL
47
98
93
0
63
96
96
89
100
99
96
100
2
100
58
97
OPR
48
94
86
0
24
68
96
95
95
100
14
100
46
80
REL
51
97
68
0
26
88
100
100
95
100
14
100
52
UTL
46
85
14
0
16
63
86
85
78
89
2
83
46
60
June 1980
Dependability r'e
AVL
42
93
100
75
53
96
100
91
69
100
99
99
100
49
100
OPR
40
93
98
81
0
87
58
100
97
90
100
46
75
REL
41
93
100
81
0
80
53
100
99
99
100
47
100
UTL
39
89
75
72
0
71
48
100
93
78
98
46
68
X
<
H-
(Continued)
-------
TABLE III (Continued)
Plant
Hunter 1
Hunter 2
Huntington 1
TOTAL
FGD system
capacity,
360
360
366
Flue gas
% scrubbed
90
90
85
FGD capacity
on line
during
period,
MWa>D
360
360
366
18,364
No information
for this
period, MW
6,067
Shut down
throughout
perigd,
64
April 1980
Dependability % '
AVL
OPR
100
98
REL
UTL
60
92
May 1980
Dependability %c>
AVL
OPR
100
100
REL
UTL
64
100
June 1980
Dependability Xc'e
AVL
OPR
100
100
REL
UTL
98
99
H-
H-
. Equivalent scrubbed capacity.
° 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 % scrubbed for prototype and demonstration units is not applicable unless the system is designed to bring a unit into compliance
with S02 emission standard.
Availability, operability, reliability, and utilization as defined in Appendix C of this report.
-------
As indicated in Table I, 73 power generating units (all coal-
fired) are now equipped with operating FGD systems. These units
represent a total controlled capacity of 27,155 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:a
Coal Nuclear Oil Hydro Gas Other GW (total)
December 1979 39% 9% 25% 13% 13% 1% 603
December 1990 44% 14% 20% 11% 10% 1% 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 (June 1980) and the future
(December 1990) is as follows:
Coal-fired generating Total generating
capacity, % capacity, %
June 1980* 11.5 4.5
December 1990 26.0 11.4
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 (June 1980) and a projected
(December 1990) breakdown of throwaway product systems versus
saleable product systems as a percent of the total known commit-
ments to FGD as of the end of the second quarter 1980:
*
The number of committed FGD systems is as of June 1980; however,
the figure used for the total generating capacity and coal-fired
generating capacity is based on the available December 1979
figures.
XVlll
-------
Throwaway product process
Wet systems
Lime
Limestone
Dual alkali
Othera
Dry systems
Lime
Aqueous carbonate
Saleable product process
Byproduct
Gypsum
Sulfur
Sulfuric acid
N/Ab
Process Undecided
Total
Percent of total MW
June 1980
39.8
45.1
4.8
3.8
-
3.6
2.9
-
100.0
December 1990
23.0
37.9
2.2
7.9
3.3
0.5
0.7
1.0
3.0
1.8
18.7
100.0
The other category contains some systems that will produce a throwaway
product, but the actual process is unknown at this time.
N/A - not available (these systems will utilize a saleable product process
but the byproduct is unknown at this time).
HIGHLIGHTS: APRIL - JUNE 1980
The following paragraphs highlight FGD system developments during
the second quarter, 1980.
Cajun Electric Power Cooperative has announced plans to construct
Big Cajun 3, unit 1 in De Soto Parish, Louisiana. The unit will
be rated at 540 MW (gross) and has a scheduled start up date of
1985. The utility is currently considering a dry scrubbing sys-
tem as an SO- emission control strategy.
A contract was awarded during the second quarter 1980 to Babcock
& Wilcox by Colorado UTE Electric Association for the installation
of a lime/spray drying FGD system to control SC>2 emissions from
the new Craig 3 unit. This unit will be rated at 447 MW (gross)
and will fire subbituminous coal with an average sulfur content
of 0.45%. Initial operations are expected to begin in 1982.
xix
-------
Initial operations of the limestone FGD system retrofitted on the
450 MW (gross) Powerton 51 unit of Commonwealth Edison began
during April. This system, which was supplied by the Air Correc-
tion Division of UOP, consists of three turbulent contact absorber
modules preceeded by a common ESP for primary particulate matter
removal. An indirect hot air reheater boosts the temperature of
the cleaned flue gas before it exits through a 450 foot stack.
As of the end of June, only two of the three absorber modules had
been placed in operation.
Delmarva Power & Light announced that initial operations of the
Wellman Lord FGD systems retrofitted on the Delaware City station
boilers 1, 2, and 3 began in May. The FGD systems, which were
supplied by Davy McKee, each consist of a four stage tray tower
design. Primary particulate matter removal is provided by a
mechanical collector and a venturi type particle scrubber which
preceed each absorber train. The utility reports that no major
operational problems have been encountered during start up of
the systems.
General Public Utilities has announced plans for a new unit,
currently being identified as Coal 4, which will be rated at 625
MW (gross). Although the exact location has not yet been deter-
mined, the unit will be either in Pennsylvania or New Jersey. The
utility is currently considering only FGD as a means to control
SO2 emissions. The scheduled start up date for this unit is
1997.
General Public Utilities began requesting/evaluating bids for FGD
systems to be installed for SC>2 emission control on the new
Coho 1 and Seward 7 units. Each unit will be rated at 690 MW
(gross). Coho 1 will be located in Erie, Pennsylvania and Seward
7 will be located in Seward, Pennsylvania. The projected start
up dates for the two units are May, 1991 for Coho 1 and May 1987
for Seward 7.
Construction began during the second quarter 1980 on the limestone
FGD system being installed by Mitsubishi Heavy Industries on the
490 MW (gross) Merom 1 unit of Hoosier Energy. The FGD system,
which consists of a grid tower design, will be preceeded by an
ESP for primary particulate matter control. A bypass reheat
system will be included to boost the temperature of the flue gas
before it exits through a 700 foot stack. Initial start up of
the system is projected for May 1982.
Houston Lighting & Power has begun requesting/evaluating bids for
wet limestone FGD systems to be installed at its planned Lime-
stone County facility. There will be two coal (1.08% S) fired
750 MW (gross) boilers with a separate FGD system for control of
S02 emissions. A cold side ESP will be used for control of
particulate matter emissions. The scheduled start up dates are
1985 for unit 1 and 1986 for unit 2.
xx
-------
During the second quarter 1980 construction began on the limestone
FGD system being installed to control S02 emissions from the 600
MW (gross) W. A. Parish 8 unit of Houston Lighting & Power. This
system, which is being supplied by Chemico, will consist of a
spray tower design preceeded by Research Cottrell fabric filters
for primary particulate matter removal. A bypass reheat system
will be included to boost the temperature of the flue gas before
exiting through a 500 foot brick lined stack. This unit is
scheduled to begin initial operations in November, 1982.
Iowa Electric Light & Power is currently evaluating bids for an
FGD system to be installed at the Guthrie County 1 station. The
unit is to be located in Pandora, Iowa and rated at 720 MW (gross).
Only wet limestone FGD systems are being evaluated. The pro-
jected start up date is December, 1984.
Jacksonville Electric Authority has announced plans for two new
units, currently being identified as New Project 1 and New Project
2, to be constructed in East Port, Florida. The units will be
rated at 600 MW (gross). A wet limestone scrubbing system is
currently under consideration as the SC>2 emission control strategy.
The projected start up for units 1 and 2 is 1985 and 1987,
respectively.
Kansas Power & Light reported that commercial operation of the
FGD system installed on the 700 MW (gross) Jeffrey 2 unit began
in May. The FGD system was supplied by Combuston Engineering and
utilizes a wet limestone process. The system design consists of
spray towers preceeded by a cold side ESP for primary particulate
matter removal. A 30% flue gas bypass reheat system boosts the
temperature of the flue gas before it exits through a 600 foot
stack. The utility reports that no major operational problems
have been encountered since system start up.
Lansing Board of Light & Water has announced plans to build a
second unit at its Erickson Station. The unit will have a rating
of between 160 and 250 MW (gross), depending on how many other
municipal utilities join in the project. Start up is projected
for 1987. The utility is currently considering only FGD as a
means to control SC>2 emissions at this unit.
Los Angeles Department of Water & Power has announced plans for
four new units, Intermountain 1-4. This is a joint venture with
Southern California Edison and will be called the Intermountain
Power Project. The plant will be located in Delta, Utah. These
units will be rated at 820 MW (gross) each and will fire a low
sulfur Utah coal. Weir type horizontal wet scrubbers along with
hot side ESP's are currently under consideration for emission
control. The first unit is scheduled to come on line in 1986 and
the following units will come on line yearly thereafter.
xxi
-------
Bids for a dry lime scrubbing system are currently being requested
by the Marquette (Michigan) Board of Light & Power. This FGD
system will be installed on unit 3 of the Shiras generating
facility. The unit has a rating of 44 MW (gross) and will fire a
low sulfur coal. A fabric filter will be used for particulate
matter control. Projected start up of this unit is 1982.
Middle South Utilities has announced that a letter of intent has
been signed with Combustion Engineering for the installation of
FGD systems to control S02 emissions from each of their six
planned 890 MW (gross) units. These units are currently known as
Arkansas Lignite 1 & 2, Unassigned 1 & 2, and Wilton 1 & 2.
Although precise locations for these units have not yet been
decided, it is known that Arkansas Lignite will be in the state
of Arkansas and Wilton will be in the state of Louisiana. The
projected start up dates for Arkansas Lignite 1 & 2 are January,
1986 and January, 1988, respectively, and the projected start up
dates for Wilton 1 & 2 are also January, 1986 and January, 1988,
respectively. Unassigned 1 & 2 are scheduled to commence opera-
tions in January, 1985 and January, 1987, respectively.
Initial FGD operations began during April 1980 at the Clay Boswell
4 unit of Minnesota Power & Light. This unit is rated at 554 MW
(gross) and burns subbituminous coal with an average sulfur con-
tent of 0.94%. The FGD system was supplied by Peabody Process
Systems and utilizes a lime/alkaline flyash process with a spray
tower configuration. Two ESP's and four (one spare) particle
scrubbers upstream of the FGD system provide primary particulate
matter removal. A chevron mist eliminator is included downstream
of each absorber and the FGD system waste product is disposed of
in a lined pond one mile from the plant site. Although operating
parameters are not yet available for this unit, the utility
reports that the system has operated well with only normal
shakedown problems being encountered.
Nebraska Public Power District is currently considering a dry
scrubbing system for its Fossill III unit, which is to be located
near Sargent, Nebraska. The planned 650 MW (gross) unit will
fire a low sulfur subbituminous coal. The projected start up is
in 1987.
Nevada Power reported that the Reid Gardner 1 FGD system had
availabilities of 97%, 98%, and 93% for the months of April, May,
and June, respectively- Some minor outages occurred during the
period; however, no major operational problems were reported. The
Reid Gardner 2 FGD system had availabilities of 99%, 93%, and
100% for the months of April, May, and June, respectively. Minor
problems were reported with plugging of the venturi nozzles
during the period. The Reid Gardner 3 FGD system did not operate
during the months of April and May for FGD system induced draft
fan repairs. It returned to service in June.
xxii
-------
Nevada Power reported that a letter of intent was signed during
the second quarter, 1980 for a wet sodium carbonate system to be
installed on the planned Reid Gardner 4 unit. This unit, which
will be rated at 250 MW (gross), will burn coal with an average
sulfur content of 0.75%. Initial start up is scheduled for
April, 1983.
Nevada Power also reported that they are currently requesting/
evaluating bids for FGD systems to be installed on the planned
Warner Valley 1 & 2 units. Each unit will be rated at 295 MW
(gross) and will burn coal with an average sulfur content of
1.15%. Initial start up of units 1 & 2 is scheduled for June,
1985 and June, 1986, respectively-
Northern Indiana Public Service announced that a contract has
been awarded to FMC for the installation of dual alkali FGD
systems at the Schahfer 17 & 18 units. The boilers, which will
be located in Wheatfield, Indiana, will fire bituminous coal
having an average sulfur content of 3.2% and will each be rated
at 421 MW (gross). Each FGD system will consist of four modules
and will utilize an ESP for primary particulate matter control.
Operations at Schahfer 17 & 18 are scheduled to commence in 1983
and 1985, respectively-
Northern States Power reported availabilities of 97%, 96%, and
96% for the months of April, May, and June, respectively, for the
Sherburne 1 FGD system. No major operational problems were
reported for the period. The Sherburne 2 FGD system was out of
service during most of May and June as a result of an annual
boiler and turbine inspection. The FGD system availabilities
were 96%, 96%, and 100% for April, May, and June, respectively.
Initial operations of the FGD system at the Bruce Mansfield 3
unit began in June, 1980. This system, which was supplied by
Pullman Kellogg and utilizes a lime process, treats the flue gas
from a 917 MW (gross) boiler that burns coal with an average
sulfur content of 3.0%. Included in the emission control
system are four ESP's for primary particulate matter removal and
direct combustion reheaters to boost the temperature of the' flue
gas before it exits through a 600 foot stack. The FGD system is
currently in the shakedown/debugging phase of operation.
Plains Electric Generation & Transmission Cooperative has awarded
a contract to Combustion Engineering for a wet limestone scrub-
bing system that will be installed on unit 1 at the Plains
Escalante Generating Station. The unit will be rated at 233 MW
(gross) and particulate matter control will be achieved with a
fabric filter. Start up is scheduled for 1983.
A contract has been awarded to Joy Manufacturing/Niro Atomizer by
Platte River Power Authority for a dry lime scrubbing system. The
XXlll
-------
FGD system will be installed on the Rawhide 1 unit which is being
built in Ft. Collins, Colorado. The unit is rated at 279 MW
(gross) and will fire a low sulfur western coal.
Potomac Electric Power announced during the second quarter, 1980
that plans for the 850 MW (gross) Dickerson 4 unit have been
cancelled. The utility reports that the demand for power has
been lower than anticipated and they feel that an oil fired unit
near completion at the Chalk Point station will be adequate to
meet present demands.
South Carolina Public Service has awarded a contract with Peabody
Process Systems for wet limestone FGD systems to be installed at
the Cross Generating Station. Two 500 MW (gross) coal fired
boilers are planned for location in Cross, S.C. The projected
start up dates are 1986 for unit 1 and 1984 for unit 2.
South Carolina Public Service also announced during the April -
June 1980 period that initial FGD operations at the Winyah 3 unit
began in May. This unit is rated at 280 MW (gross) and burns
coal with an average sulfur content of 1.7%. The FGD system,
which is preceeded by an ESP for primary particulate matter
removal, was supplied by Babcock & Wilcox and utilizes a limestone
process. The utility reports that some damper problems have been
encountered during the initial start up period.
Construction began during April, 1980 on the limestone FGD system
being supplied by American Air Filter for the Winyah 4 unit of
South Carolina Public Service. This unit will also be rated at
280 MW (gross) and will burn coal with an average sulfur content
of 1.7%. The FGD system will consist of two spray towers pre-
ceded by an ESP for primary particulate matter removal. The
projected start up date is July, 1981.
Southern Indiana Gas & Electric reported that the A.B. Brown 1
FGD system acheived availabilities of 100% for all three months
of the second quarter, 1980. No FGD system forced outages were
encountered during the three month period.
Sunflower Electric Coop has awarded a contract to Joy Manufactur-
ing/Niro Atomizer for a dry lime scrubbing system to be installed
on the planned Holcomb 1. The unit will be rated at 347 MW
(gross) and is to be located in Holcomb, Kansas. Particulate
matter control will be achieved with a fabric filter. The unit is
scheduled to commence operations in the fall of 1983.
A contract was awarded during the second quarter 1980 to Research
Cottrell for the installation of a lime/limestone FGD system at
the Big Bend 4 unit of Tampa Electric. This new unit will be
rated at 475 MW (gross) and will burn coal with an average
sulfur content of 2.35%. The FGD system will be preceded by an
ESP for primary particulate matter removal and an indirect
xxiv
-------
hot air reheat system will be included to boost the temperature
of the flue gas before it exits through a 490 foot stack. The
projected initial start up date for the system is December, 1984.
Initial operation of the Lime FGD system installed on the Hunter
2 unit of Utah Power & Light began during June, 1980. The FGD
system was supplied by Chemico and treats flue gas from a 400 MW
(gross) boiler that burns coal with an average sulfur content of
0.55%. An ESP upstream of the FGD system provides primary
particulate matter removal, while a bypass system provides stack
gas reheat. The waste product is stabilized with flyash before
being disposed of on-site. Actual performance data characteriz-
ing initial operations of this system are not yet available.
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.
xxv
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC COOP
TOMBI6BEE
TOMBI6BEE
ARIZONA ELECTRIC POUER COOP
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC COOP
THOMAS HILL
BASIN ELECTRIC POUER COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAHIE RIVER
LARAMJE RIVER
LARANIE RIVER
BIG RIVERS ELECTRIC
D. B. WILSON
0. B. WILSON
6REEN
GREEN
CAJUN ELECTRIC POWER COOP
816 CAJUN 3
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
UNIT NO.
2
3
2
3
1
2
4
1
2
3
4
5
3
1
2
1
2
3
1
2
1
2
1
1
2
UNIT LOCATION
LEROY
LEROY
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIN6TON
FARMINGTON
FARMINGTON
FARMINGTON
FARMINGTON
MOBERLY
BEULAH
BEULAH
WHEATLAND
WHEATLAND
WHEATLAND
SEBREE
SEBREE
DE SOTO PARISH
CANTON
CANTON
ALABAMA
ALABAMA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
MISSOURI
NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
WYOMING
KENTUCKY
KENTUCKY
LOUISIANA
ILLINOIS
ILLINOIS
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
4/83
10/85
7/80
6/81
4/82
11/84
0/85
12/79
11/80
0/85
7/76
1/86
STATUS
1
1
1
1
1
1
2
1
1
1
3
3
2
2
5
2
2
2
6
6
1
2
6
1
5
REG
CLASS
B
B
D
D
C
C
C
C
C
C
C
C
A
D
C
C
C
C
A
A
B
B
A
B
A
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
CENTRAL MAINE POUER
SEARS ISLAND
CINCINNATI GAS 8 ELECTRIC
EAST BEND
EAST BEND
NEWTON
ILLINOIS
PENOBSCOT BAY MAINE
COLORADO UTE
CRAIG
CRAI6
CRAIG
ELECTRIC ASSN.
RABBITHASH
RABBITHASH
CRAIG
CRAIG
CRAIG
KENTUCKY
KENTUCKY
COLORADO
COLORADO
COLORADO
COLUMBUS 8 SOUTHERN OHIO ELEC.
CONESVILLE 5
CONESVILLE 6
POSTON 5
POSTON 6
1. OPERATIONAL UNITS 4.
2. UNITS UNDER CONSTRUCTION 5.
3. PLANNED - CONTRACT AWARDED 6.
7.
CONESVILLE OHIO
CONESVILLE OHIO
NELSONVILLE OHIO
NELSONVILLE OHIO
9/79
1/89
C/ 0
9/80
7/80
12/79
0/82
1/77
6/78
8/86
0/89
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSM2/7D
C. STANDARD(S) MORE STRINGENT THAN NSPSI6/79)
D. STANOARD(S) MORE STRINGENT THAN 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: APRIL - JUNE
SECTION 1
SUMMARY LIST OF F&D SYSTEMS
COMPANY NAME/
UNIT NAME
COMMONWEALTH EDISON
POUERTON
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
DELMARVA POWER & LIGHT
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
VIENNA
DESERET GEN f, TRANS COOP
MOON LAKE
MOON LAKE
DUOUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER COOP
J. K. SPITH
j. K. SMITH
SPURLOCK
FLORIDA POWER 8 LIGHT
MARTIN
MARTIN
GENERAL PUBLIC UTILITIES
COAL
COAL
COAL
COAL
COHO
SEWARD
GRAND HAVEN BRD OF LIGHT K PWR
J. B. SIMS
HOOSIER ENERGY
MEROM
MEROM
HOUSTON LIGHTING g POWER
LIMESTONE
LIMESTONE
W.A. PARISH
INDIANAPOLIS POWFR & LIGHT
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
UNIT NO.
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
2
8
1
2
3
3
4
UNIT LOCATION
PE&K.IN
UNDERWOOD
UNDERWOOD
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
VIENNA
VERNAL
VERNAL
ELRAMA
SOUTH HEIGHT
MAYSVILLE
MARTIN COUNTY
MARTIN COUNTY
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
GIRARD TWP.
I, WHEATFIELD
GRAND HAVEN
SULLIVAN
SULLIVAN
JEWITT
JEWITT
BOOTH
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
ILLINOIS
NORTH DAKOTA
NORTH DAKOTA
DELAWARE
DELAWARE
DELAWARE
MARYLAND
UTAH
UTAH
PENNSYLVANIA
PENNSYLVANIA
KENTUCKY
FLORIDA
FLORIDA
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
PENNSYLVANIA
PENNSYLVANIA
MICHIGAN
INDIANA ,
INDIANA
TEXAS
TEXAS
TEXAS
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
START-UP
DATE
4/60
8/79
7/8T
5/8T
5/6T
5/8^
6/87
9/84
C/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
7/81
2/85
2166
11/82
0/87
0/87
0/87
12/77
10/84
STATUS
1
1
2
1
1
1
6
5
5
1
1
6
6
2
7
7
6
6
6
6
5
5
3
2
2
5
5
2
6
6
6
1
2
REG
CLASS
E
B
B
E
E
E
A
A
A
D
D
A
A
e
A
A
A
A
A
A
A
A
A
B
B
A
A
A
C
C
C
e
B
IOWA ELECTRIC LIGHT 8 PWR
GUTHRIE CO.
PANORA
IOWA
10/84
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 SYSiTEHS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSC12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) !«ORE STRINGENT THAN NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPS<6/79>
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSM2/7D
-------
EPA UTILITY FGD SURVEY: *PRIL - JUNE 198k.
SECTION 1
SUHMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
JACKSONVILLE ELECT. AUTHORITY
NEW PROJECT
NEW PROJECT
KANSAS CITY POWER K LIGHT
HAWTHORN
HAWTHORN
LA CYGNE
KANSAS POUER & LIGHT
JEFFREY
JEFFREY
LAURENCE
LAURENCE
UNIT
1
2
3
4
1
1
2
4
5
NO. UNIT LOCATION
EAST -PORT SITE
EAST PORT SITE
KANSAS CITY
KANSAS CITY
LA CYGNE
WAMEGO
WAMEGO
LAWRENCE
LAWRENCE
FLORIDA
FLORI DA
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
START-UP
DATF
C/85
C/87
11/7?
8/72
2/73
8/78
4/8"
1/76
11/71
STATUS
6
6
1
1
1
1
1
1
1
REG
CLASS
A
A
D
D
e
D
D
D
D
KENTUCKY UTILITIES
GREEN RIVER 1-3
LAKELAND UTILITIES
MCINTOSH 3
LANSING BOARD OF WATER £ LIGHT
ERICKSON 2
LOS ANGELES DEPT OF WTR g PUR
INTERMOUNTAIN 1
INTERMOUNTAIN 2
INTERMOUNTAIN 3
INTERMOUNTAIN 4
LOUISVILLE GAS 8 ELECTRIC
CANE RUN 4
CANE RUN 5
CANE RUN 6
NILL CREEK 1
HILL CREEK 2
NILL CREEK 3
NILL CREEK 4
PADDY'S RUN 6
TRIMBLE COUNTY 1
TRIMBLE COUNTY 2
NARQUETTE BOARD OF LIGHT & PWR
SHIRAS 3
MICHIGAN S.
PROJECT
CENTRAL PUR AGENCY
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
ARKANSAS LIGNITE
UNASSIGNED
UNASSIGNED
UILTON
WILTON
MINNESOTA POWER 8 LIGHT
CLAY BOSWELL
CENTRAL CITY
LAKELAND
KENTUCKY
FLORIDA
DELTA TOWNSHIP MICHIGAN
DELTA
DELTA
DELTA
DELTA
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
BEDFORD
BEDFORD
MARQUETTE
L1TCHFIELD
COHASSET
UTAH
UTAH
UTAH
UTAH
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
MICHIGAN
MICHIGAN
ARKANSAS
ARKANSAS
UNDECIDED
UNDECIDED
LOUISIANA
LOUISIANA
MINNESOTA
9/75
8/81
1/87
0/86
0/87
0/88
0/89
10/82
4/82
1/86
1/88
0/85
0/87
0/86
0/88
4/8P
8/76
12/77
4/79
12/8C
12/81
8/78
7/81
4/73
7/85
7/88
1
1
1
2
2
1
2
1
6
6
D
D
D
E
E
D
B
E
A
A
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 NSPS(6/79)
B. FEDERAL NSPSM2/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPSC6/79)
E. STANDARD(S) E8UAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT
NO. UNIT LOCATION
START-UP
DATE
STATUS
REG
CLASS
1INNKOTA POWER COOPERATIVE
MILTON R. YOUNG
MONONGAHEL* POWER
PLEASANTS
PLEASANTS
MONTANA POWER
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
2
1
2
1
2
3
4
CENTER
BELMONT
BELMONT
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
NORTH DAKOTA
WEST VIRGINIA
WEST VIRGINIA
MONTANA
MONTANA
MONTANA
MONTANA
9/77
3/79
9/80
9/75
5/76
0/83
0/84
1
1
2
1
1
2
2
D
B
B
B
e
C
C
MONTANA-DAKOTA UTILITIES
COYOTE 1
MUSCATINE POWER 8 WATER
HUSCATINE 9
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
BEULAH
MUSCATINE
SARGENT
NORTH DAKOiTA
IOWA
NEBRASKA
3/81
9/82
3/87
NEVADA POWER
HARRY ALLEN 1
HARRY ALLEN 2
HARRY ALLEN 3
HARRY ALLEN 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
REID GARDNER 4
WARNER VALLEY 1
WARNER VALLEY 2
NEW YORK STATE ELEC 8 GAS
SOMERSET 1
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
SCHAHFER 17
SCHAHFER 18
NORTHERN STATES POWER
RIVERSIDE 6,7
SHERBURNE 1
SHERBURNE 2
SHERBURNE 3
PACIFIC GAS 8 ELECTRIC
MONTEZUMA 1
MONTEZUMA 2
PACIFIC POWER 8 LIGHT
JIM BRIDGER 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
BRUCE MANSFIELD 2
1. OPERATIONAL UNITS 4.
3. UNITS UNDER CONSTRUCTION 5.
3. PLANNED - CONTRACT AWARDED 6.
7.
N.E. LAS VEGAS NEVADA
N.E. LAS VEGAS NEVADA
N.E. LAS VEGAS NEVADA
N.E. LAS VEGAS NEVADA
MOAPA NEVADA
MOAPA NEVADA
MOAPA NEVADA
MOAPA NEVADA
ST. GEORGE UTAH
ST. GEORGE UTAH
SOMERSET
BUFFALO
NEW YORK
NEW YORK
GARY
WHEATFIELD
WHEATFIELD
MINNEAPOLIS
BECKER
BECKER
BECKER
INDIANA
INDIANA
INDIANA
MINNESOTA
MINNESOTA
MINNESOTA
MINNESOTA
COLLINSVILLE CALIFORNIA
COLLINSVILLE CALIFORNIA
ROCK SPRINGS WYOMING
SHIPPINGPORT
SHIPP1NGPORT
PENNSYLVANIA
PENNSYLVANIA'
6/86
6/87
6/88
6/89
4/74
4/74
6/76
4/83
6/85
6/86
6
6
6
6
1
1
1
4
5
5
A
A
A
A
B
6
B
A
A
A
6/84
4/82
7/76
6/83
6/85
8/80
3/76
4/77
5/65
6/89
6/90
9/79
12/75
7/77
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSH2/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARDS) MORE STRINGENT THAN NSPS<12/71) BUT NOT MORE STRINGENT THAN NSPSI6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 1
SUMMARY LIST OF F£D SYSTEMS
COMPANY NAME/
UNIT NAME
PENNSYLVANIA POWER
BRUCE MANSFIELD
PHILADELPHIA ELECTRIC
CROMBY
EDDYSTONE
EDDYSTONE
UNIT NO.
3
1
1
2
UNIT LOCATION
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
EDDYSTONE
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
START-UP
DATE
10/sn
5/83
12/83
12/8?
STATUS
1
3
2
2
REG
CLASS
D
D
D
D
PLAINS ELECTRIC G & T COOP
PLAINS ESCALANTE 1
PLATTE RIVER POWER AUTHORITY
RAUHIDE 1
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
SAN JUAN 4
PWR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
COKONADO 1
CORONADO 2
CORONADO 3
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SEMINOLE ELECTRIC
SEMINOLE 1
SEMINOLE 2
SIERRA PACIFIC POWER
VALMY 2
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
CROSS 2
WINYAH 2
WINYAH 3
WINYAH 4
PREWITT
FT. COLLINS
PRINCETON
WATERFLOW
WATERFLOW
WATERFLOW
WATERFLOW
NEW YORK
ST. JOHNS
ST. JOHNS
ST. JOHNS
SAN MIGUEL
PALATKA
PALATKA
VALMY
SIKESTON
CROSS
CROSS
GEORGETOWN
GEORGETOWN
GEORGETOWN
NEW MEXICO 12/83 3
COLORADO 12/83 3
INDIANA 0/82 3
NEW MEXICO 4/78 1 C
NEW MEXICO 8/78 1 C
NEW MEXICO 12/79 1 C
NEW MEXICO 6/82 2 C
NEW YORK 11/87
ARIZONA 11/79 1 D
ARIZONA 7/80 2 D
ARIZONA 1/88 6 A
TEXAS 10/80
FLORIDA 3/83 3 A
FLORIDA 3/85 3 A
NEVADA 8/84
MISSOURI 1/81
SOUTH CAROLINA 3/85 3 A
SOUTH CAROLINA 11/83 3 A
SOUTH CAROLINA 7/77 1 B
SOUTH CAROLINA 5/80 1 B
SOUTH CAROLINA 7/81 2 A
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 1
R.D. MORROW 2
SOUTHERN ILLINOIS POWER COOP
MARION 4
MARION 5
HATTISBURG
HATTISBURG
MARION
MARION
MISSISSIPPI
MISSISSIPPI
ILLINOIS
ILLINOIS
8/78
6/79
5/79
0/86
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 FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
3. FEDERAL NSPS(12/n>
C. STANDARDISE MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPS(1?/71) BUT NOT MORE STRINGENT THAN NSPSC6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 1
SUMMARY LIST OF FGO SYSTEMS
COMPANY NAME/
UNIT NAME
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN
SOUTHyESTERN ELECTRIC POWER
HENRY U. PIRKEY
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SPRINGFIELD WATERi LIGHT 8 PWR
DALLMAN
ST. JOE ZINC
G.F. WEATON
SUNFLOWER ELECTRIC COOP
HOLCOMB
TAMPA ELECTRIC
BIG BEND
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE
PARADISE
PARADISE
SHAWNEE
SHAWNEE
WIDOWS CREEK
WIDOWS CREEK
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
TEXAS POWER 8 LIGHT
SANDOW
TWIN OAKS
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MILL CREEK
MILL CREEK
MONTICELLO
TUCSON ELECTRIC POWER
SPRINGERVILLE
SPRINGERVILLE
UNITED POWER ASSOCIATION
STANTON
UTAH POWER 8 LIGHT
HUNTER
HUNTER
HUNTER
HUNTER
HUNTINGTON
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPSM2/7D
C. STANDARD(S) MORE STRINGENT
D. STANDARD(S) MORE STRINGENT
UNIT
1
1
1
3
1
1
*
1-10
1
2
1CA
10B
7
8
1
4
1
2
1
1
2
3
4
1
2
3
1
2
1A
1
2
3
4
1
4.
5.
6.
7.
THAN
THAN
NO. UNIT LOCATION
WEST FRANKLIN INDIANA
HALLSVILLE TEXAS
SPRINGFIELD MISSOURI
SPRINGFIELD ILLINOIS
MONACA PENNSYLVANIA
HOLCOMB KANSAS
TAMP* FLORIDA
NEW JOHNSONVILLTENNESSEE
PARADISE KENTUCKY
PARADISE KENTUCKY
PADUCAH KENTUCKY
PADUCAH KENTUCKY
BRIDGEPORT ALABAMA
BRIDGEPORT ALABAMA
CARLOS TEXAS
ROCKDALE TEXAS
BREMOND TEXAS
BREMOND TEXAS
ATHENS TEXAS
TATUM TEXAS
TATUM TEXAS
TATUM TEXAS
TATUM TEXAS
HENDERSON TEXAS
HENDERSON TEXAS
MT. PLEASANT TEXAS
SPRINGERVILLE ARIZONA
SPRINGERVILLE ARIZONA
STANTON NORTH DAKOTA
CASTLE DALE UTAH
CASTLE DALE UTAH
CASTLE DALE UTAH
CASTLE DALE UTAH
PRICE UTAH
START-UP
DATE
4/79
12/84
4/77
11/80
11/79
0/83
12/84
12/81
3/82
6/82
4/72
4/72
9/81
5/77
1/82
9/80
8/84
8/85
0/81
4/77
5/78
2/79
0/85
0/85
0/86
5/78
1/85
10/86
1/82
5/79
6/80
0/83
0/85
5/78
STATUS
1
3
1
2
1
3
3
3
2
2
1
1
2
1
2
2
3
3
5
1
1
1
3
6
6
1
3
3
3
1
1
3
3
1
REG
CLASS
B
B
B
B
B
A
A
E
E
E
E
E
E
E
A
B
A
A
A
B
B
B
A
A
A
B
B
B
A
B
B
A
A
B
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING
PLANNED - CONSIDERING ONLY FGD
BIDS
SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE
NSPSI6/79)
METHODS
NSPS(12/71) BUT NOT MORE STRINGENT THAN NSPS<6/79>
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS<12/71>
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP REG
BATE STATUS CLASS
WEST PENN POWER
MITCHELL
WEST TEXAS UTILITIES
OKLAUNION
33
COURTNEY
OKLAUNION
PENNSYLVANIA
TEXAS
8/82
0/87
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 NSPS<6/79)
8. FEDERAL NSPSM2/71J
C. STANDARDS) MORE STRINGENT THAN NSPSC6/79)
D. STANOARDtS) MORE STRINGENT THAN NSPSI12/71) BUT NOT MORE STRINGENT THAN NSPS(6/79>
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSO2/71)
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198?
SECTION I
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC COOP
TOHBIGBEE
2
NEW 255.0 MW (GROSS)
179.0 MW (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3 . 1 J!
STATUS 1 STARTUP 9/78
TOMBIGBEE 2 OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLOW OF 953,OCO
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.15* AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMMISSION LIMITA-
TION VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE MATTER CONTROL IS PROVID-
ED BY A HOT SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF TUO 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 WITH BYPASSED GAS BEFORE BEING VENTED TO A 400 FOOT ACID-
BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE AND
SPENT ABSORBENT IS DISPOSED OF IN AN ON-SITE LINED POND.
ALABAMA ELECTRIC COOP
TOMBIGBEE
J
NEW 255.0 MW (GROSS)
179.0 MW (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.1X
STATUS 1 STARTUP 6/79
TOMBIGBEE 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 BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 1.15X 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 HOT
SIDE ESP. THE S02 REMOVAL EBUIPMENT CONSISTS OF TWO SPRAY TOWERS 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 MODE, AND SPENT ABSORBENT
IS DISPOSED IN AN ON-SITE LINED POND.
ARIZONA ELECTRIC POWER COOP
APACHE
2
NEW 195.0 MW (GROSS)
97.5 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH-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 BOTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOW OF 735,000
ACFM. BITUMINOUS COAL WITH A HEATING VALUE OF 1^,000 BTU/LB, A SULFUR CON-
TENT OF 0.55X AND AN ASH CONTENT OF 15X IS THE FUEL USED FOR THIS UNIT.
PARTICULATE CONTROL IS EFFECTED BY A HOT SIDE ESP. THE UNIT IS CURRENTLY
IN OPERATION WITH STARTUP IN AUGUST 1978. 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 ELIMI-
NATORS. NO REHEAT IS EMPLOYED. A 409 FT COLE BRAND CXL200C 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.
ARIZONA ELECTRIC POWER COOP
APACHE
J
NEW 195.0 MW (GROSS)
97.5 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.1X
STATUS 1 STARTUP 6/79
APACHE 3 OF ARIZONA ELECTRIC POWER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOW (Q.55X) SULFUR BITUMINOUS COAL WITH AN
AVERAGE HEATING VALUE OF 10,OCO BTU/LB PRODUCES A MAXIMUM FLUE GAS FLOW OF
735,OCO ACFM. THE FLUE GAS PASSES THROUGH A HOT SIDE ESP TO TWO RESEARCH
COTTRELL PACKED TOWERS, WHERE LIMESTONE IS USED TO REMOVE 85X (DESIGN) 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.P MW (GROSS)
119.0 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 10/73
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOSEPH CITY, ARIZONA AND
IS A TANGENTIALLY FIRED, WET BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF 0.5X 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 92X. 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 UNLINEO POND.
ARIZONA PUBLIC SERVICE
CHOLLA
2
NEW 264.0 MW (GROSS)
264.C MW (ESC)
COAL
.50 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 (0.5X 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, 1'978, IS 75*. THE CLEANED GAS
PASSES THROUGH AN IN-LINE STEAM REHEATER INTO AN ACID BRICK LINED STACK.
THE OPEN WATER LOOP SYSTEM DEPOSITS ITS SLUDGE INTO A FLt ASH POND.
-------
EPA UTILITY FGD SURVEY: APRIL ~ JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA PUBLIC SERVICE
CHOLLA
4
NEW 375.!? MW (GROSS)
126.T My (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION; *****
STATUS 2 STARTUP 6/81
CHOLLA 4 OF ARIZONA PUBLIC SERVICE IS PRESENTLY UNDER CONSTRUCTION IN
JOSEPH CITY, ARIZONA. START UP IS SCHEDULED FOR JUNE, 1980. THE PULVERIZED
COAL (0.5X S, 10,150 BTU/LB) FIRED BOILER WILL EXHAUST FLUE GAS THROUGH AN
ESP TO A PACKED TOWER WHICH WILL TREAT 36X OF THE GAS WITH LIMESTONE.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175.0 MW (GROSS)
175.C MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
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
S02 REMOVAL. INITIALLY, THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 8650 BTU/LB) UNITS 1 AND 2 SUPPLY 81*,COO ACFM EACH
INTO 2 CHEMICO VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICULATE CONTROL
AND APPROXIMATELY 3QX S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH
SCRUBBING IS 67.5X. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 175.0 MW (GROSS)
175.P MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LINE/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *****
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
S02 REMOVAL. INITIALLY, THE FRONT FIRED, DRV BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 8650 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 67.51. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
RETROFIT 229.9 MW (GROSS)
229.0 MW (ESC)
COAL
.75 XS SUBBITUMINOUS
LINE/ALKALINE FLTASH
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED ITHE OPERATIONAL PARTICULATE SCRUBBERS
AT FOUR CORNERS 1,2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
S02 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 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN SQ2 REMOVAL EFFICI-
ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 67.5*.
OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT 755.0 MW (GROSS)
755.0 MW (ESC)
COAL
.75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: *****
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 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 (0.75* S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED BV AN ESP. START UP IS EXPECTED IN
1982.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT 755.0 MW (GROSS)
755.0 MW (ESC)
COAL
.75 XS
LINE
UNITED ENGINEERS
ENERGY CONSUMPTION:
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO UNITED ENGINEERS FOR A LINE
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 BV THE UTILITY, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75* S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED BV AN ESP. START UP IS EXPECTED IN
1982.
STATUS 3
*****
STARTUP 0/82
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ASSOCIATED ELECTRIC COOP
THOMAS HILL
3
NEW 730.C MW (GROSS)
670.0 MW (ESC)
COAL
4.80 ZS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION:
STATUS 2
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A PULVERIZED COAL (4.8* S,
9,700 BTU/LB) FIRED UNIT LOCATED IN MOEERLY, MISSOURI. TWO COLD SIDE ESP'S
yiLL PRECEDE THE FOUR 91.5X EFFICIENT PULLMAN KELLOGG HORIZONTAL WEIR FGD
MODULES USING MAGNESIUM-PROMOTED LIMESTONE AS THE ABSORBENT. THE CLEANED
GAS WILL 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 WATER LOOP. THE FGD SYSTEM IS UNDER CONSTRUCTION AND START UP IS
EXPECTED IN JANUARY, 1982.
* ***X
STARTUP 1/82
3ASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
1
NEW 440.C MW (GROSS)
440.f MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: .01
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 (0.68X S, 6600 BTU/LB LIGNITE) AND SUPPLY ?,055,000 ACFH TO A DRY
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM WILL CONSIST OF 5 N1RO ATOM1ZCR 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 DRY
POWDER WILL BE USED FOR LANDFILL IN A COAL MINE. START UP IS EXPECTED
IN APRIL, 1983.
3ASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
2
NEW 440.f MW (GROSS)
440.0 MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION:
STATUS 5
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POWER COOP WILL BE LOCATED IN BEULAH,
NORTH DAKOTA. THE UTILITY IS PRESENTLY CONSIDERING VARIOUS F60 PROCESSES
FOR THIS LIGNITE (0.68* 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.
.ox
STARTUP 1C/85
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
1
NEW 570.P MW (GROSS)
570.0 MW (ESC)
COAL
.81 ZS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: .OX
STATUS 2 STARTUP 7/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLAND, WYOMING. THE PULVERIZED COAL (0.81Z S, 8139 BTU/LB)
FIRED BOILER WILL FEED 2,300,000 ACFM 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
DEMISTER 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 APRIL, 1980.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
NEW 57r.O MW (GROSS)
57CI.C1 MH (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-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
OEMISTER 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.
3ASIN ELECTRIC POWER COOP
LARAMIE RIVER
3
NEW 570.0 MW (GROSS)
570.0 MW (ESC)
COAL
.54 XS SUBBITUMINOUS
LIME/SPRAY DRYING
3ABCOCK 8 WILCOX
ENERGY CONSUMPTION: .CiX
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 (0.54X S,
8100 BTU/LB) AND WILL SUPPLY 2,800,01)0 ACFM OF FLUE GAS TO THE FGD
SYSTEM, WHICH WILL REMOVE 85X OF THE S02 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.
10
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
3IG RIVERS ELECTRIC
D. 6. WILSON
1
NEW 44T.P MW (GROSS)
440.0 MW (ESC>
COAL
***** XS BITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 11/84
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. UILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS WILL HAVE A MW RATING OF 440 EACH.
THE UNITS WILL UTILIZE EITHER A LIME, LIMESTONE OR DUAL ALKALI FGD SYSTEM.
START UP OF UNIT 1 IS EXPECTED IN 1984.
316 RIVERS ELECTRIC
D. B. UILSON
2
NEW 44".T MW (GROSS)
44P.P nu (ESC)
COAL
***** XS BITUMINOUS
LINE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/85
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.
THE UNITS WILL UTILIZE EITHER A LIME, LIMESTONE OR DUAL ALKALI FGD SYSTEM.
START UP OF UNIT 2 IS EXPECTED IN 1985.
316 RIVERS ELECTRIC
SREEN
1
NEW 242.C nu (GROSS)
242.C MW (ESC)
COAL
5.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 12/79
UNIT 1 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN
SEBREE,KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75* S, 9750 BTO/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 90* OF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A SAUERISEN 72 LINED STACK AFT£R 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
GREEN
2
NEW 242.P MW (GROSS)
242.0 MW (ESC)
COAL
3.75 XS BITUMINOUS
LINE
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRIC'S GREEN STATION IS BEING CONSTRUCTED IN
SEBREE, KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75* S, 9750 fiTU/LB)
FIRED BOILER WILL SUPPLY 1,000,000 ACFM TO A COLO SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL REMOVE 90* 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
3IG CAJUN 3
1
NEW 54".0 MW (GROSS)
540.P MW (ESC)
COAL
***** XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP C/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.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEW 416.C MW (GROSS)
416.0 MW (ESC)
COAL
3.30 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: 2.9*
STATUS 1 STARTUP 7/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT IS LOCATED IN CANTON, ILLINOIS. THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM UNIT BURNS PULVERIZED BITUMINOUS
COAL (3.3* S, 10,500 BTU/LB) AND SUPPLIES 2,415,000 ACFM OF FLUE GAS TO
TWO COLD SIDE ESP'S FOLLOWED BY FOUR RILEY STOKER/ENVIRONEER1NG ROD DECK
SPRAY TOWER MODULES. THE FGD SYSTEM HAS BEEN OPERATIONAL (ONE MODULE)
SINCE JULY, 1976, AND IS DESIGNED TO REMOVE 85* OF THE S02. HORIZONTAL
CHEVRON MIST ELIMINATORS FOLLOW THE ABSORBERS, AND THE CLEANED 6AS EXITS
TO A 500 FOOT CE1LCOTE LINED STACK WITHOUT REHEAT. THE SYSTEM OPERATES IN
A CLOSED WATER LOOP, AND THE SLUDGE IS DISPOSED OF IN AN ON SITE CLAY
LINED POND.
11
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
MEW 450.0 MW (GROSS)
450.0 MU (ESC)
COAL
3.30 IS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 1/86
CENTRAL ILLINOIS LIGHT IS CURRENTLY EVALUATING BIDS ON A LIMESTONE OR DUAL
ALKALI F6D SYSTEM FOR UNIT 2 OF ITS DUCK CREEK STATION. THE BITUMINOUS
COAL FIRED BOILER WILL FEED ITS FLUE GAS THROUGH A COLD SIDE ESP. THE
SYSTEM WILL OPERATE IN A CLOSED WATER LOOP AND IS SCHEDULED TO BEGIN
OPERATIONS IN JANUARY, 1986.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEW 617.0 KM (GROSS)
617.C MW (ESC)
COAL
2.25 XS BITUMINOUS
DUAL ALKALI
3UELL DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 9/79
NEWTON 1 OF CENTRAL ILLINOIS PUBLIC SERVICE IS A TANGENTIALLY FIRED, DRY
BOTTOM, PULVERIZED BITUMINOUS COAL N SEPTEMBER, 1980.
STATUS 2
2.9X
STARTUP 9/80
COLORADO UTE ELECTRIC ASSN.
CRAIG
1
NEW 447.P MU (GROSS)
447.0 MW (ESC)
COAL
.45 (S SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
STATUS 2 STARTUP 7/80
THE COLORADO UTE ELECTRIC ASSN IS PRESENTLY CONSTRUCTING CRAIG 1 IN CRAI6,
COLORADO. BOTH UNITS WILL FIRE PULVERIZED SUBBITUMINOUS COAL (0.4SX S.
10,000 BTU/LB). THE EMISSION CONTROL SYSTEM FOR THIS UNIT MILL 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 BE HEATED BY AN IN-LINE STEAM COIL R£HE*T£R AND KILL 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 MINEF1LL.
UNIT 1 START Up IS EXPECTED IN SEPTEMBER, 1980.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
NEW 447.0 MW (GROSS)
447.0 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
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, 1C.QCO BTU/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 853! OF THE S02. THE SCRUBBER EXHAUST IS HEATED BY AN IN-LINE
STEAM COIL REHEATER AND PASSES THROUGH A 600 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. STA.RT UP OF UNIT 2 WAS IN AUGUST, 1979.
COLORADO UTE ELECTRIC ASSN.
CRAIG
3
NEW 447.0 MW (GROSS)
447.C MU (ESC)
COAL
.45 XS SUBBITUMINOUS
LI«E/SPRAY DRYING
3ABCOCK K UILCOX
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 (0.453! S, 10,000 BTU/LB). A CONTRACT HAS
BEEN AWARDED 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.
CONESVILLE
5
MEW 411.0 MW (GROSS)
411.P MW (ESC)
COAL
4.67 XS BITUMINOUS
LIKE
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, 1C.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 89.5? (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-O-TEC STABILIZED SLUDGE is PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN WATER LOOP.
COLUMBUS I SOUTHERN OHIO ELEC.
CONESVILLE
6
MEW 411.0 MW (GROSS)
411.0 MW (ESC)
COAL
4.67 ZS BITUMINOUS
LINE
AIR 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 (4.673! 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 JUNE, 1978, IS 89.5X (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-O-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN WATER LOOP.
COLUMBUS g SOUTHERN OHIO ELEC.
POSTON
5
NEW 425.C MW (GROSS)
375.n MW
FIRED UNITS WILL UTILIZE EITHER A LINE, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 6 IS EXPECTED IN 1989.
13
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SECTION 2
STATUS OF FGD SYSTEMS
UMIT IDENTIFICATION
ABSTRACT
COMMONWEALTH EDISON
POWERTON
51
RETROFIT 450.0 My (GROSS)
45P.P My (ESC)
COAL
3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.6X
STATUS 1 STARTUP 4/80
COMMONyEALTH EDISON HAS RETROFITTED BOILER NUMBER 51 AT ITS POWERTON
STATION WITH A UOP LIMESTONE FGD SYSTEM. UNIT 51 IS ONE OF TyO IDENTICAL
BOILERS SUPPLYING STEAM TO AN 850 «W TURBINE. THE PULVERIZED COAL
(3.53X S, 10,500 BTU/LB) FIRED BOILER FEEDS FLUE GAS THROUGH AN ESP
TO 3 TCA MODULES WHICH,ARE DESIGNED (TO REMOVE 74X OF THE SOZ. A STEAM
INDIRECT HOT AIR REHEATER BOOSTS THE TEMPERATURE BEFORE THE GAS EXITS
AN ACID BRICK LINED STACK. THE SYSTEM OPERATES IN A CLOSED yATER LOOP,
AND THE SLUDGE IS P02-0-TEC STABILIZiD AND DISPOSED OF IN A LANDFILL.
THE FGD SYSTEM COMMENCED OPERATION IN APRIL, 1980.
COOPERATIVE POWER "SSOCIATION
COAL CREEK
1
NEW 545.C MW (GROSS)
327." MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 8/79
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 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CURRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 4QZ BYPASS REHEAT
WILL BE PROVIDED BEFORE TH£ CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
WILL OPERATE IN AN OPEN WATER LOOP. AND THE FLYASH STABILIZED SLUDGE WILL
BE DISPOSED IN A CLAY LINED POND. UNIT 1 OPERATIONS BEGAN IN AUGUST 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
MEW 545.0 MW (GROSS)
327.0 MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 7/80
COAL CHEEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63* 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. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40% BYPASS REHEAT
WILL BE PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
WILL OPERATE IN AN OPEN yATER LOOP, AND THE FLYASH STABILIZED SLUDGE WILL
BE DISPOSED OF IN A CLAY LINED POND. UNIT 2 IS PRESENTLY UNDER CONSTRUC-
TION AND SHOULD INITIALLY START OPERATIONS IN JULY, 1980.
DELMARVA POWER 8 LIGHT
DELAWARE CITY
1
RETROFIT 60.0 MW (GROSS)
60.0 MW (ESC)
COKE
7.00 XS FLUID PETROLEUM COKE
BELLMAN 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 5CQK
LB/Hft EACH. THE BOILERS GENERATE STCAM 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 VENiTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TVpE MIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST 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 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 POWER & LIGHT
DELAWARE CITY
2
RETROFIT 60.0 MW (GROSS)
60.0 MW (ESC)
COKE
7.CO »S FLUID PETROLEUM COKE
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: *****
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 STtAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. E'ACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENITURI 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 MIST REMOVAL. A FOUR STAGE
WELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 9CX 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 POWER & LIGHT
DELAWARE CITY
3
RETROFIT 60.0 MW (GROSS)
60.0 MW (ESC)
COKE
7.00 XS FLUID PETROLEUM COKE
WELLMAN LORD
DAVY MCKEE
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-sx S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF SOCK
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUF. GAS TO
A MECHANICAL COLLECTOR THEN TO A VENJTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMINATOR
TO A y£T ESP FOR BOTH PARTICULATE AND ACID MIST 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 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.
14
-------
EPA UTILITY FGD SURVET: APRIL - JUNE 1980
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
DELMARVA POWER g LIGHT
VIENNA
9
1EU 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 ?.7X AND IS EXPECTED TO
COMMENCE OPERATIONS IN JUNE 1987.
DESERET GEN g TRANS COOP
10ON LAKE
1
NEW 410.0 MU (GROSS)
410.P MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 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. THE UTILITY IS PRESENTLY REQUESTING BIDS FOR A WET LIME"
STONE SCRUBBING SYSTEM HAVING A S02 REMOVAL EFFICIENCY OF 95X. THE SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED TO REMOVE 99.65! OF THE PARTICULATE. TIME
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 g TRANS COOP
100N LAKE
2
NEU 410.0 MW (GROSS)
4in.O MW (ESC)
COAL
.50 ZS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 0/88
MOON LAKE 2 IS A PULVERIZED COAL (0.5Z S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION AND TRANSMISSION COOP TO BE LOCATED IN
VERNAL, UTAH. THE UTILITY IS PRESENTLY REQUESTING BIDS FOR A WET LIME-
STONE SCRUBBING SYSTEM HAVING A 502 REMOVAL EFFICIENCY OF 95*. THE SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED TO REMOVE 99.6* OF THE PARTICULATE. TlH E
UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON SITE
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1988.
DJQUESNE LIGHT
ELRAMA
1-4
RETROFIT 510.0 MW (GROSS)
510.0 MW (ESC)
COAL
2.20 ZS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 3.5Z
STATUS 1 STARTUP 10/75
ELRAMA 1-4 OF DUQUESNE LIGHT CONSISTS OF FOUR PULVERIZED COAL (2.2X S,
11,350 BTU/LB) FIRED UNITS LOCATED IN ELRAHA, PENNSYLVANIA. THE EMISSION
CONTROL SYSTEM ON THIS SITE CONSISTS OF AN ESP FOLLOWED BY A MECHANICAL
COLLECTOR AND FIVE VARIABLE THROAT VtNTURI LIME ABSORBER MODULES SUPPLIED
BY CHEMICO, WHICH ARE DESIGNED TO REMOVE 83* OF THE so2 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 LANDl-
FILL. THE SYSTEM HAS BEEN OPERATHONAL SINCE OCTOBER, 1975.
DUQUESNE LIGHT
PHILLIPS
1-6
RETROFIT 408.0 MW (GROSS)
408.0 MU (ESC)
COAL
1.92 ZS BITUMINOUS
LI (IE
CHEMICO DIVISION* ENVIROTECH
ENERGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 7/73
THE PHILLIPS POWER STATION OF DUQUESNE LIGHT CONSISTS OF SIX DRY BOTTOM
PULVERIZED COAL (1.92X 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 BY CHEMICO
ARE DESIGNED TO REMOVE 83Z OF THE S02 FROM THE FLU£ 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 JULY, 1973.
EAST KENTUCKY POWER COOP
J. K. SMITH
1
1EW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
***** ZS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 1/85
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TWO NEW UNITS. 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.
15
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
EAST KENTUCKY POWER COOP
t. K. SMITH
2
NEW 650.0 My (GROSS)
650.P MW (ESC)
COAL
***** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 1/87
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TWO NEW UNITS. THE J.K.
SMITH UNITS 1 AND 2 WILL UTILIZE EITHER A DRY PROCESS OR A «ET LIME
PROCESS FOR EMISSION CONTROL. UNIT 2 IS EXPECTED TO START UP IN JANUARY,
1987.
EAST KENTUCKY POWER COOP
SPURLOCK
2
MEW 500.0 MW (GROSS)
500.0 MW (ESC)
COAL
3.50 XS
LIKE
ADL/COMBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 1/81
SPURLOCK 2 OF EAST KENTUCKY POUER COOPERATIVE IS A BALANCED DRAFT PULVER-
IZED COAL (3.5* S, 11,000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN MAYS-
VILLE, KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOL-
LOWED BY AN AOL/COMBUSTION EOUIPMENT ASSOCIATES LIME FGD SYSTEM (90X
DESIGN so2 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 8 LIGHT
1ARTIN
3
NEW 800.C MW (GROSS)
800.0 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 7 STARTUP 0/87
FLORIDA POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA. iTHE PULVERIZED COAL FIRED BOILERS
WILL HAVE A MW RATING OF 800 EACH. THE UTILITY IS CONSIDERING FGD AND
ALTERNATIVE METHODS FOR EMISSION CONTROL. THE START UP FOR UNIT 3 IS
PROJECTED FOR 1987.
FLORIDA POWER K LIGHT
1ARTIN
4
NEW 800.P MW (GROSS)
800.0 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 7 STARTUP P/89
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 FGD AND
ALTERNATIVE METHODS FOR EMISSION CONTROL. THE START UP FOR UNIT 4 IS
PROJECTED FOR 1989.
BENERAL PUBLIC UTILITIES
COAL
1
MEW 625.0 MW (GROSS)
625.0 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
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 (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1992.
SENERAL PUBLIC UTILITIES
COAL
2
MEW 625.0 MW (GROSS)
625.0 MW (ESC)
COAL
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 (3.5Z S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1994.
16
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SENERAL PUBLIC UTILITIES
COAL
3
NEW 625.T MW (GROSS)
62S.C MW (ESC)
COAL
3.5C XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 12/95
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 «U UNITi 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
CDAL
t
MEW 625.0 My (GROSS)
625.0 nu (ESC)
COAL
3.50 IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 5/97
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MU 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 69C.C nw (GROSS)
690.0 MU (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.4Z
STATUS 5 STARTUP 5/91
COHO 1 IS A 3.5Z S COAL FIRED UNIT PLANNED BY GENERAL PUBLIC UTILITIES TO
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 HAY, 1991.
SENERAL PUBLIC UTILITIES
SEUARD
7
NEW 690.0 MU (GROSS)
690.0 MU (ESC)
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
SEWARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY REQUESTING BIDS FOR AN FGD
SYSTEM, WITH NON-SLURRY TYPE LIME AND LIMESTONE SYSTEMS BEING THE
PRIMARY CONSIDERATION. START UP IS EXPECTED IN MAY, 1987.
SRAND HAVEN BRD OF LIGHT I
1. B. SIMS
3
65.P MU (GROSS)
65.P MU (ESC)
BITUMINOUS
NEW
COAL
2.75 XS
LIME
3ABCOCK S UILCOX
ENERGY CONSUMPTION: ****Z
STATUS 3 STARTUP 6/83
PUR THE GRAND HAVEN BOARD OF LIGHT AND POWER'S J.B. SIMS 3 IS A PLANNED
BITUMINOUS COAL (2.75X S, 11,COO BTU/LB) FIRED UNIT TO BE LOCATED IN
GRAND HAVEN, MICHIGAN. A CONTRACT HAS BEEN AWARDED TO BABCOCK AND UILCOX
TO SUPPLY TUO 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.
HOOSIER ENERGY
IE ROM
1
NEW 490.0 MU (GROSS)
441.0 MU (ESC)
COAL
3.5C XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 5/82
HERON 1 AND 2 ARE TUO NEW UNITS BEING BUILT BY HOOSIER ENERGY IN SULLIVAN,
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS UILL PRODUCE 1,732.000
ACFM OF FLUE GAS UHICH UILL BE CLEANCD 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 UILL
BE STABILIZED AND LANDFILLEDt AND THE SYSTEM UILL OPERATE IN A CLOSED
UATER LOOP MODE. START UP OF UNIT 1 IS SCHEDULED FOR MAY, 1982.
17
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
HOOSIER ENERGY
HEROM
2
MEW 490.P MW (GROSS)
441.0 MW (ESC)
COAL
3.50 XS
LIMESTONE
1ITSUB1SHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 7/81
MEROM 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 LANDFILLtD, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 2 IS SCHEDULED FOR JULY, 1981.
HOUSTON LIGHTING 8 POWER
LIMESTONE
1
MEW 75*.0 MW (GROSS)
75C.C MW (ESC)
COAL
1.08 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 2/85
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, TO BE LOCATED IN JEWITT, TEXAS. THE PULVERIZED COAL (1.C8X S,
6177 BTU/LB) FIRED BOILER WILL 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 1 IS SCHEDULED TO COMMENCE OPERATIONS IN 1985.
HOUSTON LIGHTING S POWER
LIMESTONE
2
MEW 75ri.P MW (GROSS)
75".P MW (ESC)
COAL
1.08 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 2/86
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.C8X S,
6177 BTU/LB) FIRED BOILER WILL 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 1986.
HOUSTON LIGHTING & POWER
tf.A. PARISH
3
MEW 600.P MW (GROSS)
492.0 MW (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
EMERGY CONSUMPTION: ****X
STATUS 2 STARTUP 11/82
W.A. PARISH 8 OF HOUSTON LIGHTING 8 POWER IS A PULVERIZED COAL (Q.6X S,
8700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN THOMPSONS, TEXAS. CHEMICO
WILL SUPPLY A LIMESTONE FGD SYSTEM WHICH WILL REMOVE 82* OF THE FLUE
GAS S02. REHEAT WILL BE PROVIDED BY BYPASSING 18X OF THE PARTICULATE
CLEANED FLUE GAS. SLUDGE WILL BE DEWATERED, BLENDED WITH FLYASH, AND
DISPOSED IN AN ON SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE
IN NOVEMBER, 1982.
INDIANAPOLIS POWER 8 LIGHT
PATRIOT
1
MEW 650.0 MH (GROSS)
650.0 MW (ESC)
COAL
3.50 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 8 LIGHT
PATRIOT
2
MEW 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
3.5C XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/87
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITSt PATRIOT 1, 2t
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
18
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
INDIANAPOLIS POWER g LIGHT
PATRIOT
J
NEU 650.0 MW (GROSS)
650.0 MW (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/87
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITSf PATRIOT 1, Z,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POWER g LIGHT
PETERSBURG
3
NEU 532.n KW (GROSS)
532.C MW (ESC)
COAL
3.25 XS BITUMINOUS
LIMESTONE
KIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4Z
STATUS 1 STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER AND LIGHT IS LOCATED IN PETERSBURG,
INDIANA, AND BURNS 3.25* S BITUMINOUS COAL (11,"00 BTU/LB). TWO COLD SIDE
ESP'S ARE LOCATED UPSTREAM OF 4 851 EFFICIENT UOP LIMESTONE TCA MODULES.
A HORIZONTAL MIST ELIMINATOR PRECEDES AN INDIRECT HOT AIR REHEATER THAT
BOOSTS THE GAS TEMPERATURE BY 30 DEG F BEFORE IT EXITS THE 616 FOOT RIGI-
FLAKE 485T 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 g LIGHT
PETERSBURG
t
NEW 530.0 MW (GROSS)
53C.O MW (ESC)
COAL
3.5P IS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 2 . 1*
STATUS 2 STARTUP 1^/84
PETERSBURG 4 OF INDIANAPOLIS POWER AND LIGHT IS A BITUMINOUS COAL (3.SOX S
11,COO BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN PETERSBURG, INDIANA. THE
LIMESTONE FGD SYSTEM FOR THIS UNIT WILL BE SUPPLIED BY RESEARCH COTTRELL.
THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP, AND SLUDGE WILL BE P07-0-
TEC STABILIZED BEFORE PONDING. START UP IS SLATED FOR OCTOBER OF 1984.
IOWA ELECTRIC LIGHT g PWR
SUTHRIE CO.
1
NEW 720.f1 MW (GROSS)
729.0 MW (ESC)
COAL
.40 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 1"/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-
MINOUS COAL (0.4* 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, 198? AND HAS PROJECTED THE STARTUP TO BE
IN OCTOBER, 1984.
JACKSONVILLE ELECT. AUTHORITY
NEW PROJECT
1
NEW 60C.O MW (GROSS)
600.0 MW (ESC)
COAL
3.00 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/85
THE JACKSONVILLE ELECTRIC AUTHORITY HAS PLANS FOR TWO NEW 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
WET 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 1985.
JACKSONVILLE ELECT. AUTHORITY
NEW PROJECT
2
YEW 60r.C MW (GROSS)
600.C MW (ESC)
COAL
3.00 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP fl/87
THE JACKSONVILLE ELECTRIC AUTHORITY HAS PLANS FOR TWO NEW 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
WET LIMESTONE FGD PROCESS AND AN ESP FOR EMISSION CONTROL. THE CLEANED
FLUE GAS IS TO EXIT A 285 FOOT STACK. UNIT 2 IS SCHEDULED TO COMMENCE
OPERATIONS IN 1987.
19
-------
£PA UTILITY F6D SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS CITY POWER 8 LIGHT
HAWTHORN
3
RETROFIT 90.r MW (GROSS)
9P.P MW (ESC)
COAL
.60 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2X
STATUS 1 STARTUP 11/72
HAWTHORN 3 OF KANSAS CITY POWER AND LIGHT IS A DRY BOTTOM PULVERIZED
BITUMINOUS COAL (G.6X S, 9800 BTU/LB) FIRED UNIT LOCATED IN KANSAS CITY,
MISSOURI, WHICH WAS CONVERTED FROM LIMESTONE FURNACE INJECTION AND TAIL
END SCRUBBING TO A LIME SLURRY SYSTEM. TWO COMBUSTION ENGINEERING MARBLE
BED ABSORBERS, WHICH WERE DESIGNED TO REMOVE 70X OF THE FLUE GAS S02,
BEGAN OPERATION IN JANUARY, 1977. ONE HORIZONTAL CHEVRON MIST ELIMINATOR
PER MODULE IS UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER, WHICH RAISES
THE TEMPERATURE OF THE CLEANED GAS BEFORE IT EXITS THROUGH A GUNITE LINED
200 FOOT STACK. THE FLYASH STABILIZED SLUDGE IS DEPOSITED IN AN UNLINEO
SLUDGE POND. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
KANSAS CITY POWER 8 LIGHT
HAWTHORN
I
RETROFIT 90.0 MW (GROSS)
90.C MW (ESC)
COAL
.6? XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.21
STATUS 1 STARTUP 8/72
HAWTHORN 4 OF KANSAS CITY POWER AND LIGHT IS A DRY BOTTOM PULVERIZED
BITUMINOUS COAL (0.65; S, 9800 BTU/LB) FIRED UNIT LOCATED IN KANSAS CITY,
MISSOURI, WHICH WAS CONVERTED FROM LIMESTONE FURNACE INJECTION AND TAIL
END SCRUBBING TO A LIME SLURRY SYSTEM. TWO COMBUSTION ENGINEERING MARBLE
BED ABSORBERS, WHICH WERE DESIGNED TO REMOVE 7t'X OF THE FLUE GAS S02,
BEGAN OPERATION IN JANUARY, 1977. ONE HORIZONTAL CHEVRON MIST ELIMINATOR
PER MODULE IS UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER, WHICH RAISES
THE TEMPERATURE OF THE CLEANED GAS BEFORE IT EXITS THROUGH A GUNITE LINED
2DO FOOT STACK. THE FLYASH STABILIZED SLUDGE IS DEPOSITED IN AN UNLINED
SLUDGE POND. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
KANSAS CITY POWER 8 LIGHT
LA CYGNE
1
NEW 874.0 MW (GROSS)
874.0 MW (ESC)
COAL
5.39 XS SUBBITUMINOUS
LIMESTONE
3ABCOCK 8 WILCOX
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 2/73
LA CYGNE 1 IS A WET BOTTOM, CYCLONE FIRED PULVERIZED SUBBITUMINOUS COAL
(5.39X S, 9421 BTU/LB) FIRED UNIT OF KANSAS CITY POWER AND LIGHT, LOCATED
IN LA CYGNE, KANSAS. THE EMISSION CONTROL SYSTEM CONSISTS OF EIGHT VARIA-
BLE THROAT VENTURI/LIMESTONE SIEVE TRAY TOWER TRAINS SUPPLIED BY BABCOCK
AND WILCOX. EACH 8OX (S02 REMOVAL, DESIGN) EFFICIENT TRAIN IS FOLLOWED BY
A COMBINATION SIEVE TRAY AND CHEVRON MIST ELIMINATOR, FOLLOWED BY AN INDI-
RECT REHEATER. THE CLEANED GAS EXITS THROUGH A 700 FOOT STEEL LINED STACK.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP, AND THE SCRUBBER SLUDGE IS
DISPOSED IN AN UNLINED POND. INITIAL OPERATIONS OF THE FGD SYSTEM BEGAN IN
FEBRUARY, 1973.
KANSAS POWER K LIGHT
JEFFREY
1
MEW 720.T MW (GROSS)
540.C MW (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 8/78
KANSAS CITY POWER AND LIGHT'S JEFFREY 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (0.32X S, 8125 BTU/LB) UNIT IN WAKEGO, 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 50X (INCLUDING A 3OX BYPASS REHEAT).
THE UNIT HAS BEEN OPERATIONAL SINCE AUGUST, 1978.
KANSAS POWER g LIGHT
JEFFREY
2
"HEW 70C*.£ MW (GROSS)
490.r MW (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
600 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 JANUARY, 1980.
KANSAS POWER & LIGHT
LAURENCE
4
RETROFIT 125.0 MW (GROSS)
125.P MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 1/76
LAWRENCE 4 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMBUSTION 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 B» TWO CHEVRONS AND ONE BULK
ENTRA1NMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEC F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT SITACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
20
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
KANSAS POWER & LIGHT
LAURENCE
5
RETROFIT 420.0 MW (GROSS)
420." MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 11/71
LAWRENCE 5 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.557! S, 10,000 BTU/LBl UNIT LOCATED IN LAWRENCE, 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, WITH A DESIGN S02 REMOVAL OF
73*. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 DEG T BEFORE
IT IS EXHAUSTED THROUGH A 12C FOOT SITACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOW* INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (0.79* 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 g PWR
INTERMOUNTAIN
2
MEW 820.0 MW (GROSS)
82^.0 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 9/87
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAVE 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 ({J.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 75C FOOT STACK. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS
I|N 1987.
21
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UMIT IDENTIFICATION
ABSTRACT
LOS ANGELES DEPT OF WTR g PyR
INTERMOUNTAIN
J
NEW 820.P MW
820.D MW (ESC)
CDAL
.79 XS SUBBITUMINOUS
LINE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP ?/88
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAVE PLANS FOR FOUR NEW
BOILERS, INTERMOUNTA1N 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (U.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 3 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1988.
LOS ANGELES DEPT OF UTR 8 PWR
INTERMOUNTAIN
4
1EW 820.0 MW (GROSS)
820.0 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/89
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAVE PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS & ELECTRIC
1ILL CREEK
2
RETROFIT 350.0 MW (GROSS)
350.0 MW (ESC)
COAL
J.75 XS
LINE
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 LI ME/LIMESTONE FGD SYSTEM IS PRESENTLY UNDER CONSTRUC-
TION ON THIS PULVERIZED COAL (3.75* 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 OF 1982.
LOUISVILLE GAS & ELECTRIC
1ILL CREEK
3
NEW 442.0 MW (GROSS)
442.0 MW (ESC)
COAL
3.75 IS BITUMINOUS
LINE
MERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 8/78
LOUISVILLE GAS AND ELECTRU'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
1ILL CREEK
t
YEW 53£.9 MU (GROSS)
495.1 MW (ESC)
COAL
3.75 XS
LINE
MERICAN AIR FILTER
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 7/81
MILL CREEK 4 OF LOUISVILLE GAS ANt> 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 FLYASH. STEAM TUBES WILL
PROVIDE REHEAT OF THE CLEANED GASES. THE SYSTEM IS SCHEDULED TO START
UP IN JULY OF 1981.
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
HETROFIT 72.o MW (GROSS)
72.? MW (ESC)
COAL
2.50 XS BITUMINOUS
HUE
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 FGD 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 WATER LOOP IS CLOSED. THE FGD SYSTEM
BEGAN INITIAL OPERATIONS IN APRIL, 1973.
LOUISVILLE GAS 8 ELECTRIC
TRIMBLE COUNTY
1
YEW 575.0 MW (GROSS)
575.0 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 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 (90X REMOVAL!
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START UP IN JULY OF 1984.
LOUISVILLE GAS & 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 6 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 BE CLEANED BY ESP'S AND WET SCRUBBING (90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS SCHEDULED
FOR START UP IN 1986.
23
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
HARQUETTE BOARD OF LIGHT & PWR SH1RAS 3 OF THE MARQUETTE BOARD OF LIGHT AND POWER IS A PULVERIZED COAL
SHIRAS
3
NEW 44.0 MW (GROSS)
44.f MW (ESC)
COAL
***** TS
LI1E/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP m/82
FIRED BOILER PLANNED FOR LOCATION IN MARQUETTEi 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.
1ICHISAN S. CENTRAL PWR AGENCY THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POWER AGENCY IS TO BE CON-
PROJECT
1
NEW 55.0 MW (GROSS)
55.0 I"IW (ESC)
COAL
2.25 XS
LIMESTONE
3ABCOCK 8 WILCOX
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 4/82
STRUCTED IN LITCHFIELD, MICHIGAN, AND WILL UTILIZE A WET 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 APRIL, 1982.
1IDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
5
YEW 89?.0 MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 4 STARTUP 1/86
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 1986.
1IDOLE SOUTH UTILITIES
ARKANSAS LIGNITE
6
NEW 89*5.0 MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 1/88
UNIT 2 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.5X 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 1988.
HIDOLE SOUTH UTILITIES
JNASSIGNED
1
NEW 890.0 MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 4 STARTUP 0/85
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME AND LOCATION ARE NOT YET ASSIGNED. THE EXACT START UP DATE
HAS NOT BEEN DETERMINED-.
1IDDLE SOUTH UTILITIES
JNASSIGNED
2
NEW 890.H MW (GROSS)
890.0 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 4 STARTUP 0/87
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT KITH COMBUSTION
ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME AND LOCATION HAVE NOT YET BEEN ASSIGNED. THE EXACT START UP
DATE HAS NOT BEEN DETERMINED.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
IDDLE SOUTH UTILITIES
JILTON
1
*tU 890.C MW (GROSS)
890.0 MW
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
IONIAN* POUER
CDLSTRIP
1
MEW 36n.O MW (GROSS)
360.0 WW
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEBRASKA PUBLIC POWER DISTRICT FOSSIL III 1 IS A PULVERIZED SUBBITUMINOUS COAL <0.36X S, 8500 BTU/LB)
FOSSIL III
1
NEW 650.? MW (GROSS!
65^.f WW tESC>
COAL
.36 XS SUB81TUMINOUS
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 «W BOILER. STARTUP FOR
THE UNIT IS SCHEDULED FOR 1987.
NEVADA POWER
HARRY ALLEN
1
NEU 500.C MW
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198?
SECTION 2
STATUS OF FGD SYSTEMS
UMIT IDENTIFICATION
ABSTRACT
NEVADA POWER
REID GARDNER
2
RETROFIT 125.0 *W (GROSS)
125.0 MW «ESC)
COAL
.50 XS BITUMINOUS
SDDIUN CARBONATE
ADL/COHBUSTION EQUIP ASSOCIATE
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 4/74
REID GARDNER 2 is A WET BOTTOM LOU SULFUR COAL (0.5* s, 12,450 BTU/LBJ
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY AOL/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 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 PONO. THE
DESIGN SO? REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE APRIL, 1974.
MEVADA POWER
REID GARDNER
3
MEW 125.^ MW FIRED UNIT TO
BE LOCATED IN ST. GEORGE, UTAH. THE UTILITY IS CURRENTLY EVALUATING BIDS
FOR AN FGD SYSTEM. NO ANNOUNCEMENTS HAVE YET BEEN MADE CONCERNING THE
EMISSION CONTROL STRATEGY FOR THIS UNIT. START UP IS EXPECTED IN JUNE OF
1985.
MEVADA POWER
WARNER VALLEY
2
MEW 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
NEVADA POWER'S WARNER VALLEY 2 IS A PLANNED COAL (1.151 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 OF
1986.
MEW YORK STATE ELEC 8 GAS
SOMERSET
1
MEW 870.0 MW (GROSS)
870.0 MW (ESC)
COAL
2.20 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 6/84
THE SOMERSET 1 UNIT OF THE NEW YORK STATE ELECTRIC 8 GAS CORP. IS A
PULVERIZED COAL BOILER LOCATED IN SOMERSET, NEW YORK. THE BOILER
GENERATES A FLUE GAS FLOW OF 3,100,000 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 99.77Z 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 LANOFILLED.
28
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY
5S
RETROFIT 10P.P MW (GROSS)
100.P MW (ESC)
COAL
1.80 XS
*fiUEOUS CARBONATE/SPRAY DRYING
RKKUELL INTERNATIONAL
ENERGY CONSUMPTION: *****
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 HAS
AWARDED TO ATOMICS INTERNATIONAL FOR THE DESIGN AND INSTALLATION OF A 90*
EFFICIENT RETROFIT A6UEOUS CARBONATE FGD SYSTEM WHICH WILL PRODUCE ELEMEN-
TAL SULFUR AS AN END PRODUCT. FUNDS ARE BEIN6 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 CYCLONES 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.
V3RTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
RETROFIT 115.0 MW (GROSS)
115.0 MW (ESC)
COAL
3.5P XS
JELLMAN LORD
D»VY MCKEE
ENERGY CONSUMPTION: 27.SX
STATUS 1 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 WELLMAN
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 5C DEC F BEFORE THE GAS
IS DISCHARGED THROUGH A 168 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.
SOUTHERN INDIANA PUB SERVICE
SCHAHFER
17
YEW 421.P MW (GROSS)
421.0 MW (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
F*C
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/83
SCHAHFER T7 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN WHEATFIELD, 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 REHF.AT&R. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE OF 1983.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
13
NEW 421.P MW (GROSS)
421.0 MW (ESC)
COAL
3.2C XS BITUMINOUS
DUAL ALKALI
F^C
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/85
SCHAHFER 18 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN WHEA.TFIELD, 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 REHEATE.R. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE OF 1985.
NORTHERN STATES POWER
RIVERSIDE
i,7
RETROFIT 1J0.9 MW (GROSS)
719." BH
COAL
1.20 XS SUBBITUMINOUS
LINE/SPRAY DRYIW6
JOY MFG/NI8-9 ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 8/80
RIVERSIDE 6 AND 7 ARE TWO COAL FIRED BOILERS OWNED BY NORTHERN STATES
POWER AND LOCATED IN MINNEAPOLIS, MINNESOTA. EACH BOILER GENERATES A f'LUE
GAS FLOW OF 340,000 ACFM AT 350 F. CURRENTLY, A DEMONSTRATION LIME/SPRAY
DRYING FGD SYSTEM IS UNDER CONSTRUCTION THAT WILL BE CAPABLE OF TREATING
THE FLUE GAS FROM BOTH BOILERS. THE SYSTEM IS BEING SUPPLIED BY
NIRO ATOMIZER/JOY MANUFACTURING AND WILL CONSIST OF A SPRAY DRYER FOLLOWED
BY A BAGHOUSE. THE CLEAN FLUE GAS WILL BE VENTED TO TWO 275 FT CONCRETE
STACKS WITH FIRE BRICK LINERS. SPENiT ABSORBENT WILL BE DISPOSED OF IN ON
AND OFF SITE LANDFILLS. OPERATIONS ARE EXPECTED TO BEGIN IN AUGUST, 1980.
NORTHERN STATES POWER
SHERBURNE
1
NEW 740.0 MW (GROSS)
74T.C MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 3/76
NORTHERN STATES POWER'S SHERBURNE 1 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMINOUS COAL (n.BOX S, 8500 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH OF
1976. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON HlST ELIMINATORS/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT CORTEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
29
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198n
SECTION Z
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
NORTHERN STATES POWER
SHERBURNE
2
NEW 740.H MW (GROSS)
74".? MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7Z
STATUS 1 STARTUP 4177
NORTHERN STATES POWER'S SHERBURNE 2 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMINOUS COAL (C.80X S, 8503 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
5CX EFFICIENT (DESIGN) LIME STONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE APRIL OF
1977. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MlST ELIMINATORS/TRA IN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COHTEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
NDRTHERN STATES POWER
SHERBURNE
3
NEW 86".C MW (GROSS)
860.0 MW (ESC)
COAL
.85 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 5/85
NORTHERN STATES POWER'S SHERBURNE 3 IS A PLANNED TANGENTIAL FIRED PUL-
VERIZED SUBBITUKINOUS COAL (0.8DX S, 850C BTU/LB) FIRED UNIT TO BE CON-
STRUCTED IN BECKER, MINNESOTA. DUE TO THE LATEST TECHNOLOGY THAT HAS BEEN
DEVELOPED BIDS HAVE AGAIN BEEN OPENED. THE UTILITY IS PRESENTLY EVALUAT-
ING THREE DIFFERENT TYPES OF FGD SYSTEMS. MAY, 1985 is EXPECTED START UP.
PACIFIC GAS S ELECTRIC
13NTEZUMA
1
NEW aon.c MW (GROSS)
800.P MW (ESC)
C3AL
.8T XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.5X
STATUS 6 STARTUP 6/89
MONTEZUMA 1 OF PACIFIC GAS AND ELECTRIC IS A COAL (0.8X S, 12tOOO BTU/LB)
FIRED BOILER PLANNED FOR COLLINSVILL£, CALIFORNIA. THE EMISSION CONTROL
SYSTEM HILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START UP DATE IS JUNE, 1989.
PACIFIC GAS 8 ELECTRIC
13NTEZUMA
2
NEW 801.0 Fly (GROSS)
800.0 MW (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.5X
STATUS 6 STARTUP 6/90
MONTEZUMA 2 OF PACIFIC GAS AND ELECTRIC IS A COAL <0.8X S, 12,000 BTU/LB)
FIRED BOILER PLANNED FOR COLLINSVILLE, CALIFORNIA. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START UP DATE IS JUNE, 1990.
PACIFIC POWER 8 LIGHT
JI1 BRIDGER
4
NEW 550.T MW (GROSS)
55?." MW (ESC)
CDAL
.56 XS SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: .2X
STATUS 1 STARTUP 9/79
PACIFIC POWER AND LIGHT'S JIM BRIDGER 4 IS A DRY BOTTOM PULVERIZED
SUBBITUMINOUS COAL (0.56X S, 93CO 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 COLD
SIDE ESP TREATS 2,720,UOC 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 OF 1979, AND OPERATIONS BEGAN
IN SEPTEMBER, 1979.
PENNSYLVANIA POWER
9RUCE MANSFIELD
1
NEW 917.F MW (GROSS)
917.1 I»W (ESC)
COAL
3.00 XS BITUMINOUS
LI1E
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.CX S, 11,500 BTU/LB) IN SHIPPINGPORT,
PENNSYLVANIA. A CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.U) 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 FLAKEGLASS 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.
30
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PENNSYLVANIA POWER
BRUCE MANSFIELD
I
NEW 917." |»W (GROSS)
917. rt DIM <£SC)
COAL
3.00 IS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 6.JX
STATUS 1 STARTUP ?/77
BRUCE MANSFIELD 2 OF PENNSYLVANIA POyER 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 HAS DESIGNED TO REMOVE
FLYASH AND S02 (92.1*) 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 FLAKEGLASS 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.
PENNSYLVANIA POWER
3RUCE MANSFIELD
3
NEW 917." "IW (GROSS)
917.^ «IUI (ESC)
COAL
3.00 *S
LINE
PULLMAN KELLOGG
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 1~'/80
BRUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED
COAL (3.0? S, 11,500 BTU/LB) FIRED BOILER LOCATED IN SHIPPINGPORT,
PENNSYLVANIA. FOUR ESP'S TREAT 3,308i,000 ACFM OF FLUE GAS, FOLLOWED
BY FIVE (ONE SPARE) PULLMAN KELLOGG THIOSORBIC LIME ABSORBERS WHICH
REMOVE 92.2X OF THE S02. THE CLEANED GAS PASSES THROUGH
CHEVRON MIST ELIMINATORS AND DIRECT fOMBUSTION REHEATERS BEFORE
DISCHARGE THROUGH A 600 FOOT INCONEL 625 LINED STACK. THE FLYASH STA-
BILIZED SLUDGE IS PIPED TO THE EXISTING OFF SITE LANDFILL PRESENTLY
USED BY UNITS ONE AND TWO. OPERATIONS COMMENCED IN JUNE, 1980.
PHILADELPHIA ELECTRIC
CROMBY
1
RETROFIT
15'
15'
MW (GROSS)
MW (ESC)
PHILADELPHIA ELECTRIC HAS PLANS FOR THE RETROFIT OF AN FGD SYSTEM ON ONE
OF THE TWO 3.?* SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHOENIX-
VILLE, PENNSYLVANIA. A CONTRACT HAS BEEN AWA9DED TO UNITED ENGINEERS
FOR A MAGNESIUM OXIDE SYSTEM. THE SlTART UP DATE IS SET FOR 1982.
COAL
3.0" *S
1A6NESIU* OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 5/83
PHILADELPHIA ELECTRIC
EDDYSTONE
1
RETROFIT 24?.c «w (GROSS)
240.r MW (ESC)
COAL
2.60 *S
1AGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 12/82
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDDYSTONE, PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.6* S, 13,600 BTU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PARTICLE SCRUBBERS (TWO ROD DECK SPRAY
TOWERS AND ONE VENTURI) FOR PRIMARY PARTICLE CONTROL. THE UNIT 1 FGO
SYSTEM WILL FOLLOW THE TWO ROD DECK &PRAY TOWERS. UNITED ENGINEERS
IS SUPPLYING A MAGNESIUM OXIDE FGD SYSTEM FOR S02 EMISSION CONTROL
SIMILAR TO THE MAGNESIUM OXIDE PROTOTYPE SYSTEM THAT WAS PREVIOUSLY
OPERATED AT THIS UNIT. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1982.
PHILADELPHIA ELECTRIC
EDDYSTONE
2
RETROFIT 334.0 MW (GROSS)
334.? MW (ESC)
COAL
2.50 *S
1AGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 12/82
EDDYSTONE 2 OF PHILADELPHIA ELECTRIC IS A 2.5X SULFUR COAL FIRED BOILER
LOCATED IN EDDYSTONE, PENNSYLVANIA. THE PLANT'S GENERATING
CAPACITY IS 334 MW. UNITED ENGINEERS WILL SUPPLY A MAGNESIUM OXIDE
FGD SYSTEM FOR EMISSION CONTROL. START UP IS SET FOR DECEMBER, 1982.
PLAINS ELECTRIC GST COOP
PLAINS ESCALANTE
1
NEW 233.0 MW (GROSS)
233.0 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 12/83
PLAINS ESCALANTE 1 IS A PULVERIZED SUBBITUMINOUS COAL FIRED UNIT PLANNED
BY PLAINS ELECTRIC GST COOPERATIVE TO BE LOCATED IN PREWITT, NEW MEXICO.
THE 233 MW UNIT WILL UTILIZE A WET LIMESTONE SCRUBBING PROCESS FOR S02
REMOVAL AND A FABRIC FILTER FOR PRIMARY PARTICLE CONTROL. A CONTRACT
HAS BEEN AWARDED TO COMBUSTION ENGINEERING FOR THE WET LIMESTONE SYSTEM.
THE UNIT INITIAL STARTUP IS PROJECTED FOR DECEMBER 1983.
31
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198!)
SECTION 2
STATUS OF FGD SYSTEMS
U>UT IDENTIFICATION
ABSTRACT
PLATTE RIVER POWER AUTHORITY
3AWHIDE
1
JEW 279." nw (GROSS)
279.0 My (ESC)
COAL
.25 ZS BITUMINOUS
LIME/SPRAY DRYING
J3Y HFG/NIRO ATO"U7ER
ENERGY CONSUMPTION: .0*
STATUS 3 STARTUP 12/83
THE PLATTE RIVE" POWER AUTHORITY HAS PLANS TO CONSTRUCT RAWHIDE 1, IN
FT. COLLINS, COLORADO. THE 279 MW PULVERIZED COAL (0.25X S, 8702 BTU/LB)
FIRED BOILER WILL BE SUPPLIED BY COMBUSTION ENGINEERING. A CONTRACT HAS
BEEN AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A DRY LIME
SCRUBBING SYSTEM FOR EMISSION CONTROL. THE UTILITY IS CONSIDERING
IRRIGATION DITCHES FOR LIQUID WASTE DISPOSAL. THE UNIT IS SCHEDULED TO
GO ON LINE IN DECEMBER, 1983.
PUBLIC SERVICE INDIANA
3IBSON
5
MEW 650.0 MW (GROSS)
65".^ MW (ESC)
COAL
3.3H IS
LIMESTONE
"ULLMAN KELLOGG
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP f/82
GIBSON 5 OF PUBLIC SERVICE OF INDIANA IS A 3.3% SULFUR COAL FIRED UNIT
PLANNED FOR LOCATION IN PRINCETON, INDIANA. A CONTRACT WAS AWARDED TO
PULLMAN KELLOGG FOR A LIMESTONE FGD SYSTEM CONSISTING OF FOUR KELLOGG-
WEIR ABSORBER-REACTOR MODULES. SYSTEM START UP IS EXPECTED IN 1982. THE
SYSTEM WILL USE KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED LIMESTONE.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
RETROFIT 361.0 MW (GROSS)
361.n My (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.4X
STATUS 1 STARTUP 4/78
SAN JUAN 1 OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL <0.8* S, 8100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1.319.0CC ACFM OF
FLUE GAS TO A RETROFIT UELLMAN LORD FGD SYSTEM BY DAVY POUERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINtE APRIL OF 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE> VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85* 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.
"UBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
RETROFIT 350.0 MW (GROSS)
350.0 MW (ESC)
COAL
.80 IS SUBBITUMINOUS
rfELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 8/78
SAN JUAN 2 OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS ,A
COAL (0.81 S, 81&G BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT WELLMAN LORD FGD SYSTEM BY DAVY POWERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST OF 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.
PJBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
VEW 534. C MW (GROSS)
534.? MW (ESC)
COAL
.80 XS SUBBITUMINOUS
4ELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS 1 STARTUP 12/79
SAN JUAN 3 IS A COAL (C.8X S, 8100 BTU/LB) 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 WELLMAN
LORD SO? RECOVERY PROCESS. AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR
PROCESS. FIVE (ONE SPARE) VENTURI SCRUBSER/SPRAY TOWER ABSORBER (902 DE-
SIGN S02 REMOVAL) TRAINS FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AIR
REHEATER BOOSTS THE GAS TEMPERATURE SO DEG F. THE SYSTEM OPERATES
IN A CLOSED WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER, 1979.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
MEM 534.0 MW (GROSS)
534.0 MW (ESC)
COAL
.80 IS SUBBITUMINOUS
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 FGD
SYSTEM BEING SUPPLIED BY DAVY POUERGAS IS AN INTEGRATION OF THE WELLMAN
LORD S02 RECOVERY PROCESS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR
PROCESS. FIVE (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSORBER (90S DE-
SIGN S02 REMOVAL) TRAINS WILL FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AIR
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.
32
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PtfR AUTHORITY OF STATE OF NY
FOSSIL
MEW 700.0 MW (GROSS)
70ft. CT MW (ESC)
COAL
3.00 IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 11/87
THE POWER AUTHORITY OF NEW YQRK PLANS A NEW 3.01 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
NOVEMBER, 1987.
SALT RIVER PROJECT
CDRONADO
1
NEW 350.0 MW (GROSS)
ZS^.O MW
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.8X
STATUS 6 STARTUP 1/88
CORONADO 3 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS COAL (.605! 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
2PZ BYPASS REHEAT, AND THE SLUDGE WIUL PROBABLY BE PONDED. SCHEDULED OPER-
ATION DATE IS 1988.
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
1
MEW 400.0 MW (GROSS)
400.0 MW (ESC)
COAL
1.70 XS LIGNITE
LIMESTONE
3A9COCK 8 WILCOX
ENERGY CONSUMPTION: 5.OX
STATUS 2 STARTUP 10/80
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 86% EFFICIENT LIMESTONE TCA MODULES.
CHEVRON MIST ELIMINATORS WILL PRECED6 AN IN-LINE REHEATER AND AN ACID
BRICK LINED STACK. THE WATER LOOP WILL BE CLOSED, AND THE DEWATERED SLURRY
WILL BE MIXED WITH FLYASH BY RESEARCH COTTRELL AND DISPOSED IN AN OFF SITE
LANDFILL.
SEMINOLE ELECTRIC
SEMINOLE
1
«EW 620.0 MW (GROSS)
. 620.0 MW (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE-
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****x
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 FGD SYSTEM. THE FGD SYSTEM WILL BE
SUPPLIED BY PEABODY PROCESS SYSTEMS. START UP IS EXPECTED IN MARCH OF
1983.
33
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SEMINOLE ELECTRIC
SEMINOLE
2
NEW 620.n MW (GROSS)
620.7 MW (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 3/85
SEMINOLE 2 OF SEMINOLE ELECTRIC IS A COAL (2.755! 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 FGD SYSTEM WILL BE
SUPPLIED BY PEABODY SYSTEMS. START UP IS EXPECTED IN MARCH OF
1985.
SIERRA PACIFIC POWER
VALMY
2
NEW 276.? MW (GROSS)
276.0 I«W (ESC)
COAL
***** XS
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 7 STARTUP 8/84
SIERRA PACIFIC POWER HAS PLANS TO CONSTRUCT A 276 MW UNIT TO BE LOCATED
IN VALMY, NEVADA. THE FOSTER WHEELER PULVERIZED COAL FIRED BOILER AT THE
VALMY 2 STATION WILL UTILIZE AN FGD SYSTEM OR FIRE LOW SULFUR COAL TO
CONTROL S02 EMISSIONS. IF FGD IS SELECTED, A DRY LINE SYSTEM WILL BE
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN AUGUST, 1984.
SIKESTON BOARD OF MUNIC. UTIL.
SIKESTON
1
NEW 235. ^ MW (GROSS)
235.0 MW (ESC)
COAL
2.80 XS
LIMESTONE
3ABCOCK g WILCOX
ENERGY CONSUMPTION: 1.6X
STATUS 2 STARTUP 1/81
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 50* 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 WATER LOOP WILL BE OPEN, AND THE
SLUDGE WILL BE PONDED. START UP IS SLATED FOR JANUARY, 1981.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
NEW 500.0 MW (GROSS)
500.D MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
ST.ATUS 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 1.0 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 1 IS SCHEDULED TO COMMENCE OPERATIONS IN MARCH, 1985.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
2
NEW 50°.0 MW (GROSS)
500.H 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 2.3Z.
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
2
NEW 280.0 MW (GROSS)
140.0 MW (ESC)
COAL
1 .70 XS BITUMINOUS
LIMESTONE
3ABCOCK B WILCOX
ENERGY CONSUMPTION: 1.1X
STATUS 1 STARTUP 7/77
WINYAH 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 SCRUBSER/LIMESTONE TRAY
TOWER ABSORBER TRAIN DESIGNED TO REMOVE 69X OF THE SOJ 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 OF 1977.
34
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UMIT IDENTIFICATION
ABSTRACT
SOUTH CAROLINA PUBLIC SERVICE
4INYAH
3
YEW 28H.O MW (GROSS)
280. ) MW
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN
1
MEW 265.0 MW (GROSS)
265.? MW (ESC)
COAL
3.35 XS BITUMINOUS
DJAL ALKALI
FHC
ENERGY CONSUMPTION: .8*
STATUS 1 STARTUP 4/79
SOUTHERN INDIANA GAS AND ELECTRIC'S /V.B.BROwN 1 IS A DRY BOTTOM PULVERIZED
COAL (3.35X S, 13t010 BTU/LB) FIRED UNIT IN WEST FRANKLIN, INDIANA. FNC
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 MIST 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 OF 1979.
S3UTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY
1
MEW 720.? MW (GROSS)
720.n MW (ESC)
COAL
.80 XS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 12/84
HENRY W. PIRKEY 1 IS A WET BOTTOM LIGNITE (U.8X S, 6300 BTU/LB) FIRED UNIT
PLANNED BY SOUTHWESTERN ELECTRIC POWtR FOR LOCATION IN HALLSVILLE, TEXAS.
A CONTRACT HAS BEEN AWARDED TO THE AIR CORRECTION DIVISION OF UOP FOR FOUR
LIMESTONE SPRAY TOWERS (99+X 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.D MW (GROSS)
194.0 MW (ESC)
COAL
3.50 XS 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, 12,500 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/MODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
THE DRY 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
DALLMAN
3
MEW 235.0 MW (GROSS)
205.0 MW (ESC)
COAL
3.30 XS
LIMESTONE
RESEARCH-COTTHELL
ENERGY CONSUMPTION: 5.9X
DALLMAN 3 OF SPRINGFIELD WATER, LIGHT, AND POWER IS A PULVERIZED COAL
(3.3X S, 10,500 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN SPRINGFIELD,
ILLINOIS. RESEARCH COTTRELL IS SUPPLYING 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 BfcEN FINALIZED, BUT THE UTILITY IS CON-
SIDERING EITHER PONDING OR LANDFILL. FGD OPERATIONS SHOULD BEGIN IN
NOVEMBER, 1980.
STATUS 2
STARTUP 11/80
ST. JOE ZINC
S.F. WEATON
1
RETROFIT 60.0 MW (GROSS)
60.9 MW (ESC)
COAL
2.00 XS BITUMINOUS
CITRATE
1DRRISON 8 KNUDSEN/U.S.B.M.
ENERGY CONSUMPTION: ****X
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 SCRUBBER/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 SJACK . THE SYSTEM S02 REMOVAL EFFICIEN-
CY WILL BE OVER 90X. THE WATER LOOP IS CLOSED LOOP MODE. THE FGD SYSTEM
COMMENCED OPERATION IN NOVEMBER OF 1979.
SUNFLOWER ELECTRIC COOP
HOLCOMB
1
MEW 347.f> MW (GROSS)
347.n MW (ESC)
COAL
.47 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/83
SUNFLOWER ELECTRIC COOP'S HOLCOMB 1 STATION IS A 347 MW UNIT UNDER
CONSTRUCTION IN HOLCOMB, KANSAS. THE PULVERIZED COAL (0.47X S, 8800
BTU/LB) FIRED BABCOCK AND WILCOX BOILER WILL UTILIZE A JOY MANUFACTURING/
NIRO ATOMIZER DRY SCRUBBING PROCESS FOR S02 CONTROL. A FABRIC FILTER
WILL BE UTILIZED FOR PRIMARY PARTICLt CONTROL. THE UNIT IS SCHEDULED
TO COMMENCE OPERATIONS IN THE FALL OF 1983.
36
-------
EPA UTILITY f60 SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS Of FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TAMPA ELECTRIC
BIG BEND
4
MEW 475.0 MU (GROSS!
475.P MW (ESC)
COAL
2.35 ZS
LINE/LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION! 2.U
STATUS 3 STARTUP 12/84
UNIT 4 AT TAMPA ELECTRIC'S BIG BEND STATION IS A PLANNED DRY BOTTOM PUL-
VERIZED COAL (2.35* 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 90* OF THE FLUE GAS S02, WILL
INCLUDE AN INDIRECT HOT AIR REHEATER LEADING TO A 490 FOOT CONCRETE LINED
STACK. THE UNIT WILL PRODUCE GYPSUM AS A SALEABLE PRODUCT.
TENNESSEE VALLEY AUTHORITY
IDHNSONVILLE
1-10
RETROFIT 1450.C> MM (GROSS)
600." MW (ESC)
C3AL
3.10 ZS
MAGNESIUM OXIDE
ENVIRONEER1NG, RILEY STOKER
ENERGY CONSUMPTION: ****Z
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 JOHNSONVILLE, TENNESSEE. UNITED EN-
GINEERS HAS BEEN AWARDED A CONTRACT TO PROVIDE ENGINEERING ASSISTANCE TO
TVA FOR A 90* EFFICIENT MAGNESIUM OXIDE FGD SYSTEM TO BE RETROFITTED ON
THESE UNITS. SULFURIC ACID WILL BE PRODUCED AS A BYPRODUCT FROM THIS SYS-
TEM, WHICH WILL FEATURE FOUR VENTURl SCRUBBER/ABSORBER TRAINS (ONE SPARE),
60Z BYPASS REHEAT, AND A 600 FOOT STA.CK. START UP IS EXPECTED IN 1981.
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704.0 nu (GROSS)
734.0 MW (ESC)
COAL
4.20 IS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****Z
STATUS 2 STARTUP 3/82
PARADISE 1 OF TVA IS A 4.2* SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2Z EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURl SCRUB-
BERS AND VENTURl ABSORBER TRAINS WILL FOLLOW AN ESP. INLET FLUE GAS WILL
BE USED TO HEAT WATER, WHICH IN TURN WILL BE USED TO REHEAT THE OUTLET
FLUE GAS. FORCED OXIDATION WILL BE USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EXPECTS TO GET AN 80Z SOLIDS LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN MARCH, 1982.
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 704.0 MW (GROSS)
704." MW (ESC)
COAL
4.20 ZS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 6/82
PARADISE 2 OF TVA IS A 4.2* SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2* EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURl SCRUB-
BERS AND VENTURl ABSORBER TRAINS WILL FOLLOW AN ESP. INLET FLUE GAS WILL
BE USED TO HEAT WATER, WHICH IN TURN WILL BE USED TO REHEAT THE OUTLET
FLUE GAS. FORCED OXIDATION WILL BE USED IN ONE MODULE TO CONTROL SCALING
THROUGHOUT THE SYSTEM. THE UTILITY EXPECTS TO GET AN 80Z SOLIDS LANDFILL'
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN JUNE, 1982.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
IDA
RETROFIT 10.0 MU (GROSS)
10.0 MW (ESC)
COAL
2.90 ZS BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: ****Z
STATUS 1 STARTUP 4/72
SHAWNEE 10 OF TVA IS A 2.9Z SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PADUCAH, KENTUCKY. MODULE 1 DA IS A RETROFIT PROTOTYPE LIME/LIMESTONE TCA
SYSTEM SUPPLIED BY THE AIR 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 WRITER. THE SYSTEM HAS
BEEN OPERATIONAL SINCE APRIL, 1972.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10B
RETROFIT 10.0 MU (GROSS)
10.0 MW (ESC)
COAL
2.90 ZS BITUMINOUS
LIME/LIMESTONE
CHENICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 4/72
SHAWNEE 1C OF TVA IS A 2.
PADUCAH, KENTUCKY. MODULE
TURI SCRUBBER/SPRAY TOUER
TIONAL SINCE APRIL, 1972,
COMBUSTION REHEATER, AND
GRAM IS FUNDED BY THE EPA
TOR. THE BECHTEL CORP. OF
RECTOR, AND REPORT WRITER
9* SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
106 IS * RETROFIT PROTOTYPE LIME/LIMESTONE V[N-
ABSORBER SUPPLIED BY CHEMICO. 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 01-
37
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
SECTION 2
STATUS OF FGD SYSTEMS
JNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
RETROFIT 575.c *iw (GROSS)
575.r MW (ESC)
COAL
3.70 IS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 9/81
WIDOWS CRE£K 7 IS A PULVERIZED BITUMINOUS COAL (3.7* S, 11.1CO BTU/LB)
FIRED BOILER OF TVA LOCATED IN BRIDGEPORT* ALABAMA. COMBUSTION ENGINEERING
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 REHEATfcR FOLLOW THE SYSTEM* THE
SCRUBBER SLUDGE WILL BE DISPOSED IN A SLUDGE POND. CONSTRUCTION BEGAN
IN SEPTEMBER, 1978, AND START UP IS EXPECTED IN SEPTEMBER, 1981.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
S
RETROFIT 550.P MW (GROSS)
55H.9 MW (ESC)
COAL
3.70 *S
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: 4.71
STATUS 1 STARTUP 5/77
WIDOWS CREEK 8 OF TVA IS A BALANCED DRAFT, TANGENTIALLY FIRED COAL 3.72
S, 10,000 BTU/LB) BOILER IN BRIDGEPORT, ALABAMA. TVA RETROFITTED THIS UNIT
WITH A LIMESTONE FGD SYSTEM (80* DESIGN S02 REMOVAL EFFICIENCY) WHICH BE-
GAN OPERATIONS IN MAy* 1977. AN ESP PRECEDES FOUR VARIABLE THROAT VENTURI
SCRUBBER/MULTIGRID TOWER ABSORBER TRAINS (ONE 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
31880*5 CREEK
1
NEW 400.0 MW (GROSS)
40^.C 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 (1.06* S, 4860 BTU/LB) FIRED UNIT PLANNED FOR LOCATION IN
CARLOS, TEXAS. THE EMISSION CONTROL SYSTEM WILL CONSIST OF A COLD SIDE ESP
FOLLOWED BY THREE 50* CAPACITY LIMESTONE SPRAY TOWERS. A CONTRACT HAS BEEN
AWARDED TO COMBUSTION ENGINEERING FOR THE FGD SYSTEM, WHICH INCLUDES A
CHEVRON MIST ELIMINATOR AND A STEAM COIL REHEATER* CLEANED FLUE GAS WILL
BE DISCHARGED THROUGH A 465 FOOT ACID BRICK LINED STACK. THE POZ-0-TEC
STABILIZED SLUDGE WILL BE USED AS STRIP MINE LANDFILL. START UP
IS EXPECTED IN JANUARY, 1982.
TEXAS POWER 8 LIGHT
SANDOU
545.? *u (GROSS)
382.^ MW (ESC)
COAL
1.63 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 9/80
TEXAS POWER 8 LIGHT
TWIN OAKS
1
NEW 75?.? MW (GROSS)
750.H MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
CHEMICO DIVISION, FNVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 8/84
SANDOW 4 IS A PULVERIZED 1.6Z SULFUR LIGNITE FIRED BOILER OF TEXAS POUER
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 3 QX BYPASS REHEAT WILL BE USED, AND
THE OVERALL S02 REMOVAL EFFICIENCY WILL BE 75*. THE SYSTEM WILL OPERATE IN
A CLOSED WATER LOOP, AND THE SLUDGE WILL BE PONDED. START UP IS EXPECTED
IN SEPTEMBER, 1980.
TWIN OAKS 1 IS A 0.7o* SULFUR LIGNITE 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 OF 1984.
TEXAS POWER 8 LIGHT
TWIN OAKS
2
NEW
75H.P MW (GROSS)
750.P MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
CHEMICO DIVISION, ENVIRQTECH
ENERGY CONSUMPTION: *****
STATUS 3 STARTUP 8/85
TWIN OAKS 2 IS A 0.70* SULFUR LIGNITE FIRED BOILER PLANNED BY TEXAS POWER
AND LIGHT AND ALCOA FOR LOCATION IN 8REMONO, TEXAS. A CONTRACT HAS BEEN
AWARDED TO CHEMICO FOR A LIMESTONE FGD SYSTEM ON THIS UNIT. START UP IS
EXPECTED IN AUGUST OF 1985.
38
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UMIT IDENTIFICATION
TEXAS UTILITIES
FOREST GROVE
1
MEW 750.3 MW
750.f MW
COAL
.81 ZS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP ft/81
ABSTRACT
(GROSS)
(ESC)
TEXAS UTILITIES IS PLANNING A LIGNIT& (0.8X S, 7000 BTU/LB) FIRED BOILERt
FOREST GROVE 1, WHICH yiLL BE LOCATED IN ATHENS, TEXAS. THE UTILITY IS
PRESENTLY REQUESTING BIDS ON AN FGD SYSTEM FOR THIS UNIT. TWO ESP'S WILL
PROVIDE PRIMARY PART1CULATE CONTROL, AND NO STACK GAS REHEAT IS PLANNED.
START UP IS EXPECTED IN LATE 1981.
TEXAS UTILITIES
1ARTIN LAKE
1
MEW
797.0
595.0 My
COAL
.90 ZS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION
(GROSS!
(ESC)
1.3X
TEXAS UTILI
BOILER IN T
SYSTEM WHIC
SUPPLIED BY
TOWER ABSOR
ING FLUE GA
ENCY IS 7P.
CLEANING WA
THE SYSTEM
PLACE IN Ap
TIES* MAR
ATUM, TEX
H INCLUDE
RESEARCH
BERS WHIC
S IS BYPA
5X. TWO C
STES ARE
OPERATES
RIL, 1977
TIN LAKE 1 IS A LIGNITE <
AS. THIS UNIT IS EQUIPPED
S A COLD SIDE ESP AND A L
COTTRELL. THE FGD SYSTEM
H TREAT 75X OF THE TOTAL
SSED FOR REHEAT. THE TOTA
HEVRONS/MODULE PROVIDE HI
FLYASH STABILIZED AND DIS
IN A CLOSED WATER LOOP. I
0.9X S,
WITH AN
IHESTONE
CONSIST
BOILER F
L DESIGN
ST ELIHI
POSED IN
NITIAL S
738C BTU/LB) FIRED
EMISSION CONTROL
FGD SYSTEM, BOTH
S OF SIX PACKED SPRAY
LUE GAS. THE REMAIN-
SO? REMOVAL EFFICI-
NATION. THE FLUE GAS
AN ON-SITE LANDFILL.
YSTCM OPERATIONS TOOK
STATUS 1
STARTUP 4/77
TEXAS UTILITIES
MARTIN LAKE
2
MEW 793.* MW
595.!? MW
C3AL
.90 ZS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION
(GROSS)
(ESC)
1.3X
TEXAS UTILITIES
BOILER IN TATUM
SYSTEM WHICH IN
SUPPLIED BY RES
TOWER ABSORBERS
ING FLUE GAS IS
ENCY IS 70.5X.
CLEANING WASTES
THE SYSTEM OPER
PLACE IN MAY, 1
* MAR
, TEX
CLUDE
EARCH
WHIC
BVPA
TWO C
ARE
ATES
978.
TIN LAKE 2 IS A
AS. THIS UNIT IS EOU
S A COLD SIDE ESP AN
COTTRELL. THE FGD S
H TREAT 75Z OF THE T
SSED FOR REHEAT. THE
HEVRONS/MODULE PROVI
FLYASH STABILIZED AN
IN A CLOSED WATER LO
1TE (
IPPED
DAL
YSTEW
OTAL
TOTA
DE Ml
D DIS
OP. I
0.9X S,
WITH AN
IMESTONE
CONSIST
BOILER F
L DESIGN
ST ELIMI
POSED IN
NITIAL S
738G B
EMISS
FGD S
S OF S
LUE GA
S02 R
NATION
AN ON
VSTEH
TU/LB) FIRED
ION CONTROL
YSTEM, BOTH
IX PACKED SPRAY
S. THE REMAIN-
EMOVAL EFFICI-
. THE FLUE GAS
-SITE LANDFILL.
OPERATIONS TOOK
STATUS 1
STARTUP 5/78
TEXAS UTILITIES
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
1ILL CREEK
2
NEW 750.0 MW (GROSS)
751.0 MW
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
JTAH POKER 8 LIGHT
HUNTER
2
NEW ft."!n.1 MW (GROSS)
36?.C MW (ESC)
COAL
.55 XS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 6/80
UTAH POWER AND LIGHT'S HUNTER 2 IS A COAL <0.55X S, 12,500 BTU/LB) F.IRED
UNIT LOCATED IN CASTLEDALE, UTAH. FOR EMISSION CONTROL, CHEMICO SUPPLIED
A PEBBLE LIME UET SCRUBBING SYSTEM DESIGNED TO OPERATE IN AN OPEN yATER
LOOP WITH AN S02 REMOVAL EFFICIENCY OF 805!. 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, 198C.
JTAH POWER & LIGHT
HUNTER
J
NEW 4G'*.n «iw (GROSS)
40f.9 My (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP r
-------
EPA UTILITY FGO SUPVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
SET UNIT GENERATING CAPACITY y/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
ALABAMA ELECTRIC COOP
TOMBIGBEE
2
LEROY
ALABAMA
255.C
235.0
179.C
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
ASH CONTENT - X
MOISTURE CONTENT -
SULFUR CONTENT - X
AVERAGE
AVERAGE
AVERAGE
AVERAGE CHLORIDE CONTENT - x
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - %
INITIAL START-UP BATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - x
PARTICULATc DESIGN REMOVAL EFFICIENCY - X
ABSORBER SPARE CAPACITY INDEX -
ABSORBER SPARE COMPONENTS INDEX
COAL
BITUMINOUS
26749.
14.ro
( 115CC BTU/LB)
1.15
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEW
1
3
9/78
9/78
59
5C
99.3C
1CO.r<
1
* v
* WATER LOOP
TYPE
FRESH MAKE-UP WATER - L I T E ft / S
CLOSED
8.8
< 140 GPM)
* DISPOSAL
TYPE
LINED POND
. .. . .. . -PERFORMANCE DATA - --
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8
A
6
SYSTEM
35.8
9 ".7
81.5
21.1
33.5
48.1
744
439
357
** PROELE^S/SOLUTIONS/COMMENTS
DURING JANUARY UNIT 2 WAS UNAVAILABLE 69 HOURS DUE TO REPAIRS NEEDED ON
AN ABRADED EXPANSION JOINT AND A RUPTURED WASTE SLURRY LINE.
A
B
SYSTEM
99.
84.3
74.7
99.3
84.3
74.7
99.3
696
696
691
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT 2 FGD SYSTEM OPERATED ALL 6UT 5 HOURS DURING FEBRUARY, IN WHICH
TIME THE BOILER WAS BEING BROUGHT ON-LINE. 'CDKU*KT, iN WHICH
A
B
SYSTE"
81.6
79.4
9'.8
75.r
73. f
89.9
744
684
669
42
-------
EPA UTILITY FGO SURVEY; APRIL - JUNE 198C
ALABAMA ELECTRIC COOP: TOMBIGBEE 2 (CONT.)
ORMANCF DATA ---- -
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE FGD SYSTEM WAS AVAILABLE KCX OF THE TIME.
A
B
SYSTE""
100.
61.3
36.6
97.5
61.3
86.5
97.4
720
719
701
** PROELEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT FOR THfc MONTH OF APRIL THF SYSTEM WAS
AVAILABLE 1COI OF THE TIME.
5/8C A
6
SVSTE"
34.9
92.8
97.3
97.3
34.7
9?.2
96.6
744
739
719
** PROBLEMS/SOLUTIONS/COMfENTS
THE FGD SYSTEM WAS AVAILABLE 10CX DURING
SYSTEM
72C
** PR06LE*S/SOLUTIONS/COMMENTS
INFORMATION «A$ NOT AVAILABLE FOR THE MONTH OF JUNE.
43
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 196r
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - I"H
EQUIVALENT SCRUBBED CAPACITY - !*W
* FUEL DATA
FUEL TYPE
FUEL GR«DE
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
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPAR? COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
DISPOSAL
TYPE
- X
ALABAMA ELECTRIC COOP
TOMBIGBEE
3
LEROY
ALABAMA
Z55.C
235.0
170.0
< 1150C BTU/LB)
COAL
BITUMINOUS
36749.
u.cc
7.00
1.15
.04
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEW
3.1
6/79
6/79
59.50
99.3C
1CO.O
1.C
CLOSED
8.8
LINED POND
< 140 GPM)
......... .. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPIL1TY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 A
B
SYSTEM
69.2
45.4
97.9
3C.5
20.0
43.1
100.? 97.9 43.1 744
* PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY UNIT 3 WAS AVAILABLE THE ENTIRE MONTH.
328
321
2/80
A
B
SYSTEM
31.3
10P.O
10C.O
1.1
3.4
3.4
696
24
24
100. C
* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE UNIT 3 BOILER AND F60 SYSTEM OPERATED ONLY 24 HOURS.
3/8*5 A
B
SYSTEM
.0
.0
.0
100.0 .0 744
* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE UNIT 3 GENERATOR WAS KEPT OUT OF SERVICE.
4/80 SYSTEM .0 720
44
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
ALABAMA ELECTRIC COOP: TOMBIGBEE 3 (CONT.)
. . . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TH RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT DURING APRIL THE BOILER DID NOT OPERATE.
5/80 A 8.3 .7
B .0 .C
SYSTEM 95.8 ?.3 8.3 .7 744 6C 5
* PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE 713 HOURS DURING MAY; HOWEVER, THE BOILER ONLY
OPERATED 60 HOURS DUE TO BOILER RELATED PROBLEMS.
THE B MODULE WAS OUT FOR 31 HOURS WHEN THE INLET DAMPER SWITCH FAILED
CAUSING THE DRIVE MOTOR TO BURN OUT.
6/6" SYSTEM 720
« PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF JUNE.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/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 - 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
PARTICULATt DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - %
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKf-UP WATER - LITER/S
** DISPOSAL
TYPE
- X
ARIZONA ELECTRIC POWER COOP
APACHE
2
COCHISE
ARIZONA
195.0
175.0
97.5
COAL
BITUMINOUS
23260.
15.00
9.00
.55
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
4.1
8/78
1/79
85.0C
99.5C
1CC.O
1.C
( 1rC-"C BTU/LB3
OPEN
115.9
POND
( 184.P GPI»)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILE? FGD CAP.
S03 PART. HOUPS HOURS HOURS FACTOR
1/80 SYSTEM 9C.9 58.3 88.8 57.3 97.4C 744 731 426
** PROBLEMS/SOLUTIONS/COMMENTS
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.
2/60 SYSTEM 92.8 96.7 92.8 92.8 97.4i, 696 668 646
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY OUTAGE TIME WAS DUE TO A PRECIPITATOR FAILURE.
FORCED OUTAGE TIME WAS ALSO CAUSED BY A PUHP MALFUNCTION.
3/80 SYSTEM 99.H 99.0 99.0 99.C 744 744 738
** PROBLEMS/SOLUTIONS/COMMENTS
SOME OF THE OUTAGE TIME DURING MARCH OCCURRED BECAUSE OF PUMP FAILURE.
OTHER OUTAGE TIME WAS CAUSED BY STICKING VAJ.VES AND LIMESTONE FEED-BELT
PROBLEMS.
46
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
ARIZONA ELECTRIC POWER COOP: APACHE 2 (CONT.)
-- PERFORMANCE DATA --
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER fGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
t/&r SYSTEM 67.2 65.2 65.? 61.* 720 678 442
** PROBLtMS/SOLUTIONS/COMMENTS
DURING APRIL THE FGD SYSTEM WAS FORCED DOWN DUE TO PUMP FAILURES AND A
RUPTURE IN THE SLURRY RECIRCULAT ION LINE.
5/BC SYSTEM 90.5 9^.5 9C.5 9C.5 744 744 673
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE UNIT WAS FORCED OFF LINE WHEN THE LIMESTONE CRUSHER
MALFUNCTIONED.
THE UNIT WAS ALSO FORCED OUT DUE TO PUMP AND VALVE FAILURES.
6/8C SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF JUNE.
47
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198r
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MW
EOUIVALENT 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 MAKF-UP WATER - LITER/S
** DISPOSAL
TYPE
- X
ARIZONA ELECTRIC POWER COOP
APACHE
3
COCHISE
ARIZONA
195.0
175.0
97.5
COAL
BITUMINOUS
23260.
15.GO
9.CO
.55
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
4.1
6/79
4/79
85.00
99.50
1CO.O
1.0
( 1POCC BTU/LB)
OPEN
340.2
POND
< 5400 GPM)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8P SYSTEM 91.7 91.7 91.7 91.7 97.40 744 744 682
** PROBLEMS/SOLUTIONS/COMMENTS
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.
Z/8P SYSTEM 95.6 74.1 96.0 71.4 97.4C, 696 671 497
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY OUTAGE TIME WAS DUE TO A PRECIPITATOR FAILURE.
FORCED OUTAGE TIME WAS ALSO CAUSED BY A PUMP MALFUNCTION.
3/8T SYSTEM 91." 91.C 91.0 91.0 744 744 677
** PROBLEMS/SOLUTIONS/COMMENTS
SOME OF THE OUTAGE TIME DURING MARCH OCCURRED BECAUSE OF PUMP FAILURE.
OTHER OUTAGE TIME WAS CAUSED BY STICKING VALVES AND LIMESTONE FEED-BELT
PROBLEMS.
48
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
ARIZONA ELECTRIC POWER COOP: APACHE 3 (CONT.)
. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/60 SYSTEM 99.0 96.9 96.9 JT.6 7?C 227 220
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL THE FGD SYSTEM WAS FORCED DOWN DUE TO PUMP FAILURES AND A
RUPTURE IN THE SLURRY RECIRCULAT I ON LINE.
5/6T SYSTEM .3 .0 .0 744 39 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS NOT AVAILABLE DURING MAY DUE TO A SCHEDULED FGD UNIT OUTAGE.
6/8C1 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF JUNE.
49
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - My
ARIZONA PUBLIC SERVICE
CHOLLA
1
JOSEPH CITY
ARIZONA
119.0
115.0
119.C
** 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 - 7,
COAL
BITUMINOUS
23609.
13.50
15.00
.50
.02
BTU/LB)
»* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIFR
N E W / R E T R 0 F IT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - 2
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
RETROFIT
3.4
1C/73
58.50
83. OC
p
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
OPEN
7.6
POND
( 12C GPW)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/79
12/79
1/80
2/er
3/8?
A
E
SYSTEM
A
E
SYSTEM
A
B
SYSTEM
A
B
SYSTEM
A
B
SYSTE"
77. C
9?.0
87.5
94. C
87.0
91.5
95. C
99.0
97.C
100.0
99. C
99.5
99. C
93.0
96. C
77.0
98.0
87.5
94.0
87.0
90.5
95.0
99.0
97.Q
1CP.O
99.0
99.5
99.0
93.0
96.0
72C 7?C 632
744 744 672
744 744 724
696 696 694
744 744 715
PROBLEMS/SOLUTIONS/COMMENTS
NO FORCED OUTAGES WERE REPORTED BY THE UTILITY FOR THE FIVE MONTH PERIOD.
SOME SCHEDULED OUTAGE TIME WAS REQUIRED FOR REPAIR OF THE REHEATER DUCT-
WORK.
50
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
ARIZONA PUBLIC SERVICE: CHOLLA 1 (CONT.)
. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/80 SYSTEM 7?0
5/80 SYSTEM 744
6/80 SYSTEM 72D
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD taAS NOT AVAILABLE.
51
-------
EP* UTILITY FGD SURVEY: APRIL - JUNE 198<"
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
MET UNIT GENERATING CAPACITY U/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 7,
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 5!
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PPOCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DFSIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
*» DISPOSAL
TYPE
- X
ARIZONA PUBLIC SERVICE
CHOLLA
2
JOSEPH CITY
ARIZONA
264.0
235.1
264. D
COAL
BITUMINOUS
23609.
13.5C
15.00
.50
.02
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
( 1015C BTU/LE)
4/78
* * / * *
75.00
99.70
33.0
1.C
OPEN
7.6
UNL1NED POND
( 12T GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8T SYSTEM
2/8? SYSTEM
3/8C SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
NO INFORMATION IS AVAILABLE AS OF YET WITH RESPECT TO THE CHOLLA 2 FGD
OPERATIONS.
<./8T SYSTEM
5/8" SYSTEM
6/60 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE FGD SYSTEM PERFORMANCE DATA FOR THE APRIL-JUNE PERIOD IS NOT AVAILABLE
AT THIS TIME.
52
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
** 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
NEy/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
NEy MEXICO
175.0
175.0
175.0
( 86CC BTU/LB)
COAL
SUBBITUMINOUS
2C004.
22.00
1Z.30
.75
.C7
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
RETROFIT
11/79
* * / * *
*** *****
X 99.00
. u
.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 720
12/79 SYSTE" 744
** PROBLEKS/SOLUT10NS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/6C SYSTEM 744
Z/6r SYSTEM &96
3/8" SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.
4/8r SYSTEM 7?C
5/8" SYSTEM 744
6/BC SYSTEM 72C
** PROBLEMS/SOLUTIONS/COMMENTS
ALTHOUGH THE FGD SYSTEM PERFORMANCE DATA IS BEING LOGGED, THE UTILITY
REPORTED THAT IT IS UNAVAILABLE FOR RELEASE AT THIS TIME.
53
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198°
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - Mw
NET UNIT GENERATING CAPACITY W/FGD - Mh
EQUIVALENT SCRUBBED CAPACITY - PW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 1
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 1,
»* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATt DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - 'i.
ABSORBER SPARE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
FARMINGTON
NEW MEXICO
175.0
175.0
175.0
( ?60C ETU/LBJ
COAL
SUBBITUMINOUS
20004.
22.00
12.30
.75
.07
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENV1ROTECH
RETROFIT
11/79
* * y * *
99.^0
--- , --------------------------------------- PERFORMANCE DATA --------------------- - --------- - ----------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 72C
12/79 SYSTEM 744
«* PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/8T SYSTEM 744
2/8" SYSTEM 696
3/&T SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SH AK EDOVtN/ DEBUG&I NG PHASE OF OPERATION.
4/BT SYSTEM 7jn
5/8C SYSTEM 744
SYSTEM 7jQ
** PROBLEMS/SOLUTIONS/COMMENTS
ALTHOUGH THE FGD SYSTEM PERFORMANCE DATA IS BEING LOGGED, THE UTILITY
REPORTED THAT IT IS UNAVAILABLE FOR RELEASE AT THIS TIME.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SFCTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
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 - 5!
»* 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 SPAR? CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
FARMINGTON
NEU MEXICO
229.0
229.0
229.0
( 860C 6TU/LB)
COAL
SUBBITUMINOUS
2000*.
22.00
12.30
.75
.r?
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
RETROFIT
11/79
** / * *
99. 1C
.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/79 SYSTEM 72C
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS STARTED IN NOVEMBER 1979.
1/80 SYSTEM 744
2/8? SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT IS PRESENTLY IN THE SHAKEDOyN/DEBUGGING PHASE OF OPERATION.
4/8T SYSTEM 720
5/8T SYSTEM 744
6/8" SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
ALTHOUGH THE FGD SYSTEM PERFORMANCE DATA IS BEING LOGGED, THE UTILITY
REPORTED THAT IT IS UNAVAILABLE FOR RELEASE AT THIS TIME.
55
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198°
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
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 - %
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 - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
- X
BIG RIVERS 'ELECTRIC
GREEN
1
SEBREE
KENTUCKY
242.0
200.0
242.0
COAL
BITUMINOUS
22676.
20.00
11.00
3.75
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
( 9750 BTU/LB)
12/79
12/79
9n.OC
99.CC
31.0
.4
CLOSED
POZ-0-TEC
(«...« GPM)
,. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/SC SYSTEM
2/8T SYSTEM
3/8H SYSTEM
744
696
744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER, 1980.
4/6C
A
B
SYSTEM
65.C
65."
65."!
56.G
56.C
56. P
7S.8
79.0
79. r
45.C
45.0
45.0
720
576
324
»* PROBLEMS/SOLUTIONS/COMMENTS
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
5/80 A
73.7
76.1
79.0
73.7
56
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
316 RIVERS ELECTRIC: GREEN 1 (CONT.)
. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 5! REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B
SYSTEM
73.7
73.7
76.0
76.1
78.9
79."
73.5
73.7
744
720
548
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE FGD SYSTEM yAS OFF LINE FOR APPROXIMATELY 548 HOURS DUE
TO THE FOLLOWING PROBLEMS.
1. SULFUR OXIDES TOO HIGH
Z. LOW LEVEL IN ADDIT1V? TANK
3. INSTRUMENT TROUBLE
4. SCHEDULED MAINTENANCE OUTAGE
5. SOLIDS ON CARRY OVER
6. SOLID WASTE PROBLEM
7. UNIT TRIPPED
8. CONSTRUCTION WORK
6/8?
SYSTEM
720
PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION MAS NOT AVAILABLE FOR THE MONTH OF JUNE.
57
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 196r
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SBOSS UNIT GENERATING CAPACITY - MW
MET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MW
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
CANTON
ILLINOIS
416.0
378.C
416.?
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEb /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 - %
ABSORBER SPAR? COMPONENTS INDEX
COAL
BITUMINOUS
24423. ( 1C5CC BTU/LB)
9.12
18.00
3.3C
.33
WET SCRUBBING
LIMESTONE
ENVIRONEERING, RILEY STOKER
NEW
2.9
7/76
8/78
SS.T'C
- X
** WATER LOOP
TtPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
37.8
( 600 GPM)
** DISPOSAL
TYPE
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION
3! REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/sr
A
B
C
D
SYSTEM
24
58
17
29
32
.8
.5
.1
.2
.4
27
63
18
31
35
. 0
.6
.6
.8
.3
29
65
Z"
35
37
.8
.9
.3
.3
.8
24
58
17
29
32
.8
.5
.1
.3
.4
744 684 241 81.6
** PROBLEMS/SOLUTIONS/COMPENTS
2/er
A
B
C
D
SYSTEM
11 .8
72.7
T... 7
41.3
49.1
OUTAGE TIME WAS REQUIRED DURING JANUARY FOR RECYCLE TANK COVERING WORK.
THE MIST ELIMINATOR SECTION PLUGGED ALONG WITH THE NOZZLES HINDERING
SYSTEM OPERATIONS. THE MIST ELIMINATOR DRAIN LINE WAS MODIFIED ALSO
CAUSING OUTAGE TIME.
OTHER PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED A PLUGGED LIMESTONE
FEEDER, INLET DAMPER 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
3*2 73.5
58
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
_ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEKABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/6'
5/8'
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY SOME OUTAGE TIME WAS DUE
CLEANING OF THE MIST ELIMINATOR SECTION.
MODULE CLEANING AND THE
THE INLET DAMPER DRIVE WAS REPLACED DURING THE MONTH.
REPAIR OF THE FIBERGLASS ON THE SLURRY RECYCLE LINE HINDERED OPER-
ATIONS DURING THIS MONTH.
THE RECYCLE DISCHARGE VALVE WAS REPLACED CAUSING SOME DOWN TIME.
3 / 8 r A
B
C
D
SYSTEM
52.9
73.2
51."
34.'
52.8
62.5
86.6
6P.3
4T.2
62.4
64.7
86.9
6^.5
45.9
65.1
52.9
73.2
51.0
34.0
52.8
744
629
393 68.6
PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH NEW RECYCLE PUMP DISCHARGE VALVES WERE INSTALLED IN ORDER TO
ELIMINATE RESTRICTED FLOW OF THE OLD VALVES.
CARRIER BEARINGS 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 CUALITY ELIMINATION WASH WATER.
FIBERGLASS LINES ON THE RECYCLE PUMP DISCHARGE WERE ALSO REPAIRED DURING
MARCH.
A
B
C
D
SYSTEM
53. r
54.2
57.2
26."
47.6
81.7
83.6
88.3
4r.i
73.4
95.9
8^.5
95.3
71.9
89.2
52.9
54.2
57.2
26. r
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.
MINOR PROBLEMS DURING THE MONTH WERE CAUSED BY THE I NOPEHABILITY OF THE
LIMESTONE HANDLING SYSTEM.
A
B
C
D
SYSTEM
44.6
45.7
34. 7
43.6
42.1
68.6
7C.3
53.3
67. C
64.8
72. C
73.5
59.1
73.9
69.7
44.6
45.7
34.7
43.6
42.1
744
484
314 49.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING CAY REPAIRS WERE MADE TO THE RECYCLt 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.
A
e
c
D
SYSTEM
87.6
86. S
84.5
80.0
84.8
82.3
82.6
81.4
73.1
79.9
87.1
86.0
84.3
75.8
84.3
82.1
82.3
81.1
72.9
79.6
72C 718
573 78.5
59
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
_ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PR08LE!»S/SOLUTIONS/COMI«ENTS
A LEAK WAS REPAIRED IN THE SLURRY SUPPLY HEADER DURING JUNE.
WORK CONTINUED ON THE MODIFICATIONS BEING DONE ON THE ROD DECKS IN THE
ABSORBER MODULES.
61
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAM?
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
MET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GR'DE
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
GENiERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - Z
PARTICULATt DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
»* WATER LOOP
TYPE
FRtSH MAKE-UP WATER - LITER/S
«* TREATMENT
TYPE
- Z
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
NEWTON
ILLINOIS
617.0
575.0
617.0
< 1C9CC BTU/LB)
COAL
BITUMINOUS
25353.
12.70
9.50
2.25
.20
WET SCRUBBING
DUAL ALKALI
BUELL DIVISION, ENV1ROTECH
NEW
2.4
9/79
12/79
90.CO
99.50
.0
.0
CLOSED
POZ-0-TEC
(***** GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION
j/sr
X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1 / 8 C A
B
C
D
SYSTE"
68.3
66.4
52.2
21.^
52."
57.1
60. 6
48. 8
19.1
4*. 4
63.5
64.9
t?.5
26.?
57.8
55.5
58.9
47.4
18.5
45.1
744 723 336
PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY TESTS WERE CONDUCTED TO CERTIFY THE GAS EMISSIONS MONITOR
AT NEWTON.
A
e
c
D
SYSTEM
61.1
74.4
78.?
.<
53.4
42.4
55.7
5R.5
'
39.2
45.0
57.7
59.1
.C
40.4
42.4
55.7
58.5
n
V
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.
53.4
47.'
52.6
42.3
53.1
48.'
52.3
42.1
61
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198C
CENTRAL ILLINOIS PUBLIC SERV: NEWTON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION
Z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
C
D
SYSTEM
44.5
41.1
.0
34.C
46.5
(1
36.9
41."
.0
33.9
744
74C
252
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER, 19bO, THE FOLLOWING PROBLEMS WERE ENCOUNTERED:
THE VALVES AND PIPING IN THE PRECOOLER LOOP EXPERIENCED CORROSION.
THE MIST ELIMINATOR ON THE D MODULE FAILED.
THE FLY ASH SUPPLIES DEPLETED.
RUBBER LINING AND DUCTWORK LINING FAILURES OCCURRED.
BOOSTER FAN EXPANSION JOINT FAILURE OCCURRED.
THE THICKENER EXPERIENCED PLUGGING.
FOR THE QUARTER, THE TOTAL SYSTEM WAS AVAILABLE 47.25! AND WAS UTILIZED
39.4% OF THE TIME.
4/8r
C
D
SYSTEM
33. 8
35.4
37.4
26.1
33.2
31.3
25.8
35.6
21.8
28.6
31.4
25.8
35.6
21.8
28.*
31.3
25.8
35.6
21.8
28.6
720 72C
206
** PROBLEMS/SOLUTIONS/COMMENTS
THE NEWTON 1 FGD SYSTEM WAS OUT OF SERVICE DUPING THE FIRST 12 DAYS OF
APRIL FOR NECESSARY REPAIRS ON THE OUTLET DUCT LININGS. THE UTILITY FEELS
THAT THE LINING FAILURES HAY 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.
5/8r A
B 9.7
C 9.7
D
SYSTEM 4.8
** PROBLEMS/SOLUTIONS/COMMENTS
.C
9.6
9.6
.C
4.8
9.6
9.6
.r
4.8
6.2
6.2
744
477
23 45.5
6/8C
A
B
C
D
SYSTEM
40.3
40.4
1
-,
20.2
DURING "AY, THE FGD SYSTEM WAS DOWN BECAUSt THE FLUIDIZING STONES WERE
CAKED WITH FLY ASH. THIS WAS CAUSED 6Y IMPROPER WIRING OF THE HEATER WHICH
BLOWS OVER THE STONES. THE HEATER WAS REWIRED AND THE FLUIDIZING STONES
REPLACED.
.0
4C.3
4C.4
f
2<-.2
4-".3
4f>.4
.f.
2".2
4P
4C
2T.2
720
72C
145 63.
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 FLYASH COLLECTION SYSTEM.
62
-------
EPA UTILITY FGO SURVEY: APSIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
1ET UNIT GENERATING CAPACITY y/FGD - MM
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 - Z
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - *
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP yATER - LITER/S
** DISPOSAL
TYPE
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
CRAIG
COLORADO
447.0
4TO.C
447.C
< 1COOO BTU/LB)
COAL
SUBBITUMINOUS
2326C.
8.00
16.CD
.45
.00
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
NEW
5.4
12/79
5/8C!
85.00
99.80
2C.O
.6
CLOSED
19.9
MINEF1LL
( 316 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
* REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/6T SYSTEM
E/8T SYSTEM
3/80 SYSTEM
** PROBLtMS/SOLUTIONS/COMMENTS
744
69«
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/CLOS ING THE BYPASS DA-MPER HAVE BEEN ENCOUNTERED.
LARGER OPERATORS ARE BEING LOOKED AT TO SOLVE THE PROBLEM.
4/8T SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
THE FGD SYSTEM IS STILL IN STARTUP PHASE. TESTING IS BEING PERFORMED ON
THE SYSTEM, BUT THERE HAS BEEN NO OPERATIONAL DATA.
28.4
27.5
28.4
28.4
63
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
COLORADO UTE ELECTRIC ASSN.: CRAIG 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B
C
D
SYSTEM
33.1
38.4
18.6
39.5
32.1
37.2
16.0
38.3
33.1
38.4
18.6
39.5
33.1
38.4
18.6
39.5
640
661
253
78.1
PROBLEMS/SOLUTIONS/COMMENTS
CRAIG 2 UNIT COMMENCED COMMERCIAL OPERATION ON MAY 4, 19BO.
BEEN ADJUSTED ACCORDINGLY FOR THIS PERIOD TO 640.
HOURS HAVE
6/80 A
B
C
D
SYSTEM
37.9
44.2
51.4
24.9
52.?
41.2
48.0
55.8
27.0
57.4
42.0
48.9
56.9
27.5
58.5
37.9
44.2
51.4
24.9
52.8
720 663
38C 69.7
PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY AND JUNE, PROBLEMS WERE ENCOUNTERED WITH PLUGGING OF THE
ABSORBER SPRAY NOZZLES.
A PROBLEM yAS ALSO ENCOUNTERED DURING INITIATION OF COMMERCIAL OPERATION
WITH A HIGH PH LEVEL IN THE THICKENER UNDERFLOW.
64
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 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/FGD - Mh
EQUIVALENT SCRUBBED CAPACITY - MU
** 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
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO* DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** HATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
** TREATMENT
TYPE
«* DISPOSAL
TYPE
- X
COLUMBUS 8 SOUTHERN OHIO ELEC.
CONESVILLE
5
CONESVILLE
OHIO
411.0
375.0
411.0
( 1C85C BTU/LB)
COAL
BITUMINOUS
25237.
15.10
7.5C
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 GPM)
... i 1 PERFORMANCE DATA ___-..
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
i/sr
A
B
SYSTEM
25.".
29."
27."
38.t
5r.O
44.0
45.0
59.0
52.0
13.0
17.0
15.0
744
257
113 21.4
** PROBLtMS/SOLUTIONS/COMMENTS
DURING JANUARY A BOILER OUTAGE OCCURRED FROM THE FIRST OF THE MONTH TO
JANUARY 21, DURING WHICH TIME MAINTENANCE WAS PERFORMED ON THE FGD SYSTEM.
2/8C
A
B
SYSTEM
9C-."
93. f
92. "
63.C
69.r
66.0
77.0
84.0
81.0
31.0
34.0
33.0
696 343
226 31.4
«* PROBLEMS/SOLUTIONS/COMMENTS
A BOILER OUTAGE LASTING APPROXIMATELY 17 DAYS ALSO OCCURRED DURING
FEBRUARY.
IN FEBRUARY, MIST ELIMINATOR NOZZLE PLUGGING OCCURRED CAUSING SOME FGD
SYSTEM OUTAGE TIME.
3/6'
88.
82.0
82.T
82.C
65
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
COLUMBUS & SOUTHERN OHIO ELEC.: CONESVILLE 5 (CONT.)
PERFORMANCE DATA .--.
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION % REMOVAL PEP BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B 88.0 81.0 82.0 81."
SYSTEM 88.0 82.0 82.0 82.r- 744 744 6C6 75.4
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH PROBLEMS fcERE EXPERIENCED WITH THE IUCS SLUDGE STABILIZATION
PROCESS AND SOME OUTAGE TIME RESULTED. ALSO DUPING MARCH SOME GRID RODS
REQUIRED REPLACING AND SOME RUBBER LINER FAILURES OCCURRED.
THE MAJORITY OF THE MARCH FGD SYSTEM OUTAGi TIME WAS DUE TO CONTINUING
PROBLEMS WITH THE MIST ELIMINATOR NOZZLES.
4/8C A 94.6 84.4 78.9
B 74.9 65.? 61.5
SYSTEM 84.7 75.2 7C.3 720 67? 5C6 63.1
** PROBLEMS/SOLUTIONS/COMMENTS
PROBLEMS WITH THE DAMPERS AND PRESATURATOP HOSES, ALONG WITH NOZZLES, WERE
THE CONTINUOUS CAUSES OF FGD SYSTEM OUTAGE TIME IN APRIL.
5/8"1 A 92.1 86.2 86.2
B 92.3 84.3 84.3
SYSTEM 91.3 85.2 85.2 744 744 634 69.5
** PROBLEMS/SOLUTIONS/COMMENTS
IN MAY, CONTROLS AND INSTRUMENTATION DEVELOPED PROBLEMS THAT CAUSED SOME
OUTAGE TIME.
S/8r A 89.6 71.: 7C.7
B 94.3 74.8 74.4
SYSTEM 86.4 72.9 72.6 7?C 717 523 65.1
** PROBLEMS/SOLUTIONS/COMMENTS
EXTERNAL CAUSES (IUCS DISPOSAL FACILITY, LOW UNIT DEMAND, SERVICE WATER
PROBLEMS, ETC.) WERE RESPONSIBLE FOR THE MAJORITY OF THE JUNE OUTAGES.
66
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DFSIGN 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 W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - My
** FUEL DATA
FUEL TYPE
FUEL GR»DE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFU' CONTENT - X
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SU^PLI^R
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULAR DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
«* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
- X
COLUMBUS 8 SOUTHERN OHIO ELEC.
CONESVILLE
6
CONESVILLE
OHIO
411.0
375.0
411.0
< 1"850 BTU/LB)
COAL
BITUMINOUS
25237.
15.10
7.50
4.67
.01
WET SCRUBBING
LIME
AIR CORRECTION DIVISION, UOP
NEW
3.9
6/78
* * / **
89.50
.00
.0
.0
OPEN
31.5
POZ-0-TEC
( 500 GPMJ
»* DISPOSAL
TYPE
POND
>. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1 / 8 0 A
B
SYSTEM
88.0 74.0 74.0 74.0
89. C 78.0 78.0 . 78.0
89.0 76.0 76.0 76.0
744 744 566 73.9
3/80
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR FGD SYSTEM RELATED PROBLEMS WERE REPORTED FOR JANUARY.
A
B
SYSTEM
87.0
92.0
90. n
75.0
81.0
78.0
78.0
85.0
82.0
69.0
75.0
72.C
696 648
503
PROBLEMS/SOLUTIONS/COMMENTS
IN FEBRUARY, MIST ELIMINATOR NOZZLE PLUGGING OCCURRED CAUSING SOME OUTAGE
TIME.
A
B
SYSTEM
93.0
94. n
94. n
69.0
76.0
73.0
69.0
76.0
73.C
15.0
16.0
16.0
744
160
117 17.6
67
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE
COLUMBUS 6 SOUTHERN OHIO ELEC.: CONESWILLE 6 (CONT.)
* PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WENT DOWN ON MARCH 9 FOR A BO IL£R/TURBINE INSPECTION AND
REMAINED OUT OF SERVICE THROUGH THE END OF THE MONTH.
4/80 A 98.8 35.6 11.1
B 98.9 54.2 23.5
SYSTEM 98.9 40.1 17.4 7?0 312 125 19.8
** PROBLEMS/SOLUTIONS/COMMENTS
CONTINUOUS PROBLEMS WITH DAMPERS, P RES ATUR AjTOR HOSES, AND NOZZLES
ACCOUNTED FOR MOST OF THE APRIL FGD SYSTEM OUTAGES.
5/89 A 96.9 58.3 55.0
B 96.1 33.8 31.9
SYSTEM 96.5 46.1 43.4 744 701 323 39.1
** PROBLEMS/SOLUTIONS/COMMENTS
CONTROL AND INSTRUMENTATION PROBLEMS THAT DEVELOPED IN MAY WERE RESPONSI-
BLE FOR SOME FGD SYSTEM OUTAGE TIME.
6/8^ A 97.1 73.6 73.1
SYSTEM 97.1 62.1 61.7 720 715 444 52.5
** PROBLEMS/SOLUTIONS/COMMENTS
THE MAJORITY OF THE JUNE FGD SYSTEM OUTAGES WERE A RESULT OF EXTERNAL
CAUSES (IUCS DISPOSAL SYSTEM, WAST LOW UNIT DEMAND, SERVICE WATER, ETC.).
68
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
*ET PLANT GENERATING CAPACITY - MW
SROSS UNIT GENERATING CAPACITY - WW
SET UNIT GENERATING CAPACITY W/FGD - MW
HET UNIT GENERATING CAPACITY WO/FGD - MW
EOUIVALENT SCRUBBED CAPACITY - MW
** 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 - Z
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - 5!
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - *
RANGE CHLORIDE CONTENT - Z
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
S02 DESIGN REMOVAL EFFICIENCY - Z
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
COMMONWEALTH EDISON
POWERTON
51
PERKIN
ILLINOIS
43.
774.
1700.0
45^.0
4:0.0
425.?
450.0
< -1CC LE/MMBTU)
< 1.80C LE/MMETU)
BABCOCK g
CYCLONE
BASE
0/72
722.18
157.2
137.
6.4
WILCOX
(153037^ ACFM)
( 315 F)
( 450 FT)
< 21.0 FT)
COAL
24516.
9.16
16.34
3.53
< 1054C BTU/LB)
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
FULL SCALE
RETROFIT
75.50
12/8C
4/fi"
12/79
3/77
2/76
FABRIC FILTER
NUMBER
ESP
NUMBER
TYPE
SUPPLIER
PARTICULATt DESIGN REMOVAL EFFICIENCY
FLUE GAS TEMPERATURE - c
- Z
1
COLD SIDE
RESEARCH-COTTRELL
98.7
157.2 < 315 F)
* MECHANICAL COLLECTOR
NUMBER
** PARTICULATE SCRUBBER
TYPE
NONE
«* ABSORBER
NUMBER
TYPE
SUPPLIED
MOBILE PACKED TOWER
AIR CORRECTION DIVISION, UOP
69
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE
COMMONWEALTH EDISON: POWERTON 51 (CONT.)
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ABSORBER - X
GAS FLOW - CU.M/S
6AS TEMPERATURE - C
LIOUIO RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
PARTICULATE INLET LOAD - NG/J
PARTICULATE OUTLET LOAD - NG/J
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - Z
** CENTRIFUGE
NUMBER
3
55 X 30 X 18
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)
(25"UC GPM)
< 60.0 GAL/10TCACF)
(12.G IN-H20)
( 1?.5 FT/S)
( .1CC LB/MMBTU)
< .100 LB/MMBTU)
** FANS
TYPE
CONSTRUCTION MATERIALS
SERVICE - wET/DRY
CENTRIFUGAL
T-1
DRY
** VACUUM FILTER
NUMBER
TYPE
CONSTRUCTION MATERIAL
CAPACITY - M T/D
OUTLET SOLIDS - 1
** MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
WASH SYSTEM
SUPERFICIAL GAS VELOCITY - M/S
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
MODE
** TANKS
SERVICE
RECYCLE
SLURRY MAKE-UP
M.E. WASH
WASTE SLURRY
LIMESTONE TRANSFER
RECLAIMED wATFR
REHEATER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
ENERGY REQUIRED
THICKENER
NUMBER
CONSTRUCTION MATERIAL
DIAMETER - «1
OUTLET SOLIDS - Z
WATER LOOP
TYPE
FRESH MAKEUP WATER ADDITION - LITERS/S
REAGENT PREPARATION EQUIPMENT
NUMBER OF BALL MILLS
BALL MILL CAPACITY- M T/H
ROTATING DRUM
CARBON STEEL
1C88.4 I
55. D
1200 T/D)
CHEVRON
FRP
HORIZONTAL
WASH TOP AND BOTTOM LAYERS ONLY
2.7 ( 9.C FT/S)
S02, GAS FLOW, PH
AUTOMATIC
FEEDBACK £ FEEDFORWARD
NUMBER
HOT AIR INJECTION
STEAM
17.9 ( 25 F)
71 , v ~L,CrvC ETU/HR
1
CARBON STEEL
51.8
35.G
CLOSED
35.3
2
20.0
07'1 FT)
C 56C GPM)
( 22.0 TPH)
70
-------
COMMONWEALTH EDISON: POWERTON 51 (CONT.I
EPA UTILITY F6D SURVEY: APRIL JUNE 1980
** TREATMENT
TYPE
CONTRACTOR
INLET- K6/S
INLET SOLIDS - X
** DISPOSAL
NATURE
TYPE
* DISPOSAL
NATURE
TYPE
LOCATION
CAPACITY - CU.M
POZ-0-TEC
IUCS
2C.6
35.0
FINAL
LANDFILL
INTERIM
POND
ON-SITE
( 2727 LB/MIN)
1CO.C ACRE-FT)
PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILI1ATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
U8T SYSTEM
5/8T SYSTEM
i/8p SYSTEM
720
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
INITIAL FGD SYSTEM OPERATIONS BEGAN IN APRIL. THE FGD SYSTEM IS CURRENTLY
OPERATING ON FLUEGAS 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 EXPECTED TO BE DECLARED COMMERCIAL UNTIL DEC-
EMBER 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 WILL PROVE LESS EXPENSIVE THAN FGD.
71
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198T
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY H/FGD - Mta
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 - *
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPF
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S03 DESIGN REMOVAL EFFICIENCY - X
PARTICIPATE 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
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
UNDERWOOD
NORTH DAKOTA
545.0
495.0
327.1
( 6258 BTU/LB)
COAL
LIGNITE
14556.
7.14
39.83
.63
.02
WET SCRUBBING
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
8/79
**/ **
54.00
X 99.50
.0
.0
OPEN
<***»*
FLYASH STABILIZATION
LINED POND
............ . ... ___pEBFORMANCE DATA_....._....._. __ ............
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8C SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
96.1
744
715
715
E/8C SYSTEM
DURING JANUARY TWO MODULES AT A TIME WERE TAKEN OFF-LINE FOR INSPECTION
AND CLEANING. SOME CRACKED NOZZLES AND PLUGGING PROBLEMS WERE FOUND
DURING THE INSPECTION.
SOME OUTAGE TIME DURING THE MONTH WAS CAUSED BY BOILER-RELATED PROBLEMS.
A BOILER TRIP WAS CAUSED BY A TURBINE MALFUNCTION.
AN HOUR OF OUTAGE TIME RESULTED FROM A LOSS OF POWER TO THE CONTROL
SYSTEM. AN ABNORMAL POWER DRUM LEVEL WAS ALSO ENCOUNTERED.
A THREE TO FOUR HOUR OUTAGE WAS SCHEDULED TO MAKE REPAIRS ON FGD EOUIPHENT.
100.C 99.9 696 695 695
72
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
COOPERATIVE POWER ASSOCIATION: COAL CREEK 1 (CONT.)
................._..____..-.-.-._PERFORMANCE DATA__>_.
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
x REMOVAL
SO? PART.
PEP BOILER FGO CAP.
HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
WHILE THE BOILER HAS OFF-LINE DUE TO ID FAN TROUBLE CAUSED BY ELECTRICAL
GROUNDING, TWO MODULES WERE TAKEN OFF LINE SO CALIBRATIONS COULD BE DONE.
3/80 SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
96.1
744 715
715
BOILER TRIPS OCCURRED THREE TIMES DURING THE MONTH.
TO THE CUT DOWN OF TRANSMISSION POWER.
ONE TRIP WAS DUE
THE FGD SYSTEM WAS DOWN WITH THE BOILER FOR FOUR HOURS TO CLEAN THE
FILTER ON THE BOILER STATOR COOLING PUMPS.
DURING MARCH STACK EMISSION TESTS WERE UNDERTAKEN.
WITH ONE MODULE DOWN DURING TESTING.
THE SYSTEM OPERATED
4/8* 11
12
13
14
SYSTEM
96.7
100.0
100.C
100.r
99.2
58.3
96.1
96.9
9«.9
87.2
100.P
100.0
100.C
100.0
100.0
21.4
30.0
35.6
35.6
30.6
720 264
220 26.2
** PROBLEMS/SOLUTIONS/COHMENTS
THE BOILER WAS OFF LINE FOR APPROXIMATELY 19 DAYS FOR THE ANNUAL UNIT OUT-
AGE.
5/8? 11
12
13
14
SYSTEM
88.3
79.3
91.9
91.2
87.7
68.8
18.6
79.6
35.5
5P.6
1CO.P
icc.r
1CC.O
1CC.O
1CC.O
35.6
9.3
39.8
17.7
25.3
744 372
188 28.2
** PROBLEMS/SOLUTIONS/COHMENTS
THE ANNUAL UNIT OUTAGE WAS COMPLETED IN THE BEGINNING OF THE MONTH. THERE
WERE PROBLEMS WITH BOILER STARTUP AFTER THIS OUTAGE CAUSING LOW OPERABILITY
OF THE FGD SYSTEM.
8/8P 11
12
13
14
SYSTEM
92.9
98.5
74.7
93.5
89.9
49.3
47.6
42.2
73.C
53.C
ID?. 0
1C0.1
1CO.C
100.C
1CO.C
49.2
47.5
42.1
72.8
52.9
720 718
381 58.5
* PROBLEMS/SOLUTIONS/COHMENTS
THERE WERE NO MAJOR PROBLEMS REPORTED DURING JUNE.
AND REPAIRS WERE DONE THROUGHOUT THE MONTH.
ROUTINE MAINTENANCE
73
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 3
DESIGN AND PERFORMANCE DATA fOR OPERATIONS. DOMESTIC FGO SYSTEMS
COHPANt NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
SET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MU
tET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - RW
** BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILER FLUE GAS FLOU - CU.M/S
FLUE GAS TEMPERATURE - C
STACK HEIGHT - H
STACK TOP DIAMETE" - M
DELHARVA POWER ft LIGHT
DELAWARE CITY
1
DELAWARE CITY
DELAWARE
E
129.
******
18C.O
er.o
( .301 LB/MHBTU)
<****** LE/MMETU)
60.0
HILEY STOKER
PULVERIZED COKE
BASE
10/56
417.63 ( 885000 ACFM)
215.6 ( 420 F)
152. < 500 FT)
6.1
< 20.0 FT)
** 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 - Z
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - Z
AVERAGE CHLORIDE CONTENT - Z
RANGE CHLORIDE CONTENT - Z
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROUAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
SOZ DESIGN REMOVAL EFFICIENCY - Z
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
LETTER OF INTENT SIGNED
STARTED PRELIMINAY DESIGN
»* FABRIC 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.K
** MECHANICAL COLLECTOR
NUMBER
TYPE
COKE
FLUID PETROLEUM COKE
32564. ( 1400C BTU/LB)
13500-14500
.50
.3-.7
.70
.5-1.2
7.JO
5-8
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY HCKEE
DAVY MCKEE
DAVY MCKEE
FULL SCALE
RETROFIT
- Z 90.00
9% 00
5/80
5/8G
4/80
1/78
9/77
8/76
1T/77
NONE
JOY WESTERN
X 95.7
1&4.3
54.4
.69
TUBULAR
ACFM)
( 130 F)
(***** IN-H20)
« .31 GR/SCF)
74
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
DELMARVA POWER & LIGHT: DELAWARE CITY 1 CCONT.)
SUPPLIER
PART1CULATE DESIGN REMOVAL EFFICIENCY -
** PARTICULATE 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
* ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ABSORBER - X
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PAHTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD- G/CU.M
PARTICULATE REMOVAL EFFICIENCY - X
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
** CENTRIFUGE
TYPE
* FANS
NUMBER
CONSTRUCTION MATERIALS
SERVICE - WET/DRY
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
WASH SYSTEM
PRESSURE DROP - KPA
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
MODE
SENSOR LOCATION
PRAT-DANIEL
92.0
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 ( 420 F)
315.0 ( 5000 GPM)
******* (***** IN-H20)
( 1.39 GR/SCF)
( .250 GR/SCF)
3.2
.6
81.5
3500.000
.0
TRAY TOWER
4/8P
DAVY MCKEE
4
20 x 20
REINFORCED
TILE
316L SS
101.0
103.82
54.4
25.
.2
.2
.0
3 5 CO
390
NONE
CARBON STEEL
DRY
139.21
NONE
CHEVRON
GE NORYL
HORIZONTAL
1
1
1.83
2.29
CONCRETE
220CC.O ACFM)
130 F)
400 GPM)
.10C GR/SCF)
.1CO GR/SCF)
( 2950CO ACFM)
< 6.0 FT)
( 7.5 FT)
INTERMITTANT SPRAYS
.1 < .3 IN-H20)
PH, SOLIDS, SP.G., £ONC.
AUTOMATIC
FEED BACK
GAS OUTLET, SOLUTION OUTLET
75
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE
DELNARVA POWER & LIGHT: DELAWARE CITY 1 (CONT.)
** PUMPS
SERVICE
NUMBER
* REHEATER
NUMBER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
* THICKENER
TYPE
** WATER LOOP
TYPE
** BYPRODUCTS
BYPRODUCT NATURE
BYPRODUCT QUANTITY - M T/H
BYPRODUCT (JUALITY - X
DISPOSITION
» TREATMENT
TYPE
** DISPOSAL
NATURE
TYPE
HOT AIR INJECTION
FUEL GAS
27.8 ( 50 F)
NONE
CLOSED
SULFURIC ACID
11.34 ( 12.5C TPH)
93.0
SALES AND INTERNAL USE
NEUTRALIZATION
FINAL
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM
6/8!? SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
INITIAL AND COMMERCIAL OPERATIONS BEGAN ON MAY 22i 1980.
WERE REPORTED DURING STARTUP.
NO MAJOR PROBLEMS
76
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD 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
6ROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MW
NET 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.M/S
FLUE GAS TEMPERATURE - c
STACK HEIGHT - M
STACK TOP DIAMETE" - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - 2
AVERAGE MOISTURE CONTENT - *
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - T
RANGE CHLORIDE CONTENT - X
* GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROWAW AY 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 - i
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
CONTRACT AWARDED
LETTER OF INTENT SIGNED
STARTED PRELIMINAY DESIGN
FABRIC 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
- X
DELMARVA POWER & LIGHT
DELAWARE CITY
2
DELAWARE CITY
DELAWARE
E
129.
.3PG LB/MMBTU)
*,*. LB/MMBTU)
6 *..'"
RILEY STOKER
PULVERIZED COKE
BASE
10/56
417.63 ( 8550C1' ACFM)
215.6 ( 420 F)
152. ( 500 FT)
6.1 { 20.0 FT)
COKE
FLUID PETROLEUM COKC
32564. ( 1400G BTU/LB)
1350C-14500
.5C
.3-.?
.70
.5-1.2
7.00
5-8
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
DAVY MCKEE
DAVY MCKEt
FULL SCALE
RETROFIT
90. OC
90.OC
5/60
5/SO
4/8n
1/78
9/77
8/76
10/77
NONE
JOY WESTERN
95.C
U4. 3
54.4
.69
TUBULAR
( 2210rO ACFM)
< 130 F)
(***«* IN-H20)
( .30 GR/SCF)
77
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1<56r
DELMARVA POWER & LIGHT: DELAWARE CITY 2 (CONT.)
SUPPLIER PRAT-DANIEL
PARTICULATE DESIGN REMOVAL EfFIClENCY - % 92.0
** PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER Of STAGES
SHELL MATERIAL
LINING MATERIAL
NUMBER OF NOZ7LES
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 - X
SOi INLET CONCENTRATION - PPM
S02 DESIGN REMOVAL EFFICIENCY - y,
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL "ATER1AL
BOILER LOAD/ABSORBER - %
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD- G/CU.M
PARTICULATE REMOVAL EFFICIENCY - 3!
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
* CENTRIFUGE
TYPE
»* FANS
NUMBER
CONSTRUCTION MATERIALS
SERVICE - hET/DRY
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
WASH SYSTEM
PRESSURE DROP - KPA
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNER
MODE
SENSOR LOCATION
VENTURI
AIRPOL
1
CARBON STEEL
GLASS FLAKE, ACID BRICK, CAROBRAX BRICK
1
OPEN PIPF WITH REFRAX TIP
1CC.O
139.2
215.6
315.0
3.2
.6
81.5
3501.000
( 295COO ACFM)
( 42G F)
< 5^00 GPM)
(***«* IN-H20)
( 1.39 6R/SCF)
( .S5C GR/SCF)
TRAY TOWER
4/8C
DAVY MCKEE
t>
2? X 20
REINFORCED CONCRETE
TILE
316L SS
100.0
1G3.82
54.4
25.
.2
.2
< 2200Cf ACFM)
( 130 F)
< 400 GPM)
( .100 GR/SCF)
< . 1Cf' GR/SCF)
35CO
39"
NONE
CARBON STEEL
DRY
139.21 <
NONE
3
CHEVRON
GE NORYL
HORIZONTAL
1
1
1.83
2.29
295000 ACFM)
( 6.0 FT)
( 7.5 FT)
INTERMITTANT SPRAYS
1 < .3 IN-H20)
PH, SOLIDS, SP.G., £ONC.
AUTOMATIC
FEED BACK
GAS OUTLET, SOLUTION OUTLET
-------
EPA UTILITY FGD SURVEY; APRIL - JUNE 198C
DELNARVA POWER & LIGHT: DELAWARE CITY 2 (CONT.)
** PUMPS
SERVICE
NUMBER
** REHEATER
NUMBER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
* THICKENER
TYPE
* WATER LOOP
TYPE
** BYPRODUCTS
BYPRODUCT NATURE
BYPRODUCT QUANTITY - M T/H
BYPRODUCT QUALITY - X
DISPOSITION
** TREATMENT
TYPE
* DISPOSAL
NATURE
TYPE
HOT AIR INJECTION
FUEL GAS
27.8 ( 50 F)
NONE
CLOSED
SULFURIC ACID
11.34 < 12.5C TPH)
93.0
SALES AND INTERNAL USE
NEUTRALIZATION
FINAL
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
% REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM
6/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
720
INITIAL AND COMMERCIAL OPERATIONS BEGAN ON MAY 22, 1980. NO MAJOR PROBLEMS
WERE REPORTED DURING STARTUP.
79
-------
EPA UTILITY FGD SURVEY: APRIL - JUNt
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY yO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** 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
DELMARVA POWER & LIGHT
DELAWARE CITY
DELAWARE CITY
DELAWARE
E
129.
180.0
60.0
60.0
RILEY STOKER
PULVERIZED COKE
BASE
10/54
417.63
215.6
152.
6.1
.300 LB/MKBTU)
»**** LB/MMBTU)
< 8850GO ACFM)
( 420 F)
< 500 FT)
< 20.0 FT)
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - %
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
RANGE MOISTURE CONTENT - Z
AVERAGE SULFUR CONTENT - 5!
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
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 PRELI"INAY DESIGN
** FABRIC 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
- X
- X
COKE
FLUID PETROLEUM COKE
32564. ( 14000 BTU/LB)
13500-14500
.5C
.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.OC
5/80
5/80
4/80
1/78
9/77
8/76
10/77
NONE
JOY WESTERN
95.0
104.3
54.4
.69
TUBULAR
< 221CCO ACFM)
< 130 F)
(**»** IN.-H20)
( .30 GR/SCF)
80
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
DELMARVA POWER 8 LIGHT: DELAWARE CITY 3 (COM.)
SUPPLIER PRAT-DANIEL
PARTICULATE DESIGN REMOVAL EFFICIENCY - X 92.C
** PARTICULATE 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 - %
** A3SORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
BOILER LOAD/ARSOREER - X
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LIQUID RECIRCULATION RATE - LITER/S
PARTICULATE INLET LOAD - G/CU.M
PARTICULATE OUTLET LOAD- G/CU.M
PARTICULATE REMOVAL EFFICIENCY - 5!
S02 INLET CONCENTRATION - PPM
S02 OUTLET CONTRATION - PPM
** CENTRIFUGE
TYPE
** FANS
NUMBER
CONSTRUCTION MATERIALS
SERVICE - WET/DRY
CAPACITY - CU.M/S
* VACUUM FILTER
TYPE
** MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION "ATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
DEPTH - M
HASH SYSTEM
PRESSURE DROP - KPA
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL MANNEP
MODE
SENSOR LOCATION
VENTUHI
AIRPOL
1
CARBON STEEL
GLASS FLAKE, ACID BRICK, CAROBRAX BRICK
1
OPEN PIPE WITH REFRA;X TIP
100.0
139.2 295000 ACFM)
215.6 420 F)
315.0 5000 GPM)
******* ***** JN-H20)
3.2 1.39 GR/SCF)
.6 .250 GR/SCF)
81.5
3500.000
.0
TRAY TOWER
4/80
DAVY HCKEE
4
20 X 20
REINFORCED CONCRETE
TILE
316L SS
100.0
1C3.82
54.4
25.
.2
.2
.0
35QO
39H
NONE
CARBON STEEL
DRY
139.21
NONE
CHEVRON
GE NORYL
HORIZONTAL
1
1
1.83
2.29
22CCOO ACFM)
130 F)
4QO GPM)
.100 GR/SCF)
.100 GR/SCF)
< 295000 ACFM)
< 6.0 FT)
< 7.5 FT)
1NTERM1TTANT SPRAYS
.1 « .3 IN-H20)
PH. SOLIDS, SP.G., CONC.
AUTOMATIC
FEED BACK
GAS OUTLET, SOLUTION OUTLET
81
-------
EPA UTILITY FGD SUPVEY: APRIL - JUNE 198"
DELMARVA POWER & LIGHT: DELAWARE CITY 3 (CONT.)
** PUWPS
SERVICE NUMBER
** REHEATER
NUMBER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
** THICKENER
TYPE
** WATER LOOP
TYPE
** BYPRODUCTS
BYPRODUCT NATURE
BYPRODUCT QUANTITY - H T/H
BYPRODUCT QUALITY - X
DISPOSITION
** TREATMENT
TYPE
» DISPOSAL
NATURE
TYPE
HOT AIR INJECTION
FUEL GAS
27.8 < 50 F)
NONE
CLOSED
( 12.50 TPH)
SULFURIC ACID
11.34
93.0
SALES AND INTERNAL USE
NEUTRALIZATION
FINAL
LINED POND
PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER fGD C»P.
SO? PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM
6/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
72C
INITIAL AND COMMERCIAL OPERATIONS BEGAN ON MAY 22, 1980. NO MAJOR PROBLEMS
HERE REPORTED DURING STARTUP.
82
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN «ND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
Vtl 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 - *
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 - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARF COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
DUQUESNE LIGHT
ELRAMA
1-4
ELRAMA
PENNSYLVANIA
510.0
475.0
510.0
COAL
( 11350 BTU/LB)
26400.
21.00
2.20
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
RETROFIT
3.5
10/75
10/75
83.00
99.00
25.0
1.0
OPEN
(**«** GPM)
POZ-0-TEC
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
12/79
in
2C1
3M
401
5"1
SYSTEM
100.0
100.0
100.0
88.1
100.0
ioc.:>
51.6
9!?. 9
100.0
68.6
100.0
100.0
100.0
100.0
96.1
84.4
100.0
100.0
48.5
85.5
100.0
64.5
100.0
98.7
744 7CO 587
** PROBLEMS/SOLUTIONS/COMMENTS
1/SC
101
2C1
301
95.3
87.1
84.6
THERE HAVE BEEN NO SCRUBBER-RELATED OUTAGES OVER THE SEPTEMBER THRU
DECEMBER PERIOD.
THE SLUDGE IS NOW BEING TRUCKED TO A REMOTE SITE 10 MILES AWAY CAUSING
OPERATING COSTS TO INCREASE.
THE NEW S02 MONITOR HAS PLUGGED ONLY ONCE SINCE OCTOBER AND HAS REQUIRED
ONLY 4 HOURS OF MAINTENANCE PER WEEK.
91.2
ICir.c
100.0
94.8
87.1
84.6
75.2
87.1
84.6
83
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
DUQUESNE LIGHT: ELRAMA 1-4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER IGD C*P.
SO? PART. HOURS HOURS HOURS FACTOR
401
5D1
SYSTEM
2/8C 101
201
301
401
501
SYSTEM
86.4
100.0
100.0
100.0
100. T
100.0
100.0
77.6
100.0
55.6
100.0
100.0
85.4
100.0
10". 0
100.0
56.8
100.0
77.1
100.0
100.0
100.0
100.0
1CO.O
1CC.O
64.0
1CO.C1
45.8
1CC.O
98.2
6C.5
96.6
100.0
7C.7
40. 2
92.0
744 613 528
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 WORMEN RECYCLE PUMPS HAVE NOW LOGGED 14,000 HOURS
3/80 101
2P1
301
401
501
SYSTEM
100.1
10C.O
73.7
100.0
78.1
100.1
10". 0
IQf.O
73.7
48.4
78.1
100.0
100.
73,
100,
78,
100.0
101.0
100.0
100.0
73.7
48.4
78.1
100.0
744
744
595
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH OF MARCH,
4/BC
101
201
301
401
501
SYSTEM
40.3
72.3
87.3
100.0
100.0
99.4
38.1
73.3
87.3
100.0
10P.O
99.4
41.0
72.3
87.3
100.C
100.0
1CQ.C
4P.O
72.3
87.3
10C.O
100.Q
99.4
72C 720
572
PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL THE 1C1 AND 2C1 RECYCLE PUMP IMPELLERS HAD TO BE REPLACED.
THIS CAUSED 8 HOURS OF OUTAGE TIME FOR THESE TWO MODULES. NO OTHER FGD
SYSTEM OUTAGES OCCURRED.
s/er
1P1
201
301
401
501
SYSTEM
100.0
40.1
94.1
90.3
96.8
100.0
100.0
37.1
89.C
71.2
96.8
98.5
10P.O
38.2
93.8
88 .?
96.8
100.0
37.1
89.0
71.2
96.8
98.5
744
744
586
PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE FGD SYSTEM WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH.
6/80 SYSTEM 72C
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOP THE MONTH OF JUNE.
84
-------
EPA UTILITY fGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DAT* FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
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
NEb/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL ST«RT-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
( 11535 BTU/LB)
DUQUESNE LIGHT
PHILLIPS
1-6
SOUTH HEIGHT
PENNSYLVANIA
A 08.0
373.0
4 08 . 0
COAL
BITUMINOUS
26830.
16.27
5.02
1.92
********
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
RETROFIT
3.4
7/73
** / * *
83.00
99.00
n
'-/
.0
OPEN
(***** GPM)
POZ-0-TEC
LANDFILL
...._ . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79
101
201
301
4C>1
SYSTEM
99
90
77
67
.0
.9
.7
.7
.1
100.
1CC.
100.
75.
0
0
0
0
c
100
90
81
68
.0
.0
.6
.2
.0
100
9C
77
67
.0
.0
.0
.0
.0
744 567 494
** PROBLEMS/SOLUTIONS/COMMENTS
1/80 101
301
401
SYSTEM
.0
98.1
100.^
97.6
73.9
PRESENTLY THE UTILITY HAS BEEN ADDING SODIUM THIOSULFATE TO THE LIME 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 QUALITY OF
THE WET SLUDGE.
100.0
ior.o
lor.o
89.0
.0
98.0
1CO.O
97.5
73.9
.0
93.3
99.0
96.0
72.0
744
634
536
85
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
DUQUESNE LIGHT: PHILLIPS 1-6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITt RELIABILITY UTILI2ATION
x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
Z/80
101
201
301
401
SYSTEM
13
91
86
94
71
.7
.6
.2
.2
.4
17
100
100
100
79
.3
.0
.0
.0
.3
13
91
66
94
71
.7
.7
.0
.0
.4
13
91
84
9T
70
.7
.7
.6
.5
.1
696 551 48?
** PROBLEMS/SOLUTIONS/COMMENTS
SODIUM THIOSULFATE ADDITION CONTINUED THROUGH THE FIRST OUARTER AND
MIST ELIMINATOR SCALING HAS BEEN SIGNIFICANTLY REDUCED. 2CQC-5COO HOURS
OF OPERATION HAVE BEEN LOGGED WITHOUT MIST ELIMINATOR SCALE UP. THE
UTILITY REPORTS THAT S02 REMOVAL EFFICIENCY HAS IMPROVED 32 DUE TO THIS
AS WELL. THE UTILITY IS LOOKING INTO THE ADDITION OF SODIUM THIOSULFATE
AT ELRAMA.
THE FAN RUBBER LINERS HAVE BEEN A CONTINUAL. PROBLEM. TWO WILL BE REPLACED
WITH INCONEL THE NEXT TIME THE RUBBER LINERS FAIL.
THE PHILLIPS FGD SYSTEM HAD A SYSTEM AVAILABILITY OF 71.8* FOR THE YEAR
1979.
3/80 101
301
401
SYSTEM
94.7
59.r;
48.4
95.4
6C.3
84. f
53.9
4C.3
95.3
54.7
94. C
56.8
43.8
99.8
73.6
84.C
53.9
4C.3
95.3
54.7
744
744
407
** PROBLEMS/SOLUTIONS/COMMENTS
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 HUE BOLTS ON THE ID FAN OF MODULE 201f
CAUSING THE MODULE TO COME OFF LINE FOR 11 DAYS.
THE RUBBER LINING ON THE ID 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
1P1
zn
301
401
SYSTEM
92.6
14.2
99.2
95.S
96.9
89.4
ir.o
99.0
94.6
73.3
92.4
1°.5
99.8
98.6
75.6
89.4
in.o
99. P
94.6
73.3
720 72C
527
** PROBLEMS/SOLUTIONS/COMMENTS
ON APRIL 5 MODULE 1P1 HAS TAKEN OFF LINE DUE TO ID FAN BEARING PROBLEMS.
LATER IN THE MONTH THE MODULE WAS SHUTDOWN DUE TO AN ID FAN INSTRUMENTATION
PRESSURE SWITCH PROBLEM.
TOWARDS THE LATTER PART OF APRIL, MODULE 2j1 WAS SHUTDOWN DUE TO ID FAN
BEARING PROBLEMS. THIS PROBLEM WAS CORRECTED BY BALANCING THE FAN.
MODULE 301 WAS REMOVED FROM OPERATION ON APRIL 11 DUE TO AN ID FAN MOTOR
MALFUNCTION.
5/80
101
201
301
401
SYSTEM
67.5
81.6
91.7
92.2
83.2
THE RECYCLE PUMP PACKING ON MODULE 401 NEEDED TO BE REPLACED DURING THE
MONTH.
53.9
69.0
73.1
75.9
68.0
62.3
78.9
89.8
90.6
80.2
53.9
69. 0
73.1
75.9
68.0
744
744
5C6
86
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
DUQUESNE LIGHT: PHILLIPS 1-6 (CONT.)
PERFORMANCE DATA -- ~
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION T REMOVAL PER BOILER FGD CAP.
S03 PART. HOURS HOURS HOURS FACTOR
** PROBLtMS/SOLUTlONS/COMMENTS
MODULE 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 ID FAN. THE MODULE WAS TAKEN OFF LINE FOR APPROXIMATELY TWO DAYS 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 WAS SHUTDOWN APPROXIMATELY 58 HOURS SO THAT THE ID FAN CONTROL
DAMPERS COULD BE INSPECTED.
6/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOP THE MONTH OF JUNE.
87
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBED
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
INDIANAPOLIS POWER & LIGHT
PETERSBURG
3
PETERSBURG
INDIANA
532.0
515.0
5 3 2. C
** 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 - 5!
** 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 SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
COAL
BITUMINOUS
25t;n4. ( 11750 BTU/LB)
3.25
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
2.4
12/77
12/77
85.00
99.30
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
55.6
( 882 GPM)
** TREATMENT
TYPE
** DISPOSAL
TYPE
POZ-0-TEC
LANDFILL
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
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/8C SYSTEM
5/8C SYSTEM
6/8H SYSTEM
DURING THE FIRST QUARTER 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 ACCOMOD*TE NECESSARY REPAIRS AND
REPLACEMENT OF THE BALLS.
BYPASS DAMPER FAILURES ALSO OCCURRED AND AffE REPORTED TO BE A CONTINUAL
PROBLEM. MODIFICATIONS WERE MADE TO THE GULLOTINE TYPE DAMPERS DURING
THE PERIOD.
720
744
720
88
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
INDIANAPOLIS POkiER g LIGHT: PETERSBURG 3
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAM?
PLANT NAME
UNIT NUMBER
CITY
STATE
&ROSS UNIT GENERATING CAPACITY - MW
SET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
KANSAS CITY POWER g LIGHT
HAWTHORN
3
KANSAS CITY
MISSOURI
90.P
85.0
90.0
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - f
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - %
** 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 WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
- X
( 98CF BTU/LB)
COAL
BITUMINOUS
22795.
11. r'0
.60
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
11/72
* */ * *
73.00
99.00
.0
.0
CLOSED
<***** GPM)
FLYASH STABILIZATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79
11/79
12/79
1/80
2/80
3/8C
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100
10C
100
100
10C
100
.0
.0
.0
.0
.0
.0
91.
38.
91.
93.
ICO.
1CO.
n
1
9
c
0
r>
744
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 100* OF THE TIME THE BOILER OPERATED. NO
PROBLEMS WERE ENCOUNTERED.
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
68.Q
60.0
66.0
72C
744
720
49C
446
475
90
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198C*
KANSAS CITY POWER g LIGHT: HAWTHORN 3 (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER f60 CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT 5 BOILER EXPERIENCED SUPERHEATER *ND ECONOMIZER LEAKS DURING THE
APRIL-JUNE PERIOD ACCOUNTING FOR THE LOW SCRUBBER UTILIZATION FIGURES.
91
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS 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 - 1
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 - 1
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
KANSAS CITY POWER 8 LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
90. G
85.0
9-.C
COAL
BITUMINOUS
22795. < 98rr BTU/LE)
11.00
.60
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.2
8/72
* */ * +
70.00
99.00
.0
.0
** HATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
(***** GPM)
»* TREATMENT
TYPE
** DISPOSAL
TYPE
FLYASH STABILIZATION
POND
. u PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79
11/79
12/79
1/80
2/8C
3/8?
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOI
100.
100.
100.
.UTIONS/COMME
0
0
0
NTS
91.0
38.1
91.9
.0
.0
.0
744
720
744
744
696
744
677
274
684
0
c
V-
677
274
684
0
0
0
THE UNIT REMAINED OFF LINE THROUGH THE FIRST QUARTER 198 . BECAUSE OF A
TURBINE GENERATOR OVERHAUL.
4/80 SYSTEM
65.0
720
468
92
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
KANSAS CITY POWER R LIGHT: HAWTHORN 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
LOW APRIL SCRUBBER UTILIZATION FIGURES OCCURRED BECAUSE THE BOILER WAS OUT
OF SERVICE FOR SCHEDULED MAINTENANCE DURING PART OF THE MONTH.
5/80 SYSTEM 90.0 744 670
6/8? SYSTEM 98.C 720 7C6
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO UNUSUAL FGD SYSTEM PROBLEMS OCCURRED DURING
MAY AND JUNE.
93
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198r
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
KANSAS CITY POWER 8 LIGHT
LA CYGNE
1
LA CYGNE
KANSAS
874.:...
szn.r
874.0
* 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 - V
** GENEPAL 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 - 2
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - *
ABSORBER SPARE COMPONENTS INDEX
»* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
- X
COAL
SUBBITUMINOUS
21913.
24.36
S.6C
5.39
.03
WET SCRUBBING
LIMESTONE
BABCOCK S WILCOX
NEW
2.7
2/73
6/73
80.CO
99.50
A
w>
.0
( 9421 ETU/LE)
CLOSED
72.3
( 1148 GPM)
** DISPOSAL
TYPE
UNLINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
744
THE BOILER WENT DOWN FOR AN OVERHAUL ON OCTOBER 19TH 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 NOVEMBER AND DECEMBER. SOME ITEMS
INCLUDED IN THE MAINTENANCE WERE:
THE INSTALLATION OF TWO NEW SPRAY HEADERS IN SIX OF THE MODULESt RE-
PLACEMENT OF THE ABSORBER SIDEWALLS, REPLACEMENT OF THE MODULE OUTLET
DUCTS AND DAMPERS, AND VARIOUS DUCTWORK PATCHING.
1/80 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
744
2/8C1 A
B
98.2
98.2
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.
84.1
58.3
95.7
92.9
2C.O
13.2
94
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
KANSAS CITY POWEP R LIGHT: LA CYGNE 1 (CONT.)
PERIOD MODULE
C
D
E
F
G
H
SYSTEM
AVAILABILITY
97.4
99.1
98.2
99.1
99.1
99.6
98.6
OPER ABILITY
66. 2
45.9
93.0
91.7
91.7
92.4
77.7
RELIABILITY UTILIZATION
89.7
92.3
97.3
97.3
97.3
97.3
95.3
U.9
10.3
21.0
20.7
20.7
20.8
17.5
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
696 157 122 1P.9
3/6"
4/8?
** PROBLEMS/SOLUTIONS/COMMENTS
THE TURBINE/GENfRATOR OVERHAUL WAS COMPLETED IN FEBRUARY AND THE BOILER
AND FGD SYSTEM RETURNED TO SERVICE ON FEBRUARY 20. THE FGD SYSTEM WAS
AVAILABLE FOR OPERATION MOST OF THE MONTH.
4.3
4.3
4.3
4.3
4.9
2.3
1.3
.0
3.1 744 32 23
A
B
C
D
E
F
G
H
SYSTEM
94.6
96.2
96.1
96.1
95.8
94.7
93.7
95.7
95.3
100.0
10?. 0
100.0
100.0
93.8
53.1
31.3
. r'
72.3
100.0
100.0
100. 0
1CO.O
100. 0
1CO.C
1GC.O
100.?
1.7
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS 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.
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."
97.-1
95.6
96.4
94.6
95.7
95.9
96.1
96.5
96.1
96.8
96.0
94.1
78.A
97.5
93.6
86.0
76.
68,
62.
.3
.4
.9
82.2
94.5
91.4
92.9
94.8
92.3
87.2
93.9
93.4
92.6
89.4
87.9
88.3
83.9
84.4
89.3
96.0
82.3
87.7
96.T
93.9
95.2
95.1
95.3
96.2
94.C
96.2
95.5
61.7
51.4
63.9
61.4
56.4
sr.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
720 472
388 37.6
744
700
614 49.9
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR FGD-RELATED PROBLEMS WERE REPORTED FOR THE MONTHS OF APRIL OR MAY,
6/80 SYSTEM 72C
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF JUNE.
95
-------
EPA UTILITY fGD SURVEY: APRIL - JUNE 198'
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY y/FGD - My
EQUIVALENT SCRUBBED CAPACITY - MU
KANSAS POyER & LIGHT
JEFFREY
1
WAMEGO
KANSAS
720.0
680.0
54T.Q
** 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
COAL
18899.
5.80
28.00
.32
.01
< 8125 BTU/LB)
GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - X
INITIAL STAPT-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 - L1TER/S
DISPOSAL
TYPE
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
NEW
8/78
* * / **
80.00
99.00
20.0
1.0
CLOSED
35.1
POND
( 557 GPM)
< . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD C»P.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM 100.C 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
1CP.C
67.7
744
696
744
5C4
5Q4
THE BOILER WENT OFF LINE FOR TEN DAYS IN MA.RCH FOR A SCHEDULED INSPECTION.
DURING THE BOILER OUTAGE GENERAL MAINTENANCE WAS PERFORMED ON THE FGD
SYSTEM. OTHER THAN THIS OUTAGE, THE FGD UNIT OPERATED 10CX OF THE TIME
IN MARCH.
4/80 SYSTEM
5/80 SYSTEM
6/er 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 FED SYSTEM OPERATED 100* OF THE
TIME.
96
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD 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
5ROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MH
EQUIVALENT SCRUBBED CAPACITY - My
** 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 - *
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - J
AVERAGE SULFUR CONTENT - Z
RANGE SULFUR CONTENT - 7
AVERAGE CHLORIDE CONTENT - »
RANGE CHLORIDE CONTENT - I
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROUAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
** fSP
NUMBER
TYPE
SUPPLIER
PARTICULATE DESIGN REMOVAL EFFICIENCY
FLUE GAS CAPACITY - CU.M/S
FLUE GAS TEMPERATURE - C
PARTICULATE OUTLET LOAD - G/CU.M
** PARTICULATE SCRUBBER
TYPE
** ABSORBER
TYPE
INITIAL START UP
SUPPLIER
** MIST ELIMINATOR
TYPE
KANSAS POWER & LIGHT
JEF FREY
2
UAM EGO
KANSAS
D
«*.*., (***.<
***.** (****<
LB/MMBTU)
LB/MMBTU)
700.0
680.0
490.0
PULVERIZED COAL
BASE
** / **
183.
COAL
18841.
5.80
28.00
.30
(******* ACFM)
<**** F)
( 600 FT)
(**»** FT)
( 810C BTU/LB)
7-8
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
BLACK & VEATCH
FULL SCALE
NEW
89.00
1/8S
4/gr
COLD SIDE
COMBUSTION ENGINEERING
- * 98.6
1327.9 <28HOCr ACFM)
139.4 < 283 F)
.07 ( .03 GR/SCF)
NONE
SPRAY TOWER
6/80
COMBUSTION ENGINEERING
CHEVRON
97
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
KANSAS POWER 8 LIGHT: JEFF.REY 2 (CONT.)
PUMPS
SERVICE NUMBER
«* REHEATER
TYPE BYPASS
* WATER LOOP
TYPE CLOSED
** TREATMENT
TYPE BOTTOM ASH STABILIZATION
** DISPOSAL
NATURE FINAL
TYPE LINED POND
LOCATION ON-SITE
TRANSPORTATION PUMPED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PE° BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
2/80 SYSTEM 496
5/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS AT JEFFREY 2 BEGAN IN JANUARY 19g ,. NO MAJOR PROBLEMS
HAVE BEEN ENCOUNTERED SINCE STARTUP.
4/Sr1 SYSTEM 7?C
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL THE SYSTEM WAS STILL IN THE SHAKEDOWN/DEBUGGING PHASE.
5/8? SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/89 SYSTEM 100.0 100.0 100.0 10C.O 72C 72C 720
* PROBLEMS/SOLUTIONS/COMMENTS
COMMERCIAL OPERATIONS BEGAN ON MAY 1, 1980. SINCE THEN THERE HAVE BEEN
NO PROBLEMS ENCOUNTERED WITH THE FGD SYSTEM. THE UNIT HAS OPERATED 1COX
OF THE TIME.
98
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY H/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 - *
** 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
PAHTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP HATER - L1TER/S
«* TREATMENT
TYPE
** DISPOSAL
TYPE
- 3!
KANSAS POWER 8 LIGHT
LAWRENCE
4
LAWRENCE
KANSAS
125.0
115.0
125.0
COAL
23260.
9.80
12.CO
.55
.03
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
( 1POCC BTU/LB)
1/76
t * / **
73.00
98.90
n
U
.0
CLOSED
(*****
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 SYSTEM
100.0
100.0
100.0
10C1.?
1CC.O
100. 0
744 744
696 696
744 744
744
696
744
** PROBLEMS/SOLUTIONS/COKMENTS
NO MAJOR PROBLEMS WERE REPORTED FOR THE LAWRENCE 4 SCRUBBER DURING
THE FIRST QUARTER 1980.
4/80 SYSTEM 100.0' 100.0
** PROBLEWS/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 WAS PERFORMED ON THE FGD
SYSTEM.
5/80 SYSTEM
6/8" SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
744 744
720 720
744
720
99
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
KANSAS POWER 8 LIGHT: LAWRENCE 4 (CONT.)
PERFORMANCE DATA ...
PERIOD MODULE AVAILABILITY OPERABILITY RFLIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED 100X OF THE TIME IN
MAY AND JUNE.
100
-------
EPA UTILITY FGD SURVEY: A.PRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
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
* 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
KANSAS POUER & LIGHT
LAURENCE
5
LAWRENCE
KANSAS
420.0
400.0
420.0
COAL
23260. ( 1rOCC BTU/LBJ
9.80
12.00
.55
.33
UET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
RETROFIT
11/71
* * / **
52.OC
X 98.90
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
(***** GPM)
TREATMENT
TYPE
FORCED OXIDATION
** DISPOSAL
TYPE
POND
..__ . __*.. 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
3/69 SYSTEM
10P.O
100.0
100.0
100.0
51.7
54.8
744 744
696 36C
744 408
744
360
408
** PROBLEMS/SOLUTIONS/COMMENTS
4/80 SYSTEM
5/8P SYSTEM
6/8T SYSTEM
100.0
100.C
100. n
THE LAWRENCE 5 SCRUBBER OPERATED WITHOUT ANY MAJOR PROBLEMS DURING THE
FIRST OUARTER 198C. THE BOILER WAS DOWN FROM MID-FEBRUARY TO MID-
MARCH FOR TURBINE REPAIRS, DURING WHICH TIME GENERAL SCRUBBER MAINTEN-
ANCE WAS PERFORMED.
10C.O
10C.O
10P.O
100.0
100.0
100.0
100.0
80.6
100.0
720
744
720
720
600
720
72(3
610
720
101
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198n
KANSAS POWER 8 LIGHT: LAURENCE 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
FGD
CAP.
I REMOVAL PER BOILER
S02 PART. HOURS HOURS HOURS FACTOR
PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS DOWN FOR SIX DAYS DURING MAY FOR A SCHEDULED INSPECTION .
DURING THIS TIME GENERAL MAINTENANCE WAS PERFORMED ON THE ^D SYbTtM.
OTHER THAN THIS TIME, THE FGD SYSTEM OPERATED 100* OF THE TIME DUKJNfa
THE APRIL-JUNE PERIOD.
102
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - «IH
EOUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTUR-E CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
KENTUCKY UTILITIES
GREEN RIVER
1-3
CENTRAL CITY
KENTUCKY
64.0
60.0
64.0
COAL
BITUMINOUS
25586.
13.40
12.10
4.00
< 11GOC BTU/LB)
** 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 INDF.X - X
ABSORBER SPARE COMPONENTS INDEX
- X
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
3.1
9/75
6/76
80.00
99.50
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
4.7
75 GPM)
** DISPOSAL
TYPE
LINED 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 SYSTEM
100.0
100.0
100.0
.0
r
.3
744
696
744
0
c
c
c
c
0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED OUT OF SERVICE DUE TO BOILER REPAIRS,
EXPECTED TO BE OPERATING IN MAY.
THE UNIT IS
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
100.0
100.0
100.0
.0
.n
.0
720
744
72C
** PROBLEMS/SOLUTIONS/COMMENTS
.C
.0
.c
THE FGD SYSTEM REMAINED OFF LINE DURING THE SECOND QUARTER 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.
103
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS 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
** 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 - Z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - UTER/S
LOUISVILLE GAS 8 ELfcCTRIC
CANE RUN
4
LOUISVILLE
KENTUCKY
188.0
175.0
188.0
COAL
BITUMINOUS
26749.
17.10
9.00
1.75
.04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
1.6
8/76
8/77
85.00
( 11500 BTU/LB)
- X
OPEN
6.3
( 100 GPM)
** DISPOSAL
TYPE LINED POND
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILI2ATION
1/80 SYSTEM 10r.C 95.6
2/8C SYSTEM 99.8 66.7
3/80 SYSTEM 8T.5 74.3
X REMOVAL PER
S02 PART. HOURS
744
696
744
BOILER
HOURS
711
465
687
FGD
HOURS
711
464
553
CAP.
FACTOR
PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED FOR THE FIRST QUARTER OF 1980
WITH EITHER THE BOILER OR THE FGD SYSTEM.
720 582
575
4/80 SYSTEM 99.n 95.3 95.8 79.9
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL SPRAY PUMP PROBLEMS CAUSED 7 HOURS OF OUTAGE TIME.
5/8(? SYSTEM 96.8 100.0 1CO.O 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 UNIT.
ONE DAY OF OUTAGE TIME IN MAY WAS CAUSED BY A LEAK IN A SPRAY PUMP
104
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198V
LOUISVILLE GAS g ELECTRIC: CANE RUN 4 (CONT.)
PERFORMANCE DATA "
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
SEAL.
SYSTEM .0 .0 .0 .0 72C 35C C
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE BOILER yAS ON RESERVE, IN WHICH TIME THE SCRUBBER DUCTWORK
AND LININGS WERE REPAIRED.
SOME OF THE MODULES WERE REPLACED WITH 316 SS DURING THE MONTH.
ALSO DURING THE DOWN TIME THE EXPANSION JOINT LOCATED AT THE DISCHARGE
OF THE BOOSTER PUMP WAS REPLACED.
105
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198?
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
5ROSS UNIT GENERATING CAPACITY - KW
UET 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 - Z
AVERAGE CHLORIDE CONTENT - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN RE"OVAL 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 g ELECTRIC
CANE RUN
5
LOUISVILLE
KENTUCKY
200.0
192.0
2CO.O
( 115CC BTU/LB)
COAL
BITUMINOUS
26749.
17.10
9.00
3.75
.04
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
1.5
12/77
7/78
85.00
99.00
.0
.0
OPEN
<«.*..
POZ-0-TEC
LINED POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/BT SYSTEM 92.1 72.2 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY NO OPERATIONAL PROBLEMS WERE ENCOUNTERED.
2/80 SYSTEM 71.9 49.7 696
3/8C SYSTEM 44.5 27.2 744
** PROBLEMS/SOLUTIONS/COMMENTS
583
481
454
537
346
2C2
IN FEBRUARY THE UTILITY RAN OUT OF CARBIDE LIME CAUSING INTERRUPTION OF
THE FGD SYSTEM OPERATION. THE UNAVAILABILITY OF LIME WAS CAUSED BY FREEZE
UPS ENCOUNTERED BY AIRCO, THE LIME SUPPLIER.
REHEATER TUBE PROBLEMS WERE ALSO ENCOUNTERED IN FEBRUARY AND CONTINUED
THROUGH MARCH. THE UTILITY HOPES TO REPLACE THE TUBE BUNDLES IN THE
SUMMER.
4/80 SYSTEM
.C
.0
720
106
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
LOUISVILLE GAS & ELECTRIC: CANE RUN 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OFF LINE THE ENTIRE MONTH OF APRIL TO INSTALL
STAINLESS STEEL IN THE DUCTWORK AND IN THE MODULES.
5/8? SYSTEM 95.3 94.5 94.5 80.2 744 632 597
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY ONE DAY OF OUTAGE TIME HAS NECESSARY TO COMPLETE THE INSTALLA-
TION OF THE STAINLESS STEEL IN THE DUCTWORK AND MODULES.
A PUMP SEAL ON THE RECIRCULAT I ON PUMP FAILED CAUSING APPROXIMATELY 1C
HOURS OF OUTAGE TIME.
6/80 SYSTEM 78.8 74.4 74.4 61.8 7?C 598 445
** 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.
107
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 3
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
MET UNIT GENERATING CAPACITY U/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 - X
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SO? DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
LOUISVILLE GAS 8 ELECTRIC
CANE RUN
6
LOUISVILLE
KENTUCKY
299.0
2T>. C
299.C
( 110CC BTU/LB)
COAL
BITUMINOUS
255S6.
17.1C
9.0C
4.8C
WET SCRUBBING
DUAL ALKALI
ADL/COMBUSTION EQUIP ASSOCIATE
RETROFIT
1.0
4/79
* * / * *
95.00
99.00
20.0
.3
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
(*.*,. 6PM)
** DISPOSAL
TYPE
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 49.0
** PROBLtMS/SOLUTIONS/COMMENTS
13.8
744
210
1C3
FGD SYSTEM OUTAGE TIME IN JANUARY UAS CAUSED BY A THICKENER FAILURE.
THE RAKE BECAME INOPERABLE AND THE THICKENER HAD TO 8E CLEANED OUT.
2/80 SYSTEM 84.7
3/80 SYSTEM 99.9 70.0
** PROBLEMS/SOLUTIONS/COMMENTS
99.8
47.C
64.;
696 386
744 686
327
480
IN FEBRUARY AND MARCH OUTAGE TIME UAS CAUSED BY PROBLEMS WITH THE RECYCLE
PUMPS.
4/BC SYSTEM 98>8 91.6
** PROBLEMS/SOLUTIONS/COMMENTS
97.7
73.8
720 580
531
DURING AN APRIL BOILER OUTAGE THE SCRUBBER TRAYS WERE CLEANED.
(THIS WAS CONSIDERED A FORCED OUTAGE BECAUSE TH£ UNIT WOULD HAVE HAD TO
COME OFF LINE SHORTLY FOR CLEANING).
S/S'1 SYSTEM
99.6
99.9
99.9
99.5
744
741
740
108
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
LOUISVILLE GAS 8 ELECTRIC: CANE RUN 6 (CONT.)
..i _ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 5! REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE PRESSURE RELIEF VALVE ON TH£ BOOSTER FAN MALFUNCTIONED
FORCING THE FGD SYSTE"" OUT OF SERVICE.
5/8H SYSTEM 99.9 99.8 99.9 88.9 7?0 641 640
** PROBLE*S/SOLUTIONS/COMMENTS
A SPRAY PUMP MALFUNCTION CAUSED THE SYSTEM TO SHUTDOWN. APPROXIMATELY
ONE HOUR WAS NEEDED TO PUT THE SPARE INTO SERVICE.
BOILER TUBES FAILURES WERE ALSO NOTED DURING JUNE.
109
-------
EPA UTILITY FGO SUPVEY: APRIL - JUNE 1980
SECTION 3
DESIGN »ND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - PW
EQUIVALENT SCRUBBED CAPACITY - MW
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTfNT - J/G
AVERAGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 7,
* 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 - 2
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - 1
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
LOUISVILLE GAS fc ELECTRIC
MILL CREEK
3
LOUISVILLE
KENTUCKY
442.H
420.0
442.'"
COAL
BITUMINOUS
26749.
11.50
5.75
.04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
1.6
8/78
3/79
65.00
99.CO
< 1150C' BTU/LB)
OPEN
9.4
< 15C GPM)
FLYASH/LIME STABIL11ATI ON
POND
' PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER fGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8f
2/8"
3/8C
SYSTEM
SYSTEM
SYSTEM
36
36
.1
.9
26
30
.0
.6
.6
744
696
744
r-
C
512
618
B
185
228
4/80 SYSTEM
THE UNIT CAME BACK ON LINE ON FEBRUARY 10 AFTER THE TURBINE OVERHAUL
WORK WAS COMPLETED.
PROBLEMS ENCOUNTERED DURING FEBRUARY AND MA,RCH WITH THE FGD SYSTEM
OPERATION INCLUDED FROZEN WATER LINES AND WORN GASKETS BLOWING IN THE
REHEATER FLANGES.
THE UTILITY IS IN THE PROCESS OF REPLACING THE REHEATER TUBES.
42.5 42.5 42.2 720 715 304
110
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198i
LOUISVILLE GAS e. ELECTRIC: MILL CREEK 3 (CONT.)
PERFORMANCE DATA-'
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION X REMOVAL PER BOILE" FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUT10NS/COMMENTS
THE REHEATER TUBE REPLACEMENT CONTINUED INTO APRIL.
THE OTHER OUTAGE TIME ENCOUNTERED DURING APRIL WAS CAUSED BY A BLOWN
GASKET IN THE CONDENSATE PUMP.
5/8T SYSTEM 67.5 51.4 51.4 34.4 744 498 256
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE PLASTIC MIST ELIMINATOR COMPONENTS WERE REPLACED UITH
STAINLESS STEEL. THIS KEPT THE SYSTEM OFF LINE FOR APPROXIMATELY 10 DAYS.
REHEATER TUBE LEAKS WERE ALSO ENCOUNTERED IN MAY.
6/8" SYSTEM 88.? .0 ,T .0 720 85 0
** PROBLEMS/SOLUTIONS/COMMENTS
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.
111
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198s"
SECTION 3
DFSIGN »ND PERFORMANCE DA^A FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
5ROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD -
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DAT«
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 7,
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - T
LOUISVILLE GAS & ELECTRIC
PADDY'S PUN
6
LOUISVILLE
KENTUCKY
7 2. C
67.'"
72.C
COAL
BITUMINOUS
26749.
11.50
2.5C
( 1150v PTU/LE)
** 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 - %
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
WET SCRUFBING
LIME
COMBUSTION ENGINEERING
RETROFIT
2.S
4/73
** / * *
90.OC
99.1C
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
( 5C GPM)
** TREATMENT
TYPE
* DISPOSAL
TYPE
LIME STABILIZATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD C»P.
S02 PART. HOURS HOURS HOURS FACTOR
1/8 r SYSTEM
2/BT SYSTEM
3/6" SYSTEM
.0
.0
.0
744
696
744
C
0
C
C
0
0
** PROBLEMS/SOLUTIONS/COMMENTS
THIS UNIT DID NOT OPERATE DURING THE FIRST OUARTER 1980 DUE TO A LACK OF
DEMAND. PADDY'S RUN 6 IS USED AS A PEAKING UNIT AND WILL BE RETIRED
SOMETIME IN 1987.
4/80 SYSTEM 100." .C
»* PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
720
DURING APRIL THE FGO SYSTEM WAS AVAILABLE 10CX OF THE TIME BUT WAS NOT
OPERATED DUE TO A BOILER RELATED PROBLEM.
5/Sf
SYSTEM
10S.'"
86.6
86.6
7.8
744
67
58
112
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C'
LOUISVILLE GAS & ELECTRIC: PADDY'S RUN 6 (CONT.)
- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
»* PROBLEMS/SOLUTIONS/COMWENTS
DURING MAY 9 HOURS OF OUTAGE TIME RESULTED FROM THE UNAVAILABLITY OF
THE LIME SLURRY.
6/8" SYSTEM 100.0 94.1 94.1 6.7 7ZC 51 48
** PROBLEMS/SOLUTIONS/COMMENTS
THE 3 HOURS THE SCRUBBERS DID NOT OPEPATE IN JUNE yAS DUE TO THE FACT
THAT THE BOILER WAS BROUGHT ON LINE BEFORE THE SCRUBBER OPERATORS WERE
ON DUTY.
113
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198r
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD 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
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY y/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MM
MINNESOTA POWER 8 LIGHT
CLAY BOSWELL
4
COHASSET
MINNESOTA
B
43. < .101' LB/MMBTU)
516. ( 1.2CC LB/MMBTU)
100:.o
554.0
504.0
511.0
4 7 5 . :
** 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
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
2/80
1086.4C
148.9
183.
11.3
(2302181 ACFM)
( 300 F)
( 600 FT)
< 37.0 FT)
** 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 - 5!
RANGE MOISTURE CONTENT - 5!
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
COAL
SUBBITUMINOUS
19376.
9.40
4.81 - 15.99
24. 5 0
20.30 - 28.31
.94
C - 4.55
.01
: - ".07
< 8287 BTU/LB)
75C9 - 9923
** GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROW AWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
CONSTRUCTION FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
CONSTRUCTION COMPLETION
CONSTRUCTION INITIATION
LETTER OF INTENT SIGNED
STARTED REQUESTING BIDS
STARTED PRELIMINAY 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
** PARTICULATE SCRUBBER
NUMBER
TYPE
SUPPLIER
NUMBER OF STAGES
THROWAWAY PRODUCT
WET SCRUBBING
LIME/ALKALINE FLYASH
N/A
PEABODY PROCESS SYSTEMS
EBASCO
PEABODY PROCESS SYSTEMS
FULL SCALE
NEW
- X 99.73
84.60
4/80
2/80
5/78
2/77
4/76
6/75
HOT SIDE
JOY
- X 99.7
94.4
398.9
.07
< 2COOOO ACFM)
< 750 F)
(*»*** IN-N20)
( .03 6R/SCF)
RADIAL VENTURI VARIABLE THROAT
PEABODY PROCESS SYSTEMS
1
114
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
MINNESOTA POWER g LIGHT: CLAY BOSWELL 4 (CONT.)
SHELL MATERIAL
LINING MATERIAL
INTERNAL 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
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
PARTICULATE INLET LOAD - NG/J
PARTICULATE OUTLET LOAD - NG/J
PARTICULATE DESIGN REMOVAL EFFICIENCY -
S02 INLET CONCENTRATION - NG/J
S02 DESIGN REMOVAL EFFICIENCY - X
«* ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
DIMENSIONS - FT
SHELL MATERIAL
SHELL LINER MATERIAL
INTERNAL MATERIAL
NUMBER OF NOZZLES
NOZZLE TYPE
BOILER LOAD/ABSORBER - X
GAS FLOW - CU.M/S
GAS TEMPERATURE - C
LIOUID RECIRCULATION RATE - LITER/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
S02 OUTLET CONTRATION - PPM
S02 OUTLET CONCENTRATION- NG/J
S02 OUTLET CONCENTRATION- NG/J
S02 DESIGN REMOVAL EFFICIENCY - X
ABSORBS" SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENT INDEX
** FANS
NUMBER
TYPE
CONSTRUCTION MATERIALS
SERVICE - WET/DRY
CAPACITY - CU.M/S
** MIST ELIMINATOR
TYPE
** MIST ELIMINATOR
TYPE
** MIST ELIMINATOR
NUMBER
TYPE
CONSTRUCTION MATERIAL
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES
FREEBOARD DISTANCE - M
DEPTH - M
VANE SPACING - CM
VANE ANGLES
HASH SYSTEM
SUPERFICIAL GAS VELOCITY - M/S
PRESSURE DROP - KPA
** PROCESS CONTROL CHEMISTRY
CONTROL VARIABLES
CONTROL RANGE
STAINLESS STEEL
RUBBER
STAINLESS STEEL
13
TANGENTIAL AND BULL NOZZLES
33.3
394.4
148.9
841.7
2.7
5159.
43.
99.7
275?.
89.0
( 83584C ACFM)
< 300 F)
(13360 GPM)
(20.0 GAL/10CCACF)
(***** IN-H20)
(12.000 LB/MMBTU)
( .100 LB/MMBTU)
( 6.400 LB/MMBTU)
VENTURI/SPRAY TOWER
5/80
PEABODY PROCESS SYSTEMS
4
DIA 35' HT 60'
STAINLESS STEEL
RUBBER AND GLASS REINFORCED POLYESTER
STAINLESS STEEL, CARBON STEEL 8 RUBBER LINED
24
REFRAX NOZZLES
33.3
302.08 ( 640130 ACFM)
53.3 ( 128 F)
2104. (334QP GPM)
6.7 ( 5T.C GAL/1000ACF)
5.0 (20.0 IN-H20)
3.7 ( 12.0 FT/S)
.1 ( .03C GR/SCF)
43. ( . 1Ct' LB/MMBTU)
.1 ( .33C GR/SCF)
43. ( .10C LB/MMBTU)
345
(***** LB/MMBTU)
(***** LB/MMBTU)
89.0
33.Q
1.0
CENTRIFUGAL RADIAL TIP
INCONEL 625 8 INCOL1 825
WET
32fl.33 ( 678800 ACFM)
RADIAL VANE
SIEVE TRAY
CHEVRON
NORVL
HORIZONTAL
1
3
1.52
.30
3.5
< 5
( 1
0 FT)
0 FT)
( 1.38 IN)
90
HOSE CONNECTION TO HEADER FOR MANUAL WASH
3.4 ( 11.0 FT/S)
.0 < .0 IN-H20)
PH-DENSITY IN RECYCLE TANKS
5-6 PH; 7-9X DENSITY
115
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 19&r
MINNESOTA POWER 8 LIGHT: CLAY BOSWELL 4 (CONT.)
CONTROL MANNER
MODE
SENSOR LOCATION
** PUMPS
SERVICE
ALKALI FEED
FLY ASH SLURRY FEED
VENTURI RECYCLE
ABSORBER RECYCLE
WASH WATER
QUEACH BOOSTER
AUTOMATIC
FEED BACK
RECYCLE TANKS
NUMBER
** TANKS
SERVICE
RECYCLE
ALKALI STORAGE
IASH WATER
FLY ASH STORAGE
»* REHEATER
NUMBER
TYPE
HEATING MEDIUM
TEMPERATURE BOOST - C
** WATER LOOP
TYPE
EVAPORATOR WATER LOSS - LITER/S
RECOVERED UATfR RETURN - LITER/S
FRESH MAKEUP WATER ADDITION - LITEHS/S
REAGENT PREPARATION EQUIPMENT
NUMBER OF STORAGE HOPPERS
NUMBER OF SLAKERS
SLAKER CAPACITY - M T/H
REAGENT PRODUCT - X SLURRY SOLIDS
POINT OF ADDITION
** DISPOSAL
NATURE
TYPE
LOCATION
TRANSPORTATION
DIMENSIONS
AREA - ACRES
CAPACITY - CU.M
NUMBER
4
1
1
1
4
BYPASS
HOT FLUE GAS FROW ESP
14.4 ( 26 F)
CLOSED
23.9
183.1
56.4
5
4
.4
20. a
RECYCLE TANKS
( 380 GPM)
< 2985 GPM)
( 895 GPM)
.4 TPH)
FINAL
LINED POND
1 MILE WNW OF UNIT
PIPE
4000 X 3000 FT
3CO.O
9556522 < 78U.O ACRE-FT)
... _ . . -PERFORMANCE DATA _._._._.........................
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
THE BOILER BEGAN OPERATIONS ON FEBRUARY 26, 1980 AND FIRED OIL THROUGH THE
MONTH OF MARCH. INITIAL FGD SYSTEM OPERATIONS BEGAN IN EARLY APRIL WITH
THE BOILER FIRING COAL FOR TESTING PURPOSES. THE UNIT WAS SHUTDOWN IN
MID-APRIL TO RECTIFY MINOR SHAKEDOWN PROBLEMS. A TRIAL RUN OF THE FGD
SYSTEM IN AN INTEGRATED MODE OCCURRED IN LA.TE APRIL.
5/8H SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
720
SHAKEDOWN OPERATIONS CONTINUED THROUGH THE SECOND 8UARTER OF 1980. THE
FGD SYSTEM WILL BE FINE TUNED TO MEET DESK3N CRITERIA THROUGH JULY. TO
DATE THE UTILITY REPORTED THAT, ALTHOUGH MA.NY TYPICAL STARTUP PROBLEMS
116
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
HINNESOT* POWER g LIGHT: CLAY BOSWELL 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
ATTRIBUTABLE TO OPERATOR ERROR AS WELL AS MECHANICAL MALFUNCTIONS HAVE
OCCURRED, NO UNUSUAL PROBLEMS HAVE OCCURRED. THE COMPLIANCE TEST IS
SCHEDULED FOR EARLY SEPTEMBER.
117
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
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 - I
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
PAHTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
MINNKOTA POWER COOPERATIVE
MILTON R. YOUNG
2
CENTER
NORTH DAKOTA
4 4 ?>.;>
402.C
18 5 . D
( 6500 BTU/LB)
COAL
LIGNITE
15119.
6.50
38.00
.70
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
1.6
9/77
6/78
75.00
99.60
1CO.O
1.0
CLOSED
44.1
< 700 GPM)
DISPOSAL
TYPE
MINEFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
1/80
A
B
SYSTEM
67.7
67.7
7.1
10.5
.0
10.5
10.5
7.1
.0
7.1
744
504
27
PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE COLD WEATHER CAUSED SOMt PIPE LINES AND THE BOOSTER
FAN TO FREEZE.
A HIGH PERCENTAGE OF COARSE SOLIDS IN THE THICKENER CAUSED SOME OUTAGE
TIME. THE WORM GEAR ON THE THICKENER FAIUED ADDING TO THE OUTAGE TIME.
2/80 A
B
SYSTEM
.0
.0
.0
.0
.0
.0
696
696
PROBLEMS/SOLUTIONS/COMMENTS
PROBLEMS RELATED TO THE COLD WEATHER CONTINUED THROUGH FEBRUARY. ICE
ON THE BOOSTER FAN HAD TO BE MELTED.
SHAFT SLEEVES ON SEVERAL SPRAY RECYCLE PUMPS WERE REPLACED.
THE GEAR REDUCER FAILED ON THE B-SIDE ABSORBER AGITATOR CAUSING PROBLEMS.
118
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
HINNKOTA POWER COOPERATIVE: MILTON R. YOUNG ? (CONT.)
PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
3/&C
5/80
THE ISOLATION DAMPER CHAINS BROKE DURING THE MONTH.
A
B
SYSTEM
28.9
28."
28.9
23.6
6.2
2S.8
22.6
6.2
28.8
28.8
** PROBLtMS/SOLUTIONS/COMPENTS
DURING MARCH COLD WEATHER CONTINUED TO BE
744
743
1C7
PROBLEM.
THE TORQUE SWITCHES ON THE ISOLATION DAMPERS WERE REPLACED.
PROBLEMS CAUSED THE BOOSTER FAN TO TRIP.
THE DAMPER
AN EXCESSIVE AMOUNT OF COARSE PARTICLES IN THE THICKENER CONTINUED TO BF
A PROBLEM. PLUGGED BLEED LINES FROM THE ABSORBER TO THE THICKENER WERE
ALSO ENCOUNTERED.
THE A-SIDE ABSORBER AGITATOR EXPERIENCED A PROBLEM WITH THE ANCHOR BOLTS
SHEARING.
THE SHAFT SLEEVES ON THE SPRAY RECYCLE PUMPS WOULD NOT HOLD THE PACKING
SO THEY HAD TO BE REPLACED IN MARCH.
4/80 A
B
SYSTEM
1CO.O
r
.0
PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
.0
.0
.0
.0
.c
.0
720
154
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 FGD 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 NOZZLES PIPING,
AND THE RECYCLE HEADER.
THE VALVES ON BOTH THE SPRAY RECYCLE PUMP A)N D THE DISCHARGE SPRAY CYCLE
PUMP WERE REPAIRED.
THE ABSORBER LINING HAS STARTED TO WEAR AND IS NOW BEING REPAIRED.
LARGE SOLIDS PLUGGED THE THICKNER LINES. 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.
5/80 A
B
SYSTEM
100.0
41.8
41.8
.0
40.4
4C.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.
PROBLEMS WITH THE RAKE MECHANISM AND THE LIMIT SWITCH.
HIGH SOLIDS CAUSED
119
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
1INNKOTA POWER COOPERATIVE: MILTON R. YOUNG ? (CONT.)
PERFORMANCE DATA .......... .
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
TROUBLE WAS ENCOUNTERED DURING JUNE WITH THE VACUUM FILTER.
THE REPAIR WORK CONTINUED ON THE ABSORBER FLAKE LINING.
120
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198G
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET 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 - *
"* 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
MONONGAHELA POWER
PLEASANTS
1
BELMONT
WEST VIRGINIA
618.0
580.0
618.f
COAL
BITUMINOUS
27912.
15.00
3.70
WET SCRUBBING
LIME
BABCOCK 8 WILCOX
NEW
< 1200C BTU/LB)
3/79
**/ **
90.00
X 99.55
.0
.0
CLOSED
<****. GPM)
... ._ . _ -PERFORMANCE DATA ... ..... .....
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
5/80 SYSTEM
»* PROBLEMS/SOLUTIONS/COMMENTS
744
690
744
NO INFORMATION WAS AVAILABLE ON THE OPERATIONS AT PLEASANTS 1 FOR THE
FIRST QUARTER 1980.
4/80 SYSTEM 720
5/8C SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION HAS UNAVAILABLE FOR THE SECOND QUARTER 1980 REPORT PERIOD.
121
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198n
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 31
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - *
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
302 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
< 8843 BTU/LB)
MONTANA POWER
COLSTRIP
1
COLSTRIP
MONTANA
360.0
332.0
360.0
COAL
SUBBITUMINOUS
20569.
8.60
23.90
.77
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
9/75
11/75
60.00
99.5G
20.0
.5
CLOSED
23.3
POND
( 370 GPM)
k. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79
1/80
2/80
3/8"
SYSTEM
SYSTEM
SYSTEM
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 FGD SYSTEM
PROBLEMS REPORTED DURING THE FIRST QUARTER OF 1980.
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD WAS NOT AVAILABLE.
720
744
720
122
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
5ROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY W/FGD - 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 - Z
* 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 - X
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
- X
C 8343 8TU/LB)
MONTANA POWER
COLSTRIP
2
COLSTRIP
MONTANA
360.0
332.0
363.0
COAL
SUBBITUMINOUS
20569.
8.60
23.90
.77
.01
WET SCRUBBING
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
NEW
3.3
5/76
10/76
60.00
99.50
2C.O
.5
CLOSED
23.3
POND
( 370 GPM)
_ 1. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79
1/80
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
95.8
92.7
98.1
98.2
744
744
696
744
** PROBLEMS/SOLUTIONS/COMMENTS
TOTAL SYSTEM AVAILABILITY CONTINUES TO BE HIGH WITH NO MAJOR PROBLEMS
REPORTED WITH THE FGD SYSTEM FOR THE FIRST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD WAS NOT AVAILABLE.
123
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198?
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/fGD - WU
EOUIVALENT 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 WATER - LITER/S
* DISPOSAL
TYPE
NEVADA POWER
REID GARDNER
1
MOAPA
NEVADA
125.0
110.0
125.0
COAL
BITUMINOUS
28959.
8.00
5.50
.50
.05
WET SCRUBBING
SODIUM CARBONATE
AOL/COMBUSTION EOUIP ASSOCIATE
RETROFIT
( 1245C BTU/LB)
4/74
**/ **
9?.00
X 97.00
.0
.0
CLOSED
9.8
LINED POND
< 155 GPM)
PERFORMANCE DATA «
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND FGD SYSTEM OPERATED THE ENTIRE MONTH WITH NO OUTAGES.
2/80 SYSTEM 100.0 lor.C 100.0 100.0 696 696 696
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY, NO OUTAGES OCCURRED.
3/80 SYSTEM 66.2 83.7 84.7 33.8 744 300 251
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST OF MARCH THE FGD SYSTEM WAS OFF LINE FOR A SCHEDULED
OVERHAUL.
THE FGO UNIT WAS FORCED OUT OF SERVICE ONC£ TO REPAIR THE VENTURI PUMP
AND SIX OTHER TIMES DUE TO LOW VENTURI FLOW.
4/80 SYSTEM
97.2
96.7
96.7
81.0
720 603 583
124
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
NEVADA POWER: P£ID GARDNER 1
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mw
*ET UNIT GENERATING CAPACITY U/FGD -
EQUIVALENT SCRUBBED CAPACITY - «"U
NEVADA POWER
REID GARDNER
2
MOAPA
NEVADA
1 25. C
110.0
125.:;
»* FUEL DATP
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
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 - 1
ABSORBER SPARE COMPONENTS INDEX
«* WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* DISPOSAL
TYPE
- X
COAL
BITUMINOUS
28959. ( 1245^ BTU/LB)
s..:c
5.5C
.50
.35
WET SCRUBBING
SODIUM CARBONATE
ADL/COMBUSTION EOUIP ASSOCIATE
RETROFIT
4/ 74
* * / * *
9"!. 00
97.00
.C
.0
CLOSED
9.8
LINED POND
( 155 GPM)
1. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 97.3 96.9
** PROBLEMS/SOLUTIONS/COMMENTS
96 .9
81.6
627
6C7
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 WERE 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 10
FAN DAMPER CONTROLS.
2/8C SYSTEM 97.0 97.0
** PROBLEMS/SOLUTIONS/COMMENTS
97.0
97.0
696
696
675
THE SCRUBBER WAS TAKEN OFF-LINE TWICE DURING 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 TWICE, CAUSING APPROX-
126
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
NEVADA POWER: REID GARDNER 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
IMATELY 4 HOURS OUTAGE TIME.
THE DISCHARGE VALVE ON THE VENTURI RECYCLE PUMP HAS REPLACED DURING
FEBRUARY.
REPAIRS WERE MADE 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 MADE.
3/85 SYSTEM 97.5 97.5 97.5 97.5 744 744 725
* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THF SCRUBBER UAS 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.
LOU VENTURI FLOW ALSO WAS A PROBLEM DURING MARCH.
4/8n SYSTEM 99." 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 4C HOURS DUE TO BOILER TUBE LEAKS.
5/80 SYSTEM 93.3 85.5 68.1 14.2 744 124 106
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD OVERHAUL WAS COMPLETED EARLY IN MAY.
A BOILER OVERHAUL WAS STARTED AND COMPLETED DURING MAY. THIS OUTAGE LASTED
ALMOST 23 DAYS.
6/8C SYSTEM 99.6 97.5 99.5 75.2 720 541 528
** PROBLEMS/SOLUTIONS/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.
127
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C1
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY y/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
NEy/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARF CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP UATER - LITER/S
* DISPOSAL
TYPE
- X
NEVADA POWER
REID GARDNER
3
MOAPA
NEVADA
125.0
110.0
125.C
COAL
BITUMINOUS
28959.
8.00
9.00
.50
.05
MET SCRUBBING
SODIUM CARBONATE
AOL/COMBUSTION E8UIP ASSOCIATE
NEW
< 12450 BTU/LB)
6/76
7/76
85.00
99.00
.0
.0
CLOSED
9.8
LINED POND
< 155 GPM)
. _PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 100.0 99.7
** PROBLEMS/SOLUTIONS/COMMENTS
100.0
91.3
744
681
679
DURING JANUARY THE SCRUBBER AND BOILER WERE OFF LINE FOR APPROXIMATELY
64 HOURS TO REPAIR AND BALANCE THE BOILER ID FAN.
2/80 SYSTEM 78.8 98.2 77.9 77.9 696 552 542
** PROBLEMS/SOLUTIONS/COMMENTS
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 A)ND BOILER TO TRIP Off,
3/80 SYSTEM
60.3
99.7
99.7
60.3
744
450
448
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT AND SCRUBBER WENT DOWN TWICE DURING HARCH. THE FIRST OUTAGE WAS
TO BALANCE THE ID FAN. LATER IN THE MONTH THE ID FANS AND THE
PRECIPITATORS HAD TO BE REPAIRED.
128
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
NEVADA POWER: REID GARDNER 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
4/80 SYSTEM 100.0 .0 720 r 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE 1CCX 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 .0 744 462 0
** PROBLEMS/SOLUTIONS/COMMENTS
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.
6/80 SYSTEM 75.2 81.4 81.4 72.2 72C 639 520
** PROBLEMS/SOLUTIONS/COMMENTS
THE ID FAN OVERHAUL WAS COMPLETED EARLY IN JUNE.
THE BOILER WAS OUT OF SERVICE FOR 21 HOURS.
129
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
MET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
GARY
INDIANA
115.0
78.0
115.0
** 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
COAL
255S6.
11.00
3.50
< 11000 BTU/LB)
** 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
yET SCRUBBING
WELLMAN LORD
DAVY MCKEE
RETROFIT
27.8
7/76
6/77
90.00
98.50
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
GPM>
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELEMENTAL SULFUR
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
744
THE TURNAROUND ON UNIT 11 WAS COMPLETED ON DECEMBER 14, HOWEVER, THE STEAM
SUPPLY TO THE REGENERATION FACILITY WAS NOT AVAILABLE IN DECEMBER. THE
FGD SYSTEM DID NOT OPERATE THE ENTIRE MONTH.
1/80
SYSTEM 17.I
** PROBLEMS/SOLUTIONS/COMMENTS
.0
744
THE STEAM SUPPLY TO THE REGENERATION FACILITY WAS MADE AVAILABLE ON
JANUARY 15. THE FGD SYSTEM WAS OPERATIONAL, ON JANUARY 22 AFTER THE
OVERHAUL OF THE BOOSTER BLOWER DRIVE WAS COMPLETED.
THE REGENERATION FACILITY WAS FORCED OUT SEVERAL TIMES DUE TO PROBLEMS
WITH THE CONDENSATE RETURN.
2/8D SYSTEM
46.3
27.0
26.5
23.3
696
600
162
130
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
INDIANA PUB SERVICE: DEAN H. MITCHELL 11
-------
EPA UTILITY FGD SUPVEY: APRIL - JUNE 198T
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
E8UIVALENT SCRUBBED CAPACITY - My
* 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 - »
* 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 - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
* TREATMENT
TYPE
** DISPOSAL
TYPE
NORTHERN STATES POWER
SHERBURNE
1
BECKER
MINNESOTA
740.0
70P.O
740.C
C 850C BTU/LB)
COAL
SUBBITUMINOUS
19771.
9.00
25.00
.80
.03
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
3/76
5/76
50.00
99.00
9.0
1.0
CLOSED
(***** 6PM)
FORCED OXIDATION
LINED POND
: PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION I REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8C SYSTEM
2/80 SYSTEM
3/BO SYSTEM
97.0
97.0
98.0
744 793
696 687
744 688
** PROBLEMS/SOLUTIONS/COMMENTS
4/8? SYSTEM
5/80 SYSTEM
SYSTEM
97.0
96.0
96.0
DURING THE FIRST QUARTER OF 1980 NO MAJOR PROBLEMS HERE ENCOUNTERED WITH
THE FGD UNIT.
FROM MID-SEPTEMBER TO MID-OCTOBER THE UTILITY HAS SCHEDULED A BOILER
OUTAGE AT WHICH TIME THE MARBLE BEDS WILL BE INSPECTED.
7?0
744
720
720
720
697
79.4
78.1
74.7
132
-------
EPA UTILITY fGD SURVEY: APRIL - JUNE 1980
MORTHERN STATES POWER: SHERBURNE 1 (CONT.)
-PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLc*S/SOLUTIONS/COI»ll»ENTS
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED DURING THE SECOND QUARTER
OF 198C.
133
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 19ST
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
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 - 7.
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 UATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
NORTHERN STATES POWER
SHERBURNE
2
BECKER
MINNESOTA
74C. ~
7l'0.0
7 4 n. 0
( 85CC BTU/LB)
COAL
SUBBITUMINOUS
19771.
9. 00
25. DO
.80
.33
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
2.7
4/77
4/77
30
JO
.3
50.
99.
9.
1.:
OPEN
(»... GPM)
FORCED OXIDATION
LINED POND
' PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8T SYSTEM
2/8° SYSTEM
3/8C SYSTEM
97. ?
96.r
98.0
744
696
744
744
696
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 198C THE FGD 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 UNIT.
4/8C1 SYSTEM
96." 720 7P4
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR OPERATIONAL PROBLEMS WERE ENCOUNTERED IN APRIL.
5/8T SYSTEM 96.n 744 2H
6/8r SYSTEM 1CCi.n 720 51
6J.6
24.2
2.8
134
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
\I3RTHERN STATES POWER: SHERBURNE 2 CCONT.)
_ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OUT OF SERIVE MOST OF MAY AND JUNE BECAUSE OF THE ANNUAL
BOILER AND TURBINE INSPECTION.
135
-------
EP* UTILITY FGD SURVEY: APRIL - JUNE
SECTION 3
DESIGN AND PERFORMANCE DATA FOP OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
*ET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
PACIFIC POWER 8 LIGHT
JIM BRIDGER
4
ROCK SPRINGS
WYOMING
55C.O
5*7.8
55-i.r
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTEMT - 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/RETRO FIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - X
PART1CULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPAR? CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
COAL
SUBBITUMINOUS
21632. ( 930i BTU/LB)
<3.CO
18.CC
.56
.Tl
WET SCRUBBING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
NEW
.2
9/79
2/8°
9 LOG
99.00
»* WATER LOOP
TYPE
FRESH MAKF-UP WATER - LITER/S
CLOSED
(***** GPM)
** DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
SYSTEM
SYSTEM
3/8C SYSTEM
7*4
696
744
** PROBL£MS/SOLUTIONS/COM*ENTS
THE UNIT IS STILL IN THE SHAKEDOluN PHASE OF OPERATIONS. A NUMBER OF
MECHANICAL PROBLEMS AND SOME CONTROL PROBLEMS HAVE BEEN ENCOUNTERED.
41
42
43
SYSTEM
27. ?
24. -
26.6
26.:;
18.4
27.9
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 WERE INSTALLED FOR TESTING
PURPOSES.
5/8T 41
95.2
46.C
92.6
42.9
136
-------
EPA UTILITY fGD SURVEY: APRIL - JUNE 198C
PACIFIC POWER f, LIGHT: JIM BRIDGER 4 (CONT.)
... PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION T REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
42 72.4
43 1CC.C
SYSTE* 89.2
75.1 71.7
61.6 103.0
67.6 88.1
70.1
76.1
63.0
744 694
469
** PR06LEMS/SOLUTIONS/COMMENTS
MODULE 42 WAS FORCED OUT OF SERVICE FOR EIGHT DAYS IN MAY yHILE A VORTEX
BREAKER W«S INSTALLED IN THE ABSORBER VFSStL. THE VESSEL WAS DRAINING
BEFORE CACHING DESIGN FLUID LEVELS.
VORTEX PREAKERS 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.
ttS" SYSTE1"! 720
** PROGLEMS/SOLUTIONS/COM*ENTS
NO MAJOP PROBLEMS OCCURRED DURING THE APRIL-JUNE PERIOD. PERFORMANCE
FIGURES FOR JUNE WERE NOT AVAILABLE FOR TH£ SECOND QUARTER REPORT.
137
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 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
MET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MH
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 7,
AVERAGE SULFUR CONTENT - %
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 ST«RT-UP DATE
soi 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
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPPJNGPORT
PENNSYLVANIA
917.:
825.0
917.0
( 115CC BTU/LB)
COAL
BITUMINOUS
26749.
12.90
7.00
3.00
WET SCRUBBING
LIME
CHEMICO DIVISION, ENV1ROTECH
NEW
5.0
12/75
6/76
92.10
99.80
.0
OPEN
CALCILOX
LANDFILL
(**+** GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION f. REMOVAL PEP BOILEP FGD C»P.
SO? PART. HOURS HOURS HOURS FACTOR
1/8n SYSTEM 98.6 100.Q 9C.4 744 672 672
2/8" SYSTE* 98.1 100.0 93.7 696 652 652
** PROBLEMS/SOLUTIONS/COMMENTS
NO MAJOR FGD-RELATED PROBLEMS OCCURRED DURING JANUARY AND FEBRUARY.
3/80 SYSTEM 98.8 100.0 83.7 744 623 623
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS OUT OF SERVICE ONE WEEK IN MARCH DUE TO A PLUGGED AIR
PREHEATER. NO MAJOR FGD-RELATED PROBLEMS WERE REPORTED FOR MARCH.
4/8C SYSTEM
5/8p SYSTEM
SYSTEM
720
744
720
138
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C-
PENNSYLVANIA POWER: BRUCE MANSFIELD 1 fCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
302 PART. HOURS HOURS HOURS FACTOR
** PROBLE"IS/SOLUTIONS/COMI»ENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD WAS NOT AVAILABLE.
139
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1981*
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SPOSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED OPACITY - *W
** 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 - I
»* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
N E u / R i T B 0 F I T
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SOZ DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARC CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* TREATMENT
TYPE
** DISPOSAL
TYPE
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
SHIPPINGPORT
PENNSYLVANIA
917.0
825.0
917.Q
( 115CO BTU/LB)
COAL
BITUMINOUS
26749.
12.9C
7.CO
3.CO
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
NEW
6.0
7/77
* * / * *
92. 1D
99.81',
OPEN
CALCILOX
LANDFILL
(****« GPM)
PERFORMANCE DATA
"ER10D MODULE AVAILABILITY OPERAEILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8" SYSTEM 97.1 100.0 9C.6 744 67* 674
2/Sr SYSTEM 94.7 100.0 99.8 696 694 694
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM EXPERIENCED NO MAJOR PROBLEMS DURING JANUARY AND FEBRUARY.
3/80 SYSTEM 98.4 luT.C 51.1 744 380 380
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER HAS OUT OF SERVICE 16 DAYS IN MARCH FOR A SCHEDULED BOILER
INSPECTION. NO MAJOR FGD-RELATED PROBLEMS WERE REPORTED.
4/8n SYSTEM
5/8? SYSTEM
6/8T1 SYSTEM
720
744
720
1*0
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
ȣNNJYLVANIA PPwER: BRUCE MANSFIELD 2 (CCNT.)
... PERFORMANCE DATA
PERIOD MOOULF AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER ff>t CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLE1S/SOLUTIONS/CCMMENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD WAS NOT AVAILABLE.
U1
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTKULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MW
MET UNIT GENERATING CAPACITY yO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - fw
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
SHIPPINGPORT
PENNSYLVANIA
D
32. <
258. (
2751."1
917.?
825.0
.075 LE/MMBTU)
.6CC LE/MMBTU)
917.;
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
FOSTER WHEELER
PULVERIZED COAL
BASE
** / * *
1561.05
140.6
183.
(33°'80CC ACFM)
( 285 F)
( 600 FT)
(***** FT)
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - %
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
COAL
26749.
12.5C
11.5-13.5
7.-C
5.5-8.5
3. CO
1 .75-3.75
< 11500 ETU/LR)
11.5CC-11.95"
GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTKULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
THROWAWAY PRODUCT
WET SCRUBBING
LIME
MG PROMOTED
PULLMAN KELLOGG
GILBERT/COMMONWEALTH ASSOCIATE?
FULL SCALE
NEW
95. OC
92.2C
6/80
10/80
»* ESP
NUMBER
TYPE
»* PARTICUL»TE SCRUBBER
TYPE
** ABSORBER
NUMBER
TYPE
INITIAL START UP
SUPPLIER
NUMBER OF STAGES
NUMBER OF NOZZLES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENT INDEX
COLO SIDE
NONE
SPRAY TOWER
4/8"!
PULLMAN KELLOGG
6
3CO
7.C
6.7
2.5
1.0
(28.u IN-H20)
( 22.r FT/S)
142
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 19?G
PENNSYLVANIA POWER: BRUCE MANSFIELD 3 (CONT.)
»* FANS
NUMBER 4
TYPE CENTRIFUGAL, RADIAL TIP
SERVICE - wET/DRY DRY
** MIST ELIMINATOR
TYPE CHEVRON
»* PUMPS
SERVICE NUMBER
** TANKS
SERVICE NUMBER
REACTION
LIME SLURRY
** REHEATER
TYPE DIRECT COMBUSTION
TEMPERATURE BOOST - C 12. 2 ( 40 F)
** THICKENER
NUMBER 1
** TREATMENT
TYPE FLYASH STABILIZATION
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/80 SYSTEM 72C
** PROBLE^S/SOLUTIONS/COMMENTS
INITIAL OPERATION OF THE FGD SYSTEM COMMENCED ON JUNE 9, 198C. THE
UTILITY REPORTED TH«T IT IS PRESENTLY IN THE PROCESS OF DEBUGGING THE
SYSTEM.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198'
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FtD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
MET UNIT GENERATING CAPACITY W/FGO - 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 - 7.
PUBLIC SERVICE OF N£W MEXICO
SAN JUAN
1
WATERFLOW
NEW MEXICO
361.0
314.0
361.T
COAL
SUBBITUMINOUS
32795.
18.00
14.32
.80
.33
< 98<"C BTU/LB)
** 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
WET SCRUBBING
UELLMAN LORD
DAVY MCKEE
RETROFIT
4.4
4/78
* * f **
90.CO
99.80
33.0
1.C
** HATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
CLOSED
30.2
< 480 GPM)
ELEMENTAL SULFUR
MARKETED
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION
2/8P A
B
C
D
SYSTEM
3/8C A
B
C
D
SYSTEM
99.n
3."1
99. *
100.0
58.1
97.5
85.2
X REMOVAL PER BOItER FGO OP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8C
A
B
C
D
SYSTEM
81
96
83
87
.P
.0
.0
.0
.0
51.
42.
,
79.
57.
C
0
n
U
C
0
42
35
65
47
n
.
.0
.?
.0
-'
744 61C 351
94.5
3.0
98.0
65.0
74
83.6
69.4
99.'
.0
86.0
2.0
89.C
59.0
17.7
26.1
29.4
24.4
»* PROBLEMS/SOLUTIONS/COMMENTS
696 634 411
744 262 162 31.
4/sn A
SCRUBBER OPERATIONS AT UNIT ONE ARE STILL LIMITED TO TWO MODULES BECAUSE
OF THE CURRENT LACK OF REHEATER CAPACITY.
. V' .0
144
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 19SC
PUBLIC SERVICE OF NEW MEXICO: SAN JUAN 1
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198'
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - *W
NET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - Cw
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
2
WATERFLOW
NEW MEXICO
35".?
316. "
35'". ''
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HFAT CONTENT - J/G
AVERAGE ASH CONTENT - %
AVERAGE MOISTURE CONTENT - 7,
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 7,
GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
tNEPGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 DESIGN REMOVAL EFFICIENCY - x
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDFX - X
ABSORBER SPARE COMPONENTS INDEX
- X
COAL
SUBBITUMINOUS
22795.
ia.ro
14.82
.HO
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
RETROFIT
4.*
8/78
**/**
90.00
99.50
33."
1.0
< °8rC BTU/LB)
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
CLOSED
( 48C GPM)
** BYPRODUCT
3YPRODUCT NATURE
DISPOSITION
ELEMENTAL SULFUR
MARKETED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2/er
3/8C
E
F
G
H
SYSTEM
E
F
G
H
SYSTEM
97.r
22.0
.0
87.1
85.?
66.0
2.C
.C
. C
23.C
94.;
31.0
** PROBLEMS/SOLUTIONS/COMMENTS
7. REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
E
F
G
H
SYSTEM
92
31
m n
. 0
.0
r.
.^
63
21
.0
.0
.0
.0
.0
62
21
.0
.0
.0
.0
.0
744 737 155
65.0
12.C
.0
.0
26.5
.0
59.0
.0
.0
2C.1
6"6 683 178
744 472 147 33.
DURING THE FIRST QUARTER ONLY ONE ABSORBER COULD BE OPERATED DUE TO AN
ELECTRICAL PROBLEM. CURRENTLY, OPERATIONS ARE LIMITED TO TWO ABSORBERS
UNTIL A NEW REHEATER IS INSTALLED, WHICH IS TO BE COMPLETED IN APRIL.
146
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
PUBLIC SERVICE OF NEW «EX1CO: SAN JUAN 2 (CONT.)
PERIOD
4/8?
MODULE
E
F
G
H
SYSTEM
AVAILABILITY
99
99
44
81
.3
.9
. ?.
.2
.1
OPERABILITY
91
71
58
73
.3
.1
. P
.5
.6
RELIABILITY UTILIZATION
8°. 2
68.5
53.3
.0
43.9
55.2
* REMOVAL PER
S02 PART. HOURS
72C
BOILER
HOURS
540
FGD
HOURS
398
CAP.
FACTOR
66.3
5/81
6/80
** PROBLEMS/SOLUTIONS/COMMENTS
E
F
G
H
SYSTEM
99.1
98.9
.->
98.9
99. C
97.3
95.2
V.*
91.9
94.8
MODULE G IS DOWN FOR MAJOR REPAIRS UHICH WERE A RESULT OF AN INTERNAL FIRE
EARLIER IN THE YEAR.
A REGULATION CHANGE EFFECTIVE APRIL 18, NOW REQUIRES THAT 3 MODULES OPERATE
TO MEET S02 REGULATIONS.
MODULE H WAS UNAVAILABLE IN THE BEGINNING OF THE MONTH.
86.7
84.8
81.9
84.5
744
663
628 79.T
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS DOWN FOR SEVERAL HOURS FOR MINOR MAINTENANCE AND BOILER TUBE
REPAIRS.
E
F
G
H
SYSTEM
89.2
89.6
.0
88.8
69.1
72.4
74.1
.0
83.8
58.0
53.2
6C.O
57.3
.C
64.9
47.6
720
557
342 69.6
** PROBLEMS/SOLUTIONS/COMMENTS
AN ELECTRICAL CABLE FAILURE PREVENTED MODULES E AND F FROM OPERATING
SIMULTANEOUSLY. AUXILIARY POWER COULD ONLY BE PROVIDED TO ONE MODULE.
147
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU"!8ER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - Mm
NET UNIT GENERATING CAPACITY W/FGD
E8UIVALENT SCRUBBED CAPACITY - MW
PUBLIC SERVICE OF NtW MEXICO
SAN JUAN
3
WATERFLOW
NEW MEXICO
534.n
463.0
534.0
** 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 - 7.
* 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
502 DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
COAL
SUBBITUMINOUS
18841. ( 8 ICC BTU/LB)
22.45
14.82
.80
.07
WET SCRUBBING
UELLMAN LORD
DAVY MCKEE
NEW
3.6
12/79
* * / * *
90. CO
- X 99.50
.0
.0
SULFURIC ACID
MARKETED
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 M 86.0 54.4
SYSTEM
2/8" M 98.0 13.6
SYSTEM
3/80 M 85.5 78.3
SYSTEM
41.5
744 568
1.0
696 44
79.6 56.7
744 539 53. fl
** PROBLEMS/SOLUTIONS/COMMENTS
THE ONE MODULE CURRENTLY OPERATIONAL AT SAN JUAN 3 OPERATED WITHOUT ANY
MAJOR PROBLEMS DURING THE FIRST QUARTER. THE BOILER WAS OFF LINE FOR
APPROXIMATELY 24 DAYS IN FEBRUARY DUE TO AN ELECTRICAL PROBLEM.
4/8" M
SYSTEM
92.1
82.7
90.1
71.8
720 625
77.'
* PROBLEMS/SOLUTIONS/COMMENTS
ONLY ONE MODULE WILL BE NEEDED UNTIL MAY, 1982 TO MEET CURRENT S02 EMISSION
REGULATIONS.
5/80 M '00.9
SYSTEM
MINOR REPAIR WORK WAS DONE TO THE BOILER THIS MONTH. FGD SYSTEM AVAILABIL-
ITY WAS OVER 9CX.
78.1
100.0
32.7
744 311
35.0
148
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198C'
PUBLIC SERVICE OF NEW MEXICO: SAM JUAN 3 (COMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 P'RT. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS DOWN FOR SCHEDULED OUTAGE. AVAILABILITY WAS 1 . '.,7. FOR THE
MONTH.
5/8'" M 49." 47.3 39.2 27.6
SYSTE" 7?C 46C 55."
** PROBL£MS/SOLUTIONS/COMI"ENTS
MINOR REPAIR AND MAINTENANCE OF THE BOILER CAUSED SYSTEM OUTAGE TIME.
THE FGD SYSTEM DID NOT OPERATE AFTER JUNE 19 DUE TO FAILURE OF THE MIST
ELIMINATOR PADS AND BOTTOM BALLAST TRAY.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
SECTION 3
DESIGN »ND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - My
EOUIVALENT SCRUBBED CAPACITY - My
SALT RIVER PROJECT
CORONADO
1
ST. JOHNS
ARIZONA
35
28
** FUEL DATS
FUEL TYPE
FUEL GR«DE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 3!
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - %
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
SOZ DESIGN REMOVAL EFFICIENCY - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- 3!
COAL
SUBBITUWINOUS
19306.
25.00
16.DC
1.00
( 83CC BTU/LB)
WET SCRUBBING
LIMESTONE
PULLMAN KELLOGG
NEW
4.3
11/79
12/79
66.00
99.87
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* DISPOSAL
TYPE
OPEN
LINED POND
( 270 GPI")
------------------------------------------ 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/COMMENTS
696
744
DURING THE PERIOD THE STACK EMISSION TESTS WERE COMPLETED.
INFORMATION WAS AVAILABLE.
NO OPERATIONAL
4/Sfl
5/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
72C
744
720
ALTHOUGH FGD SYSTEM PERFORMANCE DATA IS BEING LOGGED, THE UTILITY REPORTED
THAT THE INFORMATION IS UNAVAILABLE FOR RELEASE AT THIS TIME.
150
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - MW
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 - 5!
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
** DISPOSAL
TYPE
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
2
GEORGETOWN
SOUTH CAROLINA
280.0
258.0
140.0
COAL
BITUMINOUS
26749.
13. 50
1.70
WET SCRUBBING
LIMESTONE
BABCOCK 8 WILCOX
1.1
7/77
* * / **
34.50
X 99.40
"i
J
.r
( 1150G BTU/LB)
OPEN
6.3
( 100 GPM)
POND
1 PERFORMANCE DATA
?ERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILI7ATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8T SYSTEM 744
2/&T SYSTEM 696
3/8n SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER 1980 THE UNIT OPERATED WITH NO MAJOR PROBLEMS.
4/8r SYSTEM 100.1 100.0 100.0 85.3 720 614 614 6C.2
5/6" SYSTEM 95.8 94.8 94.8 77.7 744 6 C>9 578 61.9
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OFF LINE IN MAY TO WASH DOWN THE ABSORBER MODULES.
SYSTEM AVAILABILITY REMAINED OVER 90X.
5/8.r> SYSTEM
100.1
10C.O
100.0
99.6
720
718
718 76.6
151
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 196T
SOUTH CAROLINA PUBLIC SERVICE: WINYAH 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE «VAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
S03 PART. HOURS HOURS HOURS FACTOR
** PRO&LEMS/SOLUT10NS/COMfENTS
NUMEROUS LEAKS IN THE SYSTEM WERE REPAIRED THROUGHOUT THE PERIOD WHILE THE
BOILER WAS ON LINE. NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED FOR APRIL,
MAY, OR JUNE.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOC OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
SET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MU
SET UNIT GENERATING CAPACITY W/FGD - l"i y
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I*U
»* BOILER DATA
SUPPLIER
TYPE
SERVICE LOAD
COMMERCIAL SERVICE DATE
MAXIMUM BOILE" FLUE GAS FLOW - CU.M/S
FLUE GAS TEMPERATURE - c
STACK HEIGHT - M
STACK TOP DIAMETEO ~ «
SOUTH CAROLINA PUBLIC SERVICE
WINYAH
3
GEORGETOWN
SOUTH CAROLINA
B
28". 1
25?. r
258.0
233.0
RILEY STOKER
PULVERIZED COAL
BASE
* * / **
LP//WMBTU)
LB/MMBTU)
(******* ACFM)
(**** F)
{*** FT)
(»***» FT)
FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 5!
RANGE ASH CONTENT - Z
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - *
RANGE CHLORIDE CONTENT - X
GENERAL EMISSION CONTROL SYSTEM DATA
SALEABLE P RODUCT / THROW AW A Y PRODUCT
SENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
S02 DESIGN REMOVAL EFFICIENCY - X
COMMERCIAL DATE
INITIAL START-UP
CONSTRUCTION INITIATION
COAL
26749.
( 115CC BTU/LB)
1.70
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
BABCOCK 8 WILCOX
BURNS 8 ROE
FULL SCALE
NEW
69.?C
6/80
5/80
3/79
** ESP
NUMBER
SUPPLIER
RESEARCH-COTTRELL
* PARTICULATE SCRUBBER
TYPE
NONE
** AaSORBER
TYPE
INITIAL START UP
SUPPLIER
SPRAY TOWER
5/8?
BABCOCK X WILCOX
** MIST ELIMINATOR
TYPE
»* PUMPS
SERVICE
CHEVRON
NUMBER
153
-------
iff. UTILITY FGD SURVEY: APRIL - JUNE 1980
SOUTH CAROLINA PUBLIC SERVICE: WINYAH 3 (CONT.)
* REHEATER
TYPE HOT AIR INJECTION
HEATING MEDIUM STEAM
>* WATER LOOP
TYPE CLOSED
PERFORMANCE DATA " *
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 5! REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/81 SYSTEM 64.2 6r.O 63.C 46.0 720 559 536 59.5
«* PROBLtWS/SOLUTIONS/COMMENTS
INITIAL OPERATIONS BEGAN JUNE 3, 1980.
THE INLET DAMPER LOCKED UP CAUSING THE FGD SYSTEM TO GO DOWN.
THERE HAVE BEEN CONTINUING PROBLEMS WITH THE THICKENER SUMP RESULTING FROM
THE SUMP LOCATION. THE FGD SYSTEM WAS DOWN ABOUT A WFEK BECAUSE OF THIS.
154
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1981'
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY W/FGD - MU
EQUIVALENT SCRUBBED C«PACITY - 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
* GENcRAL 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
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW
1
HATTISBURG
MISSISSIPPI
2 on."
18C.C
124.P
12GCC BTU/LB)
COAL
BITUMINOUS
27912.
15.00
6.5C
1.30
.01
WET SCRUBBING
LIMESTONE
ENVIRONEERING, RILEY STOKER
NEW
5.5
8/78
8/7S
52.70
99.60
.0
.0
CLOSED
<***«* GPM)
FLYASH STABILIZATION
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
SYSTEM .n
** PROBLEMS/SOLUTIONS/COMMENTS
.0
THE UNIT REMAINED OFF LINE DURING JANUARY AS RELINING OF THE SCRUBBERS
HAS COMING TO COMPLETION.
SYSTEM -1 .? 606 i C1
3/8? SYSTEM 41.5 95.1 100.0 39.5 744 3"9 294
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE UNIT 1 FGO SYSTEM RETURNED TO SERVICE OPERATING 294 HOURS.
4/8T SYSTEM 100.1 99.0 100.0 99.0 720 720 713
** PROBLEMS/SOLUTIONS/COMMENTS
THERE WERE NO OPERATIONAL PROBLEMS RELATED TO THE FGD SYSTEM DURING APRIL.
FOUR INSPECTIONS WERE PERFORMED taHICH REQUIRED THE FGD SYSTEM TO BE OUT
OF SERVICE FOR SEVEN HOURS.
155
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SOUTH MISSISSIPPI ELEC PWR: R.D. MORROW 1 (CONT.)
.. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 99.7 99.5 1CO.C 88.7 744 660 658
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SCHEDULED TO BE OUT OF SERVICE FOR 84 HOURS TO CLEAN THt
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 MAY.
5/8^ SYSTEM 99.2 97.; 99.0 93.0 90.00 720 69f 668 68.9
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE OPERATIONS CAME TO A HAULT FOR APPROXIMATELY 6 HOURS TO CLEAN
THE FIST ELIMIN«TORS. OTHER OUTAGE TIME DURING THE MONTH WAS CAUSED
BY BOILFR-RELATFD PROBLEMS.
156
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1981
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MU
(JET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - I»W
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - I
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
SOUTH MISSISSIPPI ELEC PWR
R .D . MORROW
2
HATTISBURG
MISSISSIPPI
2 JO.O
180.0
124.C
< 1?OOC BTU/LB)
COAL
BITUMINOUS
27912.
15.00
6.50
1.30
.01
WET SCRUBBING
LIMESTONE
ENVIRONEERIN&, RILEY STOKER
NEW
5.5
6/79
6/79
52.70
99.60
.0
.3
CLOSED
(***** GPM)
FLYASH STABILIZATION
LANDFILL
_ . ... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION t REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM .0
** PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
744
698
THE UNIT REMAINED OFF LINE DURING JANUARY WHILE SCRUBBER LINER REPAIRS
CONTINUED.
2/8? SYSTEM
3/80 SYSTEM
4/80 SYSTEM
.C
.0
.0
.0
.C
.0
.0
.0
.0
.0
696
744
720
650
486
0
** PROBLEMS/SOLUTIONS/COMMENTS
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
744
127
18
157
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SOUTH MISSISSIPPI ELEC PWR: P.O. MORROW 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
* PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT REMAINED OFF LINE DURING MOST OF MAY TO COMPLETE SCRUBBER AND
STACK LINING MODIFICATIONS.
THE BOILER OPERATED 127 HOURS IN MAY; HOWEVER, THE FGD SYSTEM OPERATED
ONLY 18 HOURS BECAUSE OF COMPUTER CONTROL PROBLEMS.
6/8r SYSTEM 99.7 90.0 99.1 78.3 90.00 720 625 561 68.9
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM COMPUTER LOST POWER DURING JUNE CAUSING THE UNIT TO
BE SHUT DOWN FOB 25 MINUTES.
DURING JUNE OPERATIONS CAME TO A HAULT FOR APPROXIMATELY 5 HOURS TO CLEAN
MIST ELIMINATORS. OTHER OUTAGE TIME DURING THE MONTH WAS CAUSED BY BOILER
RELATED PROBLEMS.
158
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DFSIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
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
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
S02 D.ESIGN REMOVAL EFFICIENCY - X
PARTICULATE DFSIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - X
ABSORBER SPARE COMPONENTS INDEX
- X
SOUTHERN ILLINOIS POWER COOP
MAR ION
4
MARION
ILLINOIS
184.0
UT.n
184.0
COAL/REFUSE
20934.
16.00
10.00
3.50
.10
WET SCRUBBING
LIMESTONE
BABCOCK 8 yiLCOX
NEW
*******
5/79
5/79
89.40
99.60
( 9001 ETU/LB)
»* WATER LOOP
TYPE
FRESH MAKE-UP yATER - LITER/S
* TREATMENT
TYPE
OPEN
{*«*** GPM)
FLYASH STABILIZATION
** DISPOSAL
TYPE
LANDFILL
_ . . PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
ID/79 SYSTEM
11/79 SYSTEM
1Z/79 SYSTEM
100.0
100.0
.0
26.7
71.0
744 C
720 192
744 52E
0
192
5i8
** PROBLEMS/SOLUTIONS/COMMENTS
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
THE UNIT WAS DOWN FROM OCTOBER 1 THROUGH NOVEMBER 17 FOR A BO ILER/TURBINE
INSPECTION. NO MAJOR FGD RELATED PROBLEMS WERE ENCOUNTERED DURING THE
FOURTH QUARTER OF 1979 OTHER THAN SOME FREEZE-UPS CAUSED BY THE WINTER
UEATHER.
10C.C
100.0
100.0
10.0
31.0
48.4
744 72
696 216
744 36C
72
216
360
159
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SOUTHERN ILLINOIS "OWER COOP: MARION A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION ? REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PHOBLEWS/SOLUTIONS/COMVENTS
DURING JANUARY THE LOW BOILER AND SCRUBBER HOURS WERE A RESULT OF AN
1« 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
MAINTAINING THE BELT ALIGNMENT IN THE SLUDGE DISPOSAL SYSTEM.
4/8f SYSTEM 720
5/8r SYSTEM 744
ilb~ SYSTEM 730
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THE APRIL THROUGH JUNE PERIOD WAS NOT AVAILABLE.
160
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - My
MET UNIT GENERATING CAPACITY y/FGD - MH
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
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 yATER - LITER/S
** TREATMENT
TYPE
* DISPOSAL
TYPE
- X
SOUTHERN INDIANA GAS i. ELEC
A.B. BROWN
1
WEST FRANKLIN
IND IANA
265.0
250.0
265.0
COAL
BITUMINOUS
25819.
9.40
13.30
3.35
.05.
WET SCRUBBING
DUAL ALKALI
FMC
NEW
.8
4/79
4/79
85.00
99.50
20.0
.3
CLOSED
( 1110C BTU/LB)
(***** GPM)
NONE
LANDFILL
......_....._-_--.. PERFORMANCE DATA-
PERIOD MODULE AVAILABILITY OPERABILITK RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
A
B
SYSTEM
99
99
99
.0
.0
.0
96,
99,
98,
.5
.0
.0
99.
99.
99.
1
1
1
96
99
97
.4
.0
.7
744 744 727
** 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
481
** PROBLEMS/SOLUTIONS/COMMENTS
SOME OUTAGE TIME IN FEBRUARY RESULTED FROM A y£T 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
96.3
95.8
26.5
21.1
23.8
744
304
177
161
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE
SOUTHERN INDIANA GAS K ELEC: A.B. BROwN 1 (CONT.)
PERFORMANCE DATA -
°ER10D MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * R.EMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMfENTS
DURING MARCH, BOILER DOWN TIME WAS DUE TO A SCHEDULED UNIT OUTAGE, DURING
WHICH TIME MAINTENANCE WAS PERFORMED ON THE SCRUBBER.
<,/S-> A 1CO." 96.8 1CO.P 92.9
B 1CO.T 99.7 100.0 95.7
SYSTEM 1C.:." 98.3 1C1.C 94.3 72T 691 679
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL, THERE WERE NO OPERATIONAL PROBLEMS WITH THE FGD SYSTEM. THE
SYSTEM WAS AVAILABLE 1 GO? OF THE TIKE.
5/SO A 100.^ 100.0 100.0 82.8
B ICO." 1CP.C 100.0 82.8
SYSTEM 100.0 10r.C 1Cn.C 82.8 744 6^4 616 53.7
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY 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 TI»E SOME GENERAL FGO SYSTEM MAINTENANCE WAS ALSO PERFORMED.
6/80 A 10C." 1CP.C 1CO.O 98.2
B 100.0 10C.O 1CO.O 98.2
SYSTEM 100." IOr.0 100.C 98.2 720 706 707 59.D
** PROBLEMS/SOLUTIONS/COMMENTS
NO FGD RELATED PROBLEMS WERE REPORTED FOR THE MONTH OF JUNE. THE FGD SYSTEM
OPERATED 1QCX OF THE TIME THt BOILER WAS ON LINE.
162
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 19SO
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
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 - Z
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 1
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 - z
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - Z
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** DISPOSAL
TYPE
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
SPRINGFIELD
MISSOURI
194.0
173.C
194.0
( 12500 BTU/LB)
COAL
BITUMINOUS
29075.
13.00
3.50
.30
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
4.6
4/77
* * / **
80.00
99.70
20.0
.3
CLOSED
19.8
LANDFILL
( 315 GPM)
. _ . -PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
1/80 S-1 54.5 38.7 47.9 36.3
S-2 68.7 72.6 73.1 68.1
SYSTEM 61.6 55.7 60.5 52.2
744 698 388 65.4
* PROBLEMS/SOLUTIONS/COMMENTS
2/an
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
MIST 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
PRESATURATOR SPRAY NOZZLE PROBLEMS. WHILE THIS WAS BEING REPAIRED THE
UNIT WAS TAKEN OFF LINE. APART FROM THIS TIME THE MODULE WAS ON LINE.
29.1
71.7
50.4
31.5
73.2
52.4
29.1
71.6
50.4
696 695
350 59.9
163
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198^
SPRINGFIELD CITY UTILITIES: SOUTHWEST 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE »V«ILABILITY OPERABILITY RELIABILITY UTILI2ATION x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMI»ENTS
THE S-1 MODULE WAS OUT OF SERVICE IN THE FIRST PART OF FEBRUARY DUE TO
FROZEN AND BROKEN LINES. THE SUPERNATE LINE BROKE IN SEVERAL PLACES TAKING
BOTH MODULES OUT OF SERVICE FOR SEVERAL DAYS. ONCE THIS WAS REPAIRED BOTH
MODULES WERE IN SERVICE AS REQUIRED BY LOAD EXCEPT FOR A FEW MINOR TRIPS.
3/8 "
4/80
5/80
6/80
THE S-2 MODULE WAS EITHER IN SERVICE OR AVAILABLE FOR MOST OF THE MONTH.
S-1
S-2
SYSTEW
64.5
22.^
64.1
5.8
35.G
64.4
6.9
35.7
64.1
5.8
35.0
744
744
260 57.7
PROBLEWS/SOLUTIONS/COMMENTS
DURING MARCH THE S-1 MODULE HAS 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 LOW UNIT LOAD DEMANDS.
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.
INLET SCREEN.
THIS WAS CORRECTED BY REPAIRING THE SCRUBBER
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
744
744
340 56.7
** PROBLEWS/SOLUTIONS/COMMENTS
DURING MAY THE S-1 SCRUBBER REQUIRED CLEANING.
PUMP AND PUMP CONTROL PROBLEMS ON THE S-1 SCRUBBING TRAIN OCCURRED
DURING THE PERIOD.
THE S-2 MODULE WAS OFF LINE SEVERAL DATS BECAUSE OF RECYCLE PUMP AND
RECYCLE SYSTEM REPAIRS.
FLUE GAS OUTLET DUCT REPAIRS WERE REQUIRED ON THE S-2 MODULE IN MAY.
S-1
S-2
SYSTEM
85.6
12.8
49.2
85.6
6.8
45.8
85.5
7.2
47.4
84.9
6.8
45.8
720 720
330 66.6
** PROBLEMS/SOLUTIONS/COMMENTS
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 WAS OUT OF SERVICE FOR APPROXIMATELY 23 DAYS IN JUNE BECAUSE
OF A BROKEN SLURRY HOLD TANK AGITATOR SHAFiT.
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.
164
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME ST. JOE ZINC
PLANT NAME G.f. UEATON
UNIT NUMBER 1
CITY MONACA
STATE PENNSYLVANIA
GROSS UNIT GENERATING CAPACITY - Mw 60.0
NET UNIT GENERATING CAPACITY U/FGD - MW 60.0
EQUIVALENT SCRUBBED CAPACITY - MW 60.0
** FUEL DATA
FUEL TYPE COAL
FUEL GRADE BITUMINOUS
AVERAGE HEAT CONTENT - J/G 29075.
AVERAGE ASH CONTENT - X 11.50
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 - 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
< 125GC BTU/LB)
2.00
.20
WET SCRUBBING
CITRATE
MORRISON & KNUDSEN/U.S.B.M.
RETROFIT
11/79
1/80
90.00
99.60
.0
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - L1TER/S
CLOSED
(*****
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
ELEMENTAL SULFUR
_ __ _. .. -PE R FO RM AN C E 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
3/80 SYSTEM
744
696
74*
PROBLEMS/SOLUTIONS/COMMENTS
4/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
THE SYSTEM IS STILL GOING THROUGH THE DEBUGGING PHASE OF OPERATION. SOME
EBUIPMENT 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 WtRE LOGGED DURING THE FIRST
OUARTER OF 1980 BRINGING THE TOTAL SYSTEM OPERATING HOURS TO 42 IN 1979.
720
744
720
165
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
ST. JOE ZINC: G.F. WEATON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
302 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE GEORGE F. WHEATON STATION HAS BEEN OPERATING AT A REDUCED LOAD OF 3T
TO 3C MW SINCE DECEMBER, 1979 DUE TO THE 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 MONTHSt MECHANICAL BREAKDOWNS OF
EQUIPMENT AND PROBLEMS RELATED TO LOW TEMPERATURE OPERATION HAVE PREVENTED
CONTINUOUS OPERATION TO OBTAIN MEANINGFUL DATA. ST. JOE IS ATTEMPTING TO
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.
166
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MU
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 - %
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 HATER - LITER/S
- X
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
PADUCAH
KENTUCKY
10.0
10.G
10.G
COAL
BITUMINOUS
(***.*» BTU/LB)
2.90
WET SCRUBBING
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
RETROFIT
4/72
** / * *
.0
.0
CLOSED
(***** GPM)
_.__ . _ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
D/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR SHAWNEE 1GB.
167
-------
EPA UTILITY FGD SURVEY: APRIL - JUNt 1980
SECTION 3
DESIGN »ND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU1BER
CITY
STATE
GROSS UNIT GEKERATING CAPACITY - Mm
NET UNIT GENERATING CAPACITY W/FGD - I"W
EQUIVALENT SCRUBBED CAPACITY - CW
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10B
PADUCAH
KENTUCKY
1n.O
10.0
10.0
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
COAL
BITUMINOUS
2.90
BTU/LB)
** 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 - 1
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - I
ABSORBER SPARE COMPONENTS INDEX
- X
WET SCRUBBING
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
RETROFIT
4/72
**/ **
.0
.0
»* WATER LOOP
TYPE
FRESH MAKE-UP HATER - LITER/S
CLOSED
<***** GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8" SYSTEM
2/8P SYSTEM
SYSTEM
744
696
744
PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980, ONLY THE VENTURI/SPRAY TOWER SYSTEM HAS
OPERATED. THE TCA SYSTEM CONTINUED TO OPERATE DURING THE QUARTER ON DOUA
BASIC ALUMINUM SUUFATE PROCESS UNDER EPRI/UOP/TVA SPONSORSHIP.
THE LIMESTONE/ADIPIC ACID TEST SERIES ON THE VENTUR11 SPRAY TOUER SYSTEM,
WHICH HAD BEEN INITIATED IN MID-DECEMBER TO INVESTIGATE THE RELATIONSHIP
BETWEEN THE SLURRY PH AND THE ADIPIC ACID CONSUMPTION (DEGRADATION) RATE,
HAS 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.C, ESSENTIALLY ALL OF THE AOIPIC 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 (OR CARBOXYLJC 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 HZO PRESSURE DROP. SO 2
REMOVAL WAS 65X WITH 2200 PPM INLET S02 CONCENTRATION.
168
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
TENNESSEE VALLEY AUTHORITY: SHAyNEE 10B
-------
EPA UTIL1T1 FGD SU&VHY: APRIL - JUNE
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MH
MET UNIT GENERATING CAPACITY W/FGD - MW
E8UIVALENT SC"UPEFD CAPACITY - M w
TENNESSEE VALLEY AUTHORITY
WIDOWS CPEEK
8
BRIDGEPORT
ALABAMA
550.0
516.0
55.'.'.C
FUEL DAT*
FUEL TYPE
FUEL GR»DE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 5!
AVERAGE SULFUR CONTENT - *
AVERAGE CHLORIDE CONTENT - X
GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL STAPT-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
2326C. ( 1000C1 ETU/LB)
25.00
ir.oo
3.70
WET SCRUBBING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
RETROFIT
4.7
5/77
1/78
7C.OO
99. 5C
.0
.0
«* DISPOSAL
TYPE
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER .F'GD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80
A
B
C
D
SYSTEM
70
83
100
28
70
.4
t c
B n
t 7
.6
79
ior
1C1?
54
8?
.8
.0
.0
.7
.6
39
56
55
26
44
.2
.3
.5
.9
.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 SEPiTEMBEf 1980. THE FORCED
OXIDATION TESTS ARE EXPECTED TO RESUME IN JANUARY 1981.
2/80 A
B
C
D
SYSTEM
80.0
86.5
91.1
87.6
86.3
88.6
9C.2
97.6
98.2
93.7
72.7
74.0
80.0
80.6
76.8
696
571
535 43.6
** PROBLEMS/SOLUTIONS/COMMENTS
3/80 A
93.6
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
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
TENNESSEE VALLEY AUTHORITY: WIDOWS CREEK 8 (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
B
C
D
SYSTEM
93.0
71.9
93.3
86.0
90.6
73.3
63.9
79.0
87.9
71.1
62.0
76.6 82.60
744 722 570 50.4
** PROBLEMS/SOLUTIONS/COMMENTS
ON MARCH 3 THE TCA SPHERES INSTALLED IN TRAIN C AS PART OF THE OPTIMIZA-
TION TESTS WERE REMOVED. THE SPHERES HAD BECOME PLUGGED, RESULTING IN AN
ABSORBER DIFFERENTIAL PRESSURE OF 20 INCHES WATER GAGE. THE SPHERES HAD
BEEN IN USE SINCE NOVEMBER 17, 1979.
4/sn A
B
C
D
SYSTEM
96.8
97.2
96.3
95.a
96.3
82.7
79.5
90.4
7".9
80.9
46.5
44.7
50.8
39.9
45.5
720 405
328 3C.3
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER SLURRY SPRAY NOZZLES WERE CLEANED AS PART OF A
SCHEDULED MAINTENANCE OUTAGE.
BALL MILL LINERS AND LIFTER BARS WERE REPLACED IN APRIL DURING A SCHEDULED
MAINTENANCE OUTAGE.
5/8C A
B
C
D
SYSTEM
99.2
96.1
96.1
96.1
96.9
74.5
80.9
87.7
75.2
79.6
56.2
61.0
66.1
56.7
6C.O
744
561
447 38.3
** PROBLEMS/SOLUTIONS/COMMENTS
ON MAY 16 THE LIMESTONE BUCKET ELEVATOR FAILED CAUSING UNIT 8 TO BE
REMOVED FROM SERVICE FOR 6 HOURS.
THE SCRUBBER SLURRY SPRAY NOZZLES ON THE B, C AND C MODULES WERE CLEANED
DURING MAY. THE CLEANING KEPT THE SYSTEM OFF LINE FOR 23 HOURS.
THE UNIT 8 BALL MILL MALFUNCTIONED ON MAY 28, 1980 DUE TO FAILURE OF INLET
BEARING BOLTS.
6/80
A
B
C
D
SYSTEM
100. P
100.0
99.6
100.0
99.9
5.3
100.0
93.9
98.6
74.5
100. n
100.0
99.5
100.0
99.8
4.9
91.8
86.3
90.6
68.3
82.20
720 661
492 44.C
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE BALL MILL REMAINED OUT OF SERVICE FOR MAJOR REPAIRS THAT
INCLUDED REPAIR OF THE BALL MILL SHELL (CRACKS PRESENT). THE UNIT 7
SCRUBBER BALL MILL WAS USED IN PLACE OF THE UNIT 8 BALL MILL.
171
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198?
SECTION 3
DESIGN AND PERFOR"ANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
SET UNIT GENERATING CAPACITY W/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
TEXAS UTILITIES
MARTIN LAKE
1
TATUM
TEXAS
793.0
750.0
595.0
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
** 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
ABSORBER SPARE COMPONENTS INDEX
WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
* DISPOSAL
TYPE
- X
COAL
LIGNITE
17166.
8.00
33.OC
.90
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
1.3
4/77
10/78
71.00
99.40
.0
.0
( 738C BTU/LB)
CLOSED
34.6
( 550 GPM)
FLYASH STABILIZATION
LANDFILL
i - PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
* REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
Z/8H SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/8P SYSTEM
PLUGGING PROBLEMS CONTINUED IN THE FIRST QUARTER OF 1980i 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
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
172
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
TEXAS UTILITIES: MARTIN LAKE 1 (CONT.)
-- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION T REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/8C SYSTEM 744
6/8P SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH MAINTENANCE PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
THE SECOND QUARTER OF 1980. THE ABSORBERS ARE STILL EXPERIENCING PLUGGING
PROBLEMS.
173
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198n
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - My
EQUIVALENT SCRUBBED CAPACITY - I»W
** 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
NEy/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
TEXAS UTILITIES
MARTIN LAKE
2
TATUM
TEXAS
793.0
751.0
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
( 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.
SO? PART. HOURS HOURS HOURS FACTOR
1/8T SYSTEM
2/80 SYSTEM
3/8P SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
PLUGGING PROBLEMS CONTINUED IN THE FIRST OUARTER OF 1980t PARTICULARLY IN
THE WETTED FILM CONTACT AREA AND THE MIST 6LIMINATOR SECTION. THE
MIST ELIMINATOR PLUGGING WAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
WATER FOR MIST ELIMINATOR WASH FROM AN ASH POND WATER WASH THEt HAD BEEN
TESTING.
THE FRP STRUCTURAL WORK IS BECOMING A PROBLEM.
WORK WAS REPLACED WITH STAINLESS STEEL.
MUCH OF THE FRP SUPPORT
4/8C 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
174
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
TEXAS UTILITIES: MARTIN LAKE 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH MAINTENANCE PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
THE SECOND QUARTER OF 198C. THE ABSORBERS ARE STILL EXPERIENCING PLUGGING
PROBLEMS.
175
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198^
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY y/FGD - My
EQUIVALENT SCRUBBED CAPACITY - My
TEXAS UTILITIES
MARTIN LAKE
3
TATUM
TEXAS
793.0
750.0
595.0
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 5!
AVERAGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
COAL
LIGNITE
17166.
8.00
33.00
.90
< 738Ci BTU/LB)
** 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
- X
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
1.3
2/79
* * / **
71.00
99. 40
.0
.0
TREATMENT
TYPE
FLYASH STABILIZATION
** DISPOSAL
TYPE
LANDFILL
1 PERFORMANCE 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
3/8C SYSTEM
744
696
744
** PROBLEMS/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 yAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
WATER FOR MIST ELIMINATOR UASH FROM AN ASH POND WATER WASH THEY HAD BEEN
TESTING.
4/8P SYSTEM
5/80 SYSTEM
6/8P SYSTEM
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
176
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
TEXAS UTILITIES: MARTIN LAKE 3 (CONT.)
............ PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGB 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.
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - Mb
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 - 5!
** 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 - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE CAPACITY INDEX - 2
ABSORBER SPARF COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
TEXAS UTILITIES
MONTICELLO
3
MT. PLEASANT
TEXAS
sco.a
750.0
800.0
COAL
LIGNITE
BTU/LB)
18.90
31.90
1.50
.04
WET SCRUBBING
LIMESTONE
CHEMICO DIVISION, ENV1ROTECH
NEW
5/78
10/78
74.00
X 99.50
.0
CLOSED
34.4
( 546 GPM)
FLYASH STABILIZATION
LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM 744
a/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE FIRST QUARTER OF 1980.
4/80 SYSTEM 720
5/8n SYSTEM 744
6/81 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE MONTICELLO 3 SCRUBBING SYSTEM PERFORMED WELL THROUGHOUT THE SECOND
QUARTER OF 1980. THE TEXAS AIR CONTROL BOARD REPORTED THAT IT HAD RECEIVED
VERY FEW EXCESS EMISSIONS REPORTS FROM THE STATION DURING THE APRIL-JUNE
PERIOD.
178
-------
EPA UTILITY fGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
5ROSS UNIT GENERATING CAPACITY - MW
NET 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
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEh/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
TYPE
UTAH POWER 8 LIGHT
HUNTER
1
CASTLE DALE
UTAH
4DQ.O
430.0
360.0
( 13500 BTU/LB)
COAL
BITUMINOUS
?9075.
10.00
6.50
.55
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
NEU
5/79
* * / * *
80.00
X 99.50
OPEN
(***«* 6PM)
FLYASH STABILIZATION
POND
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
ID/79
11/79
1Z/79
1/80
2/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100
100
100
100
100
.0
.c
.0
.0
.0
95
91
98
95
86
.6
.1
.2
.9
.8
744
730
744
744
696
711
656
731
713
6H4
711
656
731
713
604
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THERE UERE NO MA/OR FGD PROBLEMS ENCOUNTERED
FROM OCTOBER 1979 THROUGH FEBRUARY 1980.
3/8T SYSTEM 57.8
** PROBLEMS/SOLUTIONS/COMMENTS
56.9
744
732
423
THE FGD SYSTEM WAS FORCED OF SERVICE IN MARCH BECAUSE THE THICKENER RAKE
SHAFT FAILED AND THE TANK HAD TO BE DRAINED,. THIS OUTAGE KEPT THE SYSTEM
DOWN FOR APPROXIMATELY 309 HOURS.
179
-------
EPA UTILITY FGD SUPVEY: APRIL - JUNE 198C
UTAH POWER 8 LIGHT: HUNTER 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/80 SYSTEW 100.0 60.1 720 433 433
5/8C SYSTEM 10r.O 64.0 744 476 476
*» PROBLEMS/SOLUTIONS/COMMENTS
THE LOU FGD HOURS DURING APRIL AND MAT RESULTED FROM THE ANNUAL OUTAGE
FOR GENERAL FGD SYSTEM MAINTENANCE.
6/8? SYSTEM lOr.D 97.9 720 705 705
** PROBLEWS/SOLUTIONS/COMMENTS
NO FGD SYSTEM PROBLEMS WERE REPORTED FOR JUNE.
180
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD 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 - MU
SROSS UNIT GENERATING CAPACITY - MM
HET UNIT GENERATING CAPACITY W/FGD - MU
NET 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.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 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/THROWANAY PRODUCT
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
PARTICULATE DESIGN REMOVAL EFFICIENCY
S02 DESIGN REMOVAL EFFICIENCY - X
INITIAL START-UP
UTAH POWER 8 LIGHT
HUNTER
2
CASTLE DALE
UTAH
B
43.
516.
*******
400.0
400.0
( .1CQ LB/MMBTU)
< l.iOC LB/MMBTU)
360.0
PULVERIZED COAL
BASE
** / **
*******
(******
(**** f)
<**** fT)
(***** FT)
< 1250C BTU/LB)
12.20C - 12,700
- X
COAL
******
29C75.
10.00
9-12
6.50
*** »**
.55
******
******
THROWAWAY PRODUCT
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
STEARNS-ROGER
FULL SCALE
NEW
99.50
89.00
6/80
** ESP
NUMBER
* PARTICULATE SCRUBBER
TYPE
** ABSORBER
TYPE
INITIAL START UP
SUPPLIER
* MIST ELIMINATOR
TYPE
NONE
SPRAY TOWER
6/80
CHEMICO
CHEVRON
** REHEATER
TYPE
HOT AIR INJECTION
** REHEATER
TYPE
BYPASS
181
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
JTAH POWER & LIGHT: HUNTER 2 (CONT.)
** WATER LOOP
TYPE OPEN
** TREATMENT
TYPE FLYASH STABILIZATION
** DISPOSAL
NATURE FINAL
TYPE POND
LOCATION ON-SITE
. . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Z REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
6/8T SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
OPERATIONS COMMENCED AT THE HUNTER 2 STATION IN JUNE. THE UTILITY REPORTED
THAT THE UNIT ALSO BECAME COMMERCIAL DURING THE MONTH.
182
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 3
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - My
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 - 5!
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
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
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** TREATMENT
TYPE
** DISPOSAL
TYPE
- X
UTAH POWER g LIGHT
HUNTINGTON
1
PRICE
UTAH
43P.O
400.0
366.0
( 12500 BTU/LB)
COAL
BITUMINOUS
29075.
1C.00
6.50
.55
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
NEW
1.6
5/78
* * / * *
81.00
99.50
.0
.0
CLOSED
18.9
< 300 GPM)
FLYASH STABILIZATION
LANDFILL
... . PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
1/8D SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744 497
720 28
744 642
744 668
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.
2/8f SYSTEM
3/80 SYSTEM
4/8? SYSTEM
100.0
100.0
98.1
87.0
89.2
92.1
696 605 605
744 664 664
720 676 663
183
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
UTAH POyER g LIGHT: HUNTINGTON 1 (CONT.)
PERFORMANCE DATA _
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 5! R£MOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER DURING FEBRUARY AND MARCH
WITH NO MAJOR PROBLEMS.
5/80 SYSTEM 10r.O 99.7 744 742 742
6/80 SYSTEM 100.0 99.2 720 714 714
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER DURING THE APRIL THROUGH
JUNE PERIOD EXCEPT FOR A FEU HOURS IN APRIL. THE UTILITY REPORTED THAT
NO MAJOR PROBLEMS OCCURRED DURING THIS TIME.
184
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
» STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT PLANNED
AWARDED
COMPANY NAME
ALABAMA ELECTRIC COOP
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
BASIN ELECTRIC POWER COOP
BIG RIVERS ELECTRIC
CAJUN ELECTRIC POWER COOP
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CINCINNATI GAS 8 ELECTRIC
COLORADO UTE ELECTRIC ASSN.
COLUMBUS 8 SOUTHERN OHIO ELEC.
COMMONWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
DELMARVA POWER 8 LIGHT
DESERET GEN & TRANS COOP
DUQUESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT g PWR
HOOSIER ENERGY
HOUSTON LIGHTING g POWER
INDIANAPOLIS POWER g LIGHT
IOWA ELECTRIC LIGHT g PWR
JACKSONVILLE ELECT. AUTHORITY
KANSAS CITY POWER g LIGHT
KANSAS POWER 8 LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LANSING BOARD OF WATER g LIGHT
LOS ANGELES DEPT OF WTR g PWR
LOUISVILLE GAS g ELECTRIC
MARQUETTE BOARD OF LIGHT g PWR
MICHIGAN S. CENTRAL PWR AGENCY
MIDDLE SOUTH UTILITIES
MINNESOTA POWER g LIGHT
MINNKOTA POWER COOPERATIVE
HONONGAHELA POWER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
MUSCATINE POWER g WATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POWER
NEW YORK STATE ELEC g GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
PACIFIC GAS & ELECTRIC
PACIFIC POWER g LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC GST COOP
PLATTE RIVER POWER AUTHORITY
PUBLIC SERVICE INDIANA
PUBLIC SERVICE OF NEW MEXICO
PWR AUTHORITY OF STATE OF NY
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC COOP
SEHINOLE ELECTRIC
SIKESTON BOARD OF MUNIC. UTIL.
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS g ELEC
NO.
2
2
8
1
5
4
1
2
1
1
2
3
4
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
4
2
1
3
3
1
1
1
4
1
3
1
2
1
5
2
2
1
MW
358.
195.
2598.
670.
2590.
1364.
540.
866.
617.
60C.
1700.
1341.
1572.
45C.
654.
730.
820.
918.
1800.
3880.
65.
882.
1992.
3012.
720. '
1200.
1054.
1575.
64.
364.
160.
3280.
3554.
44.
55.
5340.
475.
185.
1236.
2120.
440.
166.
650.
3215.
870.
100.
957.
2450.
1600.
550.
2751.
724.
233.
279.
650.
1779.
700.
840.
400.
1240.
235.
1700.
248.
484.
265.
NO.
2
2
5
0
0
1
0
1
1
0
0
1
2
1
1
3
0
2
0
0
0
p,
6
1
0
0
3
4
1
0
0
0
5
0
0
0
1
1
1
2
0
0
c
3
0
0
1
2
0
1
3
0
0
0
0
3
0
1
0
0
0
2
2
1
1
MW
358.
195.
962.
0.
0.
242.
C.
416.
617.
0.
C.
447.
822.
45C.
327.
18C.
C.
918.
0.
C.
0.
C.
0.
532.
0.
0.
1054.
1575.
64.
C.
0.
C.
1201.
0.
0.
0.
475.
185.
618.
720.
0.
C.
C.
375.
0.
C.
115.
1480.
0.
550.
2751.
0.
0.
C.
0.
1245.
0.
280.
0.
0.
0.
420.
248.
184.
265.
NO.
0
o
1
1
4
1
C
Q
C
C
1
1
p.
p.
1
p
r
c
1
r,
t
2
1
1
0
0
0
c
0
1
r
0
3
0
0
p
r
r,
1
2
1
0
0
m
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT PLANNED
AWARDED
COMPANY NAME
NO. I"W
NO. MW
NO. MW
NO.
NO. MW
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT g PWR
ST. JOE ZINC
SUNFLOWER ELECTRIC COOP
TANPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER & LIGHT
TEXAS UTILITIES
TUCSON ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER 8 LIGHT
WEST PENN POWER
1
1
1
1
1
1
7
1
3
8
2
1
5
1
720.
194.
205.
60.
347.
475.
3153.
400.
1882.
5585.
74C.
5C.
1886.
300.
0
1
0
1
0
0
3
0
0
4
0
o
3
0
0.
194.
0.
60.
c.
0.
570.
0.
0.
2585.
C.
C.
1086.
C.
C
0
1
c
r
p.
3
1
1
0
C
o
0
fl
0.
c.
205.
C.
0.
0.
1983.
400.
382.
C.
0.
0.
0.
0.
1
0
c
0
1
1
1
0
2
1
2
1
2
1
720.
0.
0.
0.
347.
475.
6CQ.
r
*J«
1500.
750.
740.
50.
800.
300.
0
0
0
0
0
0
0
0
0
3
0
0
0
0
0.
0.
Q.
0.
0.
0.
0.
0.
0.
2250.
0.
c.
r\
j
0.
TOTALS
200 9C763.
73 24766.
38 165C4.
29 12919.
60 36554.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED, RE8UES TING/EV ALUTING R11, <:
AND CONSIDERING ONLY FGD SYSTEMS mua,
186
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 5
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
SYSTEM SUPPLIER/PROCESS
ADL/COMBUSTION EQUIP ASSOCIATE
DUAL ALKALI
LIME
LIME/ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK 8 WILCOX
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 -
DAVY MCKEE
WELLMAN LORD
TOTAL -
ENVIRONEERINGt RILEY STOKER
LIMESTONE
MAGNESIUM OXIDE
TOTAL -
FMC
DUAL ALKALI
TOTAL -
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
NO.
1
1
5
3
10
2
4
1
1
8
6
1
7
4
8
2
14
1
1
8
8
3
1
20
6
8
2
2
18
8
8
3
1
4
3
3
6
6
2
2
MW
299.
SCO.
2305.
375.
3479.
822.
1896.
10.
550.
3278.
1673.
28C.
1953.
1951.
2532.
1017.
5500.
617.
617.
4138.
5000.
579.
10.
9727.
1160.
3165.
148C.
654.
6459.
2074.
2074.
664.
600.
1264.
1107.
1107.
1916.
1916.
882.
882.
NO.
1
D
3
3
7
2
3
1
1
7
4
C
4
1
4
r
5
1
1
7
1
3
1
12
4
4
'2
1
11
7
7
3
0
3
1
1
0
0
Cr
0
MW
299.
0.
9C5.
375.
1579.
822.
1176.
1n.
55T.
2558.
936.
r*.
936.
618.
1478.
n.
2D96.
617.
617.
3838.
BOP.
579.
10.
5227.
452.
1575.
1480.
327.
3834.
154C.
1540.
664.
0.
664.
265.
265.
0.
0.
0.
0.
NO.
v
1
2
C
7
r-
r
o
r
r
2
1
3
2
3
1
6
C
C
C
3
l
r.
h/
3
2
3
C
1
6
1
1
C
0
0
C
C
2
2
2
2
MW
C.
500.
14CO.
C.
19P.C.
C.
P.
0.
C.
0.
737.
280.
1017.
1268.
999.
570.
2837.
0.
0.
0.
1900.
0.
C.
1900.
708.
1357.
0.
327.
2392.
534.
534.
0.
0.
0.
0.
0.
550.
550.
882.
882.
NO.
C
0
0
0
r
0
1
0
C
1
0
0
0
1
1
1
3
0
0
1
4
0
0
5
0
1
0
0
1
0
0
0
1
1
2
2
4
4
0
0
MW
0.
0.
0.
0.
e.
o.
72P.
0.
0.
72C.
0.
0.
0.
65.
55.
447.
567.
0.
0.
300.
2300.
0.
r.
2600.
0.
233.
0.
n.
233.
0.
0.
0.
600.
600.
842.
842.
1366.
1366.
0.
0.
187
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198r
SECTION 5
SUMMARY OF F60 SYSTEMS BY SYSTEM SUPPLIER
TOTAL
OPERATIONAL
CONSTRUCTION
CONTRACT
AWARDED
SYSTEM SUPPLIER/PROCESS
MORRISON 8 KNUDSEN/U.S.B.M.
CITRATE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCH-COTTRELL
LIMESTONE
LIME/LIMESTONE
LIMF/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
VHEELABRATOR-FPYE/R.I.
AQUEOUS CARBONATE/ SPRAY DRYING
TOTAL -
TOTAL -
NO.
1
1
8
1
9
1
4
5
14
1
1
16
1
1
1
1
2
3
5
1
1
140
MW
60.
6".
3492.
475.
3967.
917.
188C.
2797.
528C.
475.
5C.
5805.
100.
1CO.
550.
550.
1510.
724.
2234.
440.
440.
54209.
NO.
1
1
3
1
4
1
1
2
7
o
r
7
0
0
1
1
0
f!
c
0
c
73
MW
60.
60.
805.
475.
i2sr.
917.
28 r.
1197.
2363.
C.
"i.
2363.
n.
0.
550.
550.
P.
0.
c.
0.
0.
24766.
NO.
C
C:
1
C
1
c
2
2
5
0
**
5
1
1
C
a
c
2
2
1
1
38
MW
0.
c.
447.
C.
447.
0.
95C.
95 C.
2001.
0.
0.
2001.
1CC.
100.
C.
c.
0.
574.
574.
440.
440.
16524.
NO.
0
0
4
0
4
0
1
1
2
1
1
4
0
C
p.
0
2
1
3
t
C
29
MW
0.
0.
2240.
0.
2240.
0.
650.
650.
916.
475.
50.
1441.
0.
0.
0.
0.
1510.
150.
1660.
3.
0.
12919.
188
-------
tPA UTILITY F6D SURVEY: APRIL - JUNF. 198C
SECTION 6
SUMMARY OF FGD SYSTEMS BY PROCESS
TOTAL
. STATUS"
OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
PLANNED
PROCESS
AQUEOUS CARBONATE/SPRAY DRYING
CITRATE
LIMESTONE
LIME/LIMESTONE
MAGNESIUM OXIDE
UELLMAN LORD
SUBTOTAL - SALEABLE PRODUCT
AQUEOUS CARBONATE/SPRAY DRYING
DUAL ALKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIME/SPRAY DRYING
PROCESS NOT SELECTED
SODIUM CARBONATE
SUBTOTAL - THROWAHAY PRODUCT
NO.
1
1
3
1
4
8
18
1
5
36
72
2
11
2
1C
1f
5
154
i»y
10C.
6C.
1766.
475.
1724.
2074.
5799.
440.
2^23.
16831.
329C5.
148C.
4^13.
20.
3r'27.
597C.
1175.
67884.
NO.
0
1
r:
0
0
7
8
0
3
19
27
2
8
2
3
o
4
65
My
0.
6T.
0.
c.
c.
154D.
160C.
0.
1181.
7583.
9691.
uso.
2286.
20.
C.
r
V.
925.
23166.
NO.
1
r»
0
0
2
1
4
1
0
7
2?
-0
3
n
3
5
n
34
My
1CC.
C.
0.
0.
574.
534.
12C8.
440.
0.
3213.
8816.
r.
1727.
r.
nee.
0.
0.
15316.
NO.
0
0
1
1
2
C
4
C
2
4
13
0
0
C
6
0
C
25
MW
3.
0.
166.
475.
750.
C.
1391.
0.
842.
1875.
6948.
0.
0.
0.
1863.
D.
^
u.
11528.
NO.
0
0
2
0
0
0
2
C
0
6
12
0
0
0
1
10
1
30
ny
C.
0.
1600.
0.
C.
0.
1600.
C.
0.
416C.
745C.
0.
0.
C.
44.
5970.
250.
17874.
TOTALS
SALEABLE PRODUCT PROCESS
* OF TOTAL My
172 73683.
8
73 24766.
6
38 16524.
7
29 12919.
11
32 19474.
8
NOTE: 28 UNITS ARE UNDECIDED AND ARE NOT INCLUDED IN THIS TABLE
189
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1981
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CITRATE
G.F. UEATON
DUAL ALKALI
A.B. BROWN
CANE RUN
NEWTON
LIME
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
FLRAMA
GREEN
GREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTER
HUNTINGTON
"ILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
CORONADO
CRAIG
DUCK CREEK
JEFFREY
JEFFREY
LA CYGNE
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
POWERTON
R.D. MORROW
R.D. MORROW
SOUTHWEST
TOMBIGEEE
TOMBIGBEE
WIDOWS CREEK
WINYAH
WINYAH
UNIT NO .
1
1
6
1
1
2
T
4
c
5
6
1-4
1
1-3
T
4
1
2
1
3
6
1-6
1
2
i
1
2
1
2
4
1
2
1
4
5
4
1
2
T
3
3
51
1
2
1
2
T
8
2
3
CAPACITY
MW
6 *j
60.
265.
299.
617.
1181.
917.
917.
917.
188.
2TG.
411.
411.
510.
242.
64.
9u.
90.
360.
360.
366.
442.
72.
4C8.
618.
7583.
97.
97.
119.
264.
280.
447.
416.
54Q.
49t.
874.
125.
420.
184.
595.
595.
595.
800.
532.
450.
124.
124.
194.
179.
179.
550.
140.
280.
INITIAL
STARTUP
11/79
4/79
4/79
9/79
12/75
7/77
1C/8C
8/76
12/77
1/77
6/78
1C/75
12/79
9/75
11/72
8/72
5/79
6/8C
5/78
8/78
4/73
7/73
3/79
8/78
6/79
11/73
4/78
11/79
12/79
7/76
8/78
4/80
2/73
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
5/77
7/77
5/80
COMMERCIAL
STARTUP
1/8C
4/79
"/ 0
12/79
6/76
r/ C
6/8C
8/77
7/78
2/77
"/ C
1T/75
12/79
6/76
-"/ 0
r/ 0
-/ c
P/ C
ry C
3/79
O/ 0
r*/ 0
"/ C
1/79
4/79
12/73
r/ o
12/79
5/80
8/78
O/ f
1/80
6/73
'/ t
"/ 0
5/79
10/78
f/ 0
O/ 0
m>78
12/77
12/80
8/78
6/79
r/ o
9/78
6/79
1/78
O/ 0
6/80
9691.
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
190
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS bY PROCESS AND UNIT
PROCESS/
UNIT NAME
UNIT NO.
CAPACITY
MW
INITIAL
STARTUP
COMMERCIAL
STARTUP
LIMESTONE/ALKALINE FLYASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLYASH
CLAY BOSWELL 4
COAL CREEK 1
COLSTRIP 1
COLSTRIP 2
FOUR CORNERS 1
FOUR CORNERS 2
FOUR CORNERS 7
"ILTON R. YOUNG 2
LIME/LIMESTONE
SHAWNE? 1C-A
SHAHNEE 10B
SODIUM CARBONATE
JIM BRIDGER 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
WELLMAN LORD
CEAN H. MITCHELL 11
DELAWARE CITY 1
DELAWARE CITY 2
DELAWARE CITY 3
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
74Q.
740.
1480.
475.
327.
36C.
36u.
175.
175.
229.
185.
2286.
1C,
20.
550.
125.
125.
125.
925.
3/76
4/77
4/8C
8/79
9/75
5/76
11/79
11/79
11/79
9/77
4/72
4/72
9/79
4/74
4/74
6/76
5/76
4/77
r/ 0
f/ C
11/75
1^/76
C/ 0
n/ C
C/ C
6/78
C/ C
n/ 0
2/8C
n/ c
"/ 0
7/76
115.
6u.
6C.
6C.
361.
351.
534.
7/76
5/8C
5/80
5/8C
4/78
8/78
12/79
6/77
5/8C
5/8C
5/8C
C/ 0
r/ 0
O/ 0
1540.
TOTAL
24766.
191
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION ?
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESSy
UNIT NAME
CITRATE
S.F. WEATON
DUAL ALKALI
A.B. BROWN
CANE RUN
TEUTON
LINE
3RUCE MANSFIELD
3RUCE MANSFIELD
3RUCE MANSFIELD
CANE RUN
CANE RUN
CDNESVILLE
CONESVILLE
ELRAMA
SREEN
SREEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTER
HUNTINGTON
1ILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS
UNIT
i
1
6
1
1
i
3
4
5
5
6
1-4
1
1-3
3
4
1
2
1
3
6
1-6
1
NO STABILI2ED 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
APACHE
APACHE
CHOLLA
CHOLLA
CDRONADO
CRAIG
DUCK CREEK
JEFFREY
JEFFREY
LA CYGNE
LAWRENCE
LAWRENCE
1ARION
1ARTIN LAKE
1ARTIN LAKE
1ARTIN LAKE
HONTICELLO
PETERSBURG
"OWERTON
R.D. MORROW
R.D. MORROW
SOUTHWEST
TOW6IGBEE
TDMBIGBEE
WIDOWS CREEK
WINYAH
KINYAH
LIMESTONE/ALKALINE
SHERBURNE
SHERBURNE
2
3
1
2
1
2
1
1
2
1
4
5
4
1
2
3
3
3
51
1
2
1
2
3
&
2
3
FLYASH
1
2
2
3
1
2
1
2
1
1
2
1
4
5
4
1
2
3
3
3
51
1
2
1
2
3
&
2
3
POND
LINED POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND
POND
POND
POND
UNLINED POND
LINED POND
MINEFILL
LINED POND
UNLINED POND
POND
POND
TO WASTE
CAS03-CAS04
CAS03-CAS04
POND
POND
LINED POND
LINED POND
192
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198C
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT NAME
-THROWAWAY
UNIT NO STABILIZED UNSTABILIZED
BYPRODUCT-
(TYPE
DISPOSITION
LIME/ALKALINE FLYASH
CLAY 30SWELL 4
COAL CREEK 1
COLSTRIP 1
COLSTRIP 2
FOUR CORNERS 1
FOUR CORNERS Z
FOUR CORNERS 3
MLTON R. YOUNG 2
LIME/LIMESTONE
SHAkNEE 1DA
SHAUNEE 10B
S30IUM CARBONATE
JIM BRIDGER
REID GARDNER
REID GARDNER
REID GARDNER
BELLMAN LORD
DEAN H. MITCHELL
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
SAN JUAN
SAN JUAN
SAN JUAN
LINED POND
11
1
2
3
1
2
3
LINED POND
POND
POND
MINEF1LL
POND
LINED POND
LINED POND
LINED POND
LINED POND
LINED POND
LINED POND
ELEMENTAL SULFUR
SULFURIC ACID
SULFUPIC ACID
SULFURIC ACID
ELEMENTAL SULFUR
ELEMENTAL SULFUR
SULFURIC ACID
SALES AND INTERNAL U
SALES AND INTERNAL U
SALES AND INTERNAL U
MARKETED
MARKETED
MARKETED
193
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMBIGBEE 2
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BIG RIVERS ELECTRIC
GREEN 1
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
COLORADO UTE ELECTRIC ASSN.
CRAIG 2
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE 5
COLUMBUS & SOUTHERN OHIO ELEC.
CONESVILLE 6
COMMONWEALTH EDISON
POWERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
DELMARVA POWER 8 LIGHT
DELAWARE CITY 1
DELMARVA POWER 8 LIGHT
DELAWARE CITY 2
DELMARVA POWER & LIGHT
DELAWARE CITY 3
DUQUESNE LIGHT
ELRAMA 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
KANSAS CITY POWER % LIGHT
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NtW
RETROF IT
RETROF IT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROF IT
CAPACITY
MW
179.0
179.0
97.5
97.5
119.0
264.0
175.0
175 .r
229.^
242. C
416.0
617.0
447.0
411.0
411.0
450.0
327.0
60.0
60. C
6C.O
510.0
408.0
532. T
9f.O
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME/ALKALINE FLYASH
CHEMICO DIVlSIONt ENVIPOTECH
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY 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
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENV1ROTECH
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
11/79
11/79
11/79
12/79
7/76
9/79
12/79
1/77
6/78
4/80
8/79
5/60
5/80
5/80
10/75
7/73
12/77
11/72
COMBUSTION ENGINEERING
194
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
KANSAS CITY POWER 8 LIGHT
HAWTHORN 4
KANSAS CITY POWER g LIGHT
LA CYGNE 1
KANSAS POWER 8 LIGHT
JEFFREY 1
KANSAS POWER 8 LIGHT
JEFFREY 2
KANSAS POWER 8 LIGHT
LAWRENCE 4
KANSAS POWER 8 LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS 8 ELECTRIC
CANE RUN 4
LOUISVILLE GAS 8 ELECTRIC
CANE RUN 5
LOUISVILLE GAS 8 ELECTRIC
CANE RUN 6
LOUISVILLE G*S 8 ELECTRIC
MILL CREEK 3
LOUISVILLE GAS 8 ELECTRIC
PADDY'S RUN 6
MINNESOTA POWER 8 LIGHT
CLAY BOSWELL 4
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
SHERBURNE 1
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER 8 LIGHT
NEW OR
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROF IT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
CAPACITY
MW
90.0
874.0
540. C
490.0
125.0
420.0
64. n
188.0
200. C
299.0
442.0
72."
475.0
185.0
618.0
360.0
36C.O
125.0
125.0
125.0
115.0
740.0
740.0
550.0
PROCESS/
SYSTEM SUPPLIER
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK 8 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
ADL/COMBUSTION EQUIP ASSOCIATE
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALIHE FLYASH
PEABODY PROCESS SYSTEMS
LIME/ALKALIHE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME
BABCOCK £ WILCOX
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
LIME/ALKALINE FLYASH
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
SODIUM CARBONATE
ADL/COMBUSTION EQUIP ASSOCIATE
WELLMAN LORD
DAVY MCKEE
LIMESTONE/ALKALINE FLtASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
START-UP
DATE
8/72
2/73
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
4/74
4/74
6/76
7/76
3/76
4/77
9/79
JI«I BRIDGE"
AIR CORRECTION DIVISION, UOP
195
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198f
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PJBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
SALT RIVER PROJECT
CORONADO 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 3
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 1
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW 2
SOUTHERN ILLINOIS POWER COOP
MARION 4
SOUTHERN INDIANA GAS 8 ELEC
A.B. BROWN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
ST. JOE ZINC
G.F. WEATON 1
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10A
TENNESSEE VALLEY AUTHORITY
SHAWNEE 106
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
TEXAS UTILITIES
MONTICELLO 3
UTAH POWER & LIGHT
HUNTER 1
UTAH POWER & LIGHT
HUNTER 2
NEW OR
RETROFIT
NEW
NEW
NEW
RETROF IT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROF IT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
917.0
917.0
917.0
361.0
350.0
534 ,P
280.0
UO.O
280.0
124.0
124.0
184.0
265.0
194.1
60.0
10.0
10.0
5 5 C1 . 0
595. ?
595.0
595 .3
8P,0.-T
360. C
360.0
PROCESS/
SYSTEM SUPPUER
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
PULLMAN KELuOGG
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BABCOCK 1! W1LCOX
LIMESTONE
BABCOCK 8 UJLCOX
LIMESTONE
ENVIRONEERING. RILEY STOKER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
BABCOCK K WILCOX
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION, UOP
CITRATE
MORRISON 8 KNUDSEN/U.S.B.n.
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-CO!TTRELL
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
12/75
7/77
10/80
4/78
8/78
12/79
11/79
7/77
5/80
8/78
6/79
5/79
4/79
4/77
11/79
4/72
4/72
5/77
4/77
5/78
2/79
5/78
5/79
6/80
196
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/ NEW OR CAPACITY PROCESS/ START-UP
UNIT NAME UNIT NO. RETROFIT MW SYSTEM SUPPLIER DATE
UTAH POWER & LIGHT NEW 366.C1 LIME 5/78
HUNTINGTON 1 CHEH1CO DIVISION, ENVIROTECH
TOTAL 24766.^
197
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
CHOLLA 4
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 1
BASIN ELECTRIC POWER COOP
LARA1IE RIVER 2
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
BIG RIVERS ELECTRIC
GREEN 2
CINCINNATI GAS 8 ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC ASSN.
CRAI6 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
EAST KENTUCKY POWER COOP
SPURLOCK 2
HOOSIER ENERGY
MEROM 1
HOOSIER ENERGY
MEROM 2
HOUSTON LIGHTING 8 POWER
W.A. PARISH 8
INDIANAPOLIS POWER & LIGHT
PETERSBURG 4
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS 8 ELECTRIC
MILL CREEK 1
LOUISVILLE GAS 8 ELECTRIC
MILL CREEK 2
LOUISVILLE GAS 8 ELECTRIC
MILL CREEK 4
MONONGAHELA POWER
PLEASANTS 2
MONTANA POWER
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
MONTANA-DAKOTA UTILITIES
COYOTE 1
NIAGARA MOHAWK POWER COOP
NEW OR '
RETROFIT
NEW
NEW
NEW
NEW
NEW
NcW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
126.0
670.0
440.0
570.0
570.0
570.0
242.0
65C.Q
447.9
327.0
500.0
441. 1
441.0
492.0
530.0
364.0
358.0
350.0
495 .0
618.0
700. 0
7DC.O
440.0
100.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
PULLMAN KELLOGG
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
RESEARCH-COiTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
BABCOCK 8 WILCOX
LIME
AMERICAN AIR FILTER
LIME
BABCOCK 8 WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME
ADL/COMBUSTION EQUIP ASSOCIATE
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
BABCOCK 8 WILCOX
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
BABCOCK 8 WILCOX
LIME/ALKALINE FLYASH
ADL/COMBUSTION EOUIP ASSOCIATE
LIME/ALKALINE FLYASH
AOL/COMBUSTION EOUIP ASSOCIATE
AQUEOUS CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
AQUEOUS CARBONATF/SPRAY DRYING
START-UP
DATE
6/81
1/82
4/83
7/80
6/81
4/82
11/80
9/80
7/80
7/80
1/81
5/82
7/81
11/82
10/84
8/81
U/80
12/81
7/81
9/80
0/83
0/84
3/81
4/82
ROCKWELL INTERNATIONAL
198
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
NORTHERN STATES POWER
RIVERSIDE 6,7
PHILADELPHIA ELECTRIC
EDDYSTONE 1
PHILADELPHIA ELECTRIC
EDDYSTONE 2
PJ9LIC SERVICE OF NEW MEXICO
SAN JUAN 4
SALT RIVER PROJECT
CORONADO 2
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SIKESTON BOARD OF MUNIC. 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 8 LIGHT
SANDOW 4
NEW OR
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
CAPACITY
MW,
110.0
24Q.O
334.0
534. C
280.0
400.0
235.0
280. C
205. f
704.0
704.0
575.0
400. Q
382.0
PROCESS/
SYSTEM SUPPLIER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
WELLMAN LORD
DAVY MCKEE
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BABCOCK 8 WILCOX
LIMESTONE
GABCOCK g WILCOX
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
START-UP
DATE
8/80
12/82
12/82
6/82
7/80
10/80
1/81
7/81
11/80
3/82
6/82
9/81
1/82
9/80
TOTAL
16524.0
199
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198f
SECTION 11
SUMMARY OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS *
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
COLORADO UTE ELECTRIC ASSN.
CRAIG 3
GRAND HAVEN BRD OF LIGHT 8 PUR
J. B. SIMS 3
MICHIGAN s. CENTRAL pyR AGENCY
PROJECT 1
MUSCATINE POWER 8 WATER
MUSCATINE 9
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
PHILADELPHIA ELECTR.IC
CROMBY 1
PLAINS ELECTRIC G 8 T COOP
PLAINS ESCALANTE 1
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
PUBLIC SERVICE INDIANA
GIBSON 5
SEMINOLE ELECTRIC
SEW1NOLE 1
SEMINOLE ELECTRIC
SEMINOLE 2
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
SUNFLOWER ELECTRIC COOP
HOLCOMB 1
TAMPA ELECTRIC
BIG BEND 4
TENNESSEE VALLEY AUTHORITY
JOHNSONVILLE 1-10
TEXAS POWER 8 LIGHT
TWIN OAKS 1
TEXAS POWER 8 LIGHT
TWIN OAKS 2
TEXAS UTILITIES
MARTIN LAKE 4
TUCSON ELECTRIC POWER
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
CAPACITY
MW
755.0
755. C
447.0
65.0
55.0
166.0
421.0
421.0
150.0
233.0
279.0
650.0
620.0
620.0
500.0
500.1
72C.O
347.0
475.0
600.0
750.0
750. T
750.0
370.0
PROCESS/
SYSTEM SUPPLIER
LIME
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIME/SPRAY DRYING
BABCOCK R WILCOX
LIME
BABCOCK 8 WILCOX
LIMESTONE
BABCOCK 8 WILCOX
LIMESTONE
RESEARCH-COTTRELL
DUAL ALKALI
FMC
DUAL ALKALI
FMC
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PEABODY PR01ESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABOOY PRO.CESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/LIMESTONE
RESEARCH-COTTRELL
MAGNESIUM OXIDE
ENVIRONEERING, RILEY STOKER
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
START-UP
DATE
0/82
0/82
0/82
6/83
4/82
9/82
6/83
6/85
5/83
12/83
12/83
0/82
3/83
3/85
3/85
11/83
12/84
0/83
12/84
12/81
8/84
8/85
C/85
1/85
SPRINGERVILLE
JOY MFG/NIRO ATOMIZER
200
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 11
SUMMARY OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME
TUCSON ELECTRIC POWER
SPRINGERVILLE
UNIT NO.
2
UNITED POWER ASSOCIATION
STANTON 1A
UTAH POWER £ LIGHT
HUNTER
UTAH POWER K LIGHT
HUNTER
WEST PENN POWER
MITCHELL
3
4
33
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
37C.O
5C.5
400.0
400.0
300.0
PROCESS/
SYSTEM SUPPLIER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
PESEARCH-COTTRELL
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENV1POTECH
LIME
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
1C/86
1/82
C/83
0/85
8/82
TOTAL
12919.0
201
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT N*ME UNIT
LETTER OF INTENT
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 5
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 6
MIDDLE SOUTH UTILITIES
UNASSIGNED 1
MIDDLE SOUTH UTILITIES
UNASSIGNED 2
MIDDLE SOUTH UTILITIES
WILTON 1
MIDDLE SOUTH UTILITIES
WILTON 2
NEVADA POkrFR
REID GARDNER 4
TOTAL
REQUESTING/EVALU
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
DESERET GEN 8 TRANS COOP
MOON LAKE 1
DESEPET GEN g TRANS COOP
MOON LAKE 2
GENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
SEWARD 7
HOUSTON LIGHTING & POWER
LIMESTONE 1
HOUSTON LIGHTING & POWER
LIMESTONE 2
IOWA ELECTRIC LIGHT 8 PWR
GUTHRIE CO. 1
MARQUETTE BOARD OF LIGHT g
SHIRAS 3
NEVADA POWER
WARNER VALLEY 1
NEVADA POWER
WARNER VALLEY Z
NEW YORK STATE ELEC 8 GAS
SOMERSET 1
NORTHERN STATES POWER
SHERBURNE 3
TEXAS UTILITIES
FOREST GROVE 1
TOTAL
NEW OR
NO. RETROFIT
SIGNED
NEW
NEW
NEW
NEW
NEW
NEW
NEW
ATING BIDS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
PWR NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
890.0
893.0
890.1
890.0
890.0
890.0
25". 0
890.0
440.0
450.0
4 1 C . 1
410.0
690.0
690.0
750.0
750.0
720.0
44.0
295.0
295.0
870.0
860.0
750. 0
440.0
202
PROCESS/
SYSTEM SUPPLIER
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 EQUIPMENT ASSOCIATE
LIME/SPRAY BUYING
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
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIME/SPRAY DRYING
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
START-UP
DATE
1/86
1/88
C/85
0/87
0/86
0/88
4/83
10/85
1/86
9/84
0/88
5/91
5/87
2/85
2/86
10/84
10/82
6/85
6/86
6/84
5/85
0/81
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
NEW OR
RETROFIT
CAPACITY
MW
PROCESS/
SYSTEM SUPPLIER
START-UP
DATE
CONSIDERING FGD SYSTEMS
BIG RIVERS ELECTRIC
D. B. WILSON 1
BIG RIVERS ELECTRIC
D. B. WILSON 2
CAJUN ELECTRIC POWER COOP
GIG CAJUN 3 1
CENTRAL MAINE POWER
SEARS ISLAND 1
CINCINNATI GAS & ELECTRIC
EAST BEND 1
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON 5
COLUMBUS & SOUTHERN OHIO ELEC.
POSTON 6
DELMARVA POWER & 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 & LIGHT
PATRIOT 1
INDIANAPOLIS POWER & LIGHT
PATRIOT 2
INDIANAPOLIS POWER & LIGHT
PATRIOT 3
JACKSONVILLE ELECT. AUTHORITY
NEW PROJECT 1
JACKSONVILLE ELECT. AUTHORITY
NEW PROJECT 2
LANSING BOARD OF WATER 8 LIGHT
ERICKSON 2
LOS ANGELES DEPT OF WTR g PWR
INTERMOUNTAIN 1
LOS ANGELES DEPT OF WTR 8 PWR
INTERMOUNTAIN 2
LOS ANGELES DEPT OF WTR 8 PWR
INTERMOUNTAIN 3
LOS ANGELES DEPT OF WTR K PWR
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
N£W
NEW
NEW
NEW
NEW
NEW
NEW
NEW
440.0
440.0
540.-:
600.0
650.0
375.0
375.0
55C.O
650.9
650.0
625.0
625.0
625.0
625.0
650.0
650.0
650.0
600.0
600.0
160.0
820.0
820.0
820.0
820.0
LIME
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
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
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
11/84
C/85
0/85
1/89
C/ 0
8/86
T/89
6/87
1/85
1/87
12/92
5/94
12/95
5/97
0/87
0/87
Q/87
0/85
0/87
1/87
0/86
0/87
0/88
0/89
VENDOR NOT SELECTED
203
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION 12
SUMMARY OF PLANNED F6D SYSTEMS
COMPANY NAME/ NEM OR CAPACITY
UNIT NAME UNIT NO. RETROFIT My
LOUISVILLE GAS 8 ELECTRIC NEW
TRIMBLE COUNTY 1
LOUISVILLE GAS 8 ELECTRIC NEW
TRIMBLE COUNTY 2
NEBRASKA PUBLIC POWER D
FOSSIL III
NEVADA POWER
HARRY ALLEN
NEVADA POWER
HARRY ALLEN
NEVADA POWER
HARRY ALLEN
NEVADA POWER
HARRY ALLEN
PACIFIC GAS & ELECTRIC
MONTEZUMA
PACIFIC GAS 8 ELECTRIC
MONTEZUMA
PWR AUTHORITY OF STATE
FOSSIL
SALT RIVER PROJECT
CORONADO
SOUTHERN ILLINOIS POWER
MARION
TEXAS UTILITIES
MILL CREEK
TEXAS UTILITIES
MILL CREEK
ISTRICT NEW
1
NEW
i
NEW
2
NEW
3
NEW
4
NEW
1
NEW
2
OF NY NEW
NEW
3
COOP NEW
5
NEW
1
NEW
2
575.0
575.0
65C.O
500.0
500.0
500.0
sro.o
800.CI
800.0
700-0
28C.O
300.0
750.0
750.0
PROCESS/
SYSTEM SUPPLIER
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
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
7/85
7/88
3/87
6/86
6/87
6/88
6/89
6/89
6/90
11/87
1/38
0/86
C/85
3/86
TOTAL
440.0
204
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1981
SECTION 13
TOTAL FGD UNITS AND CAPACITY J
jl
1
3
3
3
1
o
2
u
0
0
0
G
0
a
0
V-
0
3
0
0
c
G
0
0.
14U.
0.
Ir.
175.
340.
1637.
850.
47.
0.
143.
0.
c.
a.
a.
i...
L.
u.
C.
0.
0.
0.
0.
J.
o .
u.
0.
TOTAL
NO.
1
r
1
7
1"
9
12
17
26
39
57
7?
91
111
123
13?
151
162
177
184
19.i
191
192
193
194
195
196
ON LINE
MW
140.
C.
420.
905.
22C3.
2113.
2494.
4468.
8885.
13437.
19652.
27393.
33119.
41530.
45935.
51826.
62427.
68817.
78497.
82862.
86757.
87557.
88247.
88872.
89497.
90122.
90747.
205
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
^ET 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 - 7.
»* 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 ST2 REMOVAL - 5!
PARTICLE DESIGN REMOVAL EFFICIENCY - X
COMMONWEALTH EDISON
WILL COUNTY
1
ROMEOVILLE
ILLINOIS
167.0
137.0
COAL
22260.
7.40
1.5C
WET SCRUBBING
LIMESTONE
BABCOCK S UILCCX
RETROFIT
( 957C BTU/LB)
4/72
2/73
76. GO
98.CO
** ESP
NUMBER
TYPE
1
COLD SIDE
** PARTICLE SCRUBBER
NUMBER
TYPE
VENTUR1
PEPFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION
X REMOVAL PEP BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
12/79 A 77. D 99.5
B 84.9 100.0
SYSTEM 77.0 99.5
57.5
57.8
57.5 744 431 428
PROBLEMS/SOLUTIONS/COMMENTS
1/81 A
B
SYSTEM
88.6
88.6
ON DECEMBER 4, UNIT 1 CAME OFF LINE SO THAT THE AIR 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-MODULE 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 TWO DAY FORCED OUTAGE. LATER IN THE MONTH
THE A-MODULE BLEW 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.
87.5
84.1
84.1
63.0
6C.6
6C.6
744
536
451
206
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
COMMONWEALTH EDISON: WILL COUNTY 1
-------
EPA UTILITY FGD SU"VEY: APRIL - JUNE 198P
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
OUTAGE LASTED 35 HOURS. THE UNIT RETURNED TO SERVICE ON APRIL 24 AND
WAS AVAILABLE FOR THE REST OF APRIL.
5/BC SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MAY «ND JUNE PERIODS.
5/&T SYSTEM 720
208
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
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 U/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MW
* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 5!
AVERAGE MOISTURE CONTENT - T
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 7
** 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 Sn2 REMOVAL - 5!
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** ESP
»* MECHANICAL COLLECTOR
* PARTICLE SCRUBBER
NUMBER
TYPE
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHIGAN
260.0
*******
COAL
SUBBITUMINOUS
22330.
/ e*n
«» . '.* M
22.60
.35
********
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
RETROFIT
< 960C BTU/LB)
6/75
9/75
90.00
99.70
VENTURI
-PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITK RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
302 PART. HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/8'
SYSTEM
THE SCRUBBING SYSTEM OPERATED WITH BETTER THAN BOX AVAILABILITY DURING THE
FIRST flUARTER OF 198C.
THE SCRUBBER ID FAN FAILED. THE BOLTS HOLDING 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 PUMPSi 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
209
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
, PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD 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 744
** PROBLE!"IS/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
ID FAN HAD NOT ARRIVED AT THE PLANT. SCRUBBER SERVICE WAS NOT REQUIRED
BECAUSE OF LOW BOILER LOAD.
SCRUBBER REPAIRS AT ST CLAIR REQUIRE MORE OUTA6E 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 100% CAPACITY ESP FACILITY CURRENTLY UNDER
CONSTRUCTION IS COMPLETE. AT PRESENT 50X OF THE FLUE GAS IS SCRUBBED AND
5CX PASSES THROUGH THE ESP. DURING LOW LOAD PERIODS EITHER THE SCRUBBER OR
ESP CAN BE SHUT DOWN.
210
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 1*
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
SET UNIT GENERATING CAPACITY W/SCRUBBER - MU
EQUIVALENT SCRUBBED CAPACITY - KW
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - 5!
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - Z
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - t
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL Sr2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - *
** FABRIC FILTER
NUMBER
TYPE
* ESP
DUMBER
* MECHANICAL COLLECTOR
NUMBER
* PARTICLE SCRUBBER
NUMBER
TYPE
MINNESOTA POWER 8 LIGHT
CLAY BOSWELL
3
COHASSET
MINNESOTA
364.0
347.1
35T.O
COAL
SUBBITUMINOUS
19538.
9.00
26.OC
.92
.01
WET SCRUBBING
ALKALINE FLYASH
KREBS ENGINEERS
NEW
.8
1/73
5/73
.CO
98.70
0
NONE
( 84CC BTU/LB)
1
SPRAY IMPINGEMENT TOWER
------------------------ - ----------------- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8C
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
5/Br
6/8-?
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 198T. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON TH£ MINNESOTA POWER AND LIGHT PAR-
211
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198?
1INNESOTA POWER 8 LIGHT: CLAY BOSWELL 3 (CONT.)
... _ PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER fGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
EROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/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 - I
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 SP2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - *
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
** MECHANICAL COLLECTOR
NUMBER
TYPE
* PARTICLE SCRUBBER
NUMBER
TYPE
MINNESOTA POWER 8 LIGHT
SYL LASKIN
1
AURORA
MINNESOTA
62.0
57.3
58.0
( 8800 BTU/LB)
COAL
SUBBITUMINOUS
2Q469.
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
n
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
2/8C
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80
5/8C
6/sr
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/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'
213
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
MINNESOTA POWER 8 LIGHT: SYL LASKIN 1 (CONT.)
1 PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
TICLt SCRUBBERS WHILE THEY ARE IN SERVICE.
2H
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/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
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL SCZ REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
* FABRIC FILTER
NUMBER
TYPE
* ESP
MUMBER
TYPE
** MECHANICAL COLLECTOR
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
TYPE
MINNESOTA POWER g LIGHT
SYL LASKIN
2
AURORA
MINNESOTA
62.0
57.3
58.0
( 88PO BTU/LB)
COAL
SUBBITUMINOUS
20469.
9.00
26.70
1.00
.01
UET SCRUBBING
ALKALINE FLYASH
KRE6S ENGINEERS
RETROFIT
1.1
6/71
6/71
.00
93.70
0
NONE
NONE
0
NONE
SPRAY IMPINGEMENT TOWER
.*. -------------------------------------- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
x REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8P
2/80
J/80
5/80
6/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 198C.
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELAT ED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 198C'. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON TH£ MINNESOTA POWER AND LIGHT PAR-
215
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
11NNESOTA POWER 8 LIGHT: SYL LASKIN 2 (CONT.)
PERFORMANCE DATA -
=ERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION ! REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
216
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
MET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EOUIVALENT 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 - 7.
** 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 Sr<2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
MONTANA-DAKOTA UTILITIES CO.
LEWIS g CLARK
1
SIDNEY
MONTANA
55.1
50.3
55.1
COAL
LIGNITE
15003.
7.8C
36.20
.61
.03
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
RETROFIT
2.2
* * / **
12/75
.00
98.00
< «45C BTU/LB)
** MECHANICAL COLLECTOR
NUMBER
TYPE
»* PARTICLE SCRUBBER
TYPE
1
MULTICLONE
VENTURI
.. . -PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
z REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8C SYSTEM
2/8P SYSTEM
3/80 SYSTEM
744
696
744
** PROBLEMS/SOLUTIONS/COMMENTS
4/8? SYSTEM
5/80 SYSTEM
5/8f SYSTEM
DURING THE JANUARY THROUGH MARCH PERIOD THE SCRUBBER WAS 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 WERE 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 Bt'TyEEN 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 G.
720
744
720
217
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
10NTANA-DAKOTA UTILITIES CO.: LEWIS 8 CLARK 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN FOR TWO WEEKS IN MAY.
CREWS INSPECTING THE SCRUBBING SYSTEM DISCOVERED THAT THE NINE FOOT SCRUB-
BER LINER SECTION AT THE BOTTOM OF THE CYCLONIC MIST ELIMINATOR WAS SEVERE-
LY ERRODED. THE LINER HAS LASTED THREE YE*RS. THE UTILITY CONSIDERS THIS
A NORMAL MAINTENANCE PROBLEM. AT ONE TIME LINERS IN THIS SECTION WERE RE-
PLACED EVERY SIX MONTHS. REPLACEMENT WORK ON THE LATEST FAILURE IS EXPECT-
ED TO BEGIN BY JULY 21.
THE ENTIRE SCRUBBER COLUMN SUPPORTING THE DISC WHICH WAS ERODING AS REPORT-
ED DURING THE PREVIOUS TWO QUARTERS HAS BFEN CLAD WITH HASTELLOY G.
THE UTILITY REPORTED THAT THE SCRUBBER HAS EXPERIENCED PLUGGING AT WET/DRY
INTERFACES WITHIN THE STRUCTURE. IT APPEARS THAT THIS IS RELATED TO COAL
SULFUR CONTENT. WHEN THE SULFUR CONTENT IS RELATIVELY HIGH (C.7 TO 1 . OX AT
LEWIS AND CLARK) THE PLUGGING DOES NOT OCCUR. LIMESTONE IS ADDED AS RE-
OUIRED TO PREVENT THE OCCURRANCE OF LOW PH LEVELS. WHEN THE SULFUR CONTENT
FALLS TO THE 0.3X 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.
218
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
MET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - NU
** 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 - I
«* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - J!
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL SP2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** PARTICLE SCRUBBER
NUMBER
TYPE
PACIFIC POWER 8 LIGHT
DAVE JOHNSTON
4
GLENROCK
WYOMING
330.0
326.5
330.0
( 743C BTU/LB)
COAL
SUBBITUMINOUS
17282.
12.00
26. 00
.50
.04
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
RETROFIT
1.1
4/72
**/* +
VENTURI
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION x REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/60 SYSTEM 744
2/80 SYSTEM 696
3/8C SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FIRST QUARTER OF 1980.
4/8C SYSTEM 72C
5/80 SYSTEM 744
i/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS OCCURRED DURING THE SECOND
QUARTER OF 1980.
219
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
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 - *
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 SP2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
** ESP
TYPE
** PARTICLE SCRUBBER
TYPE
POTOMAC ELECTRIC POWER
DICKERSON
1
DICKERSON
MARYLAND
190.0
183.0
COAL
272U.
14.HO
2. CO
*** *****
( 1170C BTU/LB)
WET SCRUBBING
PROCESS NOT SELECTED
VENDOR NOT SELECTED
RETROFIT
* */ * *
0/78
99.OC
COLD SIDE
VENTURI
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
2/8C
3/80
SYSTEM
SYSTEM
SYSTEM
100.
94.
100.
0
3
0
l&r.
95.
100.
r
8
0
1CO.
94.
1CO.
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 LIME LEAK.
4/80
5/8C
6/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
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.
220
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME POTOMAC ELECTRIC POyER
PLANT NAME DICKERSON
UNIT NUMBER 2
CITY DICKERSON
STATE MARYLAND
SROSS UNIT GENERATING CAPACITY - MW 190.0
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW 183.0
EQUIVALENT SCRUBBED CAPACITY - MW *******
** FUEL DATA
FUEL TYPE COAL
FUEL GRADE ******
AVERAGE HEAT CONTENT - J/G 27214. ( 11700 BTU/LB)
AVERAGE ASH CONTENT - 5! 14.00
AVERAGE MOISTURE CONTENT - X ********
AVERAGE SULFUR CONTENT - X 2.0C
AVERAGE CHLORIDE CONTENT - X ********
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE WET SCRUBBING
PH CONTROL ADDITIVE PROCESS NOT SELECTED
SYSTEM SUPPLIER VENDOR NOT SELECTED
NEW/RETROFIT RETROFIT
ENERGY CONSUMPTION - X *******
INITIAL START-UP DATE **/**
COMMERCIAL START-UP DATE 0/78
TYPICAL SC2 REMOVAL - X ********
PARTICLE DESIGN REMOVAL EFFICIENCY - X 99.00
** ESP
TYPE COLD SIDE
** PARTICLE SCRUBBER
TYPE VENTURI
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/80 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 WAS NECESSARY TO REPAIR A RECYCLE
PUMP.
2/80
SYSTEM
SYSTEM
100. D
96.9
100.0
96.9
10P.O
96.9
696
744
696
744
696
721
PROBLEMS/SOLUTIONS/COMMENTS
IN MARCH THE SCRUBBER WAS DOWN FOR A SCRUBBER LINING WARRANTY INSPECTION.
NO REPAIR WORK WAS NECESSARY.
4/80
5/sr
6/80
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
DICKERSON 2 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
221
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
PDTOWAC ELECTRIC POUER: DICKERSON 2 UONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
SECOND OUARTER WITH ESSENTIALLY ioox AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS WERE REPORTED.
^2^
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS 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
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 POyER
DICKERSON
3
DICKERSON
MARYLAND
190.0
183.0
COAL
BITUMINOUS
272H.
14.PO
2.90
WET SCRUBBING
RETROFIT
< 11700 BTU/LB)
9/75
* * / * *
.CO
99.30
COLD SIDE
VENTURI
. _ PERFORMANCE DATA
?ERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/8P SYSTEM 78.7 88.2 78.7 744 664 586
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE SCRUBBER WAS DOWN TO REPAIR THE FLAKEGLASS LINING.
2/BC SYSTEM 100.0 10P.O 10Q.O 696 696 696
3/80 SYSTEM 100.0 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED WITH NO MAJOR PROBLEMS.
4/80 SYSTEM 720
5/80 SYSTEM 744
5/8C 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 TO ESTABLISH THE OPTIMUM LINER
MATERIAL AND APPLICATION STRATEGY FOR THE UNIT 3 SCRUBBING SYSTEM.
223
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198T
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING CAPACITY - My
MET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED CAPACITY - MH
** 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
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
112.0
11)9.8
11.2
( 1CCQC BTU/LB)
COAL
SUBBITUMINOUS
23725.
9.3C
13.70
.95
.01
WET SCRUBBING
ALKALINE FLYASH
AIR CORRECTION DIVISION, UOP
RETROFIT
9/73
** / **
FABRIC FILTER
NUMBER
TYPE
0
NONE
** ESP
NUMBER
** MECHANICAL COLLECTOR
NUMBER
* PARTICLE SCRUBBER
NUMBER
TYPE
MOBILE PACKED TOWER
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/BT SYSTEM
2/80 SYSTE"
3/8P SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
THE MODULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST QUARTER OF 19PO.
USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED. THE PROGRAM FOR RE-
PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY. THE UNIT IS SHUTDOWN
UHEN MAJOR SCRUBBER PROBLEMS OCCUR.
REHE*TER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS. THE SIX STEAM COILS
ON THIS IN-LINE REHEAT SYSTEM, TyO OF WHICH ARE 316SS AND FOUR OF wHUH
ARE CARBON STEEL, ARE EXPERIENCING CORROSION PROBLEMS. A SOLUTION TO THE
PROBLEM HAS NOT YET BEEN DETERMINED.
IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER BALLS AND GRIDS. THE OLD
BALLS WERE REPLACED WITH THE NEW HOLLOW HARD PLASTIC-WALLE0 BALLS WITH
NOTCHED SEAMS. THE GRIDS WERE ORIGINALLY 316L SS, CERAMIC, POLYPROPYLENE,
AND RUBBER LINED CARBON STEEL, BUT HAVE EE£N REPLACED WITH 317L SS GRIDS.
£24
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 1980
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
- . -PERFORMANCE DATA--
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER EXCEPT FOR THE
BALL AND GRID REPLACEMENT DOWNTIME.
4/80 SYSTEM 7?D
5/80 SYSTEM 744
5/BO SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
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 REHEATEB TUBE LEAK PROBLEM CONTINUED THROUGH
THE SECOND QUARTER. THE TUBES WILL BE ENTIRELY REPLACED WITH NEW 316L SS
BUNDLES DURING THE NEXT SCHEDULED OUTAGE IN NOVEMBER AND DECEMBER. DURING
THE SECOND QUARTER MORE TUBES WERE PLUGGED WHEN STEAM LEAKS OCCURRED. TO
DATE ROUGHLY 50* OF THE TUBES ARE SEALED OFF AND ARE OUT OF SERVICE
BECAUSE OF LEAKS THAT OCCURRED OVER THE PAST MONTHS.
225
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING C'PACITY W/SCRUBBER
EQUIVALENT 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 - 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 S?2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
** MECHANICAL COLLECTOR
NUMBER
** PARTICLE SCRUBBER
NUMBER
TYPE
- MW
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
115.0
100.0
1C2.2
< 1010C BTU/LB)
COAL
BITUMINOUS
23*93.
12.50
11.30
.65
.01
WET SCRUBBING
ALKALINE FLYASH
AIR CORRECTION DIVISION, UOP
RETROFIT
4.3
6/73
* * / * *
n
NONE
MOBILE PACKED TOWE"
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
z REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8C SYSTEM
2/80 SYSTEM
3/81? SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
4/80 SYSTEM
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE FIRST QUARTER OF 1980.
THE ISOLATION DAMPERS HAVE NOT CAUSED ANY PROBLEMS BECAUSE MODULE
ISOLATION WAS NOT REQUIRED DURING THE PERIOD.
THE FANS ARE STILL EXPERIENCING EROSION PROBLEMS.
ON MAY 24 A BOILER/SCRUBBER OVERHAUL WILL BEGIN. 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 WITH REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE
TIPS.
720
226
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 1 (CONT.)
.. PERFORMANCE DATA
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION v REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
5/8C SYSTEM 744
6/8C SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBING SYSTEM WERE TAKEN OUT OF SERVICE FOR A SCHEDULED
OVERHAUL ON MAY Z4. THE UNIT IS SCHEDULED TO START UP AGAIN ON JULY 25.
THE 1B ID FAN WAS SEVERELY ERRODED. THE FAjN HAS REBUILT DURING THE OUTAGE.
THE OLD CARBON STEEL ISOLATION DAMPERS WERE REPLACED WITH 316 SS DAMPERS
DURING THE CONTINUING MAY-JULY OUTAGE.
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
MET JNIT GENERATING CAPACITY W/SCRUBBER - MW
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 - 5!
AVERAGE CHLORIDE CONTENT - 7.
** GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - Z
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL Sf2 REMOVAL - Z
PARTICLE DESIGN REMOVAL EFFICIENCY - %
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
375.0
350.0
356.4
t 10100 BTU/LB)
COAL
BITUMINOUS
23493.
12.50
11.30
.65
.01
WET SCRUBBING
ALKALINE FLYASH
AIR CORRECTION DIVISION, UOP
RETROFIT
6.7
7/74
* * / * *
** FABRIC FILTER
NUMBER
TYPE
NONE
«* ESP
NUMBER
** MECHANICAL COLLECTOR
NUMBER
** PARTICLE SCRUBBER
NUMBER
TYPE
MOBILE PACKED TQWER
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
* REMOVAL
SO? PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
1/80 SYSTEM
2/8C SYSTE"
3/8C SYSTEM
** PROBLEMS/SOLUTIONS/COMPENTS
744
696
744
t/6r SYSTEM
A BOILEP/SCRUBBFR OUTAGE BEGAN IN MID-MARCH AND IS SCHEDULED TO CONTINUE
THROUGH EARLY MAY. THE OUTLET DUCT WORK IS- BEING REBUILT INTERNALLY WITH
FIBERGLASS FOR STRUCTURAL SUPPORT AND ACID RESISTANCE. WITH REGULAR MAIN-
TENANCE THE UTILITY EXPECTS THIS TO PROVE iTO BE A PERMANENT SOLUTION TO
THE EROSION/CORROSION PROBLEM.
DURING THE OUTAGE A SECOND LAYER OF VERTICAL GRIDS IS BEING INSTALLED
ON THE THREE LAYER MOBLE BED TOWER. THE VERTICAL GRIDS SHOULD CHECK TH=
POTENTIAL FOR SIDE TO SIDE BALL MIGRATION.
THE OLD FANS ARE BEING REPLACED WITH HIGH STRENGTH CARBON STEEL FANS HAVING
REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE TIPS.
720
228
-------
EPA UTILITY FGD SURVFY: APRIL - JUNE 1980
'UBLIC SERVICE OF COLORADO: CHEROKEE
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198C
SECTION U
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTI&LE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/SCRUBBER - MW
EOUIVALENT SCRUBBED CAPACITY - MW
PUBLIC SERVICE OF COLORADO
VALMONT
5
VALMONT
COLORADO
166.D
157.0
166..-J
** 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
NEy/RETROFIT
ENERGY CONSUMPTION - X
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL ST2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - X
COAL
SUBBITUMINOUS
25121.
6. OP
15.00
.70
{ 1r'80C BTU/LB)
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
UOP/PUBLIC SERVICE OF COLORADO
RETROFIT
3.6
11/71
10/74
8 5. DC
95.00
* FABRIC FILTER
NUMBER
TYPE
0
NONE
** ESP
NUMBER
TYPE
«* MECHANICAL COLLECTOR
NUMBER
** PARTICLE SCRUBBER
NUMBER
TYPE
1
COLD SIDE
1
2
MOBILE PACKED TQHER
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
2/80
3/80
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
1/8P
A
B
SYSTEM
98.5
98.5
98.5
744
A
B
SYSTEM
A
B
SYSTEM
84.4
94.9
89.7
92.8
87.7
89.0
696
744 615
** PROBLEMS/SOLUTIONS/COMMENTS
4/80 A
B
SYSTEM
88.1
88.1
88.1
DURING THE FIRST QUARTER OF 198C, HO MAJOR PROBLEMS HERE ENCOUNTERED WITH
THE SCRUBBER.
720 716
230
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 198C
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
----- PERFORMANCE DATA--
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** 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.
S/B'' A 96.8
B TOO.7
SYSTEM 98.4 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS MERE REPORTED FOR MAY.
5 / 8 ". A 8 . r
B 8.0
SYSTEM 8.? 7?C 72C
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER WAS FORCED OUT OF SERVICE WHEN AN INBOARD FAN
PED1STLE 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 DO
NOT READILY CLOSE. THE OPERATOR MUST MOVE THE DAMPER UP AND DOWN UNTIL THE
GUILLOTINE StATS. BECAUSE Of CONTINUOUS FLY ASH ACCUMULATION IT APPEARS
THAT THE DAMPERS MUST BE EXERCISED FREQUENTLY TO PREVENT JAMMING.
^31
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
SECTION H
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
YET UNIT GENERATING CAPACITY W/SCRUB6ER - 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 - Z
AVERAGE CHLORIDE CONTENT - X
* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PH CONTROL ADDITIVE
SYSTEM SUPPLIER
NEW/RETROFIT
ENERGY CONSUMPTION - I
INITIAL START-UP DATE
COMMERCIAL START-UP DATE
TYPICAL ST2 REMOVAL - X
PARTICLE DESIGN REMOVAL EFFICIENCY - 2
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
TYPE
SOUTHWESTERN PUBLIC SERVICE
HARRINGTON
1
AMARILLO
TEXAS
363.?
320.0
360.0
COAL
SUBBITUHINOUS
19538.
5.90
27.10
.42
( "400 BTU/LB)
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
NEW
4/77
* * / * *
5".?C
99. nc
i
COLD SIDE
MOBILE PACKED TOWER
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
ID/79
11/79
12/79
SYSTEM 744
SYSTEM 720
SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THROUGH DECEMBER, TWO SPRAY PUMP MOTORS FAILED.
THE FRP FLUSH PIPING HAS FAILED CAUSING SOME LEAKING.
PLUGGING IN ONE MARBLE BED WAS ENCOUNTERED WHEN THE CHEMISTRY CONTROL WAS
TEMPORARILY LOST.
THE CONE SHAPED EXPANDED METAL <31fcL 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.
1/80
2/80
3/8?
SYSTEM
SYSTEM
SYSTEM
744
696
744
232
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SOUTHyESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA "
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOI.UTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
CAUSING PLUGGING IN SCRUBBERS 4 AND 5. TH£ UTILITY PLANS TO REPLACE
ALL FRP PIPING WITH STEEL. THE RUPTURE ON NO. 5 ALSO DAMAGED THE WATER
SUPPLY HEADER.
THE MARBLE BED PLUGGING REPORTED DURING THE LAST QUARTER IS NOT VET
COMPLETELY CLEARED. THE SOFT SCALE IS GRADUALLY GOING BACK INTO THE
SOLUTION. THE PLATE AREA IS CLEAN.
THE DUCT BENEATH THE REHEATER 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 WAS WELDED IN. NO OTHER REHEATER DUCTS HAVE EXPERIENCED ANY
SCALE OR MOISTURE ACCUMULATION.
4/80 SYSTEM 720
* PROBLEMS/SOLUTIONS/COMMENTS
A PUMP LINER FAILURE OCCURRED IN APRIL. THE IMPELLER SHAFT LINER WAS RE-
PAIRED AND REPLACED.
5/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN A FEW DAYS IN LATE APRIL AND 12 TO 14 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 AGITA.TORS 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 92.1 720 696 79.3
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER EXHIBITED AN AVAILABILITY OF 92.1Jf. THERE WAS
GREATER SCRUBBER CAPACITY AVAILABLE THAN REQUIRED BY THE BOILER. NO
PROBLEMS WERE REPORTED FOR JUNE.
DAMPER PROBLEMS REPORTED PREVIOUSLY HAVE BEEN 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 (THAN 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 BOTTOM PANELS MAY BE A RESULT OF AN
UNDERSIZED DEFLECTION SHIELD BENEATH THE TUBE BANKS. IT IS ALSO POSSIBLE
THAT THE DUCTING WAS IMPROPERLY WELDED.
233
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - ItW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - J!
AVERAGE SULFUR CONTENT - J!
AVERAGE CHLORIDE CONTENT - X
** FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/RETROFIT
ENERGY CONSUMPTION - I
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
3YPRODUCT NATURE
DISPOSITION
CHUGOKU ELECTRIC
SHIMONOSEKI
1
SHIMONOSEKI
175.0
175.H
175.0
< 10768 ETU/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 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILIT* RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
1/80
2/80
SYSTEM
SYSTEM
100.0
55.2
100.
100.
0
0
100
55
.0
.2
100.
55.
0
2
74*
696
744
384
744
384
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY AND THE FIRST HALF OF FEBRUARY THE FGD UNIT OPERATED WITH
NO PROBLEMS. THE UNIT WAS TAKEN OFF-LINE IN THE MIDDLE OF FEBRUARY FOR
SCHEDULED MAINTENANCE.
3/80 SYSTEM 100.0 .0 .0 744 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED DOUN THROUGH MARCH FOR THE ANNUAL MAINTENANCE.
4/80 SYSTEM 100.0 10P.O 83.1 720 598 598
** PROBLEMS/SOLUTIONS/COMMENTS
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.
234
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
CHUGOKU ELECTRIC: SHIMONOSEKI 1 (CONT.)
- PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION * REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR
5/80 SYSTEM 100.0 100.0 9^.3 744 672 672
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED CONTINOUSLY WITH NO PROBLEMS. A THREE DAY
SHUTDOWN FOR INSPECTION OF THE SCR UNIT FROM MAY 16 TO MAY 19 WAS THE
ONLY DOWN TIME EXPERIENCED DURING MAY.
6/80 SYSTEM 100.0 100.0 10P.O 72C 730 730
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED CONTINOUSLY WITH NO PROBLEM? DURING JUNE.
235
-------
EPA UTILITY FGO SURVEY: APRIL - JUNE 198?
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - MW
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
ELECTRIC POWER DEVELOPMENT CO.
ISOGO
1
YOKOHAMA
JAPAN
265.0
238.0
265.0
COAL
25958.
16.00
7.00
.60
< 11160 BTU/LB)
** FGD 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 - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKF-UP WATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
WET SCRUBBING
LIMESTONE
IHI - CHEMICO
RETROFIT
12/75
3/76
90.00
X 96.7C
.0
OPEN
22.3
GYPSUM
MARKETED
( 354 GPM)
_ -PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79
5/79
6/79
7/79
8/79
9/79
ID/79
11/79
12/79
1/80
2/81
3/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
720
744
744
720
744
720
744
744
696
744
236
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
ELECTRIC POWER DEVELOPMENT CO.: IS060 1 (CONT.)
.. PERFORMANCE DATA ....
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.? 10P.O 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER FOR THE ENTIRE MONTH OF
APRIL.
5/80 SYSTEM 100.P 100.0 100.0 51.6 744 384 384
5/80 SYSTEM 100.? 100.0 100.0 13.3 720 96 96
* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN FROM MAY 17 TO JUNE 27 FOR ANNUAL MAINTEN-
ANCE. THE FGD SYSTEM WAS OPERATED DURING AJ.L OF THE BOILER OPERATION
IN MAY AND JUNE.
237
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY U/FGD - MU
EOUIVALENT 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
* FGD SYSTEM
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEy/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 HATER - LITER/S
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
- X
ELECTRIC POWER
ISOGO
2
YOKOHAMA
JAPAN
265.0
238.0
265.0
COAL
DEVELOPMENT CO.
25958.
16.00
7.00
.60
********
WET SCRUBBING
LIMESTONE
IHI - CHEHICO
RETROFIT
3.0
3/76
5/76
9d.CO
96.70
.0
OPEN
22.3
GYPSUM
MARKETED
( 11.160 BTU/LB)
C 354 GPM)
........ >. PERFORMANCE DATA ..........
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79
5/79
6/79
7/79
8/79
9/79
10/79
11/79
12/79
1/80
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
720
744
744
720
744
720
744
744
696
744
238
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
ELECTRIC POWER DEVELOPMENT CO.: ISOGO 2 (CONT.)
. ...» PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
t/80 SYSTEM TOC.f? 100.0 10P.C 33.3 720 2*0 240
** PROBLEMS/SOLUTIONS/COMMENTS
ON MARCH 30 THE BOILER WAS SHUTDOWN FOR ANNUAL MAINTENANCE. THE UNIT
REMAINED DOWN THROUGH APRIL 20. 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 100.5 100.C 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY AND JUNE THE FGD OPERATED WITH NO PROBLEMS.
239
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
NET UNIT GENERATING CAPACITY U/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
AVERAGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - %
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
FGD 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 - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
* BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
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 - CHEM1CO
RETROFIT
3.2
2/75
**/**
93.00
( 11160 BTU/LB)
.0
OPEN
13.1
GYPSUM
( 208 GPM)
-.. _ _ ___ _-PERFORMANCE DATA -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SO? PART. HOURS HOURS HOURS FACTOR
4/79
5/79
7/79
S/79
9/79
10/79
11/79
12/79
1/80
2/80
3/BO
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
720
744
744
720
744
720
744
744
696
744
240
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
ELECTRIC POWER DEVELOPMENT CO.: TAKASAGO 1 (CONT.)
... __ _ ..... PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 10".0 100.C 30.0 720 216 216
** PROBLEMS/SOLUTIONS/COMMENTS
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
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM EXPERIENCED NO PROBLEMS DURING THE MAY-JUNE PERIOD.
241
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1982
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGD - MU
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 - 5!
** FGD 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 - X
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
ELECTRIC POWER DEVELOPMENT CO.
TAKASAGO
2
TAKASAGO
JAPAN
250.0
230.0
250.0
COAL
25958.
22.00
7.00
1.80
WET SCRUBBING
LIMESTONE
MITSUI - CHEMICO
RETROFIT
3.2
3/76
*»/ **
93.00
( 11160 BTU/LB)
- X
.0
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
OPEN
13.1
< 208 GPM)
** BYPRODUCT
BYPRODUCT NATURE
DISPOSITION
GYPSUM
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79
5/79
S/79
7/79
9/79
9/79
10/79
11/79
12/79
1/80
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
720
744
744
720
744
720
744
744
696
744
242
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
ELECTRIC POWER DEVELOPMENT CO.: TAKASAGO 2 (CONT.)
--- .... PERFORMANCE DATA ...- ____ _-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 198C PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 1CC.O 720 720 720
5/8C SYSTEM 100.0 100.0 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL AND MAY THE UTILITY EXPERIENCED NO PROBLEMS WITH THE FGD
SYSTEM.
6/80 SYSTEM 100.0 100.0
** PROBLENS/SOLUTIONS/COMMENTS
100.0
4.4
720
32
32
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.
243
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198P
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
5ROSS 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
ELECTRIC POWER DEVELOPMENT CO.
TAKEHARA
1
MIHARA
JAPAN
250.0
231.0
250.0
COAL
25130.
23.DO
9.C5
2.CO
.05
< 1H804 BTU/LB)
FGD 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 - I
PARTICULATE DESIGN REMOVAL EFFICIENCY
ABSORBER SPARE COMPONENTS INDEX
- X
WET SCRUBBING
LIMESTONE
BABCOCK - HITACHI
RETROFIT
3.2
2/77
2/79
94. 20
91. 7C
.3
** WATER LOOP
TYPE
FRESH MAKE-UP WATER - LITER/S
** BYPRODUCT
3YPRODUCT NATURE
DISPOSITION
OPEN
14.9
GYPSUM
MARKETED
< 237 GPM)
PERFORMANCE DATA ~ -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/79
5/79
6/79
7/79
3/79
9/79
10/79
11/79
12/79
1/80
2/80
3/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
720
744
720
744
744
720
744
72D
744
744
696
744
244
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
ELECTRIC POUER DEVELOPMENT CO.: TAKEHARA 1 tCONT.)
-PERFORMANCE DATA ~ -
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION J REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 1CO.O 100.0 720 720 720
5/8H SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 72D 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE APRIL, MAY AND JUNE PERIOD THE EGD SYSTEM OPERATED CONTINUOUSLY
MITHOUT APPRECIABLE TROUBLE.
245
-------
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.
0 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
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 Isndfill 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 cost 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 re-r
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
Costs underwritten by system supplier in-
cluded 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 FGD 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-l 8
-------
TABLE A-4. CATEGORICAL RESULTS OF THE REPORTED AND ADJUSTED
CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS
REPORTED- ADJUSTED
CATEGORY CAPITAL, t/KU -ANNUAL, HILLS/KUH -CAPITAL. $/KU -ANNUAL, HILLS/KUH---
RANGE AVG DEV RANGE AVG DEV RANGE AVG DEV RANGE AVG DEV
M
VD
ALL 29.2
NEU 31.8
RETROFIT 29.2
THROUAUAY PRODUCT 29.2
SALEABLE PRODUCT 127.9
LIMESTONE 31.8
LIME ?9,2
DUAL ALKALI 43.2
LIME/ALKALINE FLYASH 77.1
SODIUM CARBONATE 42.9
UELLHAN LORD 127.9
LIMESTONE/ALKALINE FLYASH 47.9
189.0 80.3 39.2
189.0 80.4 39.4
156.9 80.1 38. 5
189.0 76.7 37.5
.1- 14.9 4.5
.1- 14.3 3.3
2.1- 14.9 6.5
.1- 14.3 4.2
-156.9 137.6 13.7 14.9- 14.9 14.9
-.168.0 76.9 38.7 1.3- 3.3 2.1
-128.3 74.9 32.2
-189.0 96,7 65.5
- 85.9 80.0 4.1
-120.0 79.8 37.0
.1- 14.3 6.9
3.2- 3.2 3.2
.3- .3 .3
2.1- 2.1 2.1
156.9 137.6 13.7 14.9- 14.9 14.9
47.9 47.9 .0 2.0- 2.0 2.0
4.4 56.0-140.6 88.0 23.4 2.6- 12.4 5.4 2.4
3.9 66.4-117.6 86.1 17.8 2.8- 8.7 5.2 2.0
4.5 56.0-140.6 90.0 28.1 2.6- 12.4 5.6 2.7
4.1 56.0-140.6 86.2 21.9 2.6- 8.7 5.1 2.0
.0 134.8-134.8 134.8 .0 12.4- 12.4 12.4 .0
.6 56.0-117.6 88.6 25.5 2.6- 6.6 4.6 1.6
4.8 67.5-140.6 90.8 22.2 2.7- 8.7 6.4 2.0
.0 *****- .0 .0 .0 ****+- .0 .0 .0
.0 77.2- 93.0 82.5 7.4 4.1- 5.2 4.5 .5
.0 60.9-107.9 76.6 22.2 3.2- 4.4 3.6 .6
.0 134.8-134.8 134.8 .0 12.4- 12.4 12.4 .0
.0 71.2-71.2 71.2 .0 2.8- 2.8 2.8 .0
-------
EPA UTILITY F6D SURVEY: APRIL - JUNE 1980
SECTION A-1
COSTS FOR OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
ALABAMA ELECTRIC COOP
TONBIGBEE
CAPACITY FACTOR, Z *** 65
TOTAL CAPITAL, $/KW(YEAR) 69.5(1978) ******<
65
CP) ******< C)
s
179.0 MW (NET)
ARIZONA ELECTRIC POWER COOP
APACHE
97.5 MW (NET)
ARIZONA ELECTRIC POyER COOP
97.5 MW (NET)
TOTAL ANNUAL, MI LLS/ K WH ( YE AR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, M I LLS 1 KWH ( YE AR)
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
COST ELEMENTS
*****«( r:) ******(
C.E.J
4A 65
C,E,Hi,J,L,S,
U.W.YI.Z
44 65
C,E,H>,J,L,S,
U.W.Y.Z
65
65
ARIZONA PUBLIC SERVICE
CHOLLA
1
119.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
85 65 65
52.0(1973) 56.0(1977) 56.0(1977)
2.2(1976) 2.6(1977) 2.3(1977)
B,C,E,S,U,X C,E,K,S,U,W C,E,K,S,U,W
ARIZONA PUBLIC SERVICE
CHOLLA
2
264.0 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAH)
COST ELEMENTS
65 65
168.0(1978) ******(
1.5(1978) *«****(
B.D.T.X
65
0) ******( 0)
0) ******( 0)
3IG RIVERS ELECTRIC
SREEN
1
242.0 MW (NET)
CAPACITY FACTOR, X *** 65 65
TOTAL CAPITAL, J/KW(YEAR) 43.C(1976) ******( C) ******(
TOTAL ANNUAL, MILLS/KWH(YEAR) ***«**( C) ******( 0) ******(
COST ELEMENTS B,C
C)
0)
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
416.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
*** 65
93.3(1978) ******(
3.3(1976) ******(
C.E.J^N
65
0) **..**»
C) ******(
C)
C)
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
S17.0 MW (NET)
CAPACITY FACTOR, X *** 65 65
TOTAL CAPITAL, f/KW(YEAR) 189.0(1979) ******( C) *****( C)
TOTAL ANNUAL, MILLS/KWH
COST ELEMENTS C,E,6
COLORADO UTE ELECTRIC ASSN.
CRAIG
2
447.0 MW (NET)
CAPACITY FACTOR, X ***
TOTAL CAPITAL, $/KW(YEAR) 73.7(1979)
TOTAL ANNUAL, MILLS/KWH(YEAR) ******( Q)
COST ELEMENTS A,C
65 65
>**««( Q) ******< Q)
****( 0) ****»*( 0)
C3LUH3US g SOUTHERN OHIO ELEC. CAPACITY FACTOR, X 48 65 65
CONESVILLE TOTAL CAPITAL, S/KU(YEAR) 55.5O975) 70.7(1977) 70.7(1977)
5 TOTAL ANNUAL, MILLS/KWH(YEAR) 5.8(1978) 7.4(1977) 7.4(1977)
411.0 MW (NET) COST ELEMENTS B ,C , Ji,M ,S ,U , C,E,J,M,S,U, C.E.J,M.S.U,
W.X.Y U.Y W.Y
INDICATES COST FIGURES NOT YET AVAILABLE
A- 20
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
COLUMBUS & SOUTHERN OHIO ELEC. CAPACITY FACTOR, x
CONESVILLE TOTAL CAPITAL, $/KW(YEAR)
6 TOTAL ANNUAL, MILLS/KWH(YEAR)
411.0 MW (NET) COST ELEMENTS
48 65 65
55.5*1978) 70.7(1977) ******( 0)
5.8(1978) ******( 0) ******( 0)
B,C,J»,M,S,U, C.E,J,N,S,U,
W.X.Y W,Y
COMMONWEALTH EDISON
POWERTON
51
450.0 MW (NET)
CAPACITY FACTOR, I
TOTAL CAPITAL, $/KW(VEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
** 65
125.0(1979) *****(
******( ft) ****(
C,E,H,J
65
0) *****( 0)
0) ******( 0)
DUBUESNE LIGHT
ELRAMA
1-4
510.0 MW (NET)
CAPACITY FACTOR, X
TOTAL
TOTAL
COST
CAPITAL,
ANNUAL,
ELEMENTS
, $/KW(YEAR)
MILLS/KWH(YEAR)
64
113.4(1976)
8.6(1977)
B ,D,FI,I ,j ,M ,
T.V.X.Y
65
127.1
65
(1977)
127.
7.8(1977)
C.E.I,
U.Y
J.M.S,
C,
U,
E
V
7.
,1
1
(1977)
5(1977)
,
J,M,S.
DUQUESNE LIGHT
PHILLIPS
1-6
408.0 HU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, HILLS/KUH(YEAR)
COST ELEMENTS
70 65 65
106.9(1972) 140.6(1977) 140.6(1977)
7.8(1977) 8.6(1977) 8.2(1977)
B.D.F.I.J.W, C.E.I.J.M.S, C.E.I.J.M.S,
T.V.X.Y U.Y U,Y
INDIANAPOLIS POWER & LIGHT
PETERSBURG
3
532.0 MW (NET)
CAPACITY FACTOR, X ***
TOTAL CAPITAL, J/KW(YEAR) 99.5(1976)
TOTAL ANNUAL, MILLS/KUH(YEAR) ******{ C>
COST ELEMENTS C.F.GiJ.M
65 65
110.6(1977) 110.6(1977)
6.6(1977) 7.4(1977)
C,E,G,J,M,S, C,E,G,J,M,S,
u.y.v
U.W.Y
KANSAS CITY POWER S LIGHT
HAWTHORN
3
90.0 MW (NET)
CAPACITY FACTOR, X 14
TOTAL CAPITAL, J/KW(YEAR) 29.6(1972)
TOTAL ANNUAL, MILLS/KWH(YEAR) 8.4(1977)
COST ELEMENTS B,D,F,T,X
65
87.2(1977)
4.3(1977)
B,C,E,J,K,S,
u.w.x
65
87.2(1977)
4.4(1977)
B,C.E.J.K.S,
U.W.X
KANSAS CITY POWER 8 LIGHT
HAWTHORN
4
90.0 MW (NET)
CAPACITY FACTOR, x ***
TOTAL CAPITAL, J/KW(YEAR) 29.C(1972)
TOTAL ANNUAL, MILLS/KWH(YEAR) 8.4(1977)
COST ELEMENTS B.O.FitT.X
65
87.2(1977)
4.3(1977)
B,C.E.J.K.S.
u.w.x
65
87.2(1977)
4.4(1977)
B,C.E.J.K.S.
U.W.X
KANSAS CITY POWER 8 LIGHT
LA CYGNE
1
874.0 MW (NET)
CAPACITY FACTOR, X 42 65 65
TOTAL CAPITAL, $/KW(YEAR) 53.6(1972) 68.0(1977) 68.0(1977)
TOTAL ANNUAL. «ILLS/KWH(YEAR) 1.3(1978) 3.8(1977) 3.9(1977)
COST ELEMENTS T C.E.J.K.S.U C.E.J.K.S.U
KANSAS POWER & LIGHT
JEFFREY
1
540.0 HW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KWOEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
*** 65
56.8(1978) ******(
******(1978) ******(
B.C
0)
0)
65
0)
0)
KENTUCKY UTILITIES
GREEN RIVER
1-3
64.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, I/KW(YEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR)
COST ELEMENTS
16 65 65
70.3(1975) 77.5(1977) 77.5(1977)
14.3(1977) 2.7(1977) 5.2(1977)
B.C.E.J.S.U, C.E.J.S.U.W C.E.J.S.U.W
INDICATES COST FIGURES NOT YET AVAILABLE
A- 21
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION A-1
COSTS FOR OPERATIONAL F60 SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
REPORTED
COST-
ADJUSTED
STANDARDIZED
ADJUSTED
LOUISVILLE GAS & ELECTRIC
CANE RUN
4
188.D MU (NET)
CAPACITY FACTORt X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
55 65 65
66.&H975) 80.6(1977) 80.6<1977)
2.7(1977) 5.8(1977) 6.2(1977)
C,E,H,J,0,T C,E,H,J.K,0, C,E,H,J,K,Q,
S.U.W S,U,U
LDUISVILLE GAS & ELECTRIC
CANE RUN
5
200.0 MU (NET)
CAPACITY FACTOR, X *** 65 65
TOTAL CAPITAL, J/KWCYEAR) 62.4(1977) 67.5(1977) 67.5(1977)
TOTAL ANNUAL, MILLS/KWH(YEAR) ******( 0) 5.6(1977) 5.6(1977)
COST ELEMENTS C,E,HI,J C,E,H,J,K,S, C,E,H,J,K,S,
u,y u,w
LOUISVILLE GAS & ELECTRIC
CANE RUN
299.0 MW (NET)
LOUISVILLE GAS & ELECTRIC
442.0 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, M I LLS/ KUH ( YEAR )
COST ELEMENTS
CAPACITY FACTOR, X
COST ELEMENTS
*** 65
C,E,Hi,M,S,V,
U
10 65
c.s
65
65
LDUISVILLE GAS & ELECTRIC
PADDY'S RUN
5
72.0 MU (NET)
CAPACITY FACTOR, X *** 65 65
TOTAL CAPITAL, J/KU(YEAR) 52.8(1973) 76.4(1977) 76.4(1977)
TOTAL ANNUAL, MILLS/KUH(YEAR) »*****( 0) 6.5(1977) 6.4(1977)
COST ELEMENTS C.E C,E,S,U,W C.E.S.U.W
1INNKOTA POUER COOPERATIVE
1ILTON R. YOUNG
2
135.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KU(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
*** 65 65
85.9(1976) 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.M.P.S.
u,u u.w
tONONGAHELA POWER
PLEASANTS
1
618.0 MU (NET)
CAPACITY FACTOR, x
TOTAL CAPITAL, J/KU(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
65 65
128.3(1978) ******(
2.8(1978) ******(
B,C,J,S
65
0) *«..*.(
0) ******(
C)
0)
MONTANA POUER
CDLSTR1P
1
360.0 MH (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL. I/KU(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
76 65 65
77.1(1975) 77.2(1977) 77.2(1977)
.3(1977) 4.1(1977) 4.1(1977)
B,C,E(,J,P,T C,E,J,K,P,S, C.E.J.K.P.S,
U,U u,W
10NTANA POWER
C3LSTRIP
2
360.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
76 65 65
77.1(1975) 77.2O977) 77.2(1977)
.3(1977) 4.1(1977) 4.1(1977)
B,C,E),J,P,T C,E,J,K,P,S, C,E,J,K,P,S,
U.W U.W
MEVADA POWER
REID GARDNER
1
125.0 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL. MILLS/KWH(YEAR)
COST ELEMENTS
67 65 65
42.9(1973) 60.9(1977) 60.9(1977)
2.1(1977) 3.2(1977) 3.4(1977)
B,0,EI.P,S,U, B,D,E,P,S,U, B,D,E,P,S.U,
W,X W,X U,X
INDICATES COST FIGURES NOT YET AVAILABLE
A- 22
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION A-1
COSTS FOR OPERATIONAL FGD SYSTEMS
. COST-
UNIT DESCRIPTION COST DESCRIPTION REPORTED ADJUSTED STANDARDIZED
ADJUSTED
NEVADA POWER CAPACITY FACTOR, X 67 65 65
REID GARDNER TOTAL CAPITAL, S/KU(YEAR> 42.19(1973) 60.9(1977) 60.9(1977)
2 TOTAL ANNUAL, MILLS/KUH(YEAR) 2.1(1977) 3.2(1977) 3.4(1977)
125.0 MU (NET) COST ELEMENTS B,D,E,P,S,U, B,D,E,P,S,U, B,0,E,P,S,U,
U»X U.X W,X
NEVADA POyER CAPACITY FACTOR, X 67 65 65
REID GARDNER TOTAL CAPITAL, $/KW(YEAR) 113.6(1975) 107.9(1977) 107.9(1977)
3 TOTAL ANNUAL, MILLS/KUH(YEAR) 2.1(1977) 4.4(1977) 5.0(1977)
125.0 MU (NET) COST ELEMENTS B ,C ,El,L ,S , U, B,C,E,L,S,U, B,C,E,L,S,U,
W,X U.X U.X
NORTHERN INDIANA PUB SERVICE CAPACITY FACTOR, X 77 65 65
DEAN H. MITCHELL TOTAL CAPITAL, J/KU(YEAR) 156.9(1976) 134.8(1977) 134.8(1977)
11 TOTAL ANNUAL, MILLS/KUH{YEAR) 14.8(1976) 12.4(1977) 11.0(1977)
115.0 My (NET) COST ELEMENTS B,C,E,L,N,S, C,E,L,N,S,U, C,E,L,N.S,U,
u,w,x>,z w.z u,z
NORTHERN STATES POWER CAPACITY FACTOR, X 73 65 65
SHERBURNE TOTAL CAPITAL, J/Kg(YEAR) 47.9(1972) 71.2(1977) 71.2(1977)
1 TOTAL ANNUAL, MILLS/KUH(YEAR) 2.0(1977) 2.8(1977) 3.3(1977)
740.0 MU (NET) COST ELEMENTS B ,C , Jl, S ,U ,X, C,E,J,K,S,U, C,E,J,K,S,U,
Z U U
NORTHERN STATES POWER CAPACITY FACTOR, X 73 65 65
SHERBURNE TOTAL CAPITAL, S/KU(YEAR) 47.9(1972) 71.2(1977) 71.2(1977)
2 TOTAL ANNUAL, MILLS/KUH(YEAR) 2.0(1977) 2.8(1977) 3.3(1977)
740.0 MW (NET) COST ELEMENTS B.C.J.S.U.X, C,E,J,K,S,U, C.E.J.K.S.U,
Z U U
PACIFIC POUER 8 LIGHT CAPACITY FACTOR, X *** 65 65
JIN BRIDGES TOTAL CAPITAL, $/KU(YEAR) 120.0(1979) ******( C) *****( C)
4 TOTAL ANNUAL, MILLS/KUH(YEAR) ******( 0) ******( 0) ******( 0)
S50.0 MU (NET) COST ELEMENTS C.E.J
PENNSYLVANIA POUER CAPACITY FACTOR, X 40 65 65
SRUCE MANSFIELD TOTAL CAPITAL, $/KU(YEAR) 120.6(1975) 102.1(1977) 102.1(1977)
1 TOTAL ANNUAL, MILLS/KUH(YEAR) 14.3(1977) 8.7(1977) 10.8(1977)
717.0 HU (NET) COST ELEMENTS B,C,E,G,I,L, C,E,G,I,M,S, C,E.G.I,M.S.
S.U.U.X U,U U.y
PENNSYLVANIA POUER CAPACITY FACTOR, X 40 65 65
3ROCE MANSFIELD TOTAL CAPITAL, $/KU(YEAR) 120.6(1975) 102.1(1977) 102.1(1977)
2 TOTAL ANNUAL, MILLS/KUH(YEAR) 14.3(1977) 8.7(1977) 10.8(1977)
917.0 MU (NET) COST ELEMENTS B , C , E'.G , I ,L , C,E,G,I,M,S, C.E.G.I.M.S,
S,U,U%X U,U U,U
PUBLIC SERVICE OF NEW MEXICO CAPACITY FACTOR, X *** 65 65
SAN JUAN TOTAL CAPITAL, S/KW(YEAR) 127.9(1977) ******( 0) ******( 0)
1 TOTAL ANNUAL, MILLS/KUH(YEAR) ******( C) **«*( 0) ******( C)
361.0 MU (NET) COST ELEMENTS A,C,E,N
PUBLIC SERVICE OF NEW MEXICO CAPACITY FACTOR, x *** 65 65
SAN JUAN TOTAL CAPITAL, J/KU(YEAR) 127.9(1977) ******( 0) ******( D)
2 TOTAL ANNUAL, MILLS/KUH(YEAR) ******( 0) ******( 0) ******( 0)
350.0 MU (NET) COST ELEMENTS A.C.E.N
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 23
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 198"
SECTION A-1
COSTS FOP OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
COST DESCRIPTION
COST
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
SALT RIVER PROJECT
CDRONADO
1
280.0 MW (NET)
CAPACITY FACTOR, 5! ***
TOTAL CAPITAL, $/KU(YEAR) 74.£(1978)
TOTAL ANNUAL, MILLS/KWH(YEAR) ******( C)
COST ELEMENTS C,E
65
65
0) ****<
0) ******(
0)
SOUTH CAROLINA PUBLIC SERVICE CAPACITY FACTOR, X 80 65 65
TOTAL CAPITAL, $/KW(YEAR) 47.4(1976) 66.4(1977) 66.4(1977)
TOTAL ANNUAL, MILLS/KWH(YEAR) 1.6(1975) ?.9(1977) 3.Z(1977)
140.0 MW (NET) COST ELEMENTS C,F,J,M,S,V C,E,J,KtM,S, C,E,J,K,M,S,
U,W U,W
SDUTH MISSISSIPPI ELEC PWR
R.D. MORROW
1
124.0 MW (NET)
CAPACITY FACTOR, X *** 65
TOTAL CAPITAL, $/KW(YEAR) 37.4(1975) ******(
TOTAL ANNUAL, MI LLS / K WH ( YE AR ) ******( D ******(
COST ELEMENTS C,E
0)
C)
65
C)
S3UTH MISSISSIPPI ELEC PUR
R.D. MORROW
2
124.0 MW (NET)
CAPACITY FACTOR, X *** 65 65
TOTAL CAPITAL, J/KW(YEAR) 37.4(1975) *****( 0) »*****(
TOTAL ANNUAL, M I LLS/K WH ( Y E AR ) ******( O ******( C) ******(
COST ELEMENTS C,E
0)
D
SOUTHERN ILLINOIS POWER COOP CAPACITY FACTOR, X 65 65
1ARION TOTAL CAPITAL, $/KU(YEAR) 152.7(1978) ******( D)
4 TOTAL ANNUAL, MILLS/KWH(YEAR) 1.8(1978) ******( C)
1S4.0 MW (NET) COST ELEMENTS B.C.T.X
65
>( 0)
>( D
SOUTHERN INDIANA GAS 8 ELEC CAPACITY FACTOR, X ***
A.B. BROWN TOTAL CAPITAL, t/KW(YEAR) 43.6(1979)
1 TOTAL ANNUAL, MILLS/KWH(YEAR) ******( 0)
265.0 MW (NET) COST ELEMENTS C,E,G
65 65
>**.*( 0) ******( C)
»**.*< 0) ******( 0)
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
194.0 MW (NET)
CAPACITY FACTOR, % *** 65 65
TOTAL CAPITAL, J/KW(YEAR) 77.3(1974) 117.6(1977) 117.6(1977)
TOTAL ANNUAL, MILLS/KWH(YEAR) ******( 0) 6.2(1977) 6.9(1977)
COST ELEMENTS C,F,H.,J,P C,E,H,J,K,P. C, E ,H, J ,K ,P,
s.u.y s.u.w
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
3
550.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR>
COST ELEMENTS
60 65 65
98.1(1976) 113.1(1977) 113.1(1977)
3.0(1977) 5.3(1977) 5.1(1977)
B,C,EVP,R,T, C,E,J,S,U,U C.E.J.S.U.U
u
UTAH POWER & LIGHT
HUNTER
1
360.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
65 65
91.1(1978) ******(
.K1978) ******(
B,C,T,X
65
0) **(
0) ******(
0)
C)
UTAH POWER & LIGHT
HUNTINGTON
1
366.0 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, $/KU(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
80 65
85.9(1978) *****(
1.4(1978) ******(
B.C.TI.X
65
0) ******(
C) *.****(
0)
0)
INDICATES COST FIGURES NOT YET AVAILABLE
A- 24
-------
EPA UTILITY FGD SURVEY: APRIL - JUNE 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
JMIT DESCRIPTION
BASIN ELECTRIC POWER COOP
L A R A MI E RIVER
1
570.0 MW (NET)
3ASIN ELECTRIC POWER COOP
?
570. 3 MW (NET)
BOSTON EDISON
X.
150. D MW (NET)
C3LORADO UTE ELECTRIC ASSN.
1
447.0 MW (NET)
ILLINOIS POWER COMPANY
11&.0 MW (NET)
COST DESCRIPTION
CAPACITY FACTOR, %
COST ELEMENTS
CAPACITY FACTOR, X
COST ELEMENTS
CAPACITY FACTOR, %
COST ELEMENTS
CAPACITY FACTOR, X
COST ELEMENTS
CAPACITY FACTOR, %
COST ELEMENTS
REPORTED
** *
C,E
** *
56.0(1 980) '
9 (78 I'd) '
C,E
* * *
B.CVF,N«G
+ * *
BfD, F
** *
A , C , E i M t N
ADJUSTED STANDARDIZED
ADJUSTED
65 65
65 65
J>5 65
65 65
65 65
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
120.0 MW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, J/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
*** 65 65
156.7(1972) 233.2(1977) 233.2(1977)
2.6(1972) 1?.9(1977) 12.4(1977)
D,F,N.,P C.E.N.P C,E,N,P
SftLT RIVER PROJECT
280.3 MW (NET)
CAPACITY FACTOR, X
COST ELEMENTS
*** 65
C.E
65
INDICATES COST FIGURES NOT YET AVAILABLE
A- 25
-------
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 S02
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 S02 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 S02 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 SO2 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 S02
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
-------
the gross unit rating if the
system is not meant to bring
the facility into compliance
with S02 emission standards.
Unit Rating
Gross Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
New w/FGD Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Net w/o FGD 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/G 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
ft2
gr/scf
ppm ,
lb/10 Btu
ft3/min
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
ft3
(actual)
Ib
t
in. H20
Op
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
3
M2
M2
g/m3
ppm
ng/J
m3/s
liter/s
kg/s
M t/d
M t/h
J/g
m
cm
km
liter/m3
kg
Mg
kPa
°C
""T
3
m
Survey Report
Notation
SQ.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
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APPENDIX D
FGD PROCESS FLOW DIAGRAMS
D-]
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FURNACE
DAMPERS
ONE
STACK
o
i
ro
SPRAY PUMP (TRANSFER TANK
TWO PRECIPITATORS
FOUR I.D. FANS
WATER RETURN TO
REACTION TANKS
FOUR
REACTION
TANKS
SLUDGE DISPOSAL
POND
Kansas Power and Light,
Schematic of Jeffrey Steam Generator and Emission Control Equipment
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TECHNICAL REPORT DATA
(Please read Instructions on the reverse before e
1. REPORT NO.
EPA-600/7-80-029C
2.
3. RECIPIENT'S ACCESSION NO
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: April - June 1980
5 REPORT DATE
July 1980
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
M. Smith, M. Melia, N. Gregory
8 PERFORMING ORGANIZATION REPORT NO.
PN 3570-1-Z
9. PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
10. PROGRAM ELEMENT NO.
INE828
11. CONTRACT/GRANT NO.
68-01-4147, Task 143
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Quarterly: 4-6/8Q
14. SPONSORING AGENCY CODE
EPA/600/13
15. SUPPLEMENTARY NOTES
IERL-RTP project officer is Norman Kaplan, Mail Drop 61, 919/541-
2556. The report supplements EPA-600/7-80-029a.
16. ABSTRACT
This report is the second 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 opera-
tional and planned domestic utility flue gas desulfurization (FGD) systems, opera-
tional domestic particle scrubbers, and Japanese coal-fired utility boiler FGD in-
stallations. It summarizes information contributed by the utility industry, process
suppliers, regulatory agencies, and consulting engineering firms. Domestic FGD
systems are tabulated alphabetically by development status (operational, under
construction, or in planning stages), utility company, process supplier, process,
and waste disposal practice. It presents data on boiler design, FGD system design,
fuel characteristics, and actual performance. It includes unit by unit dependa-
bility parameters and discusses problems and solutions associated with the boilers
and FGD systems. Process flow diagrams and FGD system economic data are appended.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
COSATi Field/Group
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
13B
21B
07A,
15E
13A
07D
18. DISTRIBUTION STATEMENT
Release to public
19. SECURITY CLASS (THis Report)
Unclassified
21. NO. OF PAGES
308
20. SECURITY CLASS (This page)
Unclassified
22. PRICE
EPA Form 2220-1 (t-73)
D-3
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