v>EPA
United States
Environmental Protection
Agency
Industrial Environmental Research EPA-600/7-81-012a
Laboratory January 1981
Research Triangle Park NC 27711 - 1
EPA Utility FGD Survey:
OctobeV - December 1980
Volume I. Categorical
Summaries of FGD Systems
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-600/7-81-012a
January 1981
EPA Utility FGD Survey:
October - December 1980
Volume I. Categorical Summaries
of FGD Systems
by
M. Smith, M. Melia, N. Gregory, and K. Scalf
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
Contract No. 68-02-3173
Task No. 17
Program Element No. 1NE828
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
,,enc;vi Washington, DC 20460
and
rotfi '**
60604 _
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Enforcement
Washington, DC 20460
1-rnAt
-------
NOTICE
This report (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio under EPA Contract No. 68-02-3173, Task No. 17) 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 preceding 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 first or second quarter,
1981, 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 cannot be conveniently printed in this report. Direct
access to the data base will allow statistical analyses of the
data (e.g., averages, maxima, minima, and standard deviation
of various parameters) and tabulation of the data to fit the
individual informational needs of the user. 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.
11,8. Environmental Protection Agency
-------
USE OF THIS REPORT
This report is the first full compilation (not a supplement)
since the October-December 1979 report (EPA-600/7-80-029a). Be-
cause the next three reports are to be supplements, this issue
should be retained for reference throughout the year. Much of
the design and performance data contained in this issue will not
be published again until February 1982. Supplemental issues are
cumulative in nature, so that it is necessary only to retain the
latest issue and this report to have all the available informa-
tion.
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 December 1980,
future projections (December 1990) of controlled and uncontrolled
generating capacity, and unit by unit summaries of status changes
and performance during the period.
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, which is generated by a computerized data base
system, presents a survey of operational and planned domestic
utility flue gas desulfurization (FGD) systems, operational
domestic particle scrubbers, and Japanese coal-fired utility
boiler FGD installations. It summarizes information contributed
by the utility industry, system and equipment suppliers, system
designers, research organizations, and regulatory agencies. It
presents data on system design, fuel characteristics, operating
history and actual performance. Unit by unit dependability
parameters are included and problems and solutions associated
with the boilers, scrubbers, and FGD systems are discussed.
The domestic FGD systems are tabulated alphabetically by
development status (operational, under construction, or in the
planning stages), utility company, system supplier, process,
waste disposal practice, and regulatory class. FGD system
economic data, definitions, and a glossary of terms are appended
to the report. Current data for domestic FGD systems show 84
systems in operation, 34 systems under construction, and 105
planned systems. Projected 1990 FGD controlled capacity in the
U.S. is 106,846 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
Status of FGD Systems
Alabama Electric
Tombigbee 2
Tombigbee 3
Arizona Electric Power
Apache 2
Apache 3
Arizona Public Service
Cholla 1
Cholla 2
Four Corners 1
Four Corners 2
Four Corners 3
Basin Electric Power Coop
Laramie River 1
Big Rivers Electric
Green 1
Green 2
Central Illinois Light
Duck Creek 1
Central Illinois Public Service
Newton 1
Colorado Ute Electric Assn.
Craig 1
Craig 2
Columbus & Southern Ohio Electric
Conesville 5
Conesville 6
Section 3, Pages 47-656 appear in Volume II.
v
11
iii
iv
xi
xii
1
9
Design and Performance Data for Operational
FGD Systems 47*
47*
54*
60*
67*
73*
90*
95*
98*
101*
104*
108*
112*
115*
128*
134*
138*
144*
155*
EPA-600/7-81-012b,
-------
CONTENTS (continued)
Commonwealth Edison
Powerton 51
Cooperative Power Association
Coal Creek 1
Coal Creek 2
Delmarva Power & Light
Delaware City 1
Delaware City 2
Delaware City. 3
Duquesne Light
Elrama 1-4
Phillips 1-6
Gulf Power
Scholz 1
Indianapolis Power & Light
Petersburg 3
Kansas City Power & Light
Hawthorn 3
Hawthorn 4
LaCygne 1
Kansas Power & Light
Jeffrey 1
Jeffrey 2
Lawrence 4
Lawrence 5
Kentucky Utilities
Green River 1-3
Louisville Gas & Electric
Cane Run 4
Cane Run 5
Cane Run 6
Mill Creek 1
Mill Creek 3
Paddy's Run 6
Minnesota Power & Light
Clay Boswell 4
Minnkota Power Cooperative
Milton R. Young 2
Monongahela Power
Pleasants 1
Pleasants 2
Montana Power
Colstrip 1
Colstrip 2
Page
163*
167*
172*
175*
179*
183*
187*
200*
220*
222*
230*
240*
251*
272*
277*
280*
291*
301*
310*
318*
325*
331*
333*
338*
349*
354*
366*
370*
372*
379*
Section 3, Pages 47-656 appear in Volume II. EPA-600/7-81-012b.
VI
-------
CONTENTS (continued)
Nevada Power
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Northern Indiana Public Service
Dean H. Mitchell 11
Northern States Power
Riverside 6,7
Sherburne 1
Sherburne 2
Pacific Power & Light
Jim Bridger 4
Pennsylvania Power
Bruce Mansfield 1
Bruce Mansfield 2
Bruce Mansfield 3
Public Service Company of New Mexico
San Juan 1
San Juan 2
San Juan 3
Salt River Project
Coronado 1
Coronado 2
South Carolina Public Service Authority
Winyah 2
Winyah 3
South Mississippi Electric
R.D. Morrow, SR. 1
R.D. Morrow, SR. 2
Southern Illinois Power Coop
Marion 4
Southern Indiana Gas & Electric
A.B. Brown 1
Springfield City Utilities
Southwest 1
Springfield Water, Light & Power
Dallman 3
St. Joe Zinc
G.F. Weaton 1
Tennessee Valley Authority
Shawnee 10A
Shawnee 10B
Widows Creek 8
Texas Power & Light
Sandow 4
385*
399*
416*
428*
439*
442*
459*
472*
476*
489*
497*
500*
508*
516*
521*
525*
529*
536*
539*
546*
552*
558*
565*
579*
582*
586*
588*
605*
619*
Section 3, Pages 47-656 appear in Volume II. EPA-600/7-81-012b,
via.
-------
CONTENTS (continued)
Paqe
Texas Utilities
Martin Lake 1 621*
Martin Lake 2 628*
Martin Lake 3 634*
Monticello 3 639*
Utah Power & Light
Hunter 1 644*
Hunter 2 648*
Huntington 1 651*
Summary of FGD Systems by Company 657
Summary of FGD Systems by System Supplier 659
. Summary of FGD Systems by Process 661
Summary of Operating FGD Systems by
Process and Unit 662
Summary of End-Product Disposal
Practices for Operational FGD Systems 665
Summary of FGD Systems in Operation 667
Summary of FGD Systems Under Construction 671
Summary of Contract Awarded FGD Systems 673
Summary of Planned FGD Systems 675
Total FGD Units and Capacity (MW)
Installed by Year 679
Design and Performance Data for
Operational Particle Scrubbers . 680
Commonwealth Edison
Will County 1 680
Detroit Edison
St. Clair 6 699
Minnesota Power and Light
Clay Boswell 3 707
Syl Laskin 1 710
Syl Laskin 2 713
Montana-Dakota Utilities
Lewis & Clark 1 716
Section 3, Pages 47-656 appear in Volume II. EPA-600/7-81-012b,
Section 4
Section 5
Section 6
Section 7
Section 8
Section 9
Section 10
Section 11
Section 12
Section 13
Section 14
Vlll
-------
CONTENTS (continued)
Section 15
Section 16
Pacific Power and Light
Dave Johnston 4
Potomac Electric Power
Dickerson 1
Dickerson 2
Dickerson 3
Public Service of Colorado
Arapahoe 4
Cherokee 1
Cherokee 4
Valmont 5
Southwestern Public Service
Harrington 1
Design and Performance Data for
Operational Foreign FGD Systems
Chugoku Electric
Shimonoseki 1
Electric Power Development Company
Isogo 1
Isogo 2
Takasago 1
Takasago 2
Takehara 1
Hokkaido Electric Power
Tomakomai Thermal
Design and Performance Data for
Discontinued Domestic FGD Systems
Arizona Public Service
Four Corners 5A
Boston Edison
Mystic 6
Commonwealth Edison
Will County 1A
Dairyland Power Coop
Alma 5
Detroit Edison
St. Clair 6A
Gulf Power
Scholz 1A
Scholz 1B,2B
Scholz 1,2
Scholz 2A
719
722
724
726
733
736
739
742
749
752
752
756
761
766
773
779
784
787
787
790
794
798
800
803
807
812
816
IX
-------
CONTENTS (continued)
Appendix A
Appendix B
Appendix C
Appendix D
Illinois Power Company
Wood River 4
Key West Utility Board
Stock Island 1
Philadelphia Electric
Eddystone 1A
Potomac Electric Power
Dickerson 3A
Public Service of Colorado
Valmont 5A
Southern California Edison
Mohave 1A
Mohave 2A
Tennessee Valley Authority
Shawnee IOC
Union Electric
Meremac 2
FGD System Cost Data: Operational
and Nonoperational Systems
Introduction
Results of the Cost Analysis
Adjustment Procedure and Background
Costs for Operational FGD Systems
Costs for Nonoperational FGD Systems
Definitions
Table of Unit Notation
FGD Process Flow Diagrams
819
822
826
834
837
840
843
846
848
A-l
A-2
A-6
A-9
A-21
A-31
B-l
C-l
D-l
-------
TABLES
No. Page
I Number and Total Capacity of FGD Systems xii
II Summary of Changes, October - December 1980 xiv
III Performance of Operational Units,
October - December 1980 xvii
FIGURE
No. Page
1 Computerized Data Base Structure Diagram xiii
XI
-------
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
Stationary Source Enforcement Division of the U.S. Environmental
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 December 1980. Table II lists the units
that have changed status during the fourth 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
84
34
30
10
16
49
223
Total
control 1 ed
capacity, MW*
31,109
14,888
14,903
7,515
8,735
29,696
106,846
Equivalent
scrubbed +
capacity, MW
28,214
14,285
14,890
7,515
8,735
29,360
102,999
* 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).
t
Equivalent Scrubbed Capacity (ESC)
scrubbed flue gas in equivalent MW
scrubbed by the FGD system(s).
is the summation of the effective
based on the percent of flue gas
Xll
-------
Figure 1. Computerized data base
structure diagram.
-------
TABLE II. SUMMARY OF CHANGES
OCTOBER - DECEMBER 1980
FGO status report
September 30, 1980
Big Rivers Electric
Green 2
Cajun Electric Power Coop
Chicot 1
Chicot 2
Chicot 3
Chicot 4
Oxbow 1
Oxbow 2
Colorado Ute Electric Assn.
Craig 1
East Kentucky Power Coop
J.K. Smith 1
J.K. Smith 2
Florida Power 8 Light
Martin 3
Martin 4
General Public
Coal 1
Coho 1
Gulf Power
Scholz 1
Houston Lighting ?, Power
Limestone 1
Limestone 2
Operational
No.
76
+1
+1
+ 1
MW«
25,832
242
447
20
Under
construction
No.
39
-1
-1
MWa
16,442
242
447
Contract
awarded
No.
30
+1
+ 1
MWU
14,164
750
750
Letter
of intent.
No.
7
+ 1
+ 1
MW°
5,590
650
650
Requesting/
eval . bids
no.
18
-H
+ 1
-1
-1
-1
MW .
9,696^
540
625
690
750
750
Considering
FfiD
No.
38
+1
4
4
4
-
•4
-1
-1
+ 1
+ 1
-1
MW
23,000
540
540
540
540
540
540
650
F50
800
800
625
Total
Mo.
208
+ 1
+1
+ 1
+1
+1
+1
+1
-1
+1
f™ h
94,724
540
540
540
540
540
800
800
690
20
(c< ntinued)
-------
TABLE II (continued)
FGD status report
September 30, 1980
Kentucky Utilities
Hancock 1
Hancock 2
Louisville Gas & Electric
Mill Creek 1
Lower Colorado River Authority
Fayette Pwr Project 3
Marquette Board of Light
S, Pwr
Shiras 3
Michigan So. Central Pwr
Agency
Project 1
Monongahela Power
Pleasants 2
New York State Electric
ti Gas
Somerset 1
Northern States Power
Metro coal 1
Riverside 6, 7
Sherburne 3
Wisconsin coal 1
Philadelphia Electric
Cromby 1
Soy land Power Coop
Soy land 1
Operational
No.
76
+ 1
+1
+1
Mwa
25,832
358
618
110
Under
construction
No.
39
-1
+1
-1
-1
+1
MWa
16,442
358
55
618
110
150
Contract
awarded
no.
30
+1
-1
-1
MW"
14,164
31
55
150
Letter
of intent
No.
7
+ 1
MW"
5,590
625
Requesting/
eval. bids
No.
18
-1
-1
MWa,
9,696b
31
625
Considering
FGD
No.
38
+1
+1
+1
+1
+1
+1
+1
MWa
23,000
650
650
435
200
850
670
500
Total
No.
208
+1
+ 1
*1
+1
<-}
+1
+1
MW h
94,724°
650
650
435
200
850
670
500
(continued)
-------
TABLE II (continued)
FGD status report
September 30, 1980
Springfield Water, Light
* Pwr
Da 11 man 3
Tennessee Valley Authority
Johnsonville 1-10
Texas Power i Light
Sandow 4
Washington Hater Power
Creston Coal 1
West Texas Utilities
Oklaunion 1
Oklaunion 2
Total
Operational
No.
76
+1
+1
84
MWa
25,832
205
382
28,214
I'r
const
No.
39
-1
-1
34
der
ruction
MW
16,442
205
382
14,285
Contract
awarded
No.
30
-1
30
MW"
14,164
600
14,890
Letter
of intent
No.
7
10
f1W
5,590
7,515
Requesting/
eval. bids
Mo.
18
*1
16
*1Wa
9,696b
720
8,735
Considering
FGD
No.
38
tl
-1
+1
49
MW
23,000
570
720
720
29,360
Total
No.
208
-1
+1
+1
223
riw
94,724°
600
570
720
102,999
X
<
H-
Equivalent scrubbed capacity.
bThis value was modified slightly due to a MW correction.
-------
TABLE III. PERFORMANCE OF OPERATIONAL UNITS
OCTOBER - DECEMBER 1980
Plant
Tombigbee 2
Tombigbee 3
Apache 2
Apache 3
Cholla 1
Cholla 2
Four Corners 1
Four Corners 2
Four Corners 3
Laramie River 1
Green 1
Green 2
Duck Creek 1
Newton 1
v
5 Craig 1
I-1- Craig 2
Conesville 5
Conesville 6
Powerton 51
Coal Creek 1
Coal Creek 2
Delaware City 1
Delaware City 2
Delaware City 3
Elrama 1-4
Phillips 1-6
Scholz 1
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne 1
Jeffrey 1
Jeffrey 2
Lawrence 4
Lawrence 5
Green River 1-3
FGD system
capacity,
MWa
179
179
98
98
119
264
175
175
229
570
242
242
416
617
447
400
411
411
450
327
327
60
60
60
510
408
20
532
90
90
820
540
490
125
420
64
Flue gas
% scrubbed
70
70
50
50
100
100
100
100
100
100
100
100
100
100
100
87
100
100
100
60
60
100
100
100
100
100
N/Ad
100
100
100
100
75
70
100
100
100
FGD capacity
on 1 i ne
during
•Si*.
179
179
98
98
570
242
416
617
447
400
411
411
327
327
60
60
60
510
408
20
90
90
820
540
490
125
420
No information
for this
period, MWa
119
264
175
175
229
242
532
Shut down
throughout
period.
450
64
October 1980
Dependabi ity %c'e
AVL
50
97
93
76
100
73
76
100
91
92
66
60
44
100
72
100
100
100
100
100
100
100
100
OPR
0
63
88
88
100
72
36
91
79
80
0
46
68
66
60
44
97
70
100
100
0
100
100
100
100
REL
63
99
97
100
75
46
95
82
81
66
60
44
100
71
100
100
100
100
100
100
UTL
0
63
82
68
96
72
16
12
77
72
0
9
68
66
60
44
97
70
33
68
0
37
100
100
65
0
November 1980
Dependability % '
AVL
50
99
20
100
100
97
99
71
83
99
94
98
0
100
85
80
72
99
100
100
100
100
100
OPR
37
86
22
96
98
89
85
74
50
87
0
43
61
96
98
0
99
84
100
100
87
100
100
100
100
REL
37
86
40
96
100
99
100
79
52
86
96
98
0
99
85
100
100
86
100
100
100
100
UTL
8
86
7
96
79
68
85
33
44
52
0
43
43
94
98
0
99
84
40
66
8
87
56
90
100
0
December 1980
Dependability %c'e
AVL
81
100
100
100
100
92
74
63
52
92
87
34
100
82
58
92
99
100
100
100
100
100
OPR
77
77
100
99
100
91
70
57
68
88
80
0
47
55
56
100
79
100
100
94
100
100
100
100
REL
77
77
100
100
100
94
85
79
70
87
80
56
100
79
100
100
98
100
100
100
100
UTL
73
77
100
97
93
91
69
55
51
81
80
0
46
54
31
100
79
76
25
59
65
99
63
98
100
0
-------
TABLE III (continued)
Plant
Cane Run 4
Cane Run 5
Cane Run 6
Mill Creek 1
Mill Creek 3
Paddy' s Run 6
Clay Boswell 4
Milton R. Young 2
Pleasants 1
Pleasants 2
Colstrip 1
Colstrip 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 1
Riversidt 6, 7
Sherburne 1
Sherburne 2
Jim Bridger 4
Bruce Mansfield 1
Bruce Mansfield 2
Bruce Mansfield 3
San Juan 1
San Juan 2
San Juan 3
Coronado 1
Coronado 2
Winyah 2
Winyah 3
R.D. Morrow, Sr. 1
R.D. Morrow, Sr. 2
Marion 4
A.B. Brown 1
Southwest 1
:GD system
capacity,
MW*
188
200
299
358
442
72
475
185
618
618
360
360
125
125
125
1 115
110
740
740
550
917
917
917
361
350
534
280
280
280
280
124
124
173
265
194
Flue gas
% scrubbed
100
100
100
100
100
100
85
42
100
100
100
100
100
100
100
99
N/Ad
100
100
100
100
100
100
100
100
100
80
80
100
100
62
62
100
100
100
FGD capacity
on line
during
period,
MWa'C
188
200
299
358
442
475
185
618
618
125
125
125
115
110
740
740
550
917
917
917
361
350
534
280
280
124
124
173
265
194
No information
for this
period, MW
360
360
280
280
Shut down
throughout
period,
MW
72
October 1980
Dependability % '
AVL
100
100
100
100
0
100
98
100
85
97
100
100
98
97
89
51
11
14
92
63
80
100
99
0
OPR
100
100
100
97
0
51
85
98
0
84
90
100
100
100
inn
100
73
25
93
94
94
99
100
96
0
REL
100
100
100
97
100
87
98
84
90
100
100
74
27
93
91
94
99
100
96
0
UTL
82
10
100
97
0
37
76
0
93
0
81
75
72
100
0
28
90
74
51
10
14
90
25
80
58
96
0
November 1980
Dependability % '
AVL
72
100
85
57
0
100
100
100
95
95
100
100
100
100
97
90
96
82
100
73
25
80
90
98
0
OPR
53
100
97
49
0
69
95
100
94
100
94
0
100
100
100
86
60
100
73
42
95
0
84
0
REL
53
100
97
49
100
99
100
92
95
94
100
96
60
100
73
42
95
0
85
0
UTL
35
25
55
42
0
63
91
36
62
95
86
0
100
0
83
63
78
38
100
73
11
75
0
55
0
December 1980
Dependability %c'e
AVL
100
100
60
45
100
0
100
72
81
100
100
93
100
100
95
100
98
91
100
86
99
95
100
50
80
99
43
OPR
100
100
6
99
100
0
88
63
77
99
96
63
100
100
77
100
100
90
52
99
97
99
93
78
96
6
REL
100
100
6
99
100
100
67
75
100
100
63
100
100
93
99
100
99
97
99
93
78
96
8
UTL
77
100
2
45
61
0
84
61
53
98
71
50
81
100
69
0
68
68
88
42
99
95
64
50
72
93
4
X
<
H-
H-
H-
-------
TABLE III (continued)
Plant
Dallman 3
G.F. Weaton 1
Shawnee 10A
Shawnee 10B
Widows Creek 8
Sandow 4
Martin Lake 1
Martin Lake 2
Martin Lake 3
Monticello 3
Hunter 1
Hunter 2
Huntington 1
TOTAL
FGO system
capacity,
HW3
205
60
10
10
550
382
595
595
595
800
360
360
366
28,214
Flue gas
% scrubbed
100
N/Ad
N/Ad
N/Ad
100
70
75
75
75
100
90
90
85
FGD Capacity
on line
during
period,
MWa'C
205
60
10
10
382
595
595
595
800
360
360
366
24,062
No information
for this
period, MW
550
3,566
Shut down
throughout
period,
MW3
586
October 1980
Dependability %c>e
AVL
OPR
100
100
100
REL
97
99
UTL
38
86
88
97
70
98
November 1980
Dependability %c'e
AVL
OPR
80
100
100
REL
98
100
UTL
14
87
64
76
98
100
December 1980
Dependability %c'e
AVL
OPR
97
100
100
REL
UTL
25
96
100
100
H-
X
k Equivalent scrubbed capacity.
c This category includes the flue gas capacity being handled by the FGD system at least part of the time during the report period.
d 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.
-------
Current projections indicate that the total power generating
capacity of the U.S. electric utility industry will be approxi-
mately 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 capac-
ity at the end of each year.b) Approximately 370 GW or 44 per-
cent 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:9
December 1979
December 1990
Coal
39%
44%
Nuclear
9%
14%
Oil
25%
20%
Hydro
13%
11%
Gas
13%
10%
Other
1%
1%
GW (total)
603
833
Based on the known commitments to FGD by utilities as presented
in Table I, the percentage of electrical generating capacity
controlled by FGD for both the present (December 1980) and the
future (December 1990) is as follows:
December 1980*
December 1990
Coal-fired generating
capacity, %
13.2
29.2
Total generating
capacity, %
5.2
12.8
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 (December 1980) and a
projected (December 1990) breakdown of throwaway product systems
versus salable product systems as a percent of the total known
commitments to FGD as of the end of the fourth quarter 1980:
The number of committed FGD systems is as of December 1980;
however, the figure used for the total generating capacity and
coal-fired generating capacity is based on the available
December 1979 figures.
xx
-------
Throwaway product process
°Wet systems
Lime
Limestone
Dual alkali
Sodium carbonate
N/Aa
°Dry systems
Lime
Sodium carbonate
Salable product process
°Process °Byproduct
Aqueous carbonate/ Elemental sulfur
spray drying
Citrate Elemental sulfur
Lime Gypsum
Limestone Gypsum
Lime/limestone Gypsum
Magnesium oxide Sulfuric acid
Wellman Lord Sulfuric acid
Wellman Lord Elemental sulfur
Process undecided
Total
Percent of total MW
December
1980
40.5
45.9
4.2
3.3
-
0.5
-
-
0.2
-
-
-
-
2.5
2.9
_
100.0
December
1990
21.0
36.5
2.0
3.1
6.5
2.9
0.4
0.1
0.1
0.1
0.2
0.5
0.7
1.2
0.7
24.0
100.0
aNA - Not available (these systems are committed to a throwaway product
process; however, the actual process is unknown at this time).
HIGHLIGHTS: OCTOBER - DECEMBER 1980
The following paragraphs highlight FGD system developments during
the fourth quarter 1980.
Alabama Electric Cooperative reported that the Tombigbee 3 FGD
system achieved availabilities of 97%, 99%, and 100% for the
months of October, November, and December, respectively. The
utility reported that no major problems occurred during this
period.
xxi
-------
The limestone FGD system installed at the Laramie River unit of
Basin Electric Power Cooperative achieved 100% availability
during the months of October, November, and December. The only
problems reported for this period were boiler related.
Big Rivers Electric announced that initial FGD operations at
Green 2 commenced in November 1980. The 242 MW (gross) boiler
fires bituminous coal with an average sulfur content of 3.75%.
The FGD system was supplied by American Air Filter and consists
of two lime spray towers designed to remove 90% of the inlet S02-
The system is preceded by a cold side ESP for primary particulate
matter removal. The unit is currently in the start-up phase of
operation; compliance testing is scheduled for the week of
January 18.
Cajun Electric Power Cooperative announced during November 1980
that bids were being requested for a dry scrubbing process to
control SC>2 emissions from Oxbow 1 (formerly Big Cajun III 1).
Also included in the bid request is an option for five additional
dry scrubbing systems to be installed at the Oxbow 2 and Chicot
1-4 units. Oxbow 2 is to be located next to Oxbow 1 in De Soto
Parish, Louisiana. Each Oxbow unit will be rated at 540 MW
(gross) and will fire lignite with an average sulfur content of
0.6%. Oxbow 1 is scheduled for operation in 1985. No start up
date has been set for Unit 2. The Chicot 1-4 units are planned
to be constructed in Shreveport, Louisiana. Each 540 MW (gross)
unit will fire lignite with an average sulfur content of 1.7%.
The Chicot units are scheduled to commence operations in 1986,
1988, 1992, and 1994, respectively.
Initial FGD operations began at Craig 1 of Colorado Ute Electric
during October 1980. The unit is rated at 447 MW (gross) and
fires subbituminous coal with an average sulfur content of 0.45%.
The FGD system, supplied by Peabody Process Systems, utilizes
four magnesium promoted limestone spray towers for 85% SO2 re-
moval. A hot side ESP precedes the system for primary particu-
late matter control. The stabilized sludge is disposed of in an
off site minefill operation. Some FGD system equipment problems
made it necessary to operate the unit at approximately 50 to 60%
of capacity during November; however, the problems were corrected
and the unit returned to full load during the last week of
December.
Duquesne Light reported that the Elrama FGD system achieved 100%
availability for the months of October and November, respec-
tively. Some absorber module liner repairs were performed during
the two month period but no major problems were encountered. In-
formation for the month of December was not available.
East Kentucky Power Cooperative announced that a letter of intent
was signed in April 1980 with Babcock and Wilcox for the instal-
lation of wet lime FGD systems to control SO2 emissions from the
J.R. Smith units 1 and 2. The units will be rated at 650 MW
xxii
-------
(gross) each and will fire bituminous coal with an average sulfur
content of 1.5%. The FGD systems are' scheduled to commence
operations in 1985 and 1987, respectively.
Florida Power and Light announced that FGD has been selected as
the S02 emission control strategy to be used at the Martin units
3 and 4. Each unit will be rated at 800 MW (gross). Projected
start-up is 1987 for unit 3 and 1989 for unit 4.
The dual alkali FGD system originally operated in 1975-1976 at
the Scholz station of Gulf Power was reactivated in August 1980
by Combustion Equipment Associates and Arthur D. Little. The
system is being utilized for an EPA sponsored test program aimed
at determining the feasibility of utilizing limestone rather than
lime as the source of calcium for the regeneration reactions.
The reactor system configuration was changed to a four stage
system with an increased residence time; however, no other major
system modifications were required. The system was operated in
the limestone mode for approximately 70% of December and ex-
hibited SO,., removal efficiencies reportedly in excess of 90%.
Houston Lighting and Power announced that a contract was awarded
to Combustion Engineering for wet limestone FGD systems to con-
trol SO2 emissions from the new Limestone units 1 and 2. Each
unit will be rated at 750 MW (gross) and will fire coal with an
average sulfur content of 1.08%. A cold side ESP will be used
for primary particulate matter control. Scheduled start-up dates
are 1984 and 1985 for units 1 and 2, respectively.
Kansas City Power and Light reported that the limestone FGD sys-
tems at the La Cygne generating station achieved availabilities
of 100%, 99%, and 99% during October, November, and December,
respectively. A fire in the "D" module was the only major prob-
lem encountered during the quarter.
The FGD systems at Jeffrey 1 and 2 of Kansas Power and Light
achieved 100% availability for the fourth quarter 1980. The
limestone systems operated with no major problems being reported
during this period.
Kansas Power and Light also reported FGD system availabilities of
100% for the Lawrence 4 and 5 FGD systems during the months of
October, November, and December, respectively.
Kentucky Utilities announced plans to construct two new units,
Hancock 1 and 2, to be located in Hawsville, Kentucky. The units
are to be rated at 708 MW (gross) each and will fire a Western
Kentucky coal with an average sulfur content of 3.5%. ^he util-
ity is considering a wet limestone scrubbing system along with an
ESP to control SO2 and particulate matter emissions. Operations
are scheduled to commence in 1988 and 1994 for units 1 and 2,
respectively.
XXlll
-------
Louisville Gas and Electric reported that the lime scrubbing
system at the Cane Run 5 unit achieved 100% availability for the
months of October, November, and December. No operational prob-
lems were reported for this period.
Initial operation of the FGD system at Mill Creek 1 of Louisville
Gas and Electric commenced during December 1980. The 358 MW
(gross) unit fires pulverized coal with an average sulfur content
of 3.75%. The retrofitted wet lime scrubbing process was sup-
plied by Combustion Engineering and is designed to remove 85% of
the inlet SO2-
Lower Colorado River Authority has announced plans to construct
Fayette Power Project 3 in La Grange, Texas. The 435 MW (gross)
unit will fire lignite with an average sulfur content of 1.7%.
SC-2 emissions from this unit will be controlled by a FGD system
designed for 90% S02 removal efficiency. The system is scheduled
to commence operation in 1988.
Marquette Board of Light and Power announced that a contract has
been awarded to Buell Division, Envirotech for a lime/spray dry-
ing system to be installed on the Shiras 3 unit. The system will
include a fabric filter that will serve the dual function of
primary particulate matter control and spent reagent collection.
Initial FGD operations are scheduled to begin in October 1982.
Michigan South Central Power Agency announced that construction
on the Project 1 FGD system began in November 1980. This 55 MW
(gross) unit is being constructed in Litchfield, Michigan, and
will burn coal with an average sulfur content of 2.25%. The wet
limestone FGD system is being supplied by Babcock and wilcox and
is expected to begin operation in June 1982.
FGD operations began during October 1980 at the Pleasants-2 unit
of Monongahela Power. This unit, which is rated at 618 MW
(gross) fires bituminous coal with an average sulfur content of
4.5%. The lime FGD system was supplied by Babcock and Wilcox and
consists of four spray tower absorbers. For primary particulate
matter removal, an ESP precedes the FGD system. No initial
start-up problems were reported to have been encountered during
the October through December period.
Reid Gardner 2 of Nevada Power achieved availabilities of 100%,
95%, and 100% for the months of October, November, and December,
respectively. No major problems were reported during this
period.
New York State Electric and Gas announced that a letter of intent
was signed with Peabody Process Systems for a wet limestone FGD
system to be installed on the Somerset 1 unit. The system, which
will be preceded by a cold side ESP for primary particulate
matter control, will be designed for 90% S02 removal. Initial
start-up of the system is expected in 1984.
xx iv
-------
Northern Indiana Public Service reported that the Dean H. Mitchell
11 Wellman Lord FGD system achieved availabilities of 97%, 100%,
and 93% for the October, November, and December period, respec-
tively. Minor problems were encountered with the SO_ reduction
unit; however, no major problems were reported.
Northern States Power has announced plans to construct Metro Coal
1. This 200 MW (gross) unit will fire a Montana coal with an
average sulfur content of approximately 1%. The utility is
considering a lime/spray drying process for SC>2 emission control.
The expected start up is in 1990.
Initial operation of the demonstration lime/spray drying FGD
system installed at the Riverside station of Northern States
Power began during November 1980. The 110 MW (gross) system,
which was supplied by Joy Manufacturing/Niro Atomizer, consists
of a spray dryer followed by a baghouse. The spent absorbent is
disposed of in both on and off site landfills. The system
operated in a shakedown/debugging phase during November and
December.
Northern States Power reported that the limestone/alkaline flyash
systems installed at Sherburne 1 and 2 achieved 100% availabili-
ties for the fourth quarter 1980. Unit 1 was out of service in
November due to an annual boiler/turbine inspection.
Northern States Power has reaffirmed plans for a third unit,
Sherburne 3, to be located along with units 1 and 2 in Becker,
Minnesota. Current plans call for joint ownership of the facil-
ity with the Southern Minnesota Municipal Power Agency and the
United Minnesota Municipal Power Agency. The 850 MW (gross unit
will fire a Montana coal with a sulfur content of approximately
1%. The unit will utilize a lime/spray drying process for
control of SO2 emissions and is scheduled to start operations in
1985.
Northern States Power also announced plans to construct a unit,
Wisconsin Coal 1, to be located in Durand, Wisconsin. The unit
will be rated at 670 MW (gross) and will fire coal with a sulfur
content of approximately 1%. The utility is considering con-
trolling SO2 emissions from this unit by utilizing a lime/spray
drying process. The unit is scheduled to commence operations in
1991.
Philadelphia Electric announced that construction began in
September 1980 on the retrofit magnesium oxide FGD system being
supplied by United Engineers for the Cromby 1 unit. The 150 MW
(gross) unit fires coal with an average sulfur content of 3.0%.
Start-up of the FGD system is expected in May 1983.
xxv
-------
The dual alkali scrubbing system at the A.B. Brown 1 station of
Southern Indiana Gas and Electric achieved availabilities of 99%,
98%, and 99% during October, November, and December, respec-
tively. Other than some recurring water balance problems, no
major problems were reported for the three month period.
Soyland Power Cooperative has announced plans to construct
Soyland 1 in Illinois. The 500 MW (gross) unit will fire an
Illinois coal with an average sulfur content of 3.0%. The
utility is currently considering FGD as a S02 control strategy.
Operations are scheduled to commence in 1987.
Initial FGD operations began at Dallman 3 of Springfield Water,
Light, and Power in October 1980. The unit is rated at 205 MW
(gross) and fires coal with an average sulfur content of 3.3%.
The limestone FGD system is preceded by a hot side ESP and in-
cludes one horizontal chevron mist eliminator per module. The
sludge is trucked off site to a landfill. No major initial
start-up problems were reported.
Tennessee Valley Authority has announced that low sulfur coal
will be burned at the Johnsonville 1-10 units. As a result,
plans for the installation of a magnesium oxide FGD system have
been cancelled.
Texas Power and Light announced that initial FGD operations at
the Sandow 4 unit began in December 1980. The 545 MW (gross)
unit fires lignite with an average sulfur content of 1.6%. The
three limestone spray towers supplied by Combustion Engineering
will be designed for a S02 removal efficiency of 75%. Primary
particulate matter removal is provided by a cold side ESP. The
system operated in a shakedown mode through the end of December.
Washington Water Power has announced plans to construct Creston
Coal 1 in Creston, Washington. The 570 MW (gross) unit is the
first of four coal fired units planned for this site. The
utility is considering a wet limestone scrubbing system for SO2
emission control. Construction at this site is scheduled to
commence in 1983 with initial operations expected to begin in
1987.
West Texas Utilities has announced that bids are being requested
for a FGD system to be installed at the Oklaunion 1 unit. The
720 MW (gross) unit is to be located in Oklaunion, Texas and will
fire a subbituminous Wyoming coal with an average sulfur content
of 0.34%. The system will operate with a closed water loop.
Initial operations are scheduled for 1986.
West Texas Utilities also announced plans to construct a second
unit, Oklaunion 2. This unit will be similar in design to Unit 1
with startup expected in 1990.
xxvi
-------
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.
xxvi i
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC COOP
TOMBIGBEE
TOMBIGBEE
ARIZONA ELECTRIC POWER COOP
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
UNIT NO.
2
3
2
3
1
2
4
1
2
3
4
5
UNIT LOCATION
LEROY
LEROY
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMINGTON
FARMINGTON
FARMINGTON
FARMINGTON
FARMINGTON
ALABAMA
ALABAMA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
2/81
11/79
11/79
11/79
0/82
0/82
STATUS
1
1
1
1
1
1
2
1
1
1
3
3
REG
CLASS
B
B
D
D
C
c
C
c
c
c
c
c
ASSOCIATED ELECTRIC COOP
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAMIE RIVER
LARAMIE RIVER
LARAMIE RIVER
BIG RIVERS ELECTRIC
D.B. WILSON
D.B. WILSON
GREEN
GREEN
CAJUN ELECTRIC POWER COOP
CHICOT
CHICOT
CHICOT
CHICOT
OXBOW
OXBOW
CENTRAL ILLINOIS LIGHT
LUCK CREEK
CUCK CREEK
CEN1RAL ILLINOIS PUBLIC SERV
KEWTON
NEWTON
CEN1RAL MAINE POWER
fEARS ISLAND
MOBERLY
MILLVILLE
MISSOURI
NEW JERSEY
1/82
1/88
1
2
1
2
3
BEULAH
BEULAH
WHEAT LAND
WrftATLAND
WHEAT LAND
NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
WYOMING
4/83
10/85
7/80
6/81
10/82
2
5
1
2
2
D
C
C
C
C
SEBREE
SEBREE
KENTUCKY
KENTUCKY
7/84
1/86
12/79
11/80
CANTON
CANTON
NEWTON
NEWTON
ILLINOIS
ILLINOIS
ILLINOIS
ILLINOIS
PENOBSCOT BAY MAINE
7/76
1/86
9/79
12/82
1/89
A
A
B
B
1
2
3
4
1
2
SHREVEPORT LOUISIANNA
SHREVEPORT LOUISIANNA
SHREVEPORT LOUISIANNA
SHREVEPORT LOUISIANNA
DE SOTO PARISH LGU'lSlANA
DE SOTO PARISH LOUISIANA
0/86
0/88
0/92
0/94
0/85
0/85
6
6
6
6
5
6
A
A
A
A
A
A
B
A
B
A
1. OPEPATIONAL UNITS
2. UNITS UlfDER CONSTRUCTION
3. PWNNED - 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. FEUERAL NSPS(6/79)
B. >"Et ERAL NSPS(12/71)
C. STAK'DARD(S) MORE STRINGENT THAN NSPSC6/79)
D. STANDARD(S) MORE STRINGENT THAN 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: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
REG
STATUS CLASS
CENTRAL POWER & LIGHT
COLETO CREEK
CINCINNATI GAS
EAST BEND
EAST BEND
& ELECTRIC
COLORADO UTE ELECTRIC ASSN
CRAIG
CRAIG
CRAIG
COMMONWEALTH EDISON
POHERTON
DELMARVA POWER & LIGHT
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
VIENNA
DESERET GEN & TRANS COOP
MOON LAKE
MOON LAKE
DUQUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER COOP
J.K. SMITH
J.K. SMITH
SPURLOCK
FLORIDA POWER
MARTIN
MARTIN
& LIGHT
GENERAL PUBLIC UTILITIES
COAL
COAL
COAL
COAL
SEWARD
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE 5
CONESVILLE 6
POSTON 5
POSTON 6
51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COAL CREEK Z
1-6
3
4
1
Z
3
4
7
FANNIN
RABBITHASH
RABBITHASH
CRAIG
CRAIG
CRAIG
CONESVILLE
CONESVILLE
NELSONVILLE
NELSONVILLE
PEKIN
UNDERWOOD
UNDERWOOD
TEXAS
KENTUCKY
KENTUCKY
COLORADO
COLORADO
COLORADO
OHIO
OHIO
OHIO
OHIO
ILLINOIS
NORTH DAKOTA
NORTH DAKOTA
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
VIENNA MARYLAND
VERNAL
VERNAL
ELRAMA
SOUTH HEIGHT
MAYSVILLE
MARTIN COUNTY
MARTIN COUNTY
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
UTAH
UTAH
PENNSYLVANIA
PENNSYLVANIA
KENTUCKY
FLORIDA
FLORIDA
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
9/86
10/87
2/81
4/80
7/79
7/80
5/80
5/80
5/80
6/87
9/84
0/88
10/75
7/73
1/85
1/87
10/81
6
Z
10/80
12/79
0/82
1/77
6/78
8/86
0/89
1
1
3
1
1
6
6
D
D
D
D
D
D
D
B
B
E
E
E
A
A
A
D
D
A
A
B
EAST WHEATFIELDPENNSYLVANIA
0/87
0/89
5/91
5/93
5/95
5/96
5/89
6
6
5
6
6
6
5
A
A
A
A
A
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 NSPSU2/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) MORE STRINGENT THAN 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: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMP4NY NAME/
imT NAME
GRAND HAVEN BRD OF
J.B. SIMS
GULF POWER
SCHOLZ
HOOS:ER ENERGY
Mt.ROM
MEROM
HOUSTON LIGHTING &
LIMESTONE
LIMESTONE
W.A. PARISH
INDIAMAPOLIS POWER
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
UNIT NO.
LIGHT 4 PWR
3
1
1
2
POWER
1
Z
&
& LIGHT
1
Z
3
3
4
UNIT LOCATION
GRAND HAVEN
SNEADS
MEROM
MEROM
JEWITT
JEWETT
BOOTH
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
MICHIGAN
FLORIDA
INDIANA
.INDIANA
TEXAS
TEXAS
TEXAS
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
START-UP
DATE
6/83
8/80
5/82
9/81
12/84
12/85
' 11/82
0/87
O/ 0
O/ 0
12/77
10/84
STATUS
2
1
2
2
3
3
2
6
6
6
1
2
REG
CLASS
A
E
B
B
A
A
A
C
C
C
B
B
IOWA ELECTRIC LIGHT & PWR
SUTHRIE CO. 1
JACKSONVILLE ELEC AUTHORITY
ST.JOHNS RIVER PHR PARK 1
ST.JOHNS RIVER PWR PARK 2
KANSAS CITY POWER & LIGHT
HAWTHORN 3
HAWTHORN 4
LA CYGNE 1
KANSAS POWER & LIGHT
JEFFREY 1
JEFFREY . 2
LAWRENCE 4
LAWRENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
HANCOCK 1
HANCOCK 2
LAKELAND UTILITIES
MCINTOSH 3
LANSING BOARD OF WATER & LIGHT
ERICKSON 2
LOS ANGELES DEPT OF WTR & PWR
INTERMOUNTAIN 1
INTERMOUNTAIN 2
INTERMOUNTAIN 3
INTERMOUNTAIN 4
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
PANORA
IOWA
EAST PORT SITE FLORIDA
EAST PORT SITE FLORIDA
KANSAS CITY
KANSAS CITY
LA CYGNE
WAMEGO
WAMEGO
LAWRENCE
LAURENCE
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
CENTRAL CITY KENTUCKY
HAWESVILLE KENTUCKY
HAWESVILLE KENTUCKY
LAKELAND
FLORIDA
DELTA TOWNSHIP MICHIGAN
DELTA
DELTA
DELTA
DELTA
UTAH
UTAH
UTAH
UTAH
11/84
12/85
• 6/87
11/72
8/72
2/73
8/78
4/80
1/77
4/78
9/75
0/88
0/94
8/81
1/87
0/86
0/87
0/88
0/89
4.
5.
6.
7.
6
6
6
6
6
6
A
A
E
A
A
A
A
A
A
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPS(12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPS(12/71) BUT NOT MORE STRINGENT THAN NSPS16/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSU2/71)
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
LOUISVTLLE GAS & ELECTRIC
CANf. RUN
CANL: RUN
C4NE RUN
MILL CREEK
MILL CREEK
MILL CREEK
MILL CREEK
PADDY'S RUN
TRIMBLE COUNTY
TRIMBLE COUNTY
UNIT NO.
4
5
6
1
Z
3
4
6
1
Z
UNIT LOCATION
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
BEDFORD
BEDFORD
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
START-UP
DATE
8/76
12/77
4/79
12/80
12/81
8/78
6/82
4/73
7/85
7/88
STATUS
1
1
1
1
2
1
2
1
5
5
REG
CLASS
D
D
D
E
E
D
B
E
A
A
LOWE
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
NEVADA POWER
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
PARRY ALLEN
REID GARDNER
KEID GARDNER
REID GARDNER
REID GARDNER
(-.ARN^R VALLEY
WARNER VALLEY
UNIT NO.
1
2
3
4
1
Z
3
4
1
Z
UNIT LOCATION
LAS VEGAS
LAS VEGAS
LAS VEGAS
LAS VEGAS
MOAPA
MOAPA
MOAPA
MOAPA
ST. GEORGE
ST. GEORGE
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NE\ ADA
NEVADA
UTAH
UTAH
START-UP
DATE
6/86
6/87
6/88
6/89
3/74
4/74
7/76
4/83
6/85
6/86
STATUS
6
6
6
6
1
1
1
4
5
5
REG
CLASS
A
A
A
A
B
B
B
A
A
A
NEW YOHK STATE ELEC & GAS
SOMERSET 1
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
S:HAHFER i?
SZHAHFER 18
NORTHERN STATES POWER
METRO COAL
RIVERSIDE
SHERBURNE
SHERBURNE
S1ERBURNE
WISCONSIN COAL
PACIl-'IC GAS & ELECTRIC
MdNTEZUMA 1
MONTEZUMA 2
PACIFIC POWER & LIGHT
JIM BRIDGER 1
JIM BRIDGER 2
JIM BRIDGER 3
JIM BRIDGER 4
PENNSYLVANIA POWER
BR'JCE MANSFIELD 1
BRUCE MANSFIELD 2
BRUCE MANSFIELD 3
PHILADELPHIA ELECTRIC
CROMBY 1
EDDYSTONE 1
EDDYSTONE Z
PLAINS ELECTRIC G & T COOP
PLAINS ESCALANTE 1
SOMERSET
BUFFALO
GARY
WHEATFIELD
WHEATFIELD
NEW YORK
NEW YORK
INDIANA
INDIANA
INDIANA
COLLINSVILLE
COLLINSVILLE
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
SHIPPINGPORT
SHIPPIN.GPORT
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
EDDYSTONE
PREWITT
CALIFORNIA
CALIFORNIA
WYOMING
WYOMING
WYOMING
WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
NEW MEXICO
6/84
4/82
7/76
6/83
6/85
6/94
6/90
0/88
0/84
0/86
9/79
12/75
7/77
6/80
5/83
12/82
12/82
12/83
1
3
3
5
5
5
1
E
A
A
1
6,7
1
2
3
1
UNDECIDED
MINNEAPOLIS
BECKER
BECKER
BECKER
DURAND
UNDECIDED
MINNESOTA
MINNESOTA
MINNESOTA
MINNESOTA
WISCONSIN
0/90
11/80
3/76
3/77
0/85
0/91
6
1
1
1
6
6
A
E
D
D
A
A
c
c
A
A
A
D
D
D
D
D
D
D
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 NSPS{12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSU2/71) BUT NOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(12/71)
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP REG
DATE STATUS CLASS
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN I
SAN JUAN 2
SftN JUAN 3
FAN JUAN $
PWR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONADO 1
CCRONADO 2
CORONADO 3
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SEMINOLE ELECTRIC
SEM" NOLE 1
SEM::NOLE 2
SIERRA PACIFIC POWER
FT, COLLINS COLORADO
PRINCETON
WATERFLOW
WATERFLOW
WATERFLOW
WATERFLOW
NEW YORK
ST. JOHNS
ST. JOHNS
ST. JOHNS
SAN MIGUEL
PALATKA
PALATKA
VALMY
INDIANA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW YORK
ARIZONA
ARIZONA
ARIZONA
TEXAS
FLORIDA
FLORIDA
NEVADA
12/83
0/82
4/78
8/78
12/79
6/82
11/79
7/80
0/89
8/81
3/83
3/85
8/84
C
C
C
C
D
D
A
A
A
SIKE3TON BRD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
C50SS * 1
CROSS 2
WINYAH 2
WINY AH 3
WINYAH ^
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR. 1
R.D. MORROW, SR. 2
SOUTHERN ILLINOIS POWER COOP
MARION 4
M/.RION 5
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN 1
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
DCLET HILLS 2
HES-RY W. PIRKEY 1
SIKESTON
MISSOURI
6/81
CROSS
CROSS
GEORGETOWN
GEORGETOWN
GEORGETOWN
HATTISBURG
HATTISBURG
MARION
MARION
WEST FRANKLIN
MANSFIELD
MANSFIELD
HALLSVILLE
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
ILLINOIS
ILLINOIS
INDIANA
LOUISIANA
LOUISIANA
TEXAS
3/85
1/84
7/77
5/80
7/81
8/78
6/79
5/79
0/88
3/79
3/86
3/88
12/84
1
6
3
6
3
B
B
B
A
A
A
B
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PLANNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGD SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPS(12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPSC6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSC12/71) BUT NOT MORE STRINGENT THAN NSPSC6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSC12/71)
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
SOY LAND POWER COOP
SOYLAND
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SPRINGFIELD WATER, LIGHT & PWR
DALLMAN
ST. JOE ZINC
G.F. WEATON
SUNFLOWER ELECTRIC COOP
HOLCOMB
TAMPA ELECTRIC
BIS BEND
TENNESSEE VALLEY AUTHORITY
PARADISE
PARADISE
SHAUNEE
SHAU'NEE
WIDOWS CREEK
WIDOWS CREEK
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
TEXAS POWER & LIGHT
SANDOW
TWIN OAKS
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
MARTIN LAKE
MARTIN LAKE
MAR' IN LAKE
MARTIN LAKE
KILL CREEK
MTLI CREEK
M3NYICELLO
TUCSON ELECTRIC POWER
S'RINGERVILLE
S^RINGERVILLE
UNITED POWER ASSOCIATION
STANTON
UTAH POWER & LIGHT
H'JNTER
H'JNTER
H'JNTER
HUNTER
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. F'LANNED - CONTRACT AWARDED
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPS( 12/71)
C. STANDARD(S) MORE STRINGENT
D. STANDARD(S) MORE STRINGENT
UNIT
1
1
3
1
1
4
1
2
10A
10B
7
8
1
4
1
2
1
1
2
3
4
1
2
3
1
2
1A
1
2
3
^
4.
5.
6.
7.
THAN
THAN
NO. UNIT LOCATION
UNDECIDED ILLINOIS
SPRINGFIELD MISSOURI
SPRINGFIELD ILLINOIS
MONACA PENNSYLVANIA
HOLCOMB KANSAS
TAMPA FLORIDA
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 TF.XAS
TATUM TiXAS
TATUM TEXAS
HENDERSON TEXAS
HENDERSON TEXAS
MT. PLEASANT TEXAS
SPRINSERVILLE ARIZONA
SPRINGERVILLE ARIZONA
STANTON NORTH DAKOTA
CASTLE DALE UTAH
CASTLE DALE UTAH
CASTLE DALE UTAH
CASTLE DALE UTAH
START-UP
DATE
0/87
4/77
10/80
11/79
9/83
3/85
3/82
6/82
4/72
4/72
2/81
5/77
1/82
12/80
8/84
8/85
0/87
4/77
5/78
2/79
0/85
0/85
0/86
5/78
1/85
3/87
6/82
5/79
6/80
6/83
6/85
STATUS
6
1
1
1
3
3
2
2
1
1
2
1
2
1
3
3
5
1
1
1
3
6
6
1
3
3
2
1
1
3
3
REG
CLASS
A
B
B
B
A
A
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
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS;
NSPS(6/79)
NSPSC 12/71) BUT NOT MORE STRINGENT
ALSO ALTERNATIVE
METHODS
THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSC 12/71)
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP REG
DATE STATUS CUSS
UTAH POWER & LIGHT
HUNTINGTON
NAUGHTON
WASHINGTON WATER POWER
CRESTON COAL
WEST PENN POWER
MITCHELL
WEST TEXAS UTILITIES
OKLAUNION
OKLAUNION
33
PRICE
KEMMERER
CRESTON
COURTNEY
1 OKLAUNION
2 OKLAUNION
UTAH
WYOMING
WASHINGTON
PENNSYLVANIA
TEXAS
TEXAS
5/78
6/81
0/87
8/82
12/86
0/90
B
C
5
6
A
A
1. OPERATIONAL UNITS
2. JNITS UNDER CONSTRUCTION
3. =LANNED - CONTRACT AWARDED
ft. 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 NSPS(12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPSC6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSU2/71) BUT NOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(12/71)
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC COOP
TOMBIGBEE
2
NEW 255 MW (GROSS)
179 MW (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.IX
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 953,000
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 SOS 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 TWO SPRAY
TOWERS SUPPLIED BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TOWER AND THE FLUE
GAS IS REHEATED 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
TOH8IGBEE
3
NEW 255 MW (GROSS)
179 MW (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.IX
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/MtlBTU. PRIMARY PARTICULATE CONTROL IS PROVIDED BY A HOT
SIDE ESP. THE S02 REMOVAL EQUIPMENT 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 MW (GROSS)
98 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ft.17.
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 10,000 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. HALF THE FLUE GAS
PASSES THROUGH TWO PACKED TOWERS EMPLOYING LIMESTONE ABSORBENT AND
HAVING A DESIGN S02 REMOVAL OF 85X WERE SUPPLIED BY RESEARCH-COTTRELL.
MIST ELIMINATION IS PROVIDED BY CHEVRON TYPE ELIMINATORS. NO REHEAT IS
EMPLOYED. A 400 FT COLE BRAND CXL2000 LINED STACK IS IN USE. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP MODE AND WASTE MATERIAL IS DISPOSED OF IN
OFF-SITE SLUDGE PONDS. OPERATIONS COMMENCED IN AUGUST 1978.
ARIZONA ELECTRIC POWER COOP
APACHE
3
NEW 195 MW (GROSS)
98 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.IX
STATUS 1 STARTUP 6/79
APACHE 3 OF ARIZONA ELECTRIC POWER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOW (0.55X) SULFUR BITUMINOUS COAL WITH AN
AVERAGE HEATING VALUE OF 10,000 BTU/LB PRODUCES A MAXIMUM FLUE GAS FLOW OF
735,000 ACFM. HALF OF THE FLUE GAS PASSES THROUGH A HOT SIDE ESP TO TWO
RESEARCH COTTRELL PACKED TOWERS, WHERE LIMESTONE IS USED TO REMOVE 85X 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 MW (GROSS)
119 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEAFCH-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 UNLINED POND.
ARIZONA PUBLIC SERVICE
CHOLLA
2
NEW 264 MW (GROSS)
264 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGK 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 PRIMAF.Y PARTICULATE CONTROL. FOUR PARALLEL
FLOODED DISC AND PACKED TOWEH S02 ABSORBER TRAINS (THREE ARE REQUIRED FOR
FULL LOAD) REMOVE THE FLUE GAS S02. THE DESIGN S02 REMOVAL FOR THE
SYSTEM, WHICH BEGAN OPERATIONS IN APRIL, 1978, IS 75X. THE CLEANED GAS
BASSES THROUGH AN IN-LINE SfEAM REHEATER INTO AN ACID BRICK LINED STACK.
THE OPEN WATER LOOP SYSTEM DEPOSITS ITS SLUDGE INTO A FLY ASH POND.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZONA
CHOLLA
4
NEW
PUBLIC SERVICE
375 MW (GROSS)
126 MW (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 2/81
CHOLLA 4 OF ARIZONA PUBLIC SERVICE IS PRESENTLY UNDER CONSTRUCTION IN
JOSEPH CITY, ARIZONA. THE PULVERIZED COAL (0.5X S, 10,150 BTU/LB) FIRED
BOILER WILL EXHAUST FLUE GAS THROUGH AN ESP TO A DOUBLE LOOP COMBINATION
TOWER (RESEARCH-COTTRELL DESIGN) WHICH WILL TREAT 36X OF THE GAS WITH
LIMESTONE. THE SYSTEM IS SCHEDULED TO START UP IN FEBRUARY 1981.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175 MW (GROSS)
175 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 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 SOZ
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 MW (GROSS)
175 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 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 67.5X. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
3
RETROFIT 229 MW (GROSS)
229 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) 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 S02 REMOVAL EFFICI-
ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING IS 67.5X.
OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
4
RETROFIT 755 MW (GROSS)
755 MW (ESC)
COAL
.75 XS
LIME
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/82
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO UNITED ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. BASED ON THE PROTOTYPE HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY THE UTILITY, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75X S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESP. START UP IS EXPECTED IN
1982.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT 755 MM (GROSS)
755 MW (ESC)
COAL
.75 XS
LIME
UNITED ENGINEERS
ENERG> CONSUMPTION: ****x
STATUS 3 STARTUP 0/82
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO UNITED ENGINEERS FOR A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. BASED ON THE PROTOTYPE HORIZONTAL SCRUB-
BING PROGRAM CONDUCTED BY THE UTILITY, A HORIZONTAL SYSTEM WAS CHOSEN TO
CONTROL THE EMISSIONS FROM THESE COAL (0.75X S, 8650 BTU/LB) FIRED UNITS.
THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESP. START UP IS EXPECTED IN
1982.
10
-------
EPA UTILITY FSD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ASSOCIATED ELECTRIC COOP
THOMAS HILL
3
NEW 730 MW (GROSS)
670 MW (ESC)
COAL
4.80 XS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 1/82
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A PULVERIZED COAL (4.8X S,
9,700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN MOBERLY, MISSOURI. TWO COLD
SIDE ESP'S WILL PRECEDE THE FOUR 91.57. EFFICIENT PULLMAN KELLOGG HORIZONTA
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 1983.
ATLANTIC CITY ELECTRIC
CUMBER >J^ND
1
NEW 330 MW (GROSS)
330 MW (ESC)
COAL
3.25 7S BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 1/88
CUMBERLAND 1 IS A PULVERIZED COAL (3.25XS) FIRED BOILER TO BE LOCATED IN
MILLVILLE, NEW JERSEY. THE UTILITY IS CONSIDERING AN FGD SYSTEM WITH A
THROWAWAY PRODUCT FOR S02 CONTROL. OPERATIONS ARE SCHEDULED TO BEGIN IN
JANUARY 1988.
BASIN f-.LECTRIC POWER COOP
ANTELOPE VALLEY
1
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
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 2,055,000 ACFM TO A DRY
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM WILL CONSIST OF 5 NIRO ATOMIZER 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.
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
2
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POWER COOP WILL BE LOCATED IN BEULAH,
NORTH DAKOTA. THE UTILITY IS PRESENTLY CONSIDERING VARIOUS FGD PROCESSES
FOR THIS LIGNITE (0.68X S, 6600 BTU/LB) FIRED UNIT. THE UNIT WILL BE
REQUIRED TO COMPLY WITH STATE EMISSIONS STANDARDS VIA BEST AVAILABLE
CONTROL TECHNOLOGY. START UP IS SCHEDULED FOR OCTOBER 1985.
STATUS 5
STARTUP 10/85
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
1
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: .OX
STATUS 1 STARTUP 7/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS A PULVERIZED COAL
(0.8X S, 8139 BTU/LB) FIRED UNIT LOCATED IN WHEATLAND, WYOMING.
THE BOILER FEEDS 2,300,000 ACFM OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH COTTRELL LIMESTONE PACKED TOWER MODULES, WHICH
REMOVE 90X OF THE S02. THE CLEANED GAS EXITS FROM A VERTICAL CHEVRON
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT IS
USED. THE FLYASH FIXATED SLUDGE IS DEWATERED TO 83X SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM EMPLOYS A CLOSED WATER LOOP. OPERATIONS
BEGAN ON JULY 1, 1980.
BASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****X
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 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
MIST ELIMINATOR 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.
11
-------
EPA l«TILITY FED SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
BASIN ELECTRIC POWER COOP
LARAMJE RIVER
3
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
.54 7.5 SUBBITUMINOUS
LIME/SPR>iY DRYING
BABCOCK ;'• WILCOX
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 10/82
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 2,800,000 ACFM OF FLUE GAS TO THE FGD
SYSTEM, WHICH WILL REMOVE 8r.X OF THE S02 BEFORE THE 6AS 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 OCTOBER
1982.
BIG RI/ERS ELECTRIC
D.B. WILSON
1
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
***** XS BITUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 7/84
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS WILL HAVE A MW RATING OF 440 EACH.
PULLMAN KELLOG HAS BEEN AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM. STARTUP IS SCHEDULED FOR JULY 1984.
BIG RIVERS ELECTRIC
D.B. W7.LSON
2
NEW 440 MW (GROSS)
440 MW (ESC)
COAL
***** J..S BITUMINOUS
LIMESTONE
PULLMAK KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 1/86
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS WILL HAVE A MW RATING OF 440 EACH.
PULLMAN KELLOG HAS BEEN AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM. STARTUP IS SCHEDULED FOR JANUARY 1986.
BIG RIVERS ELECTRIC
GREEN
1
NEW 242 MW (GROSS)
242 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 12/79
UNIT 1 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN
SEBREE,KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S, 9750 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH WILL REMOVE 90X OF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN DECEMBER 1979.
BIG RIVERS ELECTRIC
GREEN
2
NEW 242 MW (GROSS)
242 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/80
UNIT 2 OF BIG RIVERS ELECTRIC'S GREEN STATION IS LOCATED IN SEBREE,
KENTUCKY. THE DRY BOTTOM PULVERIZED COAL (3.75X S, 9750 BTU/LB)
FIRED BOILER SUPPLIES 1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED BY
TWO AMERICAN AIR FILTER LIME SPRAY TOWERS WHICH REMOVE 90X OF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A SAUERISEN 72 LINED STACK AFTER IT IS HEATED BY A STEAM COIL
REHEATER. THE SLUDGE FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN NOVEMBER 1980.
CAJUN ELECTRIC POWER COOP
CHICOT
1
NEW 540 MW (GROSS)
540 MW (ESC)
LIGNITE
1.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/86
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A NEW UNIT, CHICOT 1, TO BE
LOCATED IN SHREVEPORT, LOUISIANA. THE UTILITY IS CONSIDERING A DRY
SCRUBBING FGD SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1936.
12
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CAJUN ELECTRIC POWER COOP
CHICOT
Z
NEW 540 MW (GROSS)
540 MW (ESC)
LIGNI1E
1.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUt 6 STARTUP 0/88
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A NEW UNIT, CHICOT 2, TO BE
LOCATED IN SHREVEPORT, LOUISIANA. THE UTILITY IS CONSIDERING A DRY
SCRUBBING FGD SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1988.
CAJUN ELECTRIC POWER COOP
CHIC01
3
NEW 540 MW (GROSS)
540 MW (ESC)
LIGNITE
1.70 7.5
PROCESS HOT SELECTED
VENDOR NOT SELECTED
ENERGY CCNSUMPTION: *****
STATUS 6 STARTUP 0/92
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A NEW UNIT, CHICOT 3, TO BE
LOCATED IN SHREVEPORT, LOUISIANA. THE UTILITY IS CONSIDERING A DRY
SCRUBBING FGD SYSTEM FOR EMIJ.SION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
CAJUN cLECTRIC POWER COOP
CHICOT
4
NEW 540 MW (GROSS)
540 MW (ESC)
LIGNITi
1.70
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
NEW 450 MW (GROSS)
450 MW (ESC)
COAL
3.30 XS 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 FGD SYSTEM FOR UNIT Z 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 MW (GROSS)
617 MW (ESC)
COAL
2.25 XS BITUMINOUS
DUAL ALKALI
BUELL 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 (2.25X S, 10,900 BTU/LB) FIRED UNIT
LOCATED IN NEWTON, ILLINOIS. A COLD SIDE ESP RECEIVES 2,163,480 ACFM
OF FLUE GAS AND FEEDS IT TO FOUR BUELL ENVIROTECH POLYSPHERE PACKED
TRAY TOWERS FOLLOWED BY TWO VERTICAL MIST ELIMINATORS PER MODULE. THE
CLEANED GAS IS BOOSTED 25 DEG F BY A COMBINATION OF TKO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS REHEAT, AND THEN EXITS A 530 FOOT
PRECRETE LINED STACK. THE WATER LOOP IS CLOSED, AND THE SLUDGE IS
POZ-0-TEC TREATED.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
2
NEW 617 MW (GROSS)
617 MW (ESC)
COAL
4.00 XS BITUMINIOUS
PROCESS I OT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.4X
STATUS 7 STARTUP 12/82
NEWTON 2 OF CENTRAL ILLINOIS PUBLIC SERVICE IS A 617 MW UNIT TO BE LOCATED
IN NEWTON, ILLINOIS. THE COMBUSTION ENGINEERING COAL FIRED BOILER WILL
UTILIZE AN FGD SYSTEM OR FIRE LOW SULFUR COAL TO CONTROL S02 EMISSIONS.
THE UNIT IS SCHEDULED TO COMhENCE OPERATIONS IN DECEMBER 1982.
CENTRAL MAINE POWER
SEARS ISLAND
1
NEW 600 MW (GROSS)
600 MW (ESC)
COAL
2.23 7.S BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****•/.
STATUS 6 STARTUP 1/89
SEARS ISLAND 1 IS A PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY CENTRAL
MAINE POUER. BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT ON SEARS
ISLAm, PLANS FOR A 1150 MW NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
PLANS FOR A 600 MW COAL FIRED PLANT. LIME AND LIMESTONE SCRUBBING ARE
THE PRIMARY METHODS BEING CONSIDERED FOR COMPLIANCE WITH THE NSPS. IT
WILL BE TWO YEARS BEFORE ALL PERMITS REQUIRED HAVE BEEN RECEIVED. START
UP IS SCHEDULED FOR NOVEMBER 1989.
CENTRAL POWER £ LIGHT
COLETO CREEK
2
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.39 XS SUBBITUMINIOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 9/86
COLETO CREEK 2 OF CENTRAL POWER AND LIGHT IS A COAL (.39XS) FIRED UNIT
PLANNED FOR CONSTRUCTION IN FANNIN, TEXAS. THE UNIT IS BEING BUILT BY
CENTRAL AND SOUTHWEST SERVICES, BUT WILL BE OPERATED BY CENTRAL POWER AND
LIGHT. ONLY DRY SCRUBBING IS BEING CONSIDERED FOR S02 CONTROL. SCHEDULED
STARTUP IS FOR SEPTEMBER 1986.
CINCINNATI GAS 8 ELECTRIC
EAST BE^D
1
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
4.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9X
STATUS 6 STARTUP 10/87
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NEW UNIT, EAST BEND 1, TO
BE LOCATED ADJACENT TO EAST BENT 2 AT THE RABBITHASH, KENTUCKY SITE. THE
COAL FIRED BOILER WILL HAVE A GENERATING CAPACITY OF 650 MW. THE UNIT IS
SCHEDULED TO STARTUP IN OCTOBER 1987.
14
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CINCINNATI GAS & ELECTRIC
EAST BEND
2
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
4.00 XS
LIME
BABCOCK ft WILCOX
ENERGY CONSUMPTION: 2.9X
EAST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL (5X S)
FIRED BOILER UNDER CONSTRUCTION IN RABBITHASH, KENTUCKY. THE EMISSION
CONTROL SYSTEM CONSISTS OF A HOT SIDE ESP FOLLOWED BY THREE BABCOCK AND
WILCOX LIME FGD MODULES. THE 87X CLEANED GAS WILL PASS THROUGH A CHEVRON
MIST ELIMINATOR BEFORE BEING WARMED BY AN INDIRECT HOT AIR REHEATER AND
EXITING THROUGH A BRICK LINED 650 FOOT STACK. THE SLUDGE FROM THIS CLOSED
WATER LOOP SYSTEM WILL BE POZ-0-TEC STABILIZED BEFORE DISPOSAL IN AN ON
SITE LANDFILL. START UP IS EXPECTED IN FEBRUARY 1981.
STATUS 2
STARTUP 2/81
COLORADO UTE ELECTRIC ASSN
CRAIG
1
NEW 447 MW (GROSS)
447 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: 5.4X
STATUS 1 STARTUP 10/80
THE COLORADO UTE ELECTRIC ASSN HAS CONSTRUCTED A NEW UNIT, CRAIG 1, LOCATE
IN CRAIG, COLORADO. BOTH UNITS FIRE PULVERIZED SUBBITUMINOUS COAL (0.45X
10,000 BTU/LB). THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HO
SIDE ESP AND FOUR MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS FOR REMOVAL
OF PARTICULATE MATTER AND 85X OF THE S02. THE SCRUBBER EXHAUST IS HEATED
BY AN IN-LINE STEAM COIL REHEATER AND PASSES THROUGH A 600 FOOT ACID LINED
STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP AND THE STABILIZED SLUD
IS DISPOSED OF IN AN OFF SITE MINEFILL. UNIT 1 START UP IS EXPECTED IN
OCTOBER 1980.
COLORADO UTE ELECTRIC ASSN
CRAIG
2
NEW 455 MW (GROSS)
400 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABOCY PROCESS SYSTEMS
ENERGY CONSUMPTION'- 1.5X
STATUS 1 STARTUP 12/79
THE CRAIG 2 UNIT OF THE COLORADO UTE ELECTRIC ASSN IS LOCATED IN CRAIG,
COLORADO AND FIRES PULVERIZED SUBBITUMINOUS COAL (0.45XS, 10,000 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 85X 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 fi. RATES IN A CLOSED LOOP, AND THE STABILIZED SLUDGE IS DIS-
POSED OF IN AN OFF SITE MINEFILL. START UP OF UNIT 2 WAS IN DECEMBER 1979.
COLORADO UTE ELECTRIC ASSN
CRAIG
3
NEW 447 MW (GROSS)
447 MW (ESC)
COAL
.45 XS SUBBITUMINOUS
LIME/SPRAf DRYINS
BABCOCK J WILCOX
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 0/82
COLORADO UTE ELECTRIC ASSN. HAS PLANS FOR A NEW UNIT, CRAIG 3, TO BE
LOCATED IN CRAIG, COLORADO ALONG WITH UNITS 1 AND 2. THE UNIT WILL FIRE
PULVERIZED SUBBITUMINOUS COAL (0.45X S, 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.
COLUMBJS 4 SOUTHERN OHIO ELEC
CONESVTLLE
5
NEW 411 MW (GROSS)
411 MW (ESC)
COAL
4.67
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLUMBUS & SOUTHERN OHIO ELEC COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS, POSTON 5
POSTON
5
NEW
COAL
425 MW (GROSS)
375 MW (ESC)
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
STATUS 6 STARTUP 8/86
AND 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2.57. S, 11,000 BTU/LB)
FIRED UNITS WILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 5 IS EXPECTED IN 1986.
COLUMBUS 8 SOUTHERN OHIO ELEC COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS, POSTON 5
POSTON
6
NEW 425 MW (GROSS)
375 MW (ESC)
COAL
2.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
STATUS 6 STARTUP 0/89
AND 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2.5X S, 11,000 BTU/LB)
FIRED UNITS WILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT 6 IS EXPECTED IN 1989.
COMMONWEALTH EDISON
POWERTON
51
RETROFIT 450 MW (GROSS)
450 MW (ESC)
COAL
3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.6X
STATUS 1 STARTUP 4/80
COMMONWEALTH EDISON HAS RETROFITTED BOILER NUMBER 51 AT ITS POWERTON
STATION WITH A UOP LIMESTONE FGD SYSTEM. UNIT 51 IS ONE OF TWO IDENTICAL
BOILERS SUPPLYING STEAM TO AN 850 MW 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 S02. A STEAM
INDIRECT HOT AIR REHEATER BOOSTS THE TEMPERATURE BEFORE THE GAS EXITS
AN ACID BRICK LINED STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP,
AND THE SLUDGE IS POZ-0-TEC STABILIZED AND DISPOSED OF IN A LANDFILL.
THE FGD SYSTEM COMMENCED OPERATION IN APRIL, 1980.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEW 545 MW (GROSS)
327 MW (ESC)
COAL
.63 XS LIGNITE
LIME//LKALINE FLYASH
COMBUITION ENGINEERING
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 7/79
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 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS
DISPOSED IN A CLAY LINED POND. UNIT 1 OPERATIONS BEGAN IN JULY 1979.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
2
NEW 545 MW (GROSS)
327 MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKA'INE FLYASH
COMBUSTION ENGINEERING
ENERGY Cf'NSUMPTION: ****X
STATUS 1 STARTUP 7/80
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63X S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AND UNITED POWER. A COLD SIDE
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FOUR COUNTER-
CUPRENT SPRAY TOWERS. MIST ELIMINATION IS PROVIDED BY A BULK ENTRAINMENT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID BRICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS
DISPOSED OF IN A CLAY LINED POND. UNIT 2 COMMENCED OPERATIONS IN JULY
1980.
DELMARVA POWER & LIGHT
DELAWARE CITY
1
RETROFIT 60 MW (GROSS)
60 MW (ESC)
COKE
7.00 :
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
DELMARVA POWER & LIGHT
DELAWARE CITY
Z
RETROFIT 60 MW (GROSS)
60 MW (ESC)
COKE
7.00 XS 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 STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
WELLMAN-LCRD 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. THE SYSTEM BECAME OPERATIONAL IN MAY 1980.
DELMARVA POWER & LIGHT
DELAWARE CITY
3
RETROFIT 60 MW (GROSS)
60 MW (ESC)
COKE
7.00 XS FLUID PETROLEUM COKE
WELLMAH 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 (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF 500K
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACFM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMINATOR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
WELLMAN-L03D 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. THE SYSTEM BECAME OPERATIONAL IN MAY 1980.
DELMARVA POWER & LIGHT
VIENNA
9
NEW 550 MW (GROSS)
550 MW (ESC)
COAL
2.50 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.7X
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 FGO UNIT FOR EMISSION CONTROL. THE PULVERIZED COAL FIRED UNIT
WILL BURN COAL WITH AN AVERAGE SULFUR CONTENT OF 2.7X AND IS EXPECTED TO
COMMENCE OPERATIONS IN JUNE 1987.
DESERET GEN & TRANS COOP
MOON LAKE
1
NEW 410 MW (GROSS)
410 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 9/84
MOON LAKE 1 IS A PULVERIZED COAL (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION AND TRANSMISSION COOP TO BE LOCATED IN
VERNAL, UTAH. A CONTRACT WAS AWARDED TO COMBUSTION ENGINEERING FOR
A WET LIMESTONE SCRUBBING SYSTEM HAVING A S02 REMOVAL EFFICIENCY OF 95X.
THE SYSTEM WILL FEATURE A BAGHOUSE, SUPPLIED BY ECOLAIRE, TO REMOVE 99.6X
OF THE PARTICULATE MATTER. THE UNIT WILL OPERATE IN A CLOSED WATER LOOP
WITH SLUDGE DISPOSAL ON SITE IN A LANDFILL. OPERATIONS ARE SCHEDULED TO
COMMENCE IN SEPTEMBER 1984.
DESERET GEN & TRANS COOP
MOON LAKE
2
NEW 410 MW (GROSS)
410 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGI CONSUMPTION: ****x
STATUS 5 STARTUP 0/88
MOON LAKE 2 IS A PULVERIZED COAL (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION AND TRANSMISSION COOP TO BE LOCATED IN
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 99.6X OF THE PARTICULATE. THE
UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL ON SITE
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1988.
DUQUESNE LIGHT
ELRAMA
1-4
RETROFIT 510 MW (GROSS)
510 MW (ESC)
COAL
2.20 XS
LIME
CHEMIC3 DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 3.5X
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 ELRAMA, PENNSYLVANIA. THE EMISSION
CONTROL SYSTEM ON THIS SITE CONSISTS OF AN ESP FOLLOWED BY A MECHANICAL
COLLECTOR AND FIVE VARIABLE THROAT VENTURI LIME ABSORBER MODULES SUPPLIED
BY CHEMICO, WHICH ARE DESIGNED TO REMOVE 83X OF THE S02 FROM THE FLUE GAS.
THE CLEANED GAS PASSES THROUGH A DIRECT OIL FIRED REHEATER BEFORE EXITING
A 400 FOOT ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER
LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE IS HAULED TO AN OFF SITE LAND-
FILL. THE SYSTEM HAS BEEN OPERATIONAL SINCE OCTOBER 1975.
17
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
DUQUESNE LIGHT
PHILLIPS
1-6
RETROFIT 408 MW (GROSS)
408 MW (ESC)
COAL
1.92 XS BITUMINOUS
LIME
CHEMICC 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 83X OF THE S02 FROM THE FLUE GAS. TWO CHEVRON MIST
ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT OIL FIRED REHEATER WHICH RAIS-
ES THE GAS TEMPERATURE BY 20 DEC F BEFORE IT LEAVES VIA A 340 FOOT TALL
ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND
THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO AN OFF SITE LANDFILL. THE
SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1973.
EAST KENTUCKY POWER COOP
J.K. SMITH
1
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
1.50 XS BITUMINOUS
PROCESS NOT SELECTED
BABCOCK & WILCOX
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 1/85
THE EAST KENTUCKY POUER COOP HAS PLANS TO FIRE TWO NEW UNITS, J.K. SMITH
1 AND 2. A LETTER OF INTENT WAS SIGNED WITH BABCOCK AND WILCOX FOR A WET
LIME PROCESS TO CONTROL EMISSIONS. THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP FOR UNIT 1 IS EXPECTED IN 1965.
EAST KENTUCKY POWER COOP
J.K. SMITH
2
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
1.50 XS BITUMINOUS
PROCESS NOT SELECTED
BABCOCK & WILCOX
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 1/87
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TWO NEW UNITS, J.K. SMITH
1 AND 2. A LETTER OF INTENT WAS SIGNED WITH BABCOCK AND WILCOX FOR A WET
LIME PROCESS TO CONTROL EMISSIONS. THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS IN 1987.
EAST KENTUCKY POWER COOP
SPURLOCK
2
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
3.50 XS
LIME
COHSUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 10/81
SPURLOCK 2 OF EAST KENTUCKY POWER COOPERATIVE IS A BALANCED DRAFT PULVER-
IZED COAL (3.5X 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 ADL/COMBUSTICN EQUIPMENT ASSOCIATES LIME FGD SYSTEM (90X
DESIGN S02 REMOVAL EFFICIENCY). FLUE GAS FROM UNIT ONE WILL BE USED TO
REHEAT THE CLEANED GAS. THE SYSTEM, SLATED FOR START UP IN OCTOBER 1981,
WILL EMPLOY A CLOSED WATER LOOP AND POZ-O-TEC SLUDGE STABILIZATION.
FLORIDA POWER & LIGHT
MARTIN
3
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/87
FLORIDA POWER AND LIGHT HAS PLANS FOR THO 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 PRESENTLY CONSIDERING
ONLY FGD AS THE EMISSION CONTROL STRATEGY. THE START UP FOR UNIT 3 IS
PROJECTED FOR 1987.
FLORIDA POWER & LIGHT
MARTIN
4
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATU:. 6 STARTUP 0/89
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 PRESENTLY CONSIDERING
ONLY FGD AS THE EMISSION CONTROL STRATEGY. THE START UP FOR UNIT 4 IS
PROJECTED FOR 1989.
18
-------
EPA UTILITY F»JD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GENERAL t'UBLIC UTILITIES
COAL
1
NEW 625 MW (GROSS)
625 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 5/91
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MW UNIT, COAL I.
THE UTILITY IS PRESENTLY REQUESTING/EVALUATING BIDS FOR A FGD SYSTEM TO
CONTROL EMISSIONS. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE
OPERATIONS IN MAY 1991.
GENERAL PUBLIC UTILITIES
COAL
2
NEW 625 MW (GROSS)
625 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 5/93
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 MW UNIT, COAL 2.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1993.
GENERAL PUBLIC UTILITIES
COAL
3
NEW 625 MW (GROSS)
625 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 5/95
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 MW UNIT, COAL 3.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1995.
GENERAL PUBLIC UTILITIES
COAL
ft
NEW 625 MW (GROSS)
625 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 5/96
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MW UNIT, COAL 4.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1996.
GENERAL PUBLIC UTILITIES
SEWARD
7
NEW 690 MW (GROSS)
690 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.4X
STATUS 5 STARTUP 5/89
GENERAL PUBLIC UTILITIES IS PLANNING A NEW UNIT, SEWARD 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 1989.
GRAND HAVEN BRD OF LIGHT &
J.B. SIMS
3
NEW 65 MW (GROSS)
65 MW (ESC)
COAL
2.75 XS BITUMINOUS
LIME
BABCOCK 8 WILCOX
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 6/83
PWR THE GRAND HAVEN BOARD OF LIGHT AND POWER'S J.B. SIMS 3 IS A BITUMINIOUS
COAL (2.75X S, 11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN
GRAND HAVEN, MICHIGAN. A CONTRACT HAS BEEN AWARDED TO BABCOCK AND WILCOX
TO SUPPLY TWO SPRAY TOWERS TO CONTROL S02 EMISSIONS. EACH SCRUBBER SYSTEM
WILL UTILIZE A CHEVRON MIST ELIMINATOR AND AN IN-LINE REHEATER. THE
SLUDGE IS TO BE DISPOSED OF IN AN OFF SITE LANDFILL. OPERATIONS ARE TO
COMMENCE IN JUNE 1983.
19
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GULF POWER
SCHOLZ
1
RETROFIT 20 MW (GROSS)
20 MM (ESC)
COAL
3.25 XS
DUAL ALKALI/LIMESTONE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 8/80
THE DUAL ALKALI FGD SYSTEM ORIGINALLY INSTALLED IN 1975-1976 AT THE SCHOLZ
STATION OF GULF POKER WAS REACTIVATED IN AUGUST 1980 BY COMBUSTION EQUIP-
MENT ASSOCIATES AND ARTHUR D. LITTLE. THE SYSTEM IS BEING UTILIZED FOR
AN EPA SPONSORED TEST PROGRAM AIMED AT DETERMINING THE FEASIBILITY OF UTIL
IZIHG LIMESTONE RATHER THAN LIME AS THE SOURCE OF CALCIUM FOR THE REGEN-
ERATION REACTIONS. WITH THE EXCEPTION OF MODIFICATIONS TO THE ORIGINAL
ABSORBER VESSELS TO PROMOTE A LON'itR RESIDENCE TIME, NO MAJOR EQUIPMENT
MODIFICATIONS OR ADDITIONS WERE NECESSARY.
HOOSIER f.NERGY
MEROM-
1
NEW 490 MW (GROSS)
441 MW (ESC)
COAL
3.50 tS
LIMESTJNE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 5/82
rtEROM 1 AND 2 ARE TWO NEW UNITS BEING BUILT BY HOOSIER ENERGY IN SULLIVAN,
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WILL PRODUCE 1,732,000
ACFM OF FLUE GAS WHICH WILL BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
MITSUBISHI LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE
SYSTEM WILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDGE WILL
BE STABILIZED AND LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 1 IS SCHEDULED FOR MAY 1982.
HOOSIER ENERGY
MEROM
2
NEW 490 MW (GROSS)
441 MW (ESC)
COAL
3.50 ;:s
LIMESTl'NE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 9/81
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 LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
WATER LOOP MODE. START UP OF UNIT 2 IS SCHEDULED FOR SEPTEMBER 1981.
HOUSTON LIGHTING & POWER
LIMESTONE
1
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
1.08 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 12/84
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, TO BE LOCATED IN JEWITT, TEXAS. THE PULVERIZED COAL (1.08X 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 HAS AWARDED A CONTRACT TO COMBUSTION ENGI-
NEERING FOR THE INSTALLATION OF THIS SYSTEM. UNIT 1 IS SCHEDULED TO COM-
MENCE OPERATIONS IN 1984.
HOUSTON LIGHTING & POWER
LIMESTONE
2
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
1.08 XS PULVERIZED COAL
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION'- ****X
STATUS 3 STARTUP 12/85
HOUSTON LIGHTING AND POWER CO HAS PLANS FOR TWO NEW UNITS, LIMESTONE 1
AND 2, TO BE LOCATED IN JEWITT, TEXAS. THE PULVERIZED COAL (1.08X 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 HAS AWARDED A CONTRACT TO COMBUSTION ENGI-
NEERING FOR THE INSTALLATION OF THIS SYSTEM. UNIT 2 IS SCHEDULED TO COM-
MENCE OPERATIONS IN 1985.
HOUSTON LIGHTING & POWER
W.A. PARISH
8
NEW 600 MW (GROSS)
492 MW (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****x
STATUS 2 STARTUP 11/82
W.A. PARISH 8 OF HOUSTON LIGHTING & POWER IS A PULVERIZED COAL (0.6X S,
8700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN THOMPSONS, TEXAS. CHEMICO
WILL SUPPLY A LIMESTONE FGD SYSTEM WHICH WILL REMOVE 82X OF THE FLUE
GAS S02. REHEAT WILL BE PROVIDED BY BYPASSING 18X OF THE 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.
20
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
INDIANAPOLIS POUER & LIGHT
PATRIOT
1
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
3.50 XS
LIMESTONE
VENDOF, 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 & LIGHT
PATRIOT
2
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NO' SELECTED
ENERGY CONSUMPTION: ****Z
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PUNS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POWER fc LIGHT
PATRICT
3
NEW 650 MW (GROSS)
650 MW (ESC)
COAL
3.50
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2.
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
JACKSONVILLE ELEC AUTHORITY
ST.JOHNS RIVER PWR PARK
1
NEW 600 MW (GROSS)
600 MW (ESC)
COAL
2.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 12/85
THE JACKSONVILLE ELECTRIC AUTHORITY HAS PLANS FOR TWO NEW UNITS, ST. JOHNS
RIVER POWER PARK 1 AND 2, TO BE LOCATED IN EAST PORT, FLORIDA. EACH
UNIT WILL BURN PULVERIZED COAL (2-4X 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 ELEC AUTHORITY
ST.JOHNS RIVER PWR PARK
2
NEW 600 MW (GROSS)
600 MW (ESC)
COAL
2.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6 STARTUP 6/87
THE JACKSONVILLE ELECTRIC AUTHORITY HAS PLANS FOR TWO NEW UNITS, ST. JOHNS
RIVER POWER PARK 1 AHD 2, TO BE LOCATED IN EAST PORT, FLORIDA. EACH
UNIT WILL BURN PULVERIZED COAL (2-4X 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.
KANSA5 CITY POWER & LIGHT
HAWTHCRN
3
RETROFIT 90 MW (GROSS)
90 MW (ESC)
COAL
.60 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERG> CONSUMPTION: 2.2X
STATUS 1 STARTUP 11/72
HAWTHORN 3 OF KANSAS CITY POWER AND LIGHT IS A DRY BOTTOM PULVERIZED
BITUMINOUS COAL (0.6X S, 9800 BTU/LB) FIRED UNIT LOCATED IN KANSAS CITY,
MISSOURI, WHICH HAS 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 J UPSTREAM OF AN IN-LINE FINNED TUBE REHEATER, WHICH RAISES
THE TEMPERATURE OF THE CLEANFD GAS BEFORE IT EXITS THROUGH A GUMITE LINED
200 FOOT STACK. THE FLYASH STABILIZED SLUDGE IS DEPOSITED IN AN UNLINED
SLUDGE POND. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.
KANSAS C.:TY POWER & LIGHT
HAWTHORN
4
RETROFIT 90 MW (GROSS)
90 MW (ESC)
COAL
.60 -
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS POWER & LIGHT
JEFFREY
2
NEW 700 MW (GROSS)
490 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 APRIL 1980.
KANSAS POWER
LAWRENCE
4
RETROFIT
& LIGHT
125 MW (GROSS)
125 MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 1/77
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 LAKRENCE, 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 BY TWO CHEVRONS AND ONE BULK
ENTRAIHMENT 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 STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
KANSAS POWER & LIGHT
LAWRENCE
5
RETROFIT 420 MW (GROSS)
420 MW (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 4/78
LAWRENCE 5 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAURENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BFD TAIL END SCRUBBER IN APRIL 1978. THE
SYSTEM TREATS 403,000 ACFM OF FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73X. 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 F BEFORE
IT IS EXHAUSTED THROUGH A 120 FOOT STACK. THE SLUDGE IS DISPOSED IN AN
UNLINED INTERIM POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES IN A CLOSED WATER LOOP.
KENTUCKY UTILITIES
GREEN RIVER
1-3
RETROFIT 64 MW (GROSS)
64 MW (ESC)
COAL
4.00 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3.IX
STATUS 1 STARTUP 9/75
GREEN RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRY BOTTOM PULVERIZED
BITUMINOUS COAL (4X S, 11,000 BTU/LB) FIRED UNITS LOCATED IN CENTRAL
CITY, KENTUCKY. EACH BOILER SUPPLIES 360,000 ACFM OF FLUE GAS TO A
VARIABLE THROAT VENTURI FOLLOWED BY AN AMERICAN AIR FILTER LIME MOBILE
BED CONTACTOR (SOX DESIGN S02 REMOVAL EFFICIENCY). A RADIAL VANE MIST
ELIMINATOR IS FOLLOWED BY A STEAM TUBE REHEATER AND A 165 FOOT STACK.
SLUDGE IS DISPOSED IN AN ON-SITE UNLINED POND, AND THE SYSTEM OPERATES
IN A CLOSED WATER LOOP. THE SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER
1975.
KENTUCKY UTILITIES
HANCOCK
1
NEW 708 MW (GROSS)
650 MW (ESC)
COAL
3.50 /.S BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/88
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO NEW 650 MW (NET) PULVERIZED
:OAL (3.5X S, 10,500 BTU/LB) FIRED BOILERS. THE UNITS, HANCOCK 1 AND 2,
ARE TO BE LOCATED IN HAWESVILLE, KENTUCKY. THE UTILITY IS CONSIDERING A
'/1ET LIMESTONE SCRUBBING SYSTEM WHICH WILL OPERATE IN A CLOSED WATER LOOP
MODE TO CONTROL EMISSIONS. HANCOCK 1 AND 2 ARE SCHEDULED TO COMMENCE
OPERATION IN 1988 AND 1994, RESPECTFULLY.
KENTUCKY UTILITIES
HANCOC C
2
NEW 708 MW (GROSS)
650 MM (ESC)
COAL
3.50 /S BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/94
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO NEW 650 MW (NET) PULVERIZED
COAL (3.5X S, 10,500 BTU/LB) FIRED BOILERS. THE UNITS, HANCOCK 1 AND 2,
ARE TO BE LOCATED IN HAWESVILLE, KENTUCKY. THE UTILITY IS CONSIDERING A
WET LIMESTONE SCRUBBING SYSTEM WHICH WILL OPERATE IN A CLOSED WATER LOOP
MODE TO CONTROL EMISSIONS. HANCOCK 1 AND 2 ARE SCHEDULED TO COMMENCE
OPERATION IN 1988 AND 1994, RESPECTFULLY.
23
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LAKELAND UTILITIES
MCINTOSH
3
NEW 364 MW (GROSS)
364 MW (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 8/81
MCINTOSH 3 OF LAKELAND UTILITIES IS BEING CONSTRUCTED IN LAKELAND,
FLORIDA. BABCOCK AND WILCOX HAS BEEN AWARDED A CONTRACT TO SUPPLY AN
85X EFFICIENT (S02) LIMESTONE FGD SYSTEM FOR THIS UNIT. THE EMISSION CON-
TROL SYSTEM WILL CONSIST OF A COLD SIDE ESP FOLLOWED BY TWO PARALLEL FGD
MODULES AND A 250 FOOT ACID BRICK LINED STACK. THE SYSTEM WILL OPERATE IN
A CLOSED WATER LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE WILL BE USED AS
A CONSTRUCTION BASE. CONSTRUCTION BEGAN IN NOVEMBER 1979 AND START
UP IS SCHEDULED TO BE IN AUGUST 1981.
LANSING BOARD OF WATER & LIGHT THE ERICKSON 2 STATION OF THE LANSING BOARD OF WATER AND LIGHT IS A
ERICKSON
2
NEW 160 MM (GROSS)
160 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 1/87
PLANNED UNIT TO BE LOCATED IN DELTA TOWNSHIP, MICHIGAN. THE UNIT WILL
HAVE A MW RATING OF BETWEEN 160 AND 250, DEPENDING ON WHETHER OTHER MUNI-
CIPALITIES WILL JOIN IN THIS PROJECT. THE UTILITY IS PRESENTLY CONSIDER-
ING THE USE OF FGD FOR EMISSION CONTROL. OPERATIONS ARE SCHEDULED TO
COMMENCE IN 1987.
LOS ANGELES DEPT OF WTR & PWR
INTERMOUNTAIN
1
NEW 820 MW (GROSS)
820 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/86
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER 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 & PWR
INTERMOUNTAIN
2
NEW 820 MW (GROSS)
820 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/87
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM.
A HORIZONTAL KEIR 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 2 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1987.
LOS AhGELES DEPT OF WTR & PWR
INTERrOUNTAIN
3
NEW 820 MW (GROSS)
820 MW (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGK CONSUMPTION: ****X
STATUS 6 STARTUP 0/88
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER 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 ANGELLS DEPT OF WTR & PWR
INTERMOUNTAIN
4
NEW 820 MW (GROSS)
820 MW (ESC)
COAL
.79 >CS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6 STARTUP 0/89
THE LOS ANGELES DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIR1:' PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
WD WILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER ALONG WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
WILL EXIT A 750 FOOT STACK. UNIT 4 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1989.
24
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEHBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS & ELECTRIC
CANE RUN
ft
RETROFIT 188 MW (GROSS)
188 HW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 8/76
UNIT 4 AT LOUISVILLE GAS AND ELECTRIC'S CANE RUN STATION IS A PULVERIZED
BITUMINOUS COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. AN ESP AND TWO AMERICAN AIR FILTER CARBIDE LIME MOBILE BED ABSORBER
MODULES (85X DESIGN S02 REMOVAL) TREAT 734,000 ACFM OF FLUE GAS FROM THE
BOILER. TWO CHEVRON MIST ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT
COMBUSTION REHEATER AND A 250 FOOT STACK. THE WATER LOOP IS OPEN, AND
THE SLUDGE IS DISPOSED IN AN ON-SITE LINED POND. THIS RETROFIT SYSTEM
HAS BEEN OPERATIONAL SINCE AUGUST 1976.
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
RETROFIT ZOO MW (GROSS)
200 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: I.5X
STATUS 1 STARTUP 12/77
CANE RUN 5 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS COAL
(3.75X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. THE
BOILER SUPPLIES 700,000 ACFM OF FLUE GAS TO AN EMISSION CONTROL SYSTEM
CONSISTING OF AN ESP FOLLOWED AND TWO COMBUSTION ENGINEERING 85X. EFFICIENT
(DESIGN) CARBIDE LIME SPRAY TOWERS. A STEAM TUBE REHEATER RAISES THE GAS
TEMPERATURE 40 DEG F. THE SYSTEM OPERATES IN AN OPEN WATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED. OPERATION OF THIS RETROFIT SYSTEM
BEGAN IN DECEMBER 1977.
LOUISVILLE GAS & ELECTRIC
CANE RUN
6
RETROFIT 299 MW (GROSS)
299 MH (ESC)
COAL
4.80 XS BITUMINOUS
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: l.OX
STATUS 1 STARTUP 4/79
LOUISVILLE GAS AND ELECTRIC'S CANE RUN 6 IS A PULVERIZED BITUMINOUS COAL
(4.SOX S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KENTUCKY. ADL/CCMSUS-
TION EQUIPMENT ASSOCIATES SUPPLIED A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS UNIT. THE EMISSION CONTROL SYSTEM, DESIGNED TO REMOVE
95X OF THE FLUE GAS SOS, CONSISTS OF A COLD SIDE ESP AND TOO TRAY TO!!ER
MODULES. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TWO
DIRECT COMBUSTION REHEATERS BEFORE EXITING A 518 FOOT STACK. THE KATER
LOOP IS OPEN, AND THE SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED POND.
FOR A ONE YEAR PERIOD FOLLOWING THE FIRST QUARTER OF OPERATION (WHICH BE-
SAN IN APRIL 1979), THE U.S.EPA WILL SUBSIDIZE A MAX OF $4.5 MM FOR OPER-
ATION, R&D, AND REPORT WRITING (NOT APPLIED TO ANY CAPITAL EXPENDITURES).
LOUISVILLE GAS & ELECTRIC
MILL CREEK
1
RETROFIT 358 KW (GROSS)
358 MW (ESC)
COAL
3.75 XS
LIME
CCttSUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 1 STARTUP 12/80
MILL CREEK 1 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY OPERATING
ON THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT. COMBUSTION
ENGINEERING SUPPLIED THE LIME/LIMESTONE FGD SYSTEM WHICH IS SCHEDULED
TO COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1981.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
2
RETROFIT 350 MW (GROSS)
350 MW (ESC)
COAL
3.75 XS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 2 STARTUP 12/81
MILL CREEK 2 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY UNDER CONSTRUC-
TION ON THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT.
COMBUSTION ENGINEERING IS SUPPLYING THE LIME FGD SYSTEM WHICH WILL
COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1982.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
3
NEW 442 MW (GROSS)
442 MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 8/78
LOUISVILLE GAS AND ELECTRIC'S MILL CREEK 3 IS A 3.75X S COAL (11,500 BTU/
LB) FIRED UNIT LOCATED IN LOUISVILLE, KENTUCKY. AMERICAN AIR FILTER SUP-
PLIED A CARBIDE LIME FGD SYSTEM FOR THIS UNIT WHICH WAS DESIGNED TO REMOVE
85X OF THE S02 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.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS & ELECTRIC
MILL C?EEK
4
NEW 530 MW (GROSS)
495 MW (ESC)
COAL
3.75 ;.'S
LIME
AMERIC/N AIR FILTER
ENERGY CONSUMPTION: *****
STATUS 2 STARTUP 6/82
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN LOUISVILLE,
KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP AND FOUR
MOBILE BED SPRAY TOWERS. THE SYSTEM'S WATER LOOP WILL BE CLOSED, AND
THE SLUDGE WILL BE STABILIZED WITH LIME AND FLYASH. STEAM TUBES WILL
PROVIDE REHEAT OF THE CLEANED GASES. THE SYSTEM IS SCHEDULED TO START
UP IN JUNE 1982.
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
RETROFIT 72 MW (GROSS)
72 MW (ESC)
COAL
2.50 X5 BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: e.ex
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 & ELECTRIC
TRIMBLE COUNTY
1
NEW 575 MW (GROSS)
575 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5 STARTUP 7/85
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING (90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START UP IN JULY 1985.
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
2
NEW 575 MW (GROSS)
575 MW (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 7/88
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGD SYSTEMS ON TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL WASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS WILL BE CLEANED BY ESP'S AND WET SCRUBBING (90X REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS SCHEDULED
FOR START UP IN 1988.
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
3
NEW 435 MW (GROSS)
435 MW (ESC)
LIGNITE
1.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.8X
STATUS 6 STARTUP 0/88
LOWER COLORADO RIVER AUTHORITY HAS PLANS TO CONSTRUCT A 435 MW UNIT,
FAYETTE POWER PROJECT 3, TO BE LOCATED IN LA GRANGE, TEXAS. THE LIGNITE
(1.7X S, 4300 BTU/LB) FIRED BOILER WILL UTILIZE A FGD SYSTEM DESIGNED TO
REMOVE 90X S02. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1988.
MARQUETTE BOARD OF LIGHT &
SHIRAS
3
NEW 44 MW (GROSS)
31 MW (ESC)
COAL
***** XS
LIME
BUELL DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 10/82
PWR SHIRAS 3 OF THE MARQUETTE BOARD OF LIGHT AND POWER IS A PULVERIZED COAL
FIRED BOILER PLANNED FOR LOCATION IN MARQUETTE, MICHIGAN. THE UTILITY
HAS AWARDED A CONTRACT TO BUELL DIVISION, ENVIROTECH FOR A LIME/SPRAY
DRYING PROCESS TO CONTROL EMISSIONS. THE SYSTEM WILL UTILIZE A FABRIC
FILTER TO OBTAIN A PARTICLE REMOVAL EFFICIENCY OF 99.8X. THE UNIT IS
SCHEDULED TO COMMENCE OPERATIONS IN OCTOBER 1982.
26
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MICHIGAN SO CENTRAL PWR AGENCY
PROJECT
1
NEW 55 MW (GROSS)
55 MW (ESC)
COAL
2.25 riS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 1.8X
STATUS Z STARTUP 6/82
THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POWER AGENCY IS UNDER CON-
STRUCTION IN LITCHFIELD, MICHIGAN, AND WILL UTILIZE A WET LIMESTONE FGD
PROCESS. THE PULVERIZED COAL FIRED BOILER WILL FEED ITS FLUE GAS THROUGH
i HOT SIDE ESP FOLLOWED BY A BABCOCK AND WILCOX LIHESTOHE SPRAY TO^ER.
THE CLEANED GAS WILL PASS THROUGH A MIST ELIMINATOR BEFORE BEING WARMED
BY AN IN-LINE REHEATER AND EXITING A 250 FOOT STACK. THE SLUDGE IS TO
BE DISPOSED OFF SITE. START UP IS SCHEDULED FOR JUNE 1982.
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
5
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
.50 XS LIGNITE
PROCESS NOT SELECTED
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****•/.
STATUS 4 STARTUP 0/90
UNIT 1 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (-5X S) FIRED
BOILER. MIDDLE SOUTH UTILITIES HAS SIGHED A LETTER OF INTENT WITH
COMBUSTION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
6
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
. 50-X3 LIGNITE
PROCESS NOT SELECTED
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 4 STARTUP 0/92
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 KET LIMESTONE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
MIDDLE SOUTH UTILITIES
UNASSIGNED
1
NEW 890 KW (GROSS)
890 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS $ STARTUP 0/89
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED. THE PLANT WILL BE LOCATED
SOMEWHERE IN LOUISIANA. STARTUP IS SCHEDULED FOR 1989.
MIDDLE SOUTH UTILITIES
UNASSIGNED
2
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ***#X
STATUS 4 STARTUP 0/93
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING FOR A K'ET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED. THE PLANT WILL BE LOCATED
SOMEWHERE IN LOUISIANA. STARTUP IS SCHEDULED FOR 1993.
MIDDLE SOUTH UTILITIES
WILTON
1
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 0/88
WILTON 1 IS A COAL (.50X S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SCUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. STARTUP IS SCHEDULED FOR 1988.
27
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MIDDLE SOUTH UTILITIES
WILTON
2
NEW 890 MW (GROSS)
890 MW (ESC)
COAL
.50 XS
PROCESS NOT SELECTED
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 0/91
WILTON 2 IS A COAL ( .50X S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. STARTUP IS SCHEDULED FOR 1991.
MINNESOTA POWER 8 LIGHT
CLAY BOSP'ELL
ft
NEW 554 MW (GROSS)
475 MW (ESC)
COAL
.94 7.S SUBBITUMINOUS
LIME/A'-KALINE FLYASH
PEABODV PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 4/80
CLAY BOSWELL 4 OF MINNESOTA POWER AND LIGHT IS A SUBBITUMINOUS COAL (0.94X
i, 8896 BTU/LB) FIRED UNIT LOCATED IN COHASSET, MINNESOTA. PEABODY
'ROCESS SYSTEMS HAS SUPPLIED A LIME/ALKALINE FLYASH SYSTEM WHICH
.CS DESIGNED TO REMOVE 84.6X OF THE S02 IN THE FLUE GAS. TWO HOT SIDE ESP'S
*RE FOLLOWED BY VENTURI/SPRAY TOWER TRAINS. MIST ELIMINATION IS PROVIDED
BY A SIEVE TRAY FOLLOWED BY A SPIN VANE CHEVRON, AND REHEAT IS SUPPLIED
BY BYPASSING 5X OF THE FLUE GAS. THE SYSTEM OPERATES IN A CLOSED WATER
LOOP MODE, AND THE SLUDGE IS DISPOSED IN A LINED POND. OPERATIONS
COMMENCED IN APRIL 1980.
MIHN'KOTA POWER COOPERATIVE
MILTON R. YOUNS
2
NEW 440 MW (GROSS)
185 MW (ESC)
COAL
.70 /.S LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 9/77
MINNKOTA POWER COOPERATIVE'S MILTON R. YOUNG 2 IS A CYCLONE FIRED LIGNITE
(0.70XS, 6500 BTU/LB) BOILER LOCATED IN CENTER, NORTH DAKOTA. THE BOILER
PRODUCES 2,021,400 ACFM OF FLUE GAS, HALF OF WHICH IS CLEANED BY TWO ESP'S
AND TWO ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME/ALKALINE FLYASH SPRAY
TOWERS (75X DESIGN S02 REMOVAL EFFICIENCY). THE CLEANED GAS PASSES THROUGH
A CHEVRON MIST ELIMINATOR BEFORE IT JOINS A 15X BYPASS REHEAT, ALONG WITH
THE UNSCRUBBED GAS, EXITS A 550 FOOT STACK. THE WATER LOOP IS OPEN, AND TH
SLUDGE IS TRUCKED TO AN OFF-SITE MINEFILL. OPERATIONS BEGAN IN 1977.
MONONGAHELA POWER
PLEASANTS
1
NEW 618 MW (GROSS)
618 MW (ESC)
COAL
3.70 X> BITUMINOUS
LIME
BABCOCK & WILCOX
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 3/79
MONOK'GAHELA POWER PLEASANTS 1 IS A BITUMINOUS COAL (3.70X S, 12,150
BTU/LB) FIRED BOILER IN BELMONT, WEST VIRGINIA. BABCOCK AND WILCOX SUP-
PLIED A LIME FGD SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS S02 FROM
THIS UNIT. THE EMISSION CONTROL SYSTEM INCLUDES AN ESP UPSTREAM OF FOUR
SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1200 FOOT PLACITE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM ON THIS
UNIT HAS BEEN OPERATIONAL SINCE MARCH 1979.
MOMONGAHELA POWER
PLEASANTS
2
NEW 618 MW (GROSS)
618 MW (ESC)
COAL
4.50 XS BITUMINOUS
LIME
BABCOCK & WILCOX
ENERGY CONSUMPTION: ***«x
STATUS 1 STARTUP 10/80
MONONGAHELA POWER PLEASANTS 2 IS A BITUMINOUS COAL (4.5X S, 12,150
BTU/LB) FIRED BOILER LOCATED IN BELMONT, WEST VIRGINIA. BABCOCK AND
WILCOX SUPPLIED A LIME FGD SYSTEM DESIGNED TO REMOVE 90X OF THE BOILER
FLUE GAS S02. THE EMISSION CONTROL SYSTEM ON THIS UNIT INCLUDES AN ESP
UPSTREAM OF FOUR SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES
REHEAT OF THE CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1200 FOOT
PLACITE LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD
SYSTEM OPERATION COMMENCED IN OCTOBER 1980.
MONTANA POWER
COLSTRIP
1
NEW 360 HW (GROSS)
360 MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 9/75
COLSTRIP 1 OF MONTANA POWER IS A SUBBITUMINOUS COAL (0.77X S, 8843 BTU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONTANA. AOL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVR0^4 MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 500
FOOT STACK. THE UHSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN SEPTEMBER 1975.
28
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA POWER
COLSTRIP
2
NEW 360 KM (GROSS)
360 MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
COLSTRIP 2 OF MONTANA POWER IS A SUBBITUMINOUS COAL (0.77X S, 8843 BTU/LB)
FIRED UNIT LOCATED IN COLSTRIP, MONTANA. ADL/COtlBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 500
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND.
THE WATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY 1976.
MONTANA POWER
COLSTRIP
3
NEW 700 MW (GROSS)
700 MW (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 0/83
MONTANA POWER'S COLSTRIP 3 IS A LOW SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN
AWARDED TO ADL/COMBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLYASH
FGD SYSTEM ON THIS UNIT. START UP IS SCHEDULED FOR 1983.
MONTANA POWER
COLSTRIP
4
NEW 700 MW (GROSS)
700 MW (ESC)
COAL
.70 7.S
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: **x*Z
STATUS 2 STARTUP
MONTANA POWER'S COLSTRIP 4 If> A LOW SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS BEEN '
WARDED TO ADL/COMBUSTION EQUIPMENT ASSOCIATES FOR A LIME/ALKALINE FLYASH
:GD SYSTEM ON THIS UNIT. S''ART UP IS SCHEDULED FOR 1984.
MONTANA-DAKOTA UTILITIES
COYOTE
1
NEW 440 MM (GROSS)
440 MW (ESC)
COAL
.87 ::S LIGNITE
SODIUM CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R.I.
ENERGY CONSUMPTION: 1.1X
STATUS 2 STARTUP 3/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LIGNITE (0.87X S, 7050 BTU/LB)
BOILER UNDER CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT IS JOINTLY
OWNED BY FIVE UTILITIES, WITH MONTANA-DAKOTA UTILITIES BEING THE MAJOR
OWNER ANO CONSTRUCTOR. AN AQUEOUS CARBONATE DRY FGD SYSTEM DESIGNED TO
REMOVE 70X OF THE S02 IS BEING SUPPLIED BY WHEELABRATOR-FRYE AND ROCKWELL
INTERNATIONAL. THE SPRAY DRYER/BAGHOUSE SYSTEM IS SCHEDULED TO START UP
IN 1981.
MUSCATINE POWER & WATER
MUSCATIME
9
NEW 166 MW (GROSS)
166 KM (ESC)
COAL
3.00 X'J BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.8X
STATUS J STARTUP 9/82
MUSCATINE 9 IS A PULVERIZED BITUMINOUS COAL (3X S, 11,200 BTU/LB) FIRED
UNIT PLANNED BY MUSCATINE POWER AND WATER TO BE LOCATED IN MUSCATINE,
IOWA. A CONTRACT WAS AWARDED TO RESEARCH COTTRELL FOR A LIMESTONE UNIT FOR
EMISSION CONTROL. THE FGD SYSTEM WILL FEATURE AN ESP, TWO 100X CAPACITY
TOWERS, STEAM COIL REHEAT, A CLOSED WATER LOOP, AND FORCED OXIDATION OF
THE SLUDGE BEFORE LANDFILL. THE DESIGN S02 REMOVAL WILL BE 94X. START UP
HILL TAKE PLACE IN 1982.
NEBRASKA PUBLIC POWER DISTRICT FOSSIL III 1 IS A PULVERIZED SUBBITUMINOUS COAL (0.36X S, 8000 BTU/LB)
FOSSIL III
1
NEW 650 KM (GROSS)
650 KM (ESC)
COAL
.36 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 3/87
FIRED UNIT PLANNED BY THE NEBRASKA PUBLIC POWER DISTRICT TO BE LOCATED
NEAR SARGENT, NEBRASKA. THE UTILITY IS CONSIDERING A DRY SCRUBBING
FGD PROCESS TO CONTROL EMISSIONS FROM THE 650 MM BOILER. STARTUP FOR
THE UNIT IS SCHEDULED FOR 1987.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
HARRY ALLEN
1
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/86
NEVADA POWER'S HARRY ALLEN 1 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION KITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1986.
NEVADA POWER
HARRY ALLEN
2
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
***** XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/87
NEVADA POWER'S HARRY ALLEN 2 IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1987.
NEVADA POWER
HARRY ALLEN
3
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
*****
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA POWER
REID GARDNER
3
NEW 125 MM (GROSS)
125 MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: *****
STATUS 1 STARTUP 7/76
REID GARDNER 3 IS A WET BOTTOM LOW SULFUR COAL (0.5X S, 12,450 BTU/LB)
FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
BONATE-BASED (TRONA) SCRUBBING SYSTEM BY 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 POND. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1976.
NEVADA POWER
REID GARDNER
4
NEW 250 MW (GROSS)
250 MW (ESC)
COAL
.75 XS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****X
STATUS 4 STARTUP 4/83
REID GARDNER 4 OF NEVADA POWER IS A COAL (0.75X S, 12,450 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN MOAPA, NEVADA. A LETTER OF INTENT HAS BEEN
SIGNED WITH COMBUSTION EQUIPMENT ASSOCIATES TO PROVIDE A SODIUM CARBONATE
FGD SYSTEM. A BAGHOUSE WILL PRECEED THE FGD SYSTEM FOR PARTICLE
CONTROL. CONSTRUCTION IS EXPECTED TO BEGIN IN 1980, AND START UP IS
EXPECTED IN 1983.
NEVADA POWER
WARNER VALLEY
1
NEW 295 MW (GROSS)
295 MW (ESC)
COAL
1.15 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS ^5 STARTUP 6/85
NEVADA POWER'S WARNER VALLEY 1 IS A PLANNED COAL (1.15X S) FIRED UNIT TO
BE LOCATED IN ST. GEORGE, UTAH. THE UTILITY IS CURRENTLY EVALUATING BIDS
FOR AN FGD SYSTEM. NO ANNOUNCEMENTS HAVE YET BEEN MADE CONCERNING THE
EMISSION CONTROL STRATEGY FOR THIS UNIT. START UP IS EXPECTED IN JUNE
1985.
NEVADA POWER
WARNER VALLEY
2
NEW 295 MW (GROSS)
295 MW (ESC)
COAL
1.15 :
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION Z
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
II
RETROFIT 116 MW (GROSS)
115 MW (ESC)
COAL
3.50 XS
WELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 12.IX
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 50 DEG 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.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
17
NEW 421 MW (GROSS)
421 MW (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/83
SCHAHFER 17 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 REHEATER. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE 1983.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
18
NEW 421 MW (GROSS)
421 MW (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/85
SCHAHFER 18 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.EX 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 REHEATER. START UP OF THIS UNIT IS
SCHEDULED FOR JUNE 1985.
NORTHERN STATES POWER
METRO COAL
1
NEW 200 MW (GROSS)
200 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****2
STATUS 6 STARTUP 0/90
NORTHERN STATES POWER HAS PLANS TO CONSTRUCT A 190 MW PULVERIZED COAL
(l.OX S, 8700 BTU/LB) FIRED UNIT, METRO COAL 1. THE UNIT IS TO UTILIZE
A LIME SPRAY DRYING SYSTEM ALONG WITH FABRIC FILTERS TO CONTROL EMISSIONS.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
NORTHERN STATES POWER
RIVERSIDE
6,7
RETROFIT 110 MW (GROSS)
110 MW (ESC)
COAL
1.20 *S SUBBITUMINOUS
LIME/S°RAY DRYIN3
JOY MFVNIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 11/80
RIVERSIDE 6 AND 7 ARE TWO COAL FIRED BOILERS OWNED BY NORTHERN STATES
POWER AND LOCATED IN MINNEAPOLIS, MINNESOTA. EACH BOILER GENERATES A FLUE
GAS FLOW OF 340,000 ACFM AT 350 F. CURRENTLY, A DEMONSTRATION LIME/SPRAY
DRYING FGD SYSTEM THAT IS CAPABLE OF TREATING THE FLUE GAS FROM BOTH
BOILERS IS BEING TESTED AT THIS UNIT. THE SYSTEM WAS SUPPLIED BY NIRO
ATOMIZER/JOY MANUFACTURING AND CONSIST OF A SPRAY DRYER FOLLOWED BY
A BAGHOUSE. THE CLEAN FLUE GAS IS VENTED TO TWO 275 FT CONCRETE STACKS
WITH FIRE BRICK LINERS. SPENT ABSORBENT IS BEING DISPOSED OF IN ON
AND OFF SITE LANDFILLS. OPERATIONS COMMENCED IN NOVEMBER 1980.
NORTHERN STATES POWER
SHERBU3NE
1
NEW 740 MW (GROSS)
740 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMSUSTICN ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 3/76
NORTHERN STATES POWER'S SHERBURNE 1 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMIKOUS COAL (0.80X S, 8500 ETU/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
1976. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATORS/TRAIN, AN IN-LINE HOT WATER
THEATER, AND A 650 FOOT OFTEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
32
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NORTHERN STATES POWER
SHERBURNE
2
NEW 740 MW (GROSS)
740 MW (ESC)
COAL
.80 X5 SUBBITUMINOUS
LIMESTOME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 3/77
NORTHERN STATES POWER'S SHERBURNE 2 IS A BALANCED DRAFT PULVERIZED SUBBI-
TUMINOUS COAL (0.80X S, 8500 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
BOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1977. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATORS/TRAIN, AN IN-LINE HOT UATER
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.
NORTHERN STATES POWER
SHERBU3NE
3
NEW 850 MW (GROSS)
850 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/85
NORTHERN STATES POUER HAS PLANS TO CONSTRUCT A 800 MW PULVERIZED COAL
(l.OXS, 8700 BTU/LB) FIRED BOILER, SHERBURNE 3, TO BE LOCATED NEXT TO THE
SHERBURNE 1 AND 2 UNITS IN BECKER, MINNESOTA. THE UTILITY IS CONSIDERING
THE USE OF A LIME SPRAY DRYING PROCESS ALONG WITH FAERIC FILTERS TO
CONTROL EMISSIONS. THE SYSTEM IS SCHEDULED TO COMMENCE OPERATIONS IN 1985.
NORTHERN STATES POWER
WISCONSIN COAL
1
NEW 670 MW (GROSS)
670 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 6 STARTUP 0/91
THE WISCONSIN COAL 1 UNIT OF NORTHERN STATES POWER IS A PLANNED 620 MW
PULVERIZED COAL (l.OXS, 8700 BTU/LB) FIRED UNIT TO BE LOCATED IN DURAND,
WISCONSIN. THE UTILITY IS CONSIDERING THE USE OF A LIME SPRAY DRYING
SYSTEM ALONG WITH FABRIC FILTERS TO CONTROL EMISSIONS. OPERATIONS ARE
SCHEDULED TO COMMENCE IN 1991.
PACIFIC GAS « ELECTRIC
MONTEZUMA
1
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.5X
STATUS 6 STARTUP 6/94
MONTEZUMA 1 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 BAGKOUSE AKD A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START UP IS SCHEDULED FOR 1993.
PACIFIC GAS & ELECTRIC
MONTEZUMA
2
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
.80 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 ANO A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START UP IS SCHEDULED FOR 1994.
PACIFIC POWER & LIGHT
JIM BRIDGER
1
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
.56 XS SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 0/88
PACIFIC POWER AND LIGHT'S JIM BRIDGER 1 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING. THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. STARTUP IS SCHEDULED
FOR 1988.
33
-------
EPA UTILITY F6D SURVEY: OCTOBE.? - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PACIFF: POWER & LIGHT
JIM BR.:DGER
2
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
.56 :'.S SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5 STARTUP 0/84
PACIFIC POUER AND LIGHT'S JIM BRIDGER 2 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING. THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. STARTUP IS SCHEDULED
FOR 1984.
PACIFIC POWER & LIGHT
JIM BRIDGER
3
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
.56 XS SUEBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS ,'i STARTUP 0/86
PACIFIC POWER AND LIGHT'S JIM BRIDGER 3 IS A DRY BOTTOM PULVERIZED SUB-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING. THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. STARTUP IS SCHEDULED
FOR 1986.
PACIFIC POWER & LIGHT
JIM BRIDGER
4
NEW 550 MW (GROSS)
550 MW (ESC)
COAL
.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, 9300 BTU/LB) FIRED BOILER LOCATED IN
ROCK SPRINGS, WYOMING. A 91X EFFICIENT SODIUM CARBONATE FGD SYSTEM FOR
THIS UNIT WAS SUPPLIED BY THE AIR CORRECTION DIVISION OF UOP. A COLD
SIDE ESP TREATS 2,720,000 ACFM OF FLUE GAS, FOLLOWED BY THREE SIEVE
TRAY ABSORBERS. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. A
SYSTEM CHECK OUT WAS CONDUCTED IN JULY 1979, AND OPERATIONS BEGAN
IN SEPTEMBER 1979.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
NEW 917 MW (GROSS)
917 MW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 6.OX
STATUS 1 STARTUP 12/75
BRUCE MANSFIELD 1 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IN SHIPPINGPORT,
PENNSYLVANIA. A CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.IX) 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 (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FROM SERVICE
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.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEW 917 MW (GROSS)
917 MW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 6.OX
STATUS 1 STARTUP 7/77
BRUCE MANSFIELD 2 OF PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED DRAFT
BOILER FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IN SHIPPINGPCRT,
PENNSYLVANIA. A CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.IX) 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 (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FROM SERVICE
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 LAND-
FILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
PENNSYLVANIA POWER
BRUCE MANSFIELD
3
NEW 917 MW (GROSS)
917 MW (ESC)
COAL
3.00 XS
LIME
PULLMAN KELLOGG
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 6/80
BRUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED
COAL (3.OX S, 11,500 BTU/LB) FIRED BOILER LOCATED IN SHIPPINGFORT,
PENNSYLVANIA. FOUR ESP'S TREAT 3,308,000 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 COMBUSTION 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.
34
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PHILADELPHIA ELECTRIC
CROMBY
1
RETROFIT 150 MW (GROSS)
150 MW (ESC)
COAL
3.00 '/.S
MAGNESIUfi OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 5/83
PHILADELPHIA ELECTRIC HAS PLANS FOR THE RETROFIT OF AN FGD SYSTEM ON ONE
OF THE TWO 3.OX SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHOENIX-
VILLE, PENNSYLVANIA. CONSTRUCTION OF THE MAGNESIUM OXIDE SYSTEM SUPPLIED
BY UNITED ENGINEERS HAS COMMENCED. THE START UP DATE IS SET FOR 1983.
PHILADELPHIA ELECTRIC
EDDYSTONE
1
RETROFIT 2*0 MW (GROSS)
£40 MW (ESC)
COAL
2.60 -
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
1
RETROFIT 361 MW (GROSS)
361 MW (ESC)
COAL
.80 7.5 SUBBITUMINOUS
WELLMArt LORD
DAVY KCKEE
ENERGY CONSUMPTION: 4.4X
STATUE 1 STARTUP 4/78
SAN JUAN 1 OF PUBLIC SERVICE OF NEW MEXICO IN WATERFLOW, NEW MEXICO IS A
COAL (0.8X S, 8100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT WELLMAN LORD FGD SYSTEM BY DAVY POWERGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE APRIL 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODUCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUftN
2
RETROFIT 350 MW (GROSS)
350 MW (ESC)
COAL
.80 /.S SUBBITUMINOUS
WELLMAN tORD
DAVY MCKFE
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 (0.8X S, 8100 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 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (OWE SPARE) VENTURI SCRUBBER/SPRAY TOWER ABSOR-
BER TRAINS WHICH WERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
3IRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODUCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
3
NEW 534 MW (GROSS)
534 MW (ESC)
COAL
.80 XS SUBBITUMINOUS
WELLMAN LORD
DAVY M;KEE
ENERGY CONSUMPTION: 3.6X
STATUS 1 STARTUP 12/79
SAN JUAN 3 IS A COAL (0.8X 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 POHERGAS 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 (90X DE-
SIGN S02 REMOVAL) TRAINS FOLLOW A HOT SIDE ESP. AN INDIRECT HOT AIR
REHEATER BOG:, ,3 THE GAS TEMPERATURE 50 DEG F. THE SYSTEM OPERATES
IN A CLOSED WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER 1979.
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN
4
NEW 534 MW (GROSS)
534 MW (ESC)
COAL
.60 ^S SUBBITUMINOUS
WELLMAK' LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS Z 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 POHERGAS 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 (90X 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 1983.
PWR AUTHORITY OF STATE OF NY
FOSSIL
NEW 700 MW (GROSS)
700 MH (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 4/87
THE POWER AUTHORITY OF NEW YORK PLANS A NEW 3.OX SULFUR COAL FIRED UNIT
WHICH WILL BE LOCATED AT THE ARTHUR KILL FACILITY ON STATEN ISLAND. THE
UTILITY IS PRESENTLY CONSIDERING FGD SYSTEMS FOR THIS UNIT. PUBLIC SERVICE
COMMISSION HEARINGS ARE CURRENTLY IN PROGRESS. START UP IS EXPECTED IN
APRIL 1987.
SALT RIVER PROJECT
CORONADO
1
NEW 350 MW (GROSS)
280 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: 4.3X
STATUS 1 STARTUP 11/79
SALT RIVER PROJECT'S CORONADO 1 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS
COAL (l.OX S, 8300 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS,
ARIZONA. PULLMAN KELLOGG SUPPLIED THE TWO LIMESTONE HORIZONTAL WEIR SPRAY
TOWERS WHICH REMOVES 82.5X OF THE S02 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL MIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS PROVIDES REHEAT. THE WATER LOOP IS AN OPEN MODE, AND THE
UNSTABILIZED SLUDGE IS DISPOSED IN AN UNLINED POND. START UP WAS
IN NOVEMBER 1979.
36
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SALT RIVER PROJECT
CORONADO
2
NEW 350 MW (GROSS)
280 MW (ESC)
COAL
1.00 XS SUBBITUMINOUS
LIMESTONE
PULLMAN KELLOGG
ENERGY CONSUMPTION: 4.3X
STATUS 1 STARTUP 7/80
SALT RIVER PROJECT'S CORONADO 2 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS
COAL U.OX S, 8300 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS, ARIZONA.
PULLMAN KELLOGG SUPPLIED TWO LIMESTONE HORIZONTAL WEIR SFRAY TOWERS
WHICH REMOVES 82.57. Of THE S02 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL MIST ELIMINATORS PRECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS PROVIDES REHEAT. THE WATER LOOP IS AN OPEN MODE, AND THE
UNSTABILIZED SLUDGE IS DISPOSED IN AN UNLINED POND. START UP WAS IN
JULY 1980.
SALT RIVER PROJECT
CORONADO
3
NEW 400 MM (GROSS)
280 MW (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.8X
STATUS 6 STARTUP 0/89
CORONADO 3 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS COAL (.60X 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 TOUERS UTILIZING LIMESTONE AS THE ABSORBENT. PLANS FOR AN
EMISSION CONTROL SYSTEM HAVE NOT BEEN FINALIZED. THE SYSTEM WILL HAVE A
20X BYPASS REHEAT, AND THE SLUDGE WILL PROBABLY BE PONDED. SCHEDULED OPER-
ATION DATE IS 1989.
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
1
NEW 400 MW (GROSS)
400 MW (ESC)
COAL
1.70 XS LIGNITE
LIMESTONI
BABCOCK ii WILCOX
ENERGY CONSUMPTION: 5.OX
STATUS 2 STARTUP 8/81
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 WIICOX 86X EFFICIENT LIMESTONE TCA MODULES.
CHEVRON MIST ELIMINATORS WILL PRECEDE AN IN-LINE REHEATER AND AN ACID
BRICK LINED STACK. THE WATER LOOP WILL BE CLOSED, AND THE DEWATERED SLURRY
WILL BE MIXED WITH FLYASH BY RESEARCH COTTRELL AND DISPOSED IN AN OFF SITE
LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN AUGUST 1981.
SEMINOIE ELECTRIC
SEMINO.E
1
NEW 620 MW (GROSS)
620 MW (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABODr 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
1983.
SEMINO^E ELECTRIC
SEMINOLE
2
NEW 620 MW (GROSS)
620 MW (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 3/85
SEMINOLE 2 OF SEMIHOLE 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 SYSTEMS. START UP IS EXPECTED IN MARCH 1985.
SIERRA PACIFIC POWER
VALMY
2
NEW
COAL
276 MW (GROSS)
276 MW (ESC)
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 LIME SYSTEM WILL BE
UTILIZED. THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN AUGUST 1984.
37
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTON
1
NEW 235 MW (GROSS)
235 MW (ESC)
COAL
2.80 XS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 1.77.
STATUS 2 STARTUP 6/81
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-
INS OF TWO ESP'S AND THREE BOX CAPACITY LIMESTONE VENTURI FGD MODULES. THE
CLEANED GAS WILL PASS THROUGH CHEVRON MIST ELIMINATORS BEFORE EXITING A
450 FOOT FRP LINED FLUE (A SECOND CARBON STEEL LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK). THE HATER LOOP WILL BE OPEN, AND THE
SLUDGE WILL BE PONDED. START UP IS SLATED FOR JUNE 1981.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 3/85
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO NEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA. EACH 500 MW
BOILER WILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.0 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 500 MW (GROSS)
500 MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMES! ONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 1/84
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO NEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA. EACH 500 MW
BOILER WILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.0 AND 2.3X.
THE UTILITY HAS SIGNED A CONTRACT WITH PEABODY PROCESS SYSTEMS FOR THE
INSTALLATION OF A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS IN JANUARY 1984.
SOUTH CAROLINA PUBLIC SERVICE
WINYAK
2
NEW 280 MW (GROSS)
140 MW (ESC)
COAL
1.70 XS BITUMINOUS
LIMESTONE
BABCOCK /• 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 HILCOX VENTURI SCRUBBER/LIMESTONE TRAY
TOWER ABSORBER TRAIN DESIGNED TO REMOVE 45X OF THE S02 FROM THE BOILER
FLUE GAS MAKE UP THE EMISSION CONTROL SYSTEM ON THIS UNIT. THE SYSTEM
OPERATES IN AN OPEN WATER LOOP, AND THE SLUDGE IS DISPOSED IN AN ON-SITE
UNLINED POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
SOUTH CAfOLINA PUBLIC SERVICE WINYAH 3 OF SOUTH CAROLINA PUBLIC SERVICE IS A DRY BOTTOM BOILER WHICH
WINYAH
3
NEW 280 MW (GROSS)
280 MW (ESC)
COAL
1.70 .
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTH MISSISSIPPI ELEC PWR
R.I). MORROW, SR.
1
NEW 200 MM (GROSS)
124 MW (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: 5.5X
STATUS 1 STARTUP 8/78
R.D. MORROW 1 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S, 12,000 BTU/LB) FIRED UNIT IN HATTISBURG, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 408 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST 1978.
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
2
NEW 200 MW (GROSS)
124 MW (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIRONEERING, RILEY STOKER
ENERGY CONSUMPTION: 5.5X
STATUS 1 STARTUP 6/79
R.D. MORROW 2 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S, 12,000 BTU/LB) FIRED UNIT IN HATTISBURG, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VEHTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 408 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK TO AN OFF SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1979.
SOUTHERN ILLINOIS POWER COOP
MARION
4
NEW 173 MW (GROSS)
173 MW (ESC)
COAL/REFUS
3.75 XS BITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 2.3X
STATUS 1 STARTUP 5/79
UNIT 4 AT SOUTHERN ILLINOIS POWER COOP'S MARION STATION IN MARION, ILLI-
NOIS IS A CYCLONE FIRED COAL (3.5X S, 9000 BTU/LB) BOILER WHICH IS SERVED
BY A 89.4X EFFICIENT (DESIGN) LIMESTONE FGD SYSTEM SUPPLIED BY BABCOCK AND
WILCOX. TWO SPRAY TOWERS AND A BRICK LINED STACK ARE DOWNSTREAM OF AN ESP
IN THIS SYSTEM. THE WATER LOOP IS OPEN, AND THE FLYASH STABILIZED SLUDGE
IS DEWATERED AND LANDFILLED. THE SYSTEM BECAME OPERATIONAL DURING MAY
1979.
SOUTHERN ILLINOIS POWER COOP
MARION
5
NEW 300 MW (GROSS)
300 MW (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOF1 NOT SELECTED
ENERGt CONSUMPTION: *#**X
STATUS 6 STARTUP 0/88
MARION 5 IS A COAL (3.OX S, 9000 BTU/LB) FIRED UNIT PLANNED BY SOUTHERN
ILLHOIS POWER COOP FOR LOCATION IN MARION, ILLINOIS. THE UTILITY HAS NOT
YET DECIDED ON AN FGD PROCESS AS IT IS WAITING FOR THE FINALIZATION OF
THE S02 REGULATIONS THE UNIT WILL HAVE TO MEET. START UP IS EXPECTED IN
1988.
SOUTHERN INDIANA GAS &.ELEC
A.B. EROWN
1
NEW 265 MW (GROSS)
265 MW (ESC)
COAL
3.35 XS BITUMINOUS
DUAL /LKAi.1
FMC
ENERGY CCNSUMPTION: .8X
STATUS 1 STARTUP 3/79
SOUTHERN INDIANA GAS AND ELECTRIC'S A.B.BROWN 1 IS A DRY BOTTOM PULVERIZED
COAL (3.35X S, 13,010 BTU/LB) FIRED UNIT IN WEST FRANKLIN, INDIANA. FMC
SUPPLIED A DUAL ALKALI FGD SYSTEM DESIGNED TO REMOVE 85X OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CONTACTORS. A COLD SIDE ESP
PROVIDES PRIMARY PARTICULATE CONTROL, AND ONE CHEVRON 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 1979.
SOUTHWESTERN ELECTRIC POWER
DOLET
1
NEW
I LS
720 MW (GROSS)
720 MW (ESC)
COAL
.70
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
2
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 3/88
DOLET HILLS 2 OF SOUTHWESTERN ELECTRIC POWER IS A PLANNED 720 MW LIGNITE
(0.7XS, 7100BTU/LB) FIRED BOILER TO BE LOCATED IN MANSFIELD, LOUISIANA.
THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOR PARTICULATE CONTROL
AND A WET LIMESTONE FGD SYSTEM FOR S02 CONTROL. THE FLUE GAS WILL EXIT
THROUGH A 525 FOOT STACK. THE UNIT IS SCHEDULED TO BEGIN OPERATIONS IN
1988.
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY
1
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.80 XS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 12/8*
HENRY W. PIRKEY 1 IS A WET BOTTOM LIGNITE (0.8X S, 6300 BTU/LB) FIRED UNIT
PLANNED BY SOUTHWESTERN ELECTRIC POWER FOR LOCATION IN HALLSVILLE, TEXAS.
A CONTRACT HAS BEEN AWARDED TO THE AIR CORRECTION DIVISION OF UOP FOR FOUR
LIMESTONE SPRAY TOWERS (99+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 198*.
SOYLAND POWER COOP
SOYLAND
1
NEW 500 MW (GROSS)
500 MW (ESC)
COAL
3.00 XS UNDECIDED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **#*X
STATUS 6 STARTUP 0/87
SOYLAND POWER COOP HAS PLANS FOR A NEW UNIT, SOYLAND 1, TO BE LOCATED IN
ILLINOIS. THE COAL FIRED BOILER IS TO BE RATED AT 500 MW (GROSS) AND UTI-
LIZE A FGD SYSTEM TO CONTROL EMISSIONS. OPERATIONS ARE SCHEDULED TO COM-
MENCE IN 1937.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEW 19* MW (GROSS)
19* MW (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: *.6X
STATUS 1 STARTUP */77
SPRINGFIELD CITY UTILITIES' SOUTHWEST 1 IS A PULVERIZED BITUMINOUS COAL
(3.5X S, 12,500 BTU/LB) FIRED BOILER LOCATED IN SFRINSFIELD, MISSOURI. THE
EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A COLD SIDE ESP FOLLOWED
BY TWO UOP LIMESTONE TCA MODULES UHICH WERE DESIGNED TO REMOVE BOX OF THE
FLUE GAS S02. ONE CHEVRON/MODULE LEADS TO A 38* 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
DALLMAN
3
NEW
205 MW (GROSS)
205 MW (ESC)
COAL
3.30 XS
LIMESTONE
RESEARCH-COTTRELL
ENERG1 CONSUMPTION: 5.9X
STATUE 1 STARTUP 10/80
LIGHT & PWR DALLMAN 3 OF SPRINGFIELD WATER, LIGHT, AND POWER IS A PULVERIZED COAL
(3.3X S, 10,500 BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD, ILLINOIS.
RESEARCH COTTRELL SUPPLIED A LIMESTONE FGD SYSTEM DESIGNED TO REMOVE
95X OF THE S02 FROM 850,000 ACFM OF BOILER FLUE GAS. A HOT SIDE ESP
PRECEDES TWO PACKED TO',4ER ABSORBERS, ONE HORIZONTAL CHEVRON PER MODULE,
AND A 500 FOOT ACID BRICK LINED STACK. NO REHEAT IS PROVIDED. SLUDGE IS
DISPOSED OF IN A LANDFILL. FGD OPERATIONS COMMENCED IN OCTOBER 1980.
ST. JOE ZINC
G.F. hEATCN
1
RETROFIT
60 MW (GROSS)
60 MW (ESC)
BITUMINOUS
COAL
2.00 XS
CITRATE
MORRIS3N « KNUDSEN/U.S.B.M.
ENERGK 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 STACK. THE SYSTEM S02 REMOVAL EFFICIEN-
CY WILL BE OVER 90X. THE WATER LOOP IS CLOSED LOOP MODE. THE FGD SYSTEM
COMMENCED OPERATION IN NOVEMBER 1979.
*0
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SUNFLOWER ELECTRIC COOP
HOLCOMB
I
NEW 347 MM (GROSS)
347 MW (ESC)
COAL
.47 '/.S SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: .9X
STATUS 3 STARTUP 9/83
SUNFLOWER ELECTRIC COOP'S HOLCOMB 1 STATION IS A PLANNED 347 MW UNIT TO BE
LOCATED IN HOLCOMB, KANSAS. THE PULVERIZED COAL (0.47X S, 8800
BTU/LB) FIRED BABCCCK AND WILCOX BOILER WILL UTILIZE A JOY MANUFACTURING/
NIRO ATOMIZER.DRY SCRUBBING PROCESS FOR S02 CONTROL. A FABRIC FILTER
WILL BE UTILIZED FOR PRIMARY PARTICLE CONTROL. THE UNIT IS SCHEDULED
TO COMMENCE OPERATIONS IN THE FALL OF 1983.
TAMPA ELECTRIC
BIG BENO
4
NEW 475 MW (GROSS)
475 MW (ESC)
COAL
2.35 XS
LIME/LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 2. IX
UNIT 4 AT TAMPA ELECTRIC'S BIG BEND STATION IS A PLANNED DRY BOTTOM PUL-
VERIZED COAL (2.35X S, 10,300 BTU/LB) FIRED UNIT TO BE LOCATED IN TAMPA,
FLORIDA. A CONTRACT HAS BEEN AWARDED TO RESEARCH-COTTRELL FOR A WET LIME/
LIMESTONE SCRUBBING PROCESS. AN ESP WILL PROVIDE PRIMARY PARTICULATE
CONTROL. THE FGD SYSTEM, WHICH WILL REMOVE 90X OF THE FLUE GAS S02, WILL
INCLUDE AN INDIRECT HOT AIR REHEATER LEADING TO A 490 FOOT CONCRETE LINED
STACK. THE UNIT WILL PRODUCE GYPSUM AS A SALEABLE PRODUCT.
STATUS 3
STARTUP 3/85
TENNESSEE VALLEY AUTHORITY
PARADISE
1
RETROFIT 704 MW (GROSS)
704 MW (ESC)
COAL
4.20 XS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 3/82
PARADISE 1 OF TVA IS A 4.2X SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2X EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS 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 SOX SOLIDS LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN MARCH 1982.
TENNESSEE VALLEY AUTHORITY
PARADISE
2
RETROFIT 704 MW (GROSS)
704 MW (ESC)
COAL
4.20 XS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 6/82
PARADISE 2 OF TVA IS A 4.2X SULFUR COAL FIRED UNIT LOCATED IN PARADISE,
KENTUCKY. A CONTRACT HAS BEEN AWARDED TO CHEMICO FOR AN 84.2X EFFICIENT
LIMESTONE FGD SYSTEM TO BE RETROFITTED ON THIS BOILER. SIX VENTURI SCRUB-
BERS AND VENTURI ABSORBER TRAINS 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 80X SOLIDS LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN JUNE 1982.
TENNESSEE VALLEY AUTHORITY
SHAWNEE
10A
RETROFIT 10 MW (GROSS)
10 MW (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 4/72
SHAWNEE 10 OF TVA IS A 2.9X SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PADUCAH, KENTUCKY. MODULE 10A IS A RETROFIT PROTOTYPE LIME/LIMESTONE TCA
SYSTEM SUPPLIED BY THE AIR-CORRECTION DIVISION, UOP. THE SYSTEM UTILIZES
A CHEVRON MIST ELIMINATOR AND A DIRECT COMBUSTION REHEATER, ANO 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 MW (GROSS)
10 MW (ESC)
COAL
2.90 XS BITUMINOUS
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 4/72
SHAWNEE 10 OF TVA IS A 2.9X SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PADUCAH, KENTUCKY. MODULE 10B IS A RETROFIT PROTOTYPE LIME/LIMESTONE VEN-
TURI SCRUBBER/SPRAY TOWER ABSORBER SUPPLIED BY CHEMICO. THE SYSTEM, OPERA-
TIONAL SINCE APRIL 1972, INCLUDES A CHEVRON MIST ELIMINATOR AND A DIRECT
COMBUSTION REHEATER, AND OPERATES IN A CLOSED WATER LOOP. THIS TEST PRO-
GRAM IS FUNDED BY THE EPA WITH TVA AS THE CONSTRUCTOR AND FACILITY OPERA-
TOR. THE BECHTEL CORP. OF SAN FRANCISCO IS THE MAJOR CONTRACTOR, TEST DI-
RECTOR, AND REPORT WRITER.
41
-------
EPA UTILITY FGD SURVEY: OCTOLER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE. VALLEY
WIDOWS CREEK
7
RETROFIT
AUTHORITY
57S m (GROSS)
575 MW (ESC)
COAL
3.70 '/.S BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS Z STARTUP 2/81
WIDOWS CREEK 7 IS A PULVERIZED BITUMINOUS COAL (3.7X S, 11,100 BTU/LB)
FIRED BOILER OF TVA LOCATED IN BRIDGEPORT, ALABAMA. COMBUSTION ENGINEERING
IS PRESENTLY RETROFITTING A LIMESTONE VENTRI ROD SCRUBBER/SPRAY TOMER AB-
SORBER FGD SYSTEM ON THIS UNIT. AN ESP WILL PRECEDE THE SCRUBBING TRAIN,
AND A COMBINATION OF A BULK ENTRAINMENT SEPARATOR, TWO CHEVRON MIST
ELIMINATORS AND A FINNED TUBE REHEATER FOLLOW THE SYSTEM. THE
SCRUBBER SLUDGE WILL BE DISPOSED IN A SLUDGE POND. CONSTRUCTION BEGAN
IN SEPTEMBER 1978, AND START UP IS EXPECTED IN FEBRUARY 1981.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
RETROFIT 550 MW (GROSS)
550 MW (ESC)
COAL
3.70 /S
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: 4.7X
STATUS 1 STARTUP 5/77
WIDOWS CREEK 8 OF TVA IS A BALANCED DRAFT, TANGENTIALLY FIRED COAL (3.7X
S, 10,000 BTU/LB) BOILER IN BRIDGEPORT, ALABAMA. TVA RETROFITTED THIS UNIT
WITH A LIMESTONE FGD SYSTEM (SOX 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
GIBBONS CREEK
1
NEW 443 MW (GROSS)
400 MW (ESC)
COAL
1.06 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 2 STARTUP 1/8E
GIBBONS CREEK 1 OF THE TEXAS MUNICIPAL POWER AGENCY IS A DRY BOTTOM PUL-
VERIZED LIGNITE (1.06X S, 4860 BTU/LB) FIRED UNIT PLANNED FOR LOCATION IN
CARLOS, TEXAS. THE EMISSION CONTROL SYSTEM WILL CONSIST OF A COLD SIDE ESP
FOLLOWED BY THREE SOX 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 HILL BE USED AS STRIP MINE LANDFILL. START UP
IS EXPECTED IN JANUARY 1982.
TEXAS POWER & LIGHT
SANDCW
4
NEW 545 MW (GROSS)
382 MW (ESC)
COAL
1.60 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 12/80
SANDOW 4 IS A PULVERIZED 1.6X SULFUR LIGNITE FIRED BOILER OF TEXAS POWER
AND LIGHT LOCATED IN ROCKDALE, TEXAS. COMBUSTION ENGINEERING HAS SUPPLIED
THREE LIMESTONE SPRAY TOWERS FOR THIS UNIT. A COLD SIDE ESP IS PROVIDING
PRIMARY PARTICULATE CONTROL. A 30X BYPASS REHEAT IS BEING USED, AND THE
OVERALL S02 REMOVAL EFFICIENCY IS 75X. THE SYSTEM OPERATES IN A CLOSED
WATER LOOP, AND THE SLUDGE IS BEING PONDED. OPERATIONS COMMENCED IN
DECEMBER 1980.
TEXAS POWER & LIGHT
TWIN OAKS
1
NEW 750 MW (GROSS)
750 MH (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 8/84
TWIN OAKS 1 IS A 0.70X 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 1984.
TEXAS POWER & LIGHT
TWIN OAKS
2
NEW 750 MVJ (GROSS)
750 MW (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 8/85
TWIN OAKS 2 IS A 0.70X SULFUR LIGNITE FIRED BOILER PLANNED BY TEXAS POWER
AND LIGHT AND ALCOA FOR LOCATION IN BREMOND, TEXAS. A CONTRACT HAS BEEN
AWARDED TO CHEMICO FOR A LIMESTONE FGD SYSTEM ON THIS UNIT. START UP IS
EXPECTED IN AUGUST 1905.
42
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS JTILITIES
FOREST GROVE
1
NEW 750 MW rGROSS)
750 MW (ESC)
COAL
.80 XS LIGNITE
PROCESS NCT SELECTED
VENDOR NOT SELECTED
ENERGY CCNSUMPTION: ****X
STATUS 5 STARTUP 0/87
TEXAS UTILITIES IS PLANNING A LIGNITE (0.8X S, 7000 BTU/LB) FIRED BOILER,
FOREST GROVE 1, WHICH WILL BE LOCATED IN ATHENS, TEXAS. THE UTILITY IS
PRESENTLY REQUESTING BIDS ON AN FGD SYSTEM FOR THIS UNIT. TWO ESP'S WILL
PROVIDE PRIMARY PARTICULATE CONTROL, AND NO STACK GAS REHEAT IS PLANNED.
START UP IS EXPECTED IN LATE 1987.
TEXAS UTILITIES
MARTIN LAKE
1
NEW 793 MW (GROSS)
595 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 4/77
TEXAS UTILITIES' MARTIN LAKE 1 IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUtl, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN SOZ REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN APRIL 1977.
TEXAS 'JTILITIES
MARTIN LAKE
2
NEW 793 MW (GROSS)
595 MW (ESC)
COAL
.90 /.S LIGNITE
LIMESTCNE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 5/78
TEXAS UTILITIES' MARTIN LAKE 2 IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SFRAY
TOWER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS TS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.*•,.. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLVASH STABILIZED AND DISPOSED IN AN CN-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN MAY 1978.
TEXAS UTILITIES
MARTIN uAKE
3
NEW 793 MW (GROSS)
595 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 2/79
TEXAS UTILITIES' MARTIN LAKE 3 IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOWER ABSORBERS iffllCH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN S02 REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING WASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED WATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN FEBRUARY 1979.
TEXAS UTILITIES
MARTIN LAKE
4
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****x
STATUS 3 STARTUP 0/85
MARTIN LAKE 4 OF TEXAS UTILITIES IS A LIGNITE (0.9X S, 7380 BTU/LB) FIRED
BOILER UNDER CONSTRUCTION IN TATUM, TEXAS. A CONTRACT FOR A LIMESTONE FGD
SYSTEM FOR THIS UNIT HAS BEEN AWARDED TO RESEARCH COTTRELL. CONSTRUCTION
HAS NOT YET BEGUN ON THE FGD SYSTEM. FGD START UP IS EXPECTED IN 1985 OR
1986.
TEXAS UTILITIES
MILL CREEK
1
NEW 750 MW (GROSS)
750 NW (ESC)
COAL
***** XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/85
MILL CREEK 1 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY WILL INCLUDE AN FGD SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE PROCESS TYPE OR
VENDOR. ESP'S WILL PROVIDE PRIMARY PARTICLE CONTROL. START UP IS
EXPECTED IN 1985.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
MILL CREEK
2
NEW 750 MW (GROSS)
750 MW (ESC)
COAL
***** 7.5 LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6 STARTUP 0/86
MILL CREEK 2 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY WILL INCLUDE AN FGD SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE PROCESS TYPE OR
VENDOR. ESP'S WILL PROVIDE PRIMARY PARTICLE CONTROL. START UP IS
EXPECTED IN 1986.
TEXAS UTILITIES
MONTICELLO
3
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
1.50 7.S LIGNITE
LIMESTONE
CHEMICO DTVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/78
MONTICELLO 3 OF TEXAS UTILITIES IS A LIGNITE (1.5X S, 7000 BTU/LB) FIRED
UNIT IN MT. PLEASANT, TEXAS. THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS
OF TWO COLD SIDE ESP'S FOLLOWED BY THREE CHEMICO LIMESTONE SPRAY TOWERS
(74X DESIGN S02 REMOVAL EFFICIENCY), ONE HORIZONTAL CHEVRON MIST ELIMINA-
TOR/MODULE, AND AN INDIRECT HOT AIR REHEATER. THE WATER LOOP IS CLOSED,
AND THE FLYASH STABILIZED SLUDGE IS DISPOSED IN AN ON SITE LANDFILL. THIS
SYSTEM HAS BEEN OPERATIONAL SINCE MAY 1978.
TUCSON ELECTRIC POWER
SPRINGERVILLE
1
NEW 370 MW (GROSS)
370 MM (ESC)
COAL
.61 7.5 SUBBITUMINOUS
LIME/S?RAY DRYING
JOY MF.VNIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 1/85
TUCSON ELECTRIC POWER WILL 3E BUILDING TWO NEW UNITS IN SPRINGERVILLE,
4RIZONA, SFRINGERVILLE 1 AND 2. THE UNITS WILL FIRE PULVERIZED SUBBITU-
MINOUS COAL (0.53-0.69X S AND 8500-8900 BTU/LB). A CONTRACT HAS BEEN
AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM WILL
BE DESIGNED TO ACCOMODATE A REHEATER (SHOULD ONE BE REQUIRED) AND WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. STARTUP IS SCHEDULED FOR JANUARY 1985.
TUCSON ELECTRIC POWER
SPRINGcRVILLE
2
NEW 370 MW (GROSS)
370 MW (ESC)
COAL
.61 ::s SUBBITUMINOUS
LIME/SKRAY DRYING
JOY MF(VNIRO ATOMIZER
ENERGY CONSUMPTION: ****x
STATUS 3 STARTUP 3/87
TUCSON GAS AND ELECTRIC WILL BE BUILDING TWO NEW UNITS IN SPRINGERVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2. THE UNITS WILL FIRE PULVERIZED SUBBITU-
MINOUS COAL (0.53-0.69X S AND 8500-8900 BTU/LB). A CONTRACT HAS BEEN
AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM WILL
BE DESIGNED TO ACCOMODATE A REHEATER (SHOULD ONE BE REQUIRED) AND WILL
OPERATE IN A CLOSED WATER LOOP. CLEANED FLUE GAS WILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. STARTUP IS SCHEDULED FOR MARCH 1987.
UNITED POWER ASSOCIATION
STANTON
1A
NEW 60 MW (GROSS)
50 MM (ESC)
COAL
.77 X5 LIGNITE
LIME/SPRAY DRYING
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ****X
STANTON 1A OF THE UNITED POWER ASSOCIATION IS A PULVERIZED COAL (0.77X S,
7000 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN STANTON, NORTH DAKOTA.
A CONTRACT HAS BEEN AWARDED TO KOMLINE AND SANDERSON FOR A LIME SPRAY
DRYER. A FABRIC FILTER SUPPLIED BY RESEARCH COTTRELL WILL BE DESIGNED
TO REMOVE 99X OF THE PARTICULATE. THE SYSTEM WILL OPERATE IN AN OPEN
LOOP MODE WITH SLUDGE DISPOSAL TO BE IN A CLAY LINED SETTLING POND.
OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1982.
STATUS 2
STARTUP 6/82
UTAH POWER & LIGHT
HUNTER
1
NEW 400 MW (GROSS)
360 MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 1 STARTUP 5/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.55X S, 12,500 BTU/LB) FIRED
UNIT IN CASTLEDALE, UTAH. CHEMICO SUPPLIED A PEBBLE LIME WET SCRUBBING
SYSTEM WHICH BECAME OPERATIONAL IN MAY 1979. THE SCRUBBING SYSTEM IS DE-
SIGNED TO OPERATE IN AN OPEN WATER LOOP WITH AN S02 REMOVAL EFFICIENCY OF
SOX. PRIMARY PARTICULATE CONTROL IS PROVIDED BY AN UPSTREAM ESP, AND STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE IS FLYASH STABILIZED AND DIS-
POSED ON-SITE.
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
UTAH POWER & LIGHT
HUNTER
2
NEW 400 MM (GROSS)
360 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) FIRED
UNIT LOCATED IN CASTLEDALE, UTAH. FOR EMISSION CONTROL, CHEMICO SUPPLIED
A PEBBLE LIME WET SCRUBBING SYSTEM DESIGNED TO OPERATE IN AN OPEN WATER
LOOP WITH AN S02 REMOVAL EFFICIENCY OF SOX. AN UPSTREAM ESP PROVIDES
PRIMARY PARTICLE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT.
THE SLUDGE IS FLYASH STABILIZED AND DISPOSED OF ON-SITE. START UP OF BOTH
THE BOILER AND FGD SYSTEM TOOK PLACE IN JUNE 1980.
UTAH POWER 8 LIGHT
HUNTER
3
NEW 400 MW (GROSS)
400 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/83
UTAH POWER AND LIGHT HAS PLANS FOR TKO NEW UNITS, HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEDALE, UTAH. A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIMESTONE, NONREGEN'ERABLE FGD UNIT FOR EMISSION CONTROL. THE
PULVERIZED COAL FIRED UNIT (0.55X S, 12,500 BTU/LB) IS TO BEGIN OPERATIONS
IN JUNE 1983.
UTAH POWER & LIGHT
HUNTER
4
NEW 400 MW (GROSS)
400 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 3 STARTUP 6/85
UTAH POWER AND LIGHT HAS PLANS FOR TWO NEW UNITS, HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEDALE, UTAH. A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIMESTONE, NONREGENERABLE FGD UNIT FOR EMISSION CONTROL. THE
PULVERIZED COAL FIRED UNIT (0.55X S, 12,500 BTU/LB) IS TO BEGIN OPERATIONS
IN JUNE 1985.
UTAH POWi.R & LIGHT
HUNTIN3TON
1
NEW 430 MW (GROSS)
366 MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 5/78
1UNTINGTON 1 OF UTAH POWER IS A TANGENTIALLY FIRED PULVERIZED COAL (0.55X
3, 12,500 BTU/LB) BOILER IN PRICE, UTAH. A COLD SIDE ESP TREATS 1,742,000
<\CFM OF FLUE GAS AND IS FOLLOWED BY A CHEMICO LIME FGD SYSTEM CONSISTING
OF FOUR SPRAY TOWERS (SOX DESIGN EFFICIENCY). ONE FOUR PASS CHEVRON/MODULE
PROVIDES MIST ELIMINATION, AND A COMBINATION OF A STEAM TUBE AND 10-20X
BYPASS REHEATERS BOOST THE GAS TEMPERATURE 45-50 DEG F. THE SYSTEM OPER-
ATES IN A CLOSED WATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS TRUCKED
TO AN ON-SITE LANDFILL. THE SYSTEM INCLUDES A 600 FOOT ACID BRICK LINED
STACK, AND HAS BEEN OPERATIONAL SINCE MAY 1978.
UTAH F3WER & LIGHT
NAUGHTON
3
RETROFIT 330 MW (GROSS)
330 MW (ESC)
COAL
.55 XS SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 1.5X
STATUS 2 STARTUP 6/81
NAUGHTON 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (.5X S, 9500
BTU/LB) FIRED BOILER LOCATED IN KEMMERER, WYOMING. THE BOILER SUPPLIES
1,500,000 ACFM OF FLUE GAS TO AN ESP FOR PARTICULATE CONTROL. THE UNIT IS
CURRENTLY BEING RETROFITTED WITH A UOP WET SODA ASH FGD SYSTEM FOR S02
CONTROL. THE FGD SYSTEM IS DESIGNED TO REMOVE 70X OF THE S02 BEFORE THE
FLUE GAS EXITS OUT A 475 FOOT STACK. INITIAL STARTUP IS SCHEDULED FOR
JUNE 1981.
WASHINGTON WATER POWER
CRESTON COAL
1
NEW 570 MW (GROSS)
570 MW (ESC)
COAL
***** X:>
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/87
WASHINGTON WATER POWER HAS PLANS FOR A NEW UNIT, CRESTON COAL 1, TO BE
LOCATED IN CRESTON, WASHINGTON. THE COAL FIRED BOILER WILL HAVE A GROSS
GENERATING CAPACITY OF 570 MW AND WILL UTILIZE A WET LIMESTONE FGD SYSTEM
FOR CONTROL OF SOE EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE
IN 1987.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
WEST PENN POWER
MITCHELL
33
RETROFIT 300 MW (GROSS)
300 MM (ESC)
COAL
2.80 XS BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: l.OX
STATUS 3 STARTUP 8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POWER STATION IN COURTNEYt
PENNSYLVANIA IS A 2.8X SULFUR COAL FIRED BOILER. A CONTRACT WAS
AWARDED TO CHEMICO FOR A LIME SCRUBBING PROCESS. S02 REMOVAL
EFFICIENCY WILL BE 95X. START UP IS PLANNED FOR AUGUST 1982.
WEST TEXAS UTILITIES
OKLAUNION
1
NEW 720 MW (GROSS)
720 MH (ESC)
COAL
.34 XS SUBBITUMIHOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****•/.
STATUS 5 STARTUP 12/86
WEST TEXAS UTILITIES HAS PLANS TO BUILD TWO PULVERIZED COAL FIRED BOILERS
TO BE LOCATED NEAR OKLAUNION, TEXAS. THE UTILITY IS REQUESTING BIDS FOR
AN FGD SYSTEM FOR EMISSION CONTROL FROM THE 720 MW UNIT. THE OKLAUNION 1
PLANT IS SCHEDULED TO COMMENCE OPERATIONS IN 1986.
WEST TEXAS UTILITIES
OKLAUNION
2
NEW 720 MW (GROSS)
720 MW (ESC)
COAL
.34 XS SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/90
WEST TEXAS UTILITIES HAS PLANS TO BUILD TWO PULVERIZED COAL FIRED BOILERS
TO BE LOCATED NEAR OKLAUHION, TEXAS. THE UTILITY WILL INCLUDE AN FGD SYS-
TEM FOR EMISSION CONTROL FROM THE 720 MW UNIT. THE OKLAUNION 2 PLANT IS
SCHEDULED TO COMMENCE OPERATIONS IN 1990.
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
COMPANY NAME
ALABAMA ELECTRIC COOP
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
ATLANTIC CITY ELECTRIC
BASIN ELECTRIC POHER COOP
BIG RIVERS ELECTRIC
CAJUN ELECTRIC POHER COOP
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CEN'-RAL MAINE POWER
CENTRAL PO'JER & LIGHT
CINCINNATI GAS 8 ELECTRIC
COLORADO UTE ELECTRIC ASSN
COLUMBUS 8 SOUTHERN OHIO ELEC
COMi"ON!,'EALTH EDISON
COOPERATIVE POWER ASSOCIATION
DELKARVA POWER & LIGHT
DESERET GEN & TRANS COOP
DUQUHSNE LIGHT
EAST KENTUCKY POWER COOP
FLORIDA POUER & LIGHT
GENERAL PUBLIC UTILITIES
GRAN!) HAVEN BRD OF LIGHT & PWR
GULF POWER
HOOSCER ENERGY
HOUSTON LIGHTING & POWER
INDIANAPOLIS POWER & LIGHT
IOW.\ ELECTRIC LIGHT & PWR
JACKSONVILLE ELEC AUTHORITY
KANSAS CITY POWER & LIGHT
KANSAS POHER & LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LANSING BOARD OF WATER & LIGHT
LOS ANGELES DEPT OF WTR & PWR
LOUISVILLE GAS & ELECTRIC
LOWER COLORADO RIVER AUTH
MARQUETTE BOARD OF LIGHT & PKR
MICHIGAN SO CENTRAL FWR AGENCY
MIDDLE SOUTH UTILITIES
MINNESOTA POWER & LIGHT
MINMKOTA POWER COOPERATIVE
MONONGAHELA POHER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
MUSCATINE POWER & WATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POWER
NEW YORK STATE ELEC & GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
PACIFIC GAS £ ELECTRIC
PACIFIC POWER & LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC G & T COOP
PLATTE RIVER POWER AUTHORITY
PUBLIC SERVICE INDIANA
NO.
2
2
8
1
1
5
4
6
2
i
i
i
z
3
4
1
2
4
2
2
3
2
5
1
1
2
3
5
1
2
3
4
3
1
1
4
10
1
1
1
6
1
1
2
4
1
1
1
10
1
1
3
6
2
4
3
3
1
1
1
MW
358.
196.
2598.
670.
330.
2590.
1364.
3240.
866.
617.
600.
720.
1300.
1294.
1572.
450.
654.
730.
820.
918.
1800.
1600.
3190.
65.
20.
882.
1992.
3012.
720.
1200.
1000.
1575.
1364.
364.
160.
3280.
3554.
435.
31.
55.
5340.
475.
185.
1236.
2120.
440.
166.
650.
3215.
625.
100.
957.
3310.
1600.
2200.
2751.
724.
233.
279.
650.
OPERATIONAL
NO.
2
2
5
0
0
1
2
0
1
1
0
0
0
2
2
1
2
3
0
2
0
0
0
0
1
0
0
1
0
0
3
4
1
0
0
0
6
0
0
0
0
1
1
2
2
0
0
0
3
0
0
1
3
0
1
3
0
0
0
0
MW
358.
196.
962.
0.
0.
570.
484.
0.
416.
617.
0.
0.
0.
847.
822.
450.
654.
180.
0.
918.
0.
0.
0.
0.
20.
0.
0.
532.
0.
0.
1000.
1575.
64.
0.
0.
0.
1559.
0.
0.
0.
0.
475.
185.
1236.
720.
0.
0.
0.
375.
0.
0.
115.
1590.
0.
550.
2751.
0.
0.
0.
0.
CONSTRUCTION CONTRACT
AWARDED
NO.
0
0
1
1
0
3
0
0
0
0
0
0
1
0
0
0
0
0
0
0
1
0
0
1
0
2
1
1
0
0
0
0
0
1
0
0
2
0
0
1
0
0
0
0
2
1
0
0
0
0
1
0
0
0
0
0
3
0
0
1
MW
0.
0.
126.
670.
0.
1580.
0.
0.
0.
0.
0.
0.
650.
0.
0.
0.
0.
0.
0.
0.
500.
0.
0.
65.
0.
882.
492.
530.
0.
0.
0.
0.
0.
364.
0.
0.
845.
0.
0.
55.
0.
0.
0.
0.
1400.
440.
0.
0.
0.
0.
100.
0.
0.
0.
0.
0.
724.
0.
0.
650.
NO.
0
0
2
0
0
0
2
0
0
0
0
0
0
1
0
0
0
0
1
0
0
0
0
0
0
0
2
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
0
1
0
0
0
0
2
0
0
0
0
0
1
1
0
MW
0.
0.
1510.
0.
0.
0.
880.
0.
0.
0.
0.
0.
0.
447.
0.
0.
0.
0.
410.
0.
0.
0.
0.
0.
0.
0.
1500.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
31.
0.
0.
0.
0.
0.
0.
0.
166.
0.
0.
0.
0.
842.
0,.
0.
0.
0.
0.
233.
279.
0.
PLANNED
NO.
0
0
0
0
1
1
0
6
1
0
1
1
1
0
2
0
0
1
1
0
2
2
5
0
0
0
0
3
1
2
0
0
2
0
1
4
2
1
0
0
6
0
0
0
0
0
0
1
7
1
0
0
3
2
3
0
0
0
0
0
MW
0.
0.
0.
0.
330.
440.
0.
3240.
450.
0.
600.
720.
650.
0.
750.
0.
0.
550.
410.
0.
13CO.
1600.
3190.
0.
0.
0.
0.
1950.
720.
1200.
0.
0.
1300.
0.
160.
3280.
1150.
435.
0.
0.
5340.
0.
0.
0.
0.
0.
0.
650.
2840.
625.
0.
0.
1720.
1600.
1650.
0.
0.
0.
0.
0.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED, REQUESTING/EVALUATING BIDS,
AND CONSIDERING ONLY FGD SYSTEMS
657
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
COMPANY NAME
PUB '.1C SERVICE OF NEW MEXICO
PWR AUTHORITY OF STATE OF NY
SALT RIVER PROJECT
SAM MIGUEL ELECTRIC COOP
SEM.'CNOLE ELECTRIC
SIK'iSTPN BSD OF MUNICIPAL U'lL
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS & ELEC
SOUTHWESTERN ELECTRIC POWER
SOYUNJ POWER COOP
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT & PWR
ST. JOE ZINC
SUNF LOWER ELECTRIC COOP
TAMF'A ELECTRIC
TEHKESSEE VALLEY AUTHORITY
TEX^S MUNICIPAL POWER AGENCY
TEX/S POWER & LIGHT
TEXAS UTILITIES
TUC5.0N ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER & LIGHT
WASHNGTON WATER POWER
NEST PENN POWER
WEST TEXAS UTILITIES
NO.
4
I
3
1
Z
1
5
Z
Z
1
3
1
1
1
1
1
1
6
1
3
8
2
1
6
1
1
Z
MW
1779.
700.
840.
400.
1240.
235.
1700.
248.
473.
265.
2160.
500.
194.
205.
60.
347.
475.
2553.
400.
1882.
5585.
740.
50.
2216.
570.
3! . .
1440.
OPERATIONAL
NO.
3
0
2
0
0
0
2
2
1
1
0
0
1
1
1
0
0
3
0
1
4
0
0
3
0
0
0
MW
1245.
0.
560.
0.
0.
0.
420.
248.
173.
265.
0.
0.
194.
205.
60.
0.
0.
570.
0.
382.
2585.
0.
0.
1086.
0.
0.
0.
CONSTRUCTION CONTRACT
AWARDED
NO.
1
0
0
1
0
1
1
0
0
0
0
0
0
0
0
0
0
3
1
0
0
0
1
1
0
0
0
MW
534.
0.
0.
400.
0.
235.
280.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1983.
400.
0.
0.
0.
50.
330.
0.
0.
0.
NO.
0
0
0
0
2
0
2
0
0
0
2
0
0
0
0
1
1
0
0
2
1
2
0
2
0
1
0
MW
0.
0.
0.
0.
1240.
0.
1000.
0.
0.
0.
1440.
0.
0.
0.
0.
347.
475.
0.
0.
1500.
750.
740.
0.
800.
0.
300.
0.
PLANNED
NO.
0
1
1
0
0
0
0
0
1
0
1
1
0
0
0
0
0
0
0
0
3
0
0
0
1
0
2
MW
0.
700.
280.
0.
0.
0.
0.
0.
300.
0.
720.
500.
0.
0.
0.
0.
0.
0.
0.
0.
2250.
0.
0.
0.
570.
0.
1440.
TOTALS
223 102999.
84 28214.
34 14285.
30 14890.
75 45610.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED, REQUESTING/EVALUATING BIDS,
AND CONSIDERING ONLY FGD SYSTEMS
658
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 5
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
CTAT! 1C
TOTAL
SYSTEM SUPPLIER/PROCESS
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTONE
SODIUM CARBONATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK & WILCOX
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
BUELL DIVISION, ENVIRO'ECH
DUAL ALKALI
vIME
TOTAL -
C1EMICO DIVISION, ENVIROTECH
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LIMESTONE
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
TOTAL -
COMBUSTION EQUIP ASSOCIATES
DUAL ALKALI
DUAL ALKALI/LIMESTONE
LIME
LIME/ALKALINE FLYASH
SODIUM CARBONATE
TOTAL -
DAVY MCKEE
WELLMAN LORD
TOTAL -
ENVIRONEERING, RILEY STOKER
LIMESTONE
TOTAL -
FMC
DUAL ALKALI
TOTAL -
NO.
2
5
I
2
10
6
1
7
4
8
2
14
1
1
2
8
8
3
1
20
6
11
Z
2
21
1
1
1
5
3
11
8
8
3
3
3
3
MM
822.
2616.
10.
880.
4328.
1673.
280.
1953.
1951.
2467.
1017.
5435.
617.
31.
648.
4138.
5000.
579.
10.
9727.
1160.
5075.
1480.
654.
8369.
299.
20.
500.
2305.
375.
3499.
2074.
2074.
664.
664.
1107.
1107.
OPERATIONAL
NO.
2
3
1
1
7
5
0
5
2
4
0
6
1
0
1
7
1
3
1
12
5
5
2
2
14
1
1
0
3
3
8
7
7
3
3
1
1
MW
822.
1176.
10.
550.
2558.
1178.
0.
1178.
1236.
1413.
0.
2V»9.
617.
0.
617.
3838.
800.
579.
10.
5227.
810.
1957.
1480.
654.
4901.
299.
20.
0.
905.
375.
1599.
1540.
1540.
664.
664.
265.
265.
CONSTRUCTION
NO.
0
0
0
1
1
1
1
2
2
4
1
7
0
0
0
0
3
0
0
3
1
2
0
0
3
0
0
1
2
0
3
1
1
0
0
0
0
MW
0.
0.
0.
330.
330.
495.
280.
775.
715.
1054.
570.
2339.
0.
0.
0.
0.
1900.
0.
0.
1900.
350.
975.
0.
0.
1325.
0.
0.
500.
1400.
0.
1900.
534.
534.
0.
0.
0.
0.
CONTRACT
AWARDED
NO.
0
2
0
0
2
0
0
0
0
0
1
1
0
1
1
1
4
0
0
5
0
4
0
0
4
0
0
0
0
0
0
0
0
0
0
2
2
MW
0.
1440.
0.
0.
1440.
0.
0.
0.
0.
0.
447.
447.
0.
31.
31.
300.
2300.
0.
0.
2600.
0.
2143.
0.
0.
2143.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
842.
842.
659
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 5
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
SYSTEM SUPPLIER/PROCESS
JOY MF6/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
MORRISON & 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
LIME/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY AUTHOPITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
WHEELABRATOR-FRYE/R . I .
SODIUM CARBONATE/SPRAY DRYING
TOTAL -
NO.
6
6
2
Z
I
I
a
I
<)
1
6
7
14
1
1
16
1
1
1
1
Z
3
5
1
1
MW
1916.
1916.
882.
882.
60.
60.
3445.
475.
3920.
917.
2760.
3677.
5281.
475.
50.
5806.
100.
100.
550.
550.
1510.
724.
2234.
440.
440.
NO.
1
1
0
0
1
1
4
1
5
1
2
3
9
0
0
9
0
0
1
1
0
0
0
0
0
MM
110.
110.
0.
0.
60.
60.
1205.
475.
1680.
917.
560.
1477.
3139.
0.
0.
3139.
0.
0.
550.
550.
0.
0.
0.
0.
0.
NO.
1
1
2
2
0
0
0
0
0
0
2
2
3
0
1
4
1
1
0
0
0
3
3
1
1
MM
440.
440.
882.
882.
0.
0.
0.
0.
0.
0.
1320.
1320.
1226.
0.
50.
1276.
100.
100.
0.
0.
0.
724.
724.
440.
440.
NO.
4
4
0
0
0
0
4
0
4
0
2
2
2
1
0
3
0
0
0
0
2
0
2
0
0
MW
1366.
1366.
0.
0.
0.
0.
2240.
0.
2240.
0.
880.
880.
916.
475.
0.
1391.
0.
0.
0.
0.
1510.
0.
1510.
0.
0.
TOTAL -
148 57389.
84 28214.
34 14285.
30 14890.
660
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 6
SUMMARY OF FGD SYSTEMS BY PROCESS
TOTAL
OPERATIONAL
CONSTRUCTION CONTRACT
PLANNED
AWARDED
PROCESS
AQUEOUS CARBONATE/SPRAY DRYING
CITRATE
LIME
LIMESTONE
LIME/LIMESTONE
MAGNESIUM OXIDE
WELLMAN LORD
SUBTOTAL - SALEABLE PRODUCT
DUAL ALKALI
DUAL ALKALI/ LIMESTONE
LIME
LIMESTONE
LIMESTONE/ALKALINE FLY ASH
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIME/SPRAY DRYING
PROCESS NOT SELECTED
SODIUM CARBONATE
SODIUM CARBONATE/SPRAY DRYING
SUBTOTAL - THROWAWAY PRODUCT
NO.
1
1
1
1
1
3
8
16
5
1
37
78
2
11
2
9
12
9
1
167
MW
100.
60.
65.
166.
475.
724.
2074.
3664.
2023.
20.
17637.
36189.
1480.
4013.
20.
2983.
6650.
3155.
440.
74610.
NO.
0
1
0
0
0
0
7
8
3
1
22
32
2
9
2
1
0
4
0
76
MW
0.
60.
0.
0.
0.
0.
1540.
1600.
1181.
20.
8801.
11464.
1480.
2613.
20.
110.
0.
925.
0.
26614.
NO.
1
0
1
0
0
3
1
6
0
0
4
17
0
2
0
3
0
1
1
28
MM
100.
0.
65.
0.
0.
724.
534.
1423.
0.
0.
1995.
7637.
0.
1400.
0.
1060.
0.
330.
440.
12862.
NO.
0
0
0
1
1
0
0
2
2
0
4
17
0
0
0
5
0
0
0
28
MW
0.
0.
0.
166.
475.
0.
0.
641.
842.
0.
1841.
9753.
0.
0.
0.
1813.
0.
0.
0.
14249.
NO.
0
0
0
0
0
0
0
0
0
0
7
12
0
0
0
0
12
4
0
35
MW
0.
0.
0.
0.
0.
0.
0.
0.
0.
0,
5000.
7335.
0.
0.
0.
0.
6650.
1900.
0.
20885.
TOTALS
SALEABLE PRODUCT PROCESS
7. OF TOTAL MW
183 78274.
84 28214.
34 14285.
5 6 10
NOTE: 40 UNITS ARE UNDECIDED AND ARE NOT INCLUDED IN THIS TABLE
30 14890.
35 20885.
661
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 7
SUMMARY OF OPERATIONAL F6D SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CITRATE
G.F. ME ATOM
DUAL ALKALI
NEWTON
CANE RUN
A.B. BROWN
DUAL ALKALI/LIMESTONE
SCHOLZ
LIME
CONESVILLE
CONESVILLE
CANE RUN
GREEN
GREEN
GREEN RIVER
MILL CREEK
PLEASANTS
PLEASANTS
BRUCE MANSFIELD
BRUCE MANSFIELD
ELRAMA
HUNTER
HUNTER
HUNTINGTON
PHILLIPS
CANE RUN
HAWTHORN
HAWTHORN
MILL CREEK
PADDY'S RUN
BRUCE MANSFIELD
LIMESTONE
PETERSBURG
POWERTON
SOUTHWEST
LA CYGNE
MARION
WINY AH
WINYAH
MONTICELLO
JEFFREY
JEFFREY
LAWRENCE
LAWRENCE
SANDOW
DUCK CREEK
R.D. MORROW, SR.
R.D. MORROW, SR.
CRAIG
UNIT NO.
1
1
6
1
1
5
6
4
1
2
1-3
3
1
Z
1
Z
1-4
1
2
1
1-6
5
3
4
1
6
3
3
51
1
1
4
2
3
3
1
Z
4
5
4
1
1
Z
I
CAPACITY
MW
60.
60.
617.
299.
265.
1181.
20.
20.
411.
411.
188.
242.
242.
64.
442.
618.
618.
917.
917.
510.
360.
360.
366.
408.
200.
90.
90.
358.
72.
917.
8801.
532.
450.
194.
820.
173.
140.
280.
800.
540.
490.
125.
420.
382.
416.
124.
124.
447.
INITIAL
STARTUP
11/79
9/79
4/79
3/79
8/80
1/77
6/78
8/76
12/79
11/80
9/75
8/78
3/79
10/80
12/75
7/77
10/75
5/79
6/80
5/78
7/73
12/77
11/72
8/72
12/80
4/73
6/80
12/77
4/80
4/77
2/73
5/79
7/77
5/80
5/78
8/78
4/80
1/77
4/78
12/80
7/76
8/78
6/79
10/80
COMMERCIAL
STARTUP
1/80
12/79
O/ 0
4/79
O/ 0
2/77
7/78
8/77
12/79
12/80
6/76
3/79
3/79
0/81
6/76
10/77
10/75
5/79
6/80
5/78
6/74
7/78
O/ 0
O/ 0
4/81
O/ 0
6/80
12/77
6/81
9/77
6/73
6/79
O/ 0
6/80
10/78
O/ 0
1/80
O/ 0
O/ 0
1/81
8/78
8/78
6/79
8/80
THIS .TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANtES CAN BE FOUND IN SECTION 1.
662
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CRAIG
TOMBIGBEE
TOMBIGBEE
CORONADO
CORONADO
APACHE
APACHE
CHOLLA
CHOLLA
DALLMAN
LARAMIE RIVER
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
WIDOWS CREEK
LIMESTONE/ALKALINE FLY ASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLYASH
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
COAL CREEK
COAL CREEK
COLSTRIP
COLSTRIP
MILTON R. YOUNG
CLAY BOSWELL
LIME/LIMESTONE
SHAWNEE
SHAWNEE
LIME/SPRAY DRYING
RIVERSIDE
SODIUM CARBONATE
JIM BRIDGER
REID GARDNER
REID GARDNER
REID GARDNER
HELLMAN LORD
DEAN H. MITCHELL
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
SAN JUAN
UNIT NO.
Z
Z
3
1
2
Z
3
1
2
3
I
1
2
3
8
1
2
1
2
3
1
2
1
2
2
4
IDA
10B
6,7
4
1
2
3
11
1
2
3
1
CAPACITY
MM
400.
179.
179.
280.
280.
98.
98.
119.
264.
205.
570.
595.
595.
595.
550.
11464.
740.
740.
1480.
175.
175.
229.
327.
327.
360.
360.
185.
475.
2613.
10.
10.
20.
110.
110.
550.
125.
125.
125.
925.
115.
60.
60.
60.
361.
INITIAL
STARTUP
12/79
9/78
6/79
11/79
7/80
8/78
6/79
10/73
4/78
10/80
7/80
4/77
5/78
2/79
5/77
3/76
3/77
11/79
11/79
11/79
7/79
7/80
9/75
5/76
9/77
4/80
4/72
4/72
11/80
9/79
3/74
4/74
7/76
7/76
5/80
5/80
5/80
4/78
COMMERCIAL
STARTUP
5/80
9/78
6/79
12/79
10/81
1/79
4/79
12/73
6/78
1/81
7/80
10/78
O/ 0
O/ 0
1/78
5/76
4/77
O/ 0
O/ 0
O/ 0
8/79
9/80
11/75
10/76
6/78
O/ 0
O/ 0
O/ 0
12/80
2/80
4/74
O/ 0
7/76
6/77
5/80
5/80
5/80
4/78
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
663
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/ CAPACITY INITIAL COMMERCIAL
UNIT NAME UNIT NO. MW STARTUP STARTUP
SAN JUAN 2 350. 8/78 8/78
SAN JUAN 3 534. 12/79 O/ 0
1540.
TOTAL 28214.
664
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT N«1E
CITRATE
6.F. WEATON
DUAL A IK A LI
NEWTON
CANE RUN
A.B. BF'OWN
DUAL AU
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
PROCESS/
UNIT NAME
CHOLLA
DALLMAU
LARAMI? RIVER
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
WIDOWS CREEK
UNIT NO
2
3
1
1
Z
3
8
STABILIZED UNSTABILIZED TYPE DISPOSITION
LANDFILL
LANDFILL
LANDFILL
LANDFILL
UNLINED POND
LANDFILL
POND
LIMESTONE/ALKALINE FLYASH
SHERBUHNE 1 LINED POND
SHERBURNE 2 LINED POND
LIME/A -KAIINE FLY ASH
FOUR CORf-'^RS 1
FOUR CORKERS 2
FOUR CORNERS 3
COAL C(?EE< 1 LINED POND
COAL CP2EX 2 LINED POND
COLSTRIP 1
COLSTRIP 2
MILTON R. YOUNG 2
CLAY BCSWELL $
LIME/LIMESTONE
SHAHNEE: IDA
SHAWNEL 10B
LIME/SPRAY DRYING
RIVERSIDE 6,7 LANDFILL
SODIUM CARBONATE
JIM BRIDGER 4
REID GARDNER 1
REID GARDNER 2
REID GARDNER 3
WELLMAN LORD
DEAN H. MITCHELL 11
DELAWARC CITY 1 LINED POND
DELAWARE CITY 2 LINED POND
DELAWARE CITY 3 LINED POND
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
POND
POND
MINEFILL
LINED POND
LINED POND
LINED POND
LINED POND
LINED POND
ELEMENTAL SULFUR
SULFURIC ACID
SULFURIC ACID
SULFURIC ACID
ELEMENTAL SULFUR
ELEMENTAL SULFUR
SULFURIC ACID
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
666
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMBIGBEE Z
ALABAMA ELECTRIC COOP
TOMBIGBEE 3
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARTZONA PUBLIC SERVICE
CHQLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA 2
AR.CZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOJR CORNERS 3
BASIN ELECTRIC POWER COOP
LARAME RIVER 1
BH9 RIVERS ELECTRIC
GRI-3N 1
Bid RIVERS ELECTRIC
GRFEN 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CE11TRAL ILLINOIS PUBLIC SERV
NEUTON 1
COLORADO UTE ELECTRIC ASSN
CR*iIG I
COLORADO UTE ELECTRIC ASSN
CR/IG 2
COLUMBUS ft SOUTHERN OHIO ELEC
CONESVILLE 5
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE 6
COMMONWEALTH EDISON
POW;-:RTON 51
COOPERATIVE POWER ASSOCIATION
COA'. CREEK 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELMARVA POWER & LIGHT
DELAWARE CITY 1
DELMARVA POWER ft LIGHT
DELAWARE CITY 2
NEW OR (
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
:APACITY
MW
179.
179.
98.
98.
119.
26*.
175.
175.
229.
570.
242.
242.
416.
617.
447.
400.
411.
411.
450.
327.
327.
60.
60.
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 FLY ASH
CHEMICO DIVISION, ENVIROTECH
LIME/ALKALINE FLY ASH
CHEMICO DIVISION, ENVIROTECH
LIME/ALKALINE FLY ASH
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
REf,EARCH-COTTRELL
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONS ER ING, RILEY STOKER
DUAL ALKALI
BUELL DIVISION, ENVIROTECH
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/78
11/79
11/79
11/79
7/80
12/79
11/80
7/76
9/79
10/80
12/79
1/77
6/78
4/80
7/79
7/80
5/80
5/80
667
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO
DELMARVA POWER & LIGHT
DELAWARE CITY 3
DUQUESNE LIGHT
ELRAMA 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
GULF POWER
SCHOLZ 1
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
KANSAS CITY POWER 8 LIGHT
HAWTHORN 3
KANSAS CITY POWER & LIGHT
HAWTHORN 4
KANSAS CITY POWER & LIGHT
LA CYGNE 1
KANSAS POWER & LIGHT
JEFFREY 1
KANSAS POWER ft LIGHT
JEFFREY 2
KANSAS POWER & LIGHT
LA-iRENCE 4
KANSAS POWER & LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS & ELECTRIC
CANE 3UN 4
LOUISVILLE GAS & ELECTRIC
CANE RUN 5
LOUISVILLE GAS & ELECTRIC
CAUE RUN 6
LOUISVILLE GAS & ELECTRIC
MI».L CREEK 1
LOUISVILLE GAS & ELECTRIC
MI!.L CREEK 3
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN 6
MINNESOTA POWER & LIGHT
CLAY BOSWELL 4
MINNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONONGAHELA POWER
PLEASANTS 1
MONONGAHELA POWER
NEW OR CAPACITY
. RETROFIT MW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
60.
510.
408.
20.
532.
90.
90.
820.
540.
490.
125.
420.
64.
188.
200.
299.
358.
442.
72.
475.
185.
618.
618.
PROCESS/
SYSTEM SUPPLIER
WELLMAN LORD
DAVY MCKEE
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
DUAL ALKALI/LIMESTONE
COMBUSTION EQUIP ASSOCIATES
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK & WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LII1E
COMBUSTION ENGINEERING
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLY ASH
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLY ASH
COMBUSTION EQUIP ASSOCIATES
LIME
BABCOCK & WILCOX
LIME
START-UP
DATE
5/80
10/75
7/73
8/80
12/77
11/72
8/72
2/73
8/78
4/80
1/77
4/78
9/75
8/76
12/77
4/79
12/80
8/78
4/73
4/80
9/77
3/79
-10/80
BABCOCK ft WILCOX
668
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
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
RIVERSIDE 6,7
NORTHERN STATES POWER
SHERBURNE 1
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER S LIGHT
JIM BRIDGER 4
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PUBLIC SERVICE OF NEW MEXICO
S/N JUAN 1
PU3LIC SERVICE OF NEW MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAS JUAN 3
SALT RIVER PROJECT
CCRONADO 1
SALT RIVER PROJECT
CORONADO 2
SOUT}, CAROLINA PUBLIC SERVI :E
WI,W'.H 2
SO'JTH CAROLINA PUBLIC SERVICE
WINYAH 3
SOUTH MISSISSIPPI ELEC PWR
R.O. MORROW, SR. 1
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR. 2
SOJTHERN ILLINOIS POWER COOP
NEW OR (
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
:APACITY
MW
360.
360.
125.
125.
125.
115.
110.
740.
740.
550.
917.
917.
917.
361.
350.
534.
280.
280.
140.
280.
124.
124.
173.
PROCESS/
SYSTEM SUPPLIER
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
WELLMAN LORD
DAVY MCKEE
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
PULLMAN KELLOGG
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
LIMESTONE
PULLMAN KELLOGG
LIMF.STOHE
PULLMAN KELLOGG
LIMESTONE
BA3COCK * WILCOX
LIMESTONE
BABCOCK & MILCOX
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
START-UP
DATE
9/75
5/76
3/74
4/74
7/76
7/76
11/80
3/76
3/77
9/79
12/75
7/77
6/80
4/78
8/78
12/79
11/79
7/80
7/77
5/80
8/78
6/79
5/79
BABCOCK & WILCOX
669
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME
SOUTHERN INDIANA
A.B. BROWN
SPRINGFIELD CITY
SOUTHWEST
SPRINGFIELD WATER
DALLMAN
ST. JOE ZINC
G.F. WEATON
TENNESSEE VALLEY
SHAWNEE
TENNESSEE VALLEY
SHAWNEE
TENNESSEE VALLEY
WIDOWS CREEK
NEW OR CAPACITY
UNIT NO. RETROFIT MW
GAS & ELEC NEW
1
UTILITIES NEW
1
, LIGHT & PWR NEW
3
RETROFIT
I
AUTHORITY RETROFIT
10A
AUTHORITY RETROFIT
10B
AUTHORITY RETROFIT
8
TEXAS POWER & LIGHT NEW
SANDOW 4
TEXAS UTILITIES
MARTIN LAKE
TEXAS UTILITIES
MARTIN LAKE
TEXAS UTILITIES
MARTIN LAKE
TEXAS UTILITIES
MONTICELLO
NEW
1
NEW
2
NEW
3
NEW
3
UTAH POWER & LIGHT NEW
HUNTER I
UTAH POWER & LIGHT NEW
HUNTER 2
UTAH POWER & LIGHT NEW
HUNTINGTON 1
265.
194.
205.
60.
10.
10.
550.
382.
595.
595.
595.
800.
360.
360.
366.
PROCESS/
SYSTEM SUPPLIER
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
RESEARCH-COTTRELL
CITRATE
MORRISON & KNUDSEN/U.S.B.M.
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
3/79
4/77
10/80
11/79
4/72
4/72
5/77
12/80
4/77
5/78
2/79
5/78
5/79
6/80
5/78
TOTAL
28214.
670
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
CHCLLA ft
ASSOCIATED ELECTRIC COOP
THCMAS HILL 3
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 2
BASIN ELECTRIC POWER COOP
LARAMIE RIVER 3
CINCINNATI GAS & ELECTRIC
EAST BEND 2
EAST KENTUCKY POWER COOP
SPUR LOCK 2
GRAND HAVEN BRD OF LIGHT & PWR
J.B. SIMS 3
HOOSIER ENERGY
MEROM 1
HOOSIER ENERGY
MEROM 2
HOUSTON LIGHTING & POWER
W.A. PARISH 8
INDIANAPOLIS POWER & LIGHT
PETERSBURG 4
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS & ELECTRIC
MILL CREEK 2
LOUISVILLE GAS & ELECTRIC
MILL CREEK 4
MICHIGAN SO CENTRAL PWR AGENCY
PROJECT 1
MONTANA POWER
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
MONTANA-DAKOTA UTILITIES
COYOTE 1
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEY 66
PHILADELPHIA ELECTRIC
CROMBY 1
PHILADELPHIA ELECTRIC
EDDYSTONE 1
PHILADELPHIA ELECTRIC
NEW OR (
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
:APACITY
MW
126.
670.
440.
570.
570.
650.
500.
65.
441.
441.
492.
530.
364.
350.
495.
55.
700.
700.
440.
100.
150.
240.
334.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
PULLMAN KELLOGG
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
BABCOCK & WILCOX
LIME
BABCOCK & WILCOX
LIME
COMBUSTION EQUIP ASSOCIATES
LIME
BABCOCK & WILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
BABCOCK & WILCOX
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIMESTONE
BABCOCK & WILCOX
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE/SPRAY DRYING
WHEELABRATOR-FRYE/R. I.
AQUEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
START-UP
DATE
2/81
1/82
4/83
6/81
10/82
2/81
10/81
6/83
5/82
9/81
11/82
10/84
8/81
12/81
6/82
6/82
0/83
0/84
3/81
4/82
5/83
12/82
12/82
UNITED ENGINEERS
671
-------
EPA UTIIITY FGD SURVEY: OCTOBIR - DECEMBER 1980
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
C01PANY NAME/ NEW OR C
UNIT NAME UNIT NO. RETROFIT
PU3LIC SERVICE INDIANA NEW
61 3SON 5
PU3LIC SERVICE OF NEW MEXICO NEW
SA-J JUAN 4
SA-4 MIGUEL ELECTRIC COOP NEW
SAS MIGUEL 1
SIKESTON BRD OF MUNICIPAL UTIL NEW
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE NEW
WIMYAH 4
TENNESSEE VALLEY AUTHORITY RETROFIT
PARADISE 1
TEKNESSEE VALLEY AUTHORITY RETROFIT
PARADISE 2
TENNESSEE VALLEY AUTHORITY RETROFIT
WIDOWS CREEK 7
TEXAS MUNICIPAL POWER AGENCY NEW
GIBBONS CREEK 1
UNITED POWER ASSOCIATION NEW
STANTON 1A
UTAH POWER & LIGHT RETROFIT
NAUGHTON 3
:APACITY PROCESS/
MW SYSTEM SUPPLIER
650. LIMESTONE
PULLMAN KELLOGG
534. WELLMAN LORD
DAVY MCKEE
400. LIMESTONE
BABCOCK & WILCOX
235. LIMESTONE
BABCOCK & WILCOX
280 . LIMESTONE
AMERICAN AIR FILTER
704. LIMESTONE
CHEMICO DIVISION, ENVIROTECH
704. LIMESTONE
CHEMICO DIVISION, ENVIROTECH
575. LIMESTONE
COMBUSTION ENGINEERING
400. LIMESTONE
COMBUSTION ENGINEERING
50. LIME/SPRAY DRYING
RESEARCH-COTTRELL
330. SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
START-UP
DATE
0/82
6/82
8/81
6/81
7/81
3/82
6/82
2/81
1/82
6/82
6/81
TOTAL
14285.
672
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 11
SUMMARY OF CONTRACT AWARDED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
BIG KIVERS ELECTRIC
D.3. WILSON 1
Bli FIVERS ELECTRIC
D.g. WILSON 2
CO.ORADO UTE ELECTRIC ASSN
CR UG 3
DE3ERET GEN & TRANS COOP
MOON LAKE 1
HOUSTON LIGHTING & POWER
LI 1ESTONE 1
HOUSTON LIGHTING & POWER
LI.1ESTONE 2
MAUQUETTE BOARD OF LIGHT & PWR
SHIRAS 3
MUiCATINE POWER & WATER
MUSCATINE 9
NORTHERN INDIANA PUB SERVICE
SCKAHFER 17
NORFHERN INDIANA PUB SERVICE
SCHAHFER 18
PLAINS ELECTRIC 6 & T COOP
PLAINS ESCALANTE 1
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
SEMINOLE ELECTRIC
SEMINOLE 1
SEMINOLE ELECTRIC
SEMINOLE 2
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
SUNFLOWER ELECTRIC COOP
HOLCOK3 1
TAMPA ELECTRIC
BIG BEND 4
TEXAS POWER & LIGHT
TWIN OAKS 1
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
755.
755.
440.
440.
447.
410.
750.
750.
31.
166.
421.
421.
233.
279.
620.
620.
500.
500.
720.
720.
347.
475.
750.
PROCESS/
SYSTEM SUPPLIER
LIME
UNITED ENGINEERS
LIM£
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIME/SPRAY DRYING
BABCOCK & WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
BUELL DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COTTRELL
DUAL ALKALI
F«C
DUAL ALKALI
FMC
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
0/82
0/82
7/84
1/86
0/82
9/84
12/84
12/85
10/82
9/82
6/83
6/85
12/83
12/83
3/83
3/85
3/85
1/84
3/86
12/84
9/83
3/85
8/84
673
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 11
SUMMARY OF CONTRACT AWARDED FED SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NC
TEXAS POWER & LIGHT
TWIN OAKS 2
TEXAS UTILITIES
MARTIN LAKE 4
TUCSON ELECTRIC POWER
SPRINGERVILLE 1
TUCSON ELECTRIC POWER
SPRINGERVILLE Z
Ul AH POWER & LIGHT
HL'NTER 3
UTAH POWER & LIGHT
HliNTEP 4
WEST PENN POWER
MITCHELL 33
NEW OR CAPACITY PROCESS/
3. RETROFIT MW SYSTEM SUPPLIER
NEW 750. LIMESTONE
CHEMICO DIVISION, ENVIROTECH
NEW 750. LIMESTONE
RESEARCH-COTTRELL
NEW 370. LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
NEW 370. LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
NEW 400. LIMESTONE
CHEMxCO DIVISION, ENVIROTECH
NEW 400. LIMESTONE
CHEHICO DIVISION, ENVIROTECH
RETROFIT 300. LH.E
CH'iMICO DIVISION, ENVIROTECH
START-UP
DATE
8/85
0/85
1/85
3/87
6/83
6/85
8/82
TOTAL
14890.
674
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION IZ
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME
NEW OR CAPACITY PROCESS/
UNIT NO. RETROFIT MW SYSTEM SUPPLIER
START-UP
DATE
LETTER OF INTENT SIGNED
EAST KENTUCKY POWER COOP
J.K. SMITH 1
EAST KENTUCKY POWER COOP
J.K. SMITH 2
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 5
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 6
MIDDLE SOUTH UTILITIES
UNASSIGNED 1
MIDDLE SOUTH UTILITIES
UbASSIGNED 2
MIDDLE SOUTH UTILITIES
WILTON 1
MIDDLE SOUTH UTILITIES
WILTON 2
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
650. PROCESS NOT SELECTED
BABCOCK & WILCOX
650. PROCESS NOT SELECTED
BABCOCK & WILCOX
650. PROCESS NOT SELECTED
COMBUSTION ENGINEERING
650. PROCESS NOT SELECTED
COMBUSTION ENGINEERING
650. PROCESS NOT SELECTED
COMBUSTION ENGINEERING
650. PROCESS NOT SELECTED
COMBUSTION ENGINEERING
650. PROCESS NOT SELECTED
COMBUSTION ENGINEERING
650. PROCESS NOT SELECTED
COMBUSTION ENGINEERING
TOTAL
REQUESTING/EVALU/TING BIDS
BASIN ELECTRIC POWER COOP NEW
ANTELOPE VALLEY 2
CA IUN ELECTRIC POWER COOP NEW
OXBOW 1
CENTRAL ILLINOIS LIGHT NEW
DUCK CREEK 2
DESERET GEN & TRANS COOP NEW
MOON LAKE 2
GENERAL PUBLIC UTILITIES NEW
COAL 1
GENERAL PUBLIC UTILITIES NEW
SEfcARD 7
IOWA ELECTRIC LIGHT & PWR NEW
GUTMRIE CO. 1
LOUISVILLE GAS & ELECTRIC NEW
TRII1BLE COUNTY 1
LOUISVILLE GAS & ELECTRIC NEW
TRIMBLE COUNTY 2
NEVADA POWER NEW
WARNER VALLEY 1
650.
440.
440.
440.
440.
440.
440.
440.
440.
440.
440.
LIME/SPRAY DRYING
VENDOR NOT SELECTED
PROCESS NOT SELECTED
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
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
1/85
1/87
0/90
0/92
0/89
0/93
0/88
0/91
NEVADA POWER
REID GARDNER
NE-J YtiRK STATE
SOMERSET
4
ELEC & GAS
1
NEW
NEW
650.
650.
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
LIMLSTONE
PEABODY PROCESS SYSTEMS
4/83
6/84
10/85
0/85
1/86
0/88
5/91
5/89
11/84
7/85
7/88
6/85
675
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
NEVADA POWER
WARNER VALLEY 2
PACIFIC POWER & LIGHT
JIM BRIDGER 1
PACIFIC POWER & LIGHT
JIM BRIDGER 2
PACIFIC POWER & LIGHT
JIM BRIDGER 3
TEXAS UTILITIES
FOREST GROVE 1
WEST TEXAS UTILITIES
OKLAUNIOM 1
TOTAL
CONSIDERING FGD SYSTE
ATLANTIC CITY ELECTRIC
CUMBERLAND 1
CAJUN ELECTRIC POWER COOP
CHICOT 1
CAJUN ELECTRIC POWER COOP
CHICOT 2
CAJUN ELECTRIC POWER COOP
CHICOT 3
CAJUN ELECTRIC POWER COOP
CHICOT 4
CAJUN ELECTRIC POWER COOP
OX30W 2
CENTRAL MAINE POWER
SEXRS ISLAND 1
CENTRAL POWER 8 LIGHT
COJ.E10 CREEK 2
CINCINNATI GAS 8 ELECTRIC
EA'ST 3END 1
COi.UMBUS 4 SOUTHERN OHIO ELEC
POSTON 5
COt.UMBUS & SOUTHERN OHIO ELEC
POSTON 6
DE!.MARVA POWER & LIGHT
VIENNA 9
FLORIDA POWER & LIGHT
MARTIN 3
FLORIDA POWER & LIGHT
MARTIN 4
GEKERAL PUBLIC UTILITIES
NEW OR
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
;MS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MM
440.
WO.
440.
440.
440.
440.
440.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
START-UP
DATE
6/86
0/88
0/84
0/86
0/87
12/86
1/88
0/86
0/88
0/92
0/94
0/85
1/89
9/86
10/87
8/86
0/89
6/87
0/87
0/89
5/93
VENDOR NOT SELECTED
676
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
GENERAL PUBLIC UTILITIES
COAL 3
GENERAL PUBLIC UTILITIES
COAL 4
INDIANAPOLIS POWER ft LIGHT
PATRIOT 1
INDIANAPOLIS POWER & LIGHT
PATRIOT 2
INDIANAPOLIS POWER ft LIGHT
PATRIOT 3
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RIVER PWR PARK1
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RIVER PWR PARK2
KENTUCKY UTILITIES
HANCOCK 1
KENTUCKY UTILITIES
HANCOCK 2
LANSING BOARD OF WATER « LIGHT
ERICKSON 2
LOS AHGELES DEPT OF WTR ft PWR
INTERMOUNTAIN 1
LOS ANGELES DEPT OF WTR ft PWR
INTERMOUNTAIN 2
LOS ANGELES DEPT OF WTR ft PWR
INTERMOUNTAIN 3
LOS ANGELES DEPT OF WTR ft PWR
INTERMOUNTAIN 4
LOWER COLORADO RIVER AUTH
FAfETTE POWER PROJECT 3
NEBRASKA PUBLIC POWER DISTRICT
F03SIL III 1
NE/ADA POWER
HA3RY ALLEN 1
NEVADA POWER
HA^RY ALLEN 2
NEVADA POWER
HAJRY ALLEN 3
NEVADA POWER
HAHR1 ALLEN 4
NORTHERN STATES POWER
MEfRO COAL 1
NOHTHERN STATES POWER
SHI..RBURNE 3
NORTHERN STATES POWER
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
PROCESS/
SYSTEM SUPPLIER
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
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
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
VEHDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
START-UP
DATE
5/95
5/96
0/87
O/ 0
O/ 0
12/85
6/87
0/88
0/94
1/87
0/86
0/87
0/88
0/89
0/88
3/87
6/86
6/87
6/88
6/89
0/90
0/85
0/91
WISCONSIN COAL
VENDOR NOT SELECTED
677
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 12
SUMMARY OF PLANNED FSD SYSTEMS
COMPANY NAME/
UNIT NAME
PACIFIC GAS 4 ELECTRIC
MONTEZUMA
PACIFIC GAS * ELECTRIC
MCNTEZUMA
PWR AUTHORITY OF STATE
FOSSIL
SALT RIVER PROJECT
CORONADO
UNIT NO.
1
2
OF NY
3
SOUTHERN ILLINOIS POWER COOP
MARION 5
SOUTHWESTERN ELECTRIC
DOLET HILLS
SOY LAND POWER COOP
SOY LAND
TEXAS UTILITIES
MILL CREEK
TEXAS UTILITIES
MILL CREEK
WASHINGTON WATER POWER
CRESTON COAL
WEST TEXAS UTILITIES
OKLAUNION
POWER
2
1
1
2
1
2
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MW
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
330.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
START-UP
DATE
6/94
6/90
<4/87
0/89
0/88
3/88
0/87
0/85
0/86
0/87
0/90
TOTAL
330.
678
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 13
TOTAL FGD UNITS AND CAPACITY (MW) INSTALLED BY YEAR
YEAR
1968
1969
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
UNDEFINED
NEW ON LINE
NO. MW
1
0
9
5
3
7
7
11
14
20
20
13
22
11
12
18
12
15
12
8
4
3
2
2
3
1
1
7
140.
0.
674.
1514.
416.
2182.
2699.
4589.
4973.
6300.
6711.
5261.
9510.
3905.
6971.
10276.
6880.
8920.
6720.
4955.
2610.
2185.
1430.
1515.
1990.
625.
625.
1806.
TERMINATED
NO. MW
0
1
0
1
3
5
4
4
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0.
140.
0.
10.
340.
628.
1014.
2049.
0.
143.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
TOTAL
NO.
1
0
9
13
13
15
18
25
39
57
77
90
112
123
135
153
165
180
192
200
204
207
209
211
214
215
216
ON LINE
MW
140.
0.
674.
2178.
2254.
3808.
5493.
8033.
13006.
19163.
25874.
31135.
40645.
44550.
51521.
61797.
68677.
77597.
84317.
89272.
91882.
94067.
95497.
97012.
99002.
99627.
JWUHC^tW
679
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMSSION LIMITATION - NS/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UFIT GENERATING CAPACITY U/FGD - MW
NET UNIT GENERATING CAPACITY W1/FGD - MW
EQUIVALEKT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STAC,<
BOILER SUPPLIER
BOIIER TYPE
BOILER SERVICE LOAD
DJESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FU5L DATA
FJEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - z
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
R/NGE SULFUR CONTENT - 7.
A-iERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - '/.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
COMMONWEALTH EDISON
WILL COUNTY
1
ROMEOVILLE
ILLINOIS
******
86.
774.
******
( .200 LB/MMBTU)
( 1.800 LB/MMBTU)
(****** LB/MMBTU)
1147
167
137
144
167
BABCOCK & WILCOX
CYCLONE
CYCLING
363.36 (
179.4 (
107. (
******
3.8 (
770000 ACFM)
355 F)
350 FT)
12.4 FT)
COAL
******
22260. ( 9570 BTU/LB)
9,100 - 10,500
7.40
3-16
********
******
1.50
0.3 - 4.5
******
0
NONE
0
NONE
COLD SIDE
WESTERN PREC. DIVISION, JOY
179.4 ( 355 F)
90.0
2
NONE
VARIABLE-THROAT/SIDE-MOVABLE BLADES
BABCOCK & WILCOX
8 X 26 X 16 (THROAT 21 X 1.8)
365.4 ( 5800 6PM)
2.4 (18.0 GAL/1000ACF)
2.2 ( 9.0 IN-H20)
36.6 ( 120.0 FT/S)
( 385000 ACFM)
( 355 F)
181.7
179.4
98.0
680
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S03 PART. HOURS HOURS HOURS FACTOR
2/72 SYSTEM 696
** PROBLEMS/SOLUTIONS/COMMENTS
IN FEBRUARY 1972 THE BABCOCK & MILCOX WET LIMESTONE FGD SYSTEM AT WILL
COUNTY COMMENCED OPERATION. THE LONGEST PERIOD OF CONTINUOUS OPERATION
WAS 23 DAYS WITH ONE OF THE TWO MODULES. THE S02 REMOVAL EFFICIENCY WAS
ABOUT 85X AND THE PARTICULATE MATTER REMOVAL EFFICIENCY WAS ABOUT 98X.
THE SYSTEM WAS PLAGUED WITH MANY MECHANICAL PROBLEMS. THE MAIN
PROBLEMS ASSOCIATED WITH THE FGD SYSTEM WERE PLUGGING OF THE MIST
ELIMINATORS, CORROSION OF THE REHEATER TUBES AND SLUDGE DISPOSAL. TO
SOLVE THE MIST ELIMINATOR AND REHEATER PROBLEMS, A CONSTANT UNDERSPRAY AND
INTERMITTENT OVERSPRAY WERE USED TO WASH ALL THE MIST ELIMINATOR COMPART-
MENTS. THE REHEATER UNIT WAS ALSO RETUBED.
DURING THE FIRST TWO MONTHS OF 1975 MODULE A WAS OPERATIONAL WHEN NEEDED
WHILE MODULE B WAS UNDERGOING MODIFICATIONS.
3/75 A 94.0 99.2 81.2
B .0 .0 .0
SYSTEM 744 609
*i PROBLEMS/SOLUTIONS/CC'IMENTS
A VENTJRI HOSE LEAK FORCED MODULE A OUT ONCE.
MODULL B WAS OUT OF SERVICE TWICE FOR NO DEMAND AND ONCE AS A RESULT OF AN
ACCIDENTAL 50 MINUTE TRIP.
COAL BURNED THIS MONTH AVERAGED LESS THAN ONE PERCENT SULFUR.
4/75 A 37.0 39.5 35.0
B .0 .0 .0
SYSTEM 720 638
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO FLY ASH IS TREATING MATERIAL FROM THE SCRUBBER WITH LIME AND FLY
ASH AND DUMPING IT INTO THE HOLDING BASIN.
A BOILER OUTAGE FORCED MODULE A OUT OF SERVICE ONCE THIS MONTH (MODULE B
WAS ALREADY OUT OF SERVICE).
COAL BURNED THIS MONTH WAS RECLAIM COAL AND VARIED IN SULFUR CONTENT.
5/75 A 84.5 84.5 84.5
B 37.1 37.1 37.1
SYSTEM 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE B WAS IN SERVICE ON MAY 20 FOR THE FIRST TIME SINCE APRIL 13, 1973.
RECIRCULATION TANK MIXERS.
MODULE A (WHICH WAS THE ONLY ONE OPERATING) WAS FORCED OUT TWICE IN APRIL
TO AVOID POND OVERBOARDING INTO THE DES PLAINES RIVER. THE SECOND OUTAGE
LASTED UNTIL MAY 5. DURING THE PAST SEVERAL MONTHS OF GENERALLY CONTINUOUS
OPERATION OF MODULE A. IT HAS BECOME APPARENT THAT THE PRESENT LIQUID
CIRCULATING SYSTEM CANNOT BE OPERATED IN A CONTINUOUSLY CLOSED CYCLE. THE
WATER IMBALANCE POSES A HIGH RISK OF OVERBOARDING FROM THE SLUDGE POND
DURING LONG PERIODS OF SUSTAINED OPERATON. THE FOLLOWING REVISIONS HAVE
BEEN MADE TO REDUCE THE WATER IMBALANCE:
1. THE PUMP GLAND WATER FLOWS HAVE BEEN CUT FROM 10 GPM TO 5 GPM.
681
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
303 PART. HOURS HOURS HOURS FACTOR
Z. THE SCRUBBER HOUSE SERVICE WATER FILTER BACKWASH HAS BEEN ROUTED
OUT OF THE SYSTEM.
3. THE CONTINUOUS UNDERSPRAY HAS BEEN CHANGED TO AN INTERMITTENT
SPRAY 5 MINUTES ON, 5 MINUTES OFF.
THE THICKENER HAS BEEN DOWN SINCE APRIL Z\ DUE TO A BROKEN GEAR AND A STUCK
SWEEP ARM. THE THICKENER HAS BEEN BYPASSED AND THE SLUDGE IS GOING TO THE
POND.
DURING MAY, MODULE A WAS OUT FOR 45 MINUTES DUE TO A DAMPER TRIP.
MODULE A WAS OUT ONCE FOR SPRAY NOZZLE CLEANING.
MODULE B WAS OUT TWICE AFTER START UP, ONCE FOR A VENTURI PUMP TRIP AND
ONCE FOR A RECIRCULATION TANK LEVEL TRIP.
CHICAGO FLY ASH IS TREATING THE MATERIAL FROM THE SCRUBBER WITH LIME AND
FLY ASH AND DUMPING IT INTO THE HOLDING BASIN. A MIXER HAS BEEN INSTALLED
AT THE THICKENER, WHICH ENABLES THEM TO SUBSTITUTE SEALED DUMP TRUCKS FOR
THE CEMENT TRUCKS WHICH WERE USED IN THE PAST FOR MIXING AND TRANSPORTING
THE WASTE MATERIAL TO THE HOLDING BASIN.
COAL BURNED THIS MONTH VARIED GREATLY IN SULFUR CONTENT, RANGING FROM LOW
SULFUR WESTERN COAL TO HIGH SULFUR ILLINOIS COAL,
6/75 A 64.1 60.6 54.1
B 85.5 84.6 75.4
SYSTEM 720 642
** PROBLEMS/SOLUTIONS/COMMENTS
A REHEATER PLUGGAGE INSPECTION FORCED ONE MODULE A OUTAGE.
A LOV LEVEL TRIP CAUSED A 35 MINUTE OUTAGE, AND NO DEMAND ACCOUNTED FOR TWO
MORE ilODULE A OUTAGES.
MODULE B WAS OUT FOR 95 HOURS TO ULEAN THE BOOSTER FAN AND DEMISTER.
HIGH BOOSTER FAN VIBRATIONS CAUSED MODULE B TO SHUT DOWN ON JUNE 30.
DURING THIS MONTH HIGH SULFUR COAL WAS BURNED IN A TWO WEEK TEST, AND LOW
SULFUR COAL WAS BURNED THE REST OF THE MONTH.
7/75 A .0 .0 .0
B 79.3 79.4 73.5
SYSTEM 744 689
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO FLY ASH IS TREATING THE SCRUBBER WASTE MATERIAL WITH LIME AND FLY
ASH AND DUMPING IT INTO THE ON SITE HOLDING BASIN. THE MATERIAL FROM THE
HOLDING BASIN IS BEING TRUCKED TO AN OFF SITE DUMP.
MODULE B WAS OUT ONCE (30 MINUTES) TO REPAIR A MINOR STEAM HEADER LEAK.
MODULE B WAS OUT ONCE DUE TO NO DEMAND.
LOW SULFUR COAL WAS BURNED MOST OF THIS MONT, WITH HIGH SULFUR COAL BEING
BURNED DURING THE LAST WEEK OF THE MONTH.
8/75 A .0 .0 .0
B 93.5 100.0 76.4
SYSTEM 744 565
682
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
IN JUNE, MODULE A ENCOUNTERED PLUG6AGE IN THE DEMISTER, WHICH REQUIRED ITS
REPLACEMENT. THE WORK WAS COMPLETED IN AUGUST.
MODULE A WENT OUT OF SERVICE ON JUNE 20 AND REMAINED OUT THROUGH AUGUST DUE
TO MASSIVE REHEATER LEAKS. THERE IS PRESENTLY A HOLD ON THE NEW REHEATER
ORDER BECAUSE OF MATERIAL FAILURES EXPERIENCED IN MODULE B'S CARBON STEEL
REHEATER.
MODULE B SUFFERED TWO OUTAGES IN JULY AND ONE IN AUGUST BECAUSE OF REHEATER
TUBE LEAKS. THE FAILURES WERE DUE TO VIBRATION FATIGUE. THE REHEATER, WHICH
WAS INSTALLED IN MAY, HAS LOST SIX OF ITS TWELVE TUBE BUNDLES SO FAR. THE
LENGTH OF TIME THAT THE TUBES HAVE LASTED WOULD SEEM TO INDICATE THAT THERE
IS A DIESIGN RELATED MATERIAL DEFICIENCY. THREE OF THE TUBE BUNDLES WERE
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
A SMALL STEAM HEADER LEAK CAUSED ONE MODULE B OUTAGE.
MODULE B WAS OUT FOUR TIMES FOR NO DEMAND AND ONCE FOR A LOW FLOW TRIP.
HIGH SULFUR COAL WAS BURNED ALL MONTH, CAUSING AN INCREASE IN SLUDGE
PRODUCTION WHICH HAS FORCED A MINIMUM SIX DAY A WEEK, TEN HOUR A DAY
SLUDGE DISPOSAL OPERATION. THE SLUDGE IS BEING TREATED WITH LIME AND
FLY ASH AND BEING DUMPED INTO THE ON SITE HOLDING POND. STABILIZED
MATERIAL IS BEING TRUCKED FROM THE POND TO AN OFF SITE DISPOSAL AREA.
9/75 A
B
SYSTEM
10/75
A
B
SYSTEM
.0
32.3
.0
100.0
.0
26.6
720
744 194
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OFF THE ENTIRE 11 DAYS THE BOILER OPERATED THIS MONTH, WAITING
FOR ITS NEW REHEATER, WHICH HAS NOW BEEN RELEASED FOR MANUFACTURING BY
SMED.
MODULE B HAD TWO OUTAGES, ONE FOR NO DEMAND AND ONE MINOR 15 MINUTE TRIP.
HIGH SULFUR COAL WAS BURNED THIS MTNTH WHEN THE SCRUBBER WAS IN SERVICE.
THE KLUDGE IS BEING TREATED WITH LIME AND FLY ASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
11/75 A
B
S"STEM
12/75
1/76
2/76
A
B
SYSTEM
A
B
SYSTEM
A
B
SYSTEM
.0
.0
.0
.0
.0
.0
.0
.0
.3
.0
.0
.0
.0
.0
.0
.0
720
744
744
696
683
-------
EPA UTILITY FSO SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/76 A
B
SYSTEM
30.1
8.8
45.2
20.4
18.8
8.5
744 309
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS DOWN FROM OCTOBER 11 THROUGH MARCH 19 FOR ITS BOILER TURBINE
AND SCRUBBER OVERHAUL. THE MAJOR ITEMS TO BE ACCOMPLISHED DURING THE
OUTAGE WERE:
1. SIMPLIFICATION OF THE MILLING SYSTEM CONTROL.
2. PULLING AND CLEANING OF THE MODULE B REHEATER AND RETURNING IT
REPLACED WITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
3. CLEANING OF THE POND PUMP BAY.
4. REMOVAL OF THE VENTURI AND ABSORBER PUMP CHECK VALVES (ONE OF THEM
FAILED LAST SPRING AND DESTROYED A PUMP LINER AND IMPELLER).
5. CLEANING AND REPAIR OF THE VENTURI NOZZLES AND SUPPORTS.
6. REPAIR OF CORRODED REHEATER SUPPORTS.
7. RESETTING AND ADJUSTMENT OF ALL DAMPERS.
8. REVISION OF SCRUBBER CONTROLS BY REMOVING THE CONTROLS NO LONGER
USED OR NEEDED.
9. INSPECTION AND CLEANING OF THE ENTIRE SCRUBBER AND RELATED
EQUIPMENT.
MODULE A WAS PUT INTO THE GAS PATH ON MARCH 22 AND REMAINED AVAILABLE FOR
SERVICE THE REST OF THE MONTH.
MODULE B HAD TO REMAIN OUT OF SERVICE UNTIL MARCH 29 WHILE ITS REPAIRED
REHEATER WAS INSTALLED.
4/76 A 23.0 20.0 19.2
B 49.3 47.3
SYSTEM 720 691
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 RETURNED TO SERVICE APRIL 2 AFTER A SHORT TURBINE CONTROL OUTAGE.
BOTH MODULES CAME ON LINE JUST BEFORE THE BOILER.
A FIVE DAY OUTAGE OF MODULE B WAS DUE TO REHEATER TUBE BUNDLE LEAKS.
SEVERAL MODULE B OUTAGES WERE DUE TO PLUGGED ABSORBER TANK SCREENS CAUSED
BY MILL AND CLASSIFIER FAILURES WHICH ALLOWED ROCK TO GET INTO THE SYSTEM.
MODULE B WAS THOROUGHLY CLEANED.
ONLY ONE ABSORBER PUMP IS BEING USED IN MODULE B, SINCE THE 1B2 PUMP LINER
FAILED AS A RESULT OF A BROKEN DISCHARGE VALVE. A REPLACEMENT LINER IS
BEING INSTALLED.
A SCRUBBER TESTING AND EVALUATING PROGRAM WAS STARTED THIS MONTH. MUCH OF
THE LATTER TWO WEEKS OF THE MONTH WERE SPENT TRAINING THE TESTING PERSON-
NEL. THE PROGRAM WILL PROVIDE CHEMISTRY DATA AND OPERATING CHARACTERISTICS.
5/76 A .0 .0 .0
SYSTEM 744 665
** PROBLEMS/SOLUTIONS/COMMENTS
A VENTRUI HOSE LEAK FORCED MODULE » OFF ONCE THIS MONTH.
MODULE B WAS TAKEN OUT OF SERVICE ONCE BECAUSE OF A PLUGGED ABSORBER TANK
SCREE!'.
MODULE B WAS OFF ONCE DUE TO A FCULED I.D. FAN.
684
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
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
MODULE B WAS OUT OF THE GAS PATH ONCE DUE TO NO DEMAND.
6/76 A 52.0 44.2 37.6
B 86.2 84.5 71.9
SYSTEM 720 612
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A SUFFERED VENTURI PUMP LINER FAILURES ON APRIL 78 WHEN AN INLET 16
INCH BUTTERFLY ISOLATION VALVE BROKE APART AND FELL INTO THE VENTURI PUMP.
BOTH THE A AND BACKUP AB VENTURI PUMP LINERS WERE DESTROYED. MODULE A
REMAINED OUT SERVICE UNITL JUNE 9, WHEN THE LINERS WERE REPLACED.
MODULE A WAS OFF ONCE FOR SHEARED BYPASS DAMPER PINS.
I.D. BOOSTER FAN FOULING FORCED MODULE A OFF ONCE THIS MONTH FOR ABOUT
164 HOURS.
BOTH MODULES WERE OFF TWICE DUE TO NO DEMAND. DURING THESE OUTAGES, THE
DEMISTERS WERE WASHED AND ABSORBER TRAY SCALE, IF ANY, WAS KNOCKED OFF.
MODULE B WAS OUT OF THE GAS PATH FOR SEVERAL SHORT VENTURI LOW FLOW TRIP
OUTAGES DUE TO A PLUGGED, SCALED VENTURI TANK SCREEN. AT THE END OF THE
MONTH, THE MODULE WAS TAKEN OUT TO CLEAN THE SCREEN.
THE MODULE B I.D. BOOSTER FAN REQUIRED CLEANING DURING THE MONTH.
THE REHEATER TUBES ARE SCALING, WHICH RESULTS IN A LOWER HEAT TRANSFER RATE
RATE, AND THEREFORE INCREASES I.D. BOOSTER FAN FOULING. THE ONLY WAY TO
CLEAN THE REHEATERS EFFECTIVELY IS TO REMOVE THEM, WHICH DEMANDS A SUBSTAN-
TIAL OUTAGE.
7/76 A 19.9 .0 .0
B 86.2 90.0 72.3
SYSTEM 744 598
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OFF THE FIRST PART OF THE MONTH DURING REPAIRS TO THE ABSORBER
THE LATTER PART OF THE MONTH THE MODULE WAS READY FOR SERVICE BUT WAS NOT
OPERATED BECAUSE OF THICKENER-POND SLUDGE OVERLOADING.
MODULE B WAS FORCED OFF ONCE TO BALANCE THE I.D. BOOSTER FAN, AND ONCE TO
WASH THE FAN.
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND.
8/76 A 98.2 57.6 38.3
B 65.4 61.4 • 40.9
SYSTEM 744 495
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS OUT OF THE GAS PATH THE FIRST HALF OF THE MONTH T AVOID
THICKENER-POND OVERLOADING.
DURING THE LATTER HALF OF THE MONTH, MODULE A WAS USED WITH THREE MINOR
FORCED OUTAGES AND ONE FOUR DAY NO DEMAND OUTAGE.
MODULE B WAS OUT OF THE GAS PATH THREE TIMES DUE TO NO DEMAND.
LOSS OF CHEMICAL CONTROL CAUSED TWO MODULE A OUTAGES.
685
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
MODULE B WAS OFF FOR NINE DAYS DUE TO FOULING.
SPENT SLURRY VALVE REPAIRS FORCED A MODULE B OUTAGE.
ON AUGUST 12 THE OPERATING PH CONTROL SET POINT WAS REDUCED FROM 5.4 TO
5.1. IT IS BELIEVED THAT THIS LOWER PH IS THE CAUSE OF THE FOULING OUTAGE
OF MODULE B ON AUGUST 21. MODULE A WAS ALSO OPERATED FOR THREE DAYS, AND
IT, TOO, EXPERIENCED INCREASED SACLE FOULING. THE PH SET POINT WAS THEN
INCREASED BACK TO 5.4.
9/76 A
B
SYSTEM
42.3
79.4
28.7
22.6
59.9
720 566
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WENT OFF ONCE DUE TO A LOW FLOW TRIP.
MODULE A WAS TAKEN OFF ONCE FOR CLEANING OF THE RECIRCULATION TANK AND
PUMPS, AND INSPECTION OF PUMP ISOLATION VALVES.
A LINER LEAK IN 1A2 ABOSORBER PUMP ALSO FORCED MODULE A OFF.
MODULE A WAS OUT OF TH GAS PATH TWICE DUE TO NO DEMAND.
MODULE A WAS TAKEN OFF ONCE TO AVOID THICKENER-POND OVERLOADING.
SPENT SLURRY VALVE TROUBLE CAUSED TWO MODULE B OUTAGES.
10/76 A
B
SYSTEM
27.9
76.4
28.9
56.2
37.9
54.8
744 7E6
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR ILLINOIS COAL WAS BURNED IN THE BOILER FROM MARCH THROUGH
OCTOBER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED TO
AN OFF SITE DISPOSAL AREA.
MODULE A OPERATED ON ONE ABSORBER PUMP, ALLOWING TESTING ON A LOWER
ABSORBER FAN.
MODULE A WAS OUT OF THE GAS PATH ONCE FOR AN I.D. BOBOOSTER FAN TRIP.
WORK ON RECIRCULATION TANK LEVEL CONTROLS CAUSED A MODULE A OUTAGE.
MODULE B WAS FORCED OFF ONCE TO REPAIR A REHEATER HEADER LEAK.
ONE MODULE B OUTAGE WAS FOR VENTURI NOZZLE CLEANING.
MODULE B WENT OFF FOR A VENTURI LOW FLOW TRIP.
MODULE B REMAINED OUT OF SERVICE WHILE MODULE A WAS BEING TESTED TO AVOID
THICKENER-POND OVERLOADING.
A VACUUM FILTER WAS TIED IN AT THE THICKENER.
11/76 A
B
SYSTEM
20.1
72.2
25.6
69.6
20.1
4.7
720 566
686
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMOt-WEALTH 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
*« PROBLEMS/SOLUTIONS/CCMMENTS
MODULE A OPERATED ON ONE ABSORBER PUMP DURING MODULE B OUTAGE.
MODULE B WAS FORCED OUT OF THE GAS PATH ONCE FOR A MILLING SYSTEM FAILURE.
MODULE B ENCOUNTERED A VENTURI HEADER LEAK.
THE VENTURI NOZZLES REQUIRED CLEANING DURING THE MONTH.
REPLACEMENT OF THE SPENT SLURRY VALVE NECESSITATED A MODULE OUTAGE.
MODULE B WAS OFF ONCE DUE TO A CHEMICAL SYSTEM UPSET.
MODULE B WAS OUT OF THE GAS PATH TWICE DUE TO NO DEMAND (MODULE A WAS NOT
IN SERVICE AT THE TIME OF THE OUTAGE).
12/76 A 44.9 48.3 44.9
B 53.4 51.7 48.0
SYSTEM 744 692
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST WEEK OF NOVEMBER, THE 1A2 ABSORBER PUMP WAS TAKEN OUT OF
SERVICE FOR OVERHAUL. THE REPAIRS WERE COMPLETED ON DECEMBER 6, WHEN THE
MODULE ASSUMED A ONE ABSORBER PUMP STANDBY CAPABILITY UNTIL THE 1A1 ABSOR-
BER PUMP CAN BE REPAIRED.
DURING THE LAST HALF OF THE MONTH, MODUELE A OPERATED WHILE MODULE B WAS
BEING REPAIRED.
MODULE B PERFORMED SATISFACTORILY DURING THE FIRST HALF OF THE MONTH,
EXPERIENCING ONLY ONE NO DEMAND OUTAGE. ON THE 17TH, HOWEVER, THE SPENT
SLURRY VALVE FAILED AND THE MODULE HAS REMAINED OUT OF SERVICE.
1/77 A 98.2 98.7 95.8
B 13.5 1.1 1.1
SYSTEM 744 722
** PROBLEMS/SOLUTIONS/COMMENTS
THE 1A1 ABSORBER PUMP WENT OUT IN LATE SEPTEMBER WITH BURNED OUT BEARINGS
AND REMAINED OUT THROUGH JANUARY WAITING FOR PARTS.
LOW SULFUR COAL WAS BURNED IN THE BOILER FROM NOVEMBER THROUGH JANUARY.
DUE TO THE LOW VOLUME OF SLUDGE PRODUCED WHILE BURNING LOW SULFUR COAL,
MUCH OF THE SLUDGE HANDLING TIME WAS SPENT DIGGING OUT THE ACCUMULATED
SLUDGE IN THE RECIRCULATION PONDS. THIS MATERIAL, ALONG WITH SCRUBBER
WASTE MATERIAL, WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF
SITE DISPOSAL AREA.
MODULE A WAS FORCED OUT ONCE BY A FAILED SPENT SLURRY VALVE.
PLUGGED DEMISTER UNDERSPRAYS CAUSED ANOTHER MODULE A OUTAGE.
MODULE A WENT OUT ONCE BECAUSE OF NO DEMAND AND ONCE DUE TO A BOILER OUTAGE
(MODULE B WAS ALREADY OUT OF SERVICE FOR REPAIRS).
MODULE B BECAME AVAILABLE FOR SERVICE ON JANUARY 27, AFTER REPAIRS TO THE
SPENT SLURRY VALVE WERE COMPLETED. DUE TO SEVERE WEATHER CONDITIONS, THE
MODULE WAS PLACED IN THE GAS PATH JANUARY 31.
687
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 ICONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/77 A 38.8 42.6 38.8
B 72.0 45.7 41.7
SYSTEM 672 613
** PROBLEMS/SOLUTIONS/COMMENTS
THERE WAS VERY LITTLE DIGGING IN THE RECIRCULATION PONDS. CHICAGO FLYASH
SPENT MOST OF THEIR TIME ON CLEANING AND MAINTENANCE.
3/77 A 96.9 66.7 64.2
B 80.9 75.5 73.9
SYSTEM 744 728
* * PROB LEMS/SOLUTIONS/CC1MENTS
AN ERT S02 ANALYZER WAS INSTALLED ON THE DISCHARGE SIDE OF MODULE B I.D.
BOOSTF.R FAN. THIS IS AN "IN SITU" ON-DISPERSIVE ANALYZER THAT CONTINUALLY
MEASURES AND READS OUT CONCENTRATIONS OF S02, CO, C02, AND NO.
AN ABSORBER SUCTION HEADER LEAK FORCED MODULE B FROM THE GAS PATH.
MODULE B WAS FORCED OUT DUE TO A SLURRY VALVE GASKET LEAK.
A PLUGGED FEED SLURRY RECIRCULATION LINE WAS ENCOUNTERED IN MODULE B.
HIGH SULFUR COAL WAS BURNED FOR SEVEN DAYS THIS MONTH TO PROVIDE HIGH
SULFUR SLUDGE FOR THE UOP SLUDGE TEST.
CHICAGO FLYASH SPENT 75X OF THEIR TIME DIGGING IN THE POND. THE REST WAS
SPENT ON THE THICKENER AND VACUUM FILTER IPERATION. THE SCRUBBER WASTE
MATERIAL WAS TREATED WITH LIME FLYASH AND HAULED OFF SITE.
DISPOSAL AREA.
4/77 A 86.1 67.7 61.2
B 45.5 30.2 27.3
SYSTEM 720 650
** PROBLEMS/SOLUTIONS/COMMENTS
THE PERFORMANCE OF THE ERT S02 ANALYZER TO DATE HAS BEEN, AT BEST, UNRELIA-
BLE AND INCONSISTENT. THE ERT TECHNICIANS ARE OUT TO SERVICE THE ANALYZER
ALMOST EVERY OTHER DAY. THE PROBLEM, ACCORDING TO ERT TECHNICIANS, IS OF A
"THERMAL NATURE". WHEN THE ANALYZER REACHES A CERTAIN TEMPERATURE, A CHIP
SHORTS OUT. THEY HAVE NOT BEEN ABLE TO LOCATE THE FAULTY INTEGRATED CIRCUIT
YET.
A BOILER TUBE LEAK REPAIR FORCED MODULE A OUT OF THE GAS PATH ONCE THIS
MONTH (MODULE B WAS ALREADY DOWN FOR REPAIRS).
MODULE B WAS FORCED OUT OF THE GAS PATH TWICE FOR AN ABSORBER SUCTION
HEADER LEAK REPAIR.
MODULE B WAS OUT OF SERVICE ONCE TO WASH THE I. D. BOOSTER FAN.
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME DIGGING IN THE SMALL POND,
GETTING READY FOR THE MGO ADDITION AND FORCED OXIDATION TEST. THE SCRUBBER
WASTE MATERIAL WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
5/77 A 89.4 2.2 2.0
B 98.0 50.9 47.3
SYSTEM 744 691
688
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
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
** PROBLEMS/SOLUTIONS/COMMENTS
THE ERT SOZ ANALYZER HAS BEEN REMOVED FROM SERVICE DUE TO A POOR PERFORM-
ANCE RECORD OVER THE LAST THREE MONTHS. ERT IS IN THE PROCESS OF RE-
ENGINEERING THEIR ANALYZER.
THE MGO ADDITION TEST WENT WELL. ALTHOUGH THE MGO INCREASED S02 REMOVAL
EFFICIENCY ABOUT 10X, IT DID PRACTICALLY NOTHING FOR THE TWO MORE SERIOUS
PROBLEMS, SINCE THICKENER AND SLUDGE PRODUCTION AND LIMESTONE CONSUMPTION
RATE WERE ABOUT THE SAME.
MODULE A WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE INLET
VALVE ON 1A2 ABSORBER PUMP FAILED.
MODULE B WAS TAKEN OFF TO CLEAN AND INSPECT THE REHEATER TUBES.
BOTH MODULES WERE FORCED OFF FOR THE FIRST FIFTEEN DAYS OF THE MONTH DUE TO
A FAILED 120V CONTROL TRANSFORMER FOR THE POND RETURN PUMPS. THE TRANSFORM-
ER HAD TO BE ORDERED FROM WESTINGHOUSE.
HIGH SULFUR COAL HAS BURNED FOR ELEVEN DAYS DURING THE MONTH.
6/77 A
B
SYJTEM
31.8
93.2
13.3
93.4
10.5
73.5
720 566
. PROBLEMS/SOLUTIONS/CC1MENTS
7/77 B
SYSTEM
70.3
THE 1A1 ABSORBER PUMP IS STILL OUT OF SERVICE WAITING FOR PARTS 1A2
ABSORFER PUMP'S ISOLATION VALVES FORCED MODULE A OFF FOR MOST OF T(E MONTH.
MODULE A HAD ONE NO DEMAND AND ONE BOILER OUTAGE THIS MONTH.
MODULE B WAS ALSO FORCED OFF TO CLEAN THE I.D. BOOSTER FAN.
NO HIGH SULFUR COAL WAS BURNED THIS MONTH.
41.4 21.0
744
377
** PROBLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR COAL HAS BURNED FOR EIGHT DAYS THIS MONTH. LIMESTONE OPERATION
WAS NORMAL FOR HIGH SULFUR OPERATION.
MODULE B WAS FORCED OUT OF THE GAS PATH ONCE TO REMOVE A PLUGGED DIFFUSES.
THE FINAL TEST, FORCED OXIDATION SEEMDD TO BE THE MOST SUCCESSFUL OF ALL.
USING LIQUID OXYGEN, UP TO 12,000 CFM OF GASEOUS 02 WAS FED INTO EACH
VENTURI DOWNCOMER, OXIDATION OF SULFITE TO SULFATE WAS INCREASED FROM
35 TO 90 y.
MODULE B WAS ALSO FORCED OFF DUE TO A LOW LEVEL IN THE SLURRY STORAGE TANK.
MODULE B WAS ALSO FORCED OFF DUE TO REHEATER TUBE BUNDLE LEAKS.
8/77 A
,3
SYSTEM
99.8
9.7
99.6
12.0
80.8
9.7
744 604
689
-------
10/77
11/77
A
B
SYSTEM
A
B
SYSTEM
.0
.0
.0
8.8
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY I (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A WAS AVAILABLE THE ENTIRE MONTH WITH JUST THE VENTURI PUMP OPERAT-
ING.
9/77 A 61.0 77.8 54.0
B 52.3 75.4 52.3
SYSTEM 720 499
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE B ENCOUNTERED HIGH VIBERATIONS IN ITS BOOSTER FAN DURING THE FIRST
WEEK OF THE MONTH. AFTER THE FAN WAS BALANCED, THE MODULE OPERATED INTIL
THE UNIT OUTAGE ON SEPTEMBER 21.
.0
.0
744 0
.0
50.1 8.8
720 126
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT ONE CAME UP ON NOVEMBER 25 AFTER A SIXTY-THREE DAY OUTAGE.
MODULE B IS IN THE GAS PATH FATER EXPERIENCING SOME DIFICULTY IN BALANCING
ITS BOOSTER FAN.
12/77 A 42.5 42.5 47.8 42.5
B 84.1 84.1 94.6 84.1
SYSTEM 744 661
** PROBLEMS/SOLUTIONS/COMMENTS
PLUGPAGE WAS ENCOUNTERED IN THE MODULE B REHEATER. BECAUSE NO SPARE REHEAT
COILS WERE AVAILABLE, THE UTILITY TRIED TAKING SOME COILS FROM MODULE A
MODULI B APPEARED TO BE MORE ORE SEVERELY PLUGGED THAN ORIGINALLY THOUGHT.
MODULE A WAS DOWN HALF THE MONTH BECAUSE OF A MAIN STEAM LEAK WHICH COULD
NOT BE ISOLATED.
MODULI A OPERATED UNTIL SEPTEMBER 19, WH E A COMBINATION OF MUD AND SCALE
BUILD-UP ON THE SUMP FLOOR STRUCTURALLY DAMAGED THE MODULE. REPAIRS PUT
THE NODULE OUT OF SERVICE UNTIL HID DECEMBER.
1/78 A 69.0 89.9 66.3
B 22.0 29.8 22.0
SYSTEM 744 549
** PROBLEMS/SOLUTIONS/COMMENTS
ON JANUARY 7, THE MODULE B I.D. BOOSTER FAN DISCHARGE DUCT STARTED VIBRAT-
ING WILDLY. THIS FORCED THE BOILER OFF WHILE THE SHOP MADE REPAIRS TO THE
DUCTWORK AND BALANCED THE FAN WITH AN I.R.D. MACHINE.
WHEN THE UTILITY ATTEMPTED TO PUT MODULE B BACK IN THE GAS PATH, A LEAK IN
THE SLURRY LINE FORCED IT BACK OFF.
A PLUGGED VENTURI PUMP FORCED MODULE B OFF THE REST OF THE MONTH.
DURING THE OUTAGE, THE REHEATER COILS WERE CLEANED WITH A HIGH PRESSURE
690
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
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
C5000 LB) SPRAYER.
MODULE A WAS FORCED OFF WHEN A STEAM REGULATING VALVE BLEW ITS PACKING.
ON THE 23RD, BOTH MODULES WERE TAKEN OFF AND DRAINED TO ALLOW THE SHOP TO
INSTALL NEW ISOLATION VALVES IN THE ABSORBER AND VENTURI PUMPS.
TOWARD THE END OF THE MONTH, SOME PROBLEMS WERE ENCOUNTERED WITH THE POND
RETURN PUMPS FREEZING.
a/78 A 40.9 56.5 34.4
B 69.5 93.9 56.5
SYSTEM 672 409
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A RAN INTO DIFFICULT OPERATIONG CONDITIONS THIS MONTH DUE TO RAPID
PLUGGING OF THE REHEAT COILS.
INSPECTION AND SUBSEQUENT CLEANING OF MODULE A UNCOVERED PLUGGED SPRAY
NOZZLES AND DEMISTER TRAYS DUE TO NOZZLE INEFFICIENCY.
MODULE B OPERATED VERY WELL AND AN INSPECTION SHOWED THE MODULE TO BE VERY
CLEAN.
3/78 A 93.5 100.0 90.6
B 88.5 84.7 76.0 26.2
SYSTEM 744 230
** PROBLEMS/SOLUTIONS/COMMENTS
THIS MONTH, DUE TO COAL CONSERVATION, UNIT 1 WAS ON THE SYSTEM VERY LITTLE.
MODULE B HAD DIFFICULTY FOR SEVERAL DAYS BECAUSE OF A CRACKED SHEAVE ON THE
VENTURI PUMP.
HIGH PRESSURE CLEANING ON BOTH MODULES DURING THE COAL CONSERVATION ALONG
WITH REMOVING THE VENTURI THROAT RESTRICTOR BLOCKS PROVED BENEFICIAL IN
MAINTAINING BETTER CONTROL OF THE DRAFT CONDITIONS IN THE SCRUBBER.
4/78 A 99.9 99.7 92.0
B 100.0 99.9 92.2
SYSTEM 720 665
** PROBLEMS/SOLUTIONS/COMMENTS
THE PRESSURE DIFFERENTIAL ACROSS THE VENTURIS HAS BEEN REDUCED BY APPROXI-
MATELY 40X AT 140 MW BY REMOVING THE VENTURI RESTRICTOR BLOCKS. PARTICULATE
REMOVAL AND SOLIDS CARRYOVER COULD bE ADVERSELY AFFECTED BY THIS ACTION.
SINCE PARTICULATE REMOVAL AT THE VENTURI IS A FUNCTION OF WATER DROPLET
SIZE. WHICH IN TURN IS A FUNCTION OF PRESSURE DROP. INCREASED SOLIDS CARRY-
OVER COULD POSSIBLY COMPUND REHEATER PLUGGING PROBLEMS. THE UTILITY IS
KEEPIilG A CLOSE WATCH FOR PLUGGING, BUT HAS NOT YET FOUND ANYTHING UNUSUAL.
MODULE A WAS FORCED OUT OF THE GA3 PATH ONCE THIS MONTH FOR A VENTURI PIPE
LEAK.
5/78 A 9.5 99.4 55.2
B 89.2 100.0 56.1
SYSTEM 744 413
691
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
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
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST PART OF THE MONTH BOTH MODULES WERE FORCED OUT OF THE GAS
PATH DUE TO REHEATER LEAKS. IT REQUIRED A TWO DAY OUTAGE TO REMOVE THE
LEAKING REHEATER BUNDLES. ADDITIONAL REHATERS ARE ON ORDER AND ARE EXPECT-
ED TO ARRIVE IN JUNE.
6/78 A
B
SYSTEM
87.1
85.6
94.5
100.0
23.7
25.1
720 181
** PROBLEMS/SOLUTIONS/COMMENTS
DURING A SCRUBBER INSPECTION, 25X DIEMISTER AND 75X ABSORBER SPRAY PLUGGAGE
WAS DISCOVERED IN MODULE A. MODULE B WAS NOT AS BAD.
HIGH VIBRATION WAS ENCOUNTERED IN THE TURBINE BEARINGS DURING BOILER START
UP, CAUSING THE BOILER TO SHUT BACK DOWN.
THE PUG MILL FOR CHICAGO ADMIXTURES HAS BEEN APPROVED, AND THE NEW SLUDGE
TREATMENT SYSTEM SHOULD BE OPERATING BY FALL.
THE SCRUBBER WAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE 1B1
ABSORBER DISCHARGE VALVE FAILED TO OPEN.
THE BOILER WAS FORCfcD OFF THE LAST FOUR DAYS OF THE MONTH FOR CYCLONE
LEAKS. DURING THIS OUTAGE, THE A AND B MODULE SPENT SLURRY VALVES
WERE REPLACED.
7/78 A
B
SYSTEM
97.0
99.2
100.0
100.0
11.6
11.6
744
77
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS PLAGUED ALL MONTH BY CYCLONE CASING LEAKS. BECAUSE OF THE
CYCLONE PROBLEMS AND THE COAL CONSERVATION PROGRAM, THE BOILER WAS ONLY
OPERATED SEVENTY-SEVEN HOURS FOR THE MONTH.
THE BOILER DOWN TIME WAS USED FOR PREVENTATIVE MAINTENANCE ON THE SCRUBBER.
SIX NEW REHEATERS WERE INSTALLED AND A DRAIN VALVE ON THE SPENT SLURRY LINE
WAS REPAIRED.
A VALVE FAILURE ON THE 1A1 ABSORBER PUMP FORCED THE SCRUBBER FROM THE GAS
PATH ONCE DURING THE MONTH.
MODULE B EXPERIENCED A LEAKING VENTURI HEADER.
8/78 A
B
SYSTEM
97.8
99.6
100.0
100.0
59.1
59.1
744 440
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF THE THICKENER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED
OFF TO AN OFF SITE DISPOSAL AREA.
REPAIRS TO THE VENTURI EMERGENCY SPRAY VALVE CAUSED ONE BOILER OUTAGE
DURING THE MONTH.
A REHEATER FLANGE LEAK WAS RESPONSIBLE FOR FORCING THE UNIT OFF.
692
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MODULE A WAS FORCED OFF ONCE DUE TO HIGH VIBRATION OF THE I.D. BOOSTER FAN.
THE PROBLEM WAS CORRECTED BY REPACKING THE COUPLING ON THE FAN.
9/78
A
B
SYSTEM
77.7
77.7
95.9
96.0
55.4
55.5
720
** PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF THE THICKENER.
THE SCRUBBER WASTE MATERIAL WAS TREATED WITH LIME AND FLY ASH AND HAULED TO
AN OFF SITE DISPOSAL AREA.
REHEATER TUBE LEAKS, ONE IN MODULE A AND FOUR IN MODULE B, CAUSED ONE
BOILER OUTAGE AND CAUSED THE FGO SYSTEM TO BE UNAVAILABLE FOR A TOTAL
OF NINETY HOURS. SAMPLES OF THE TUBES HAVE BEEN SUBMITTED TO O.A.D. FOR
METALLURGICAL EXAMINATION.
A RUPTURED AIR LINE ON A VENTURI PUMP ISOLATION VALVE WOULD NOT ALLOW THE E
VALVE TO GO COMPLETELY CLOSED.
WHEN THE A VENTURI PUMP WAS STARTED, A VENTURI SPRAY HOSE RUPTURED.
IT WAS DISCOVERED THAT THE MODULE A VENTURI TANK LEVEL PRESSURE SWITCH WAS
NOT WORKING PROPERLY.
THE PUGMILL ORDERED FOR CHICAGO ADMIXTURES HAS ARRIVED ON SITE. IN OCTOBER,
THEY WILL FINISH THE CONVERSION, WHICH WILL ALLOW THE MATERIAL SERVICE
MIXER TRUCKS TO BE ELIMINATED.
IN OCTOBER, THE THICKENER WILL HAVE TO BE BYPASSED WHILE THE UTILITY DOES
MAINTENANCE ON THE RAKE AND REPLACES SOME LEAKING VALVES.
10/78
A
B
SYSTEM
100.0
100.0
100.0
100.0
35.0
35.0
261
** PROBLEMS/SOLUTIONS/COMMENTS
LOW BOILER HOURS WERE DUE TO FOUR OUTAGES CAUSED BY HIGH BEARING METAL
TEMPERATURES AND EXCESSIVE VIBRATION IN THE 1-B FORCED DRAFT FAN.
THE BOILER DOWN TIME WAS UTILIZED FOR CLEANING AND REPAIR OF THE VENTURI
THROAT, SUMP AND SUMP SCREENS, AND INLET BLOCK DAMPERS OF MODULE A, AS
WELL AS THE VENTURI AND ABSORBER TANKS AND SCREENS AND ALL ABSORBER SPRAY
NOZZLES OF BOTH MODULES.
ON INSPECTION, IT WAS DISCOVERED THAT THE B MODULE ABSORBER DEPARTMENTAL
DAMPER HAD SLIPPED SO'/. CLOSED. THE DAMPERS WERE JACKED OPEN AND WELDED
IN PLACE.
TO CORRECT A HIGH PRESSURE DROP ACROSS THE MODULE B REHEATER, A NEW METHOD
WAS EMPLOYED WHEREBY ONLY THE MIDDLE TUBES WERE REMOVED, ALLOWING THE TOP
AND BOTTOM TUBES TO BE SEEN AND CLEANED, ELIMINATING THE REMOVAL OF ALL THE
TUBES. THIS PROCEDURE CUT OUTAGE TIME FROM ONE OR TWO WEEKS TO TWO DAYS.
11/78 A
B
SYSTEM
96.2
85.2
100.0
100.0
48.3
48.3
720 348
693
-------
EPA UTILITY F6D SURVEY: OCTOaER - DECEMBER 1980
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
———--— —— — — —— — — —-——— ————— — — _ „___
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS DOWN THREE TIMES THIS MONTH DUE TO A VENTURI PUMP AND TWO
BOOSTER FAN OUTAGES.
12/78 A 65.3 100.0 64.5
B 64.5 100.0 64.5
SYSTEM 744 430
** PROBLEMS/SOLUTIONS/COMMENTS
REHEATER TUBE LEAKS CAUSED TWO OUTAGES.
THE MODULE B SPENT SLURRY DRAIN WAS REPAIRED.
1/79 A 83.5 100.0 61.3
B 62.2 87.1 53.4
SYSTEM 744 456
** PROBLEMS/SOLUTIONS/COMMENTS
THE 302 PLANT WAS FORCED OFF TWICE THIS MONTH DUE TO REHEATER TUBE LEAKS.
TWO TUBES ON MODULE A AND FOUR TUBES ON MODULE B WERE REPLACED.
THE I.D. BOOSTER FAN ON MODULE B WAS FOULED AND HAD TO BE REPLACED.
TWO SPECIAL SECTIONS OF VENTURI PIPING, A SIXTEEN TO EIGHT INCH ECCENTRIC
REDUCER AND AN OFFSET TEE WERE PREPARED BY LOCKPORT FABRICATING AND INSTAL-
LED THIS MONTH. THE ORIGINAL REDUCER AND TEE HAD BEEN PATCHED AND WELDED SO
MANY TIMES THAT THEY WERE BEYOND REPAIR.
2/79 A 93.0 91.3 54.2
B 93.0 91.3 54.2
SYSTEM 672 399
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS FORCED OFF ONCE FOR A MAIN STEAM HEADER LEAK.
3/79 A 100.0 100.0 46.0
B 68.6 100.0 46.0
SYSTEM 744 343
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS FORCED OUT TWICE IN FEBRUARY AND FOUR TIMES IN MARCH DUE E
TO A VENTURI HEADER LEAK. A TEN FOOT SECTION OF PIPE WILL HAVE TO BE
REPLACED DUE TO EXTENSIVE CORROSION.
THE SYSTEM WAS DOWN ONCE FOR A SPRAY HEADER LEAK.
MODULE B EXPERIENCED A LEAK IN THE VENTURI DOWNCOMER. A FIVE FOOT SECTION
OF THE PIPE WILL HAVE TO BE REPLACED.
4/79 A
SYSTEM 720
5/79 A .0
B .0
SYSTEM 744 0
694
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
COMMOHWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS OUT OF SERVICE THE ENTIRE MONTH DUE TO A BOILER OVERHAUL.
CHICAtO ADMIXTURES WILL STOCKPILE THE FIXED SLUDGE ON STATION PROPERTY.
6/79 SYSTEM 720 0
7/79 SYSTEM 744 0
8/79 SYSTEM 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 WAS OUT OF SERVICE TO REPLACE THE AIR HEATER TUBES, TUBE SHEET AND
HOPPERS. DURING THIS OUTAGE, THE WORN VENTURI SPRAY NOZZLES AND DEMISTERS
WERE REPLACED. WELDING LEAKS AND GENERAL CLEANING OF THE S02 INTERNALS
WAS ALSO DONE AT THIS TIME.
THE BOILER AND THE SCRUBBER ARE SCHEDULED TO RETURN TO SERVICE OCTOBER I,
1979.
720 0
744 0
85.4
85.4
85.4 720 336 336
** PROBLEMS/SOLUTIONS/COMMENTS
ON NOVEMBER 5, UNIT 1 RETURNED TO SERVICE AFTER A SIX MONTH OUTAGE TO
REPLACE THE AIR HEATER TUBES, TUBE SHEET AND HOPPERS.
DURING THE OUTAGE, SEVERAL LENGTHS OF VENTURI PIPING HAD TO BE REPLACED
WITH NEW RUBBER LINED PIPE.
THE UNIT DID NOT FORCE THE BOILER OFF AT ANY TIME DURING NOVEMBER.
12/79 A 77.0 99.5 57.5
B 84.9 100.0 57.8
SYSTEM 77.0 99.5 57.5 744 431 428
** PROBLEMS/SOLUTIONS/COMMENTS
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.
1/80 A 91.0 87.5 63.0
695
9/79
10/79
11/79
SYSTEM
SYSTEM
A
B
SYSTEM
53.3
53.3
53.3
100.0
100.0
100.0
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
'/. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
B
SYSTEM
88.6
88.6
84.1
84.1
60.6
60.6
744 536
451
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST SIX DAYS OF JANUARY, UNIT 1 BOILER WAS OFF THE SYSTEM BECAUSE
OF A SLAG SCREEN TUBE LEAK. THE UNIT RETURNED TO SERVICE ON JANUARY 7.
ON JANUARY 16, THE UTILITY HAD TO DERATE UNIT 1 TO 50 MW BECAUSE THE RE-
HEATER SECTIONS ON A AND B MODULES WERE PLUGGING. ON JANUARY 17, THE
MODULES WERE TAKEN OUT OF THE GAS PATH TO BEGIN REMOVING AND CLEANING THE
REHEATER SECTIONS WITH A HIGH PRESSURE (4000 PSD WATER SPRAY. UNIT 1
BOILER WAS LEFT ON TO PROVIDE STABILITY FOR THE 138 KV SYSTEM.
IN THE PAST, ALL 42 BUNDLES CONSISTING OF SEVEN TUBES PER BUNDLE,
HAD TO BE TAKEN OUTSIDE TO BE CLEANED ON A CONCRETE SLAB. IN THIS CASE
SINC:" TIME WAS THE MOST IMPORTANT FACTOR, A DIFFERENT APPROACH WAS USED.
ONLY THE MIDDLE SIX BUNDLES ON EACH MODULE WERE REMOVED. THIS PROVIDED A
LARGE ENOUGH SPACE SO THAT A LANC1 WITH AN EXTENSION ON IT COULD BE USED
TO CLEAN THE BOTTOM OF THE TWO TCP BUNDLES AND THE TOP OF THE TWO BOTTOM
BUNDLtS. THERE ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
OF THE REHEATER. USING THIS METHOD, ONLY 12 OR THE 42 BUNDLES WERE
REMOV:D. IN THE PAST, THIS JOB HAS TAKEN AS LONG AS TWO WEEKS TO
COMPLETE. USING THE NEW METHOD, ALL THE REHEATER BUNDLES WERE CLEANED IN
20 HOURS.
THE B-MODULE WAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY. BOTH
THESE OUTAGES WERE CAUSED BY THE REHEATER (A COIL LEAK AND A FLANGE LEAK)
TOTALING 18 HOURS AND 24 MINUTES.
2/80
A
B
SYSTEM
79.7
78.6
74.1
90.5
89.2
84.2
79.7
78.6
74.1
696 613
516
** PROBLEMS/SOLUTIONS/COMMENTS
SCRUBBER PROBLEMS IN FEBRUARY WERE CAUSED FROM LEAKS IN THE VENTURI SPRAY
HEADER. THESE LEAKS DEVELOP WHERE THE RUBBER LINING INSIDE THE VENTURI
PIPING HAS HORN AWAY SO THAT THE BARE METAL IS EXPOSED. THIS EXPOSED METAL
IS THEN SUBJECT TO ERROSION/CORROSION. THE LINING IS MOST LIKELY TO WEAR
AT THE WELD HEAD OF THE SPRAY NOZZLE TO THE MAIN HEADER. ALL THE VENTURI
SPRAY PIPING IS BEING REPLACED.
TUBE LEAKS IN THE STEAM COIL REHEAT SYSTEM CAUSED SCRUBBER PROBLEMS THIS
MONTH. MODULE A WAS FORCED OUT ONCE AND MODULE B WAS FORCED OUT THREE
TIMES. THESE TUBES WILL BE REPLACED DURING THE NEXT OUTAGE.
3/80
A
A
SYSTEM
83.9
83.9
83.9
.0
.0
.0
744
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS OUT OF SERVICE FOR ALL OF MARCH DUE TO BOILER TUBE LEAKS IN
THE REHEAT SECTION OF THE BOILER.
4/80
A
B
SYSTEM
100.0
87.7
93.9
71.0
71.0
71.4
17.3
17.3
17.3
720 175
125
696
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
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
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST 15 DAYS OF APRIL THE BOILER WAS OUT OF SERVICE DUE TO
TUBE LEAKS IN THE AIR PREHEATER.
WHEN ATTEMPTS WERE MADE TO BRING THE BOILER ON LINE ON THE 16 THE
B-MODULE OF THE S02 SYSTEM DEVELOPED REHEATER TUBE LEAKS. THIS CAUSED
A FORCED OUTAGE OF 53 HOURS AND 40 MINUTES.
WHEN ATTEMPTS WERE MADE TO RETURN THE BOILER TO SERVICE AGAIN, THE AUXIL-
IARY LOW PRESSURE GOVENOR DEVELOPED AN OIL LEAK CAUSING A FOUR DAY OUTAGE,
FOLLOWED BY ANOTHER REHEATER TUBE LEAK OUTAGE ON THE B MODULE. THIS
OUTAGE LASTED 35 HOURS. THE UNIT RETURNED TO SERVICE ON APRIL 24 AND
WAS AVAILABLE FOR THE REST OF APRIL.
5/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF MAY.
6/80 A 86.5 100.0 81.2
B 86.5 100.0 81.2
SYSTEM 86.5 100.0 81.2 720 584 584
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM FORCED THE BO.CLER OUT OF SERVICE FROM JUNE 6 TO
JUNE 10. THE OUTAGE WAS CAUSED BY PLUGGED REHEATERS ON BOTH MODULES.
THIS WAS THE ONLY FORCED OUTAGE EXPERIENCED DURING JUNE.
7/80 A 87.8 78.3 55.0
B 87.8 78.3 55.0
SYSTEM 87.8 78.3 55.0 744 522 409
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE MONTH OF JULY THERE WERE NO FORCED SCRUBBER OUTAGES.
TWO SLAG LINE OUTAGES, ONE FORCED DRAFT FAN AND ONE BOILER SCREEN WALL
TUBE OUTAGE OCCURRED. THIS ACCOUNTED FOR 193 HOURS OF BOILER-RELATED
OUTAGE TIME DURING THE MONTH.
ON NINE OCCASIONS IN JULY THE SCRUBBER WAS BY-PASSED SO THAT THE BOILER
COULD CARRY MAXIMUM LOAD (163 MW). THE UNIT WAS LIMITED TO 135 MW AFTER
A RECENT STACK EMISSION TEST.
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE MONTHS OF AUGUST AND SEPTEMBER.
10/80 A 69.9 100.0 60.9
B 69.9 100.0 60.9
SYSTEM 69.9 100.0 60.9 744 453 453
697
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
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
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THERE WAS ONE FORCED OUTAGE DUE TO PROBLEMS WITH THE AB-
SORBER RECIRCULATION PUMP ON MODULE B. DURING THIS OUTAGE THE WALL WASH
HEADERS WERE REPLACED ON BOTH MODULES.
DURING OCTOBER THE BOILER WAS SHUT DOWN TWICE DUE TO A LACK OF DEMAND.
THIS ACCOUNTED FOR APPROXIMATELY 51 HOURS OF DOWN TIME. ADDITIONAL UNIT
OUTAGE TIME WAS DUE TO INTERCEPT VALVE AND AIR HEATER PROBLEMS.
11/80 A 92.4 100.0 83.4 33.0
B 92.4 100.0 83.4 33.0
SYSTEM 92.4 100.0 83.4 33.0 720 238 238
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WITH THE SCRUBBING SYSTEM WERE
ENCOUNTERED DURING NOVEMBER.
12/80 A 77.9 100.0 31.5 31.5
B 77.9 100.0 31.5 31.5
SYSTEM 77.9 100.0 31.5 31.5 744 234 234 20.3
** PROBLEMS/SOLUTIONS/COMMENTS
DURING DECEMBER AVAILABILITY OF THE FGD SYSTEM WAS LOW DUE TO PLUGGED
VENTURI NOZZLES AND HEADER, WHICH HAD TO BE HIGH-PRESSURE JETTED.
698
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** E5P
t!UMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
iPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
JHEL'. SPECIFIC MATERIAL
I.INET GENERIC MATERIAL
LINFR SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
1IQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
FREINSURE DROP - KPA
SbPl.RFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHIGAN
C
86.
1376.
.200 LB/MMBTU)
.200 LB/MMBTU)
(****** LB/MMBTU)
1798
260
*****
*****
163
COMBUSTION ENGINEERING
******
PEAK
465.77
132.2
130.
******
*******
( 987000 ACFM)
( 270 F)
( 425 FT)
(***** FT)
( 9600 BTU/LB)
9,500 - 9,600
COAL
SUBBITUMINOUS
22330.
4.00
3.0-4.0
22.60
22 - 24
.35
0.3 - 0.4
********
******
0
NONE
0
NONE
WHEELABRATOR-FRYE
90.0
VENTURI TOWER
VARIABLE-THROAT/ADJUSTABLE DRUM
PEABODY-LURGI
STAINLESS S'EEL
AUSTENITIC
ORGANIC
RUBBER
RUBBER LINcD CARBON STEEL & 316L 55
278.5 ( 4420 GPM)
2.7 (20.0 GAL/1000ACF)
3.5 (14.0 IN-H20)
28.3 ( 93.0 FT/S)
116.6 ( 247000 ACFM)
699
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
DETROI" EDISON: ST. CLAIR 6 (CONT.)
iriLET GAS TEMPERATURE - C 132.2
( 270 F)
PERFORMANCE DATA—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/74 SYSTEM
12/74 SYSTEM
1/75 SYSTEM
720
744
** PROBLEMS/SOLUTIONS/COMMENTS
INSTALLATION OF THE F6D SYSTEM WlAS ESSENTIALLY COMPLETED BY THE NOVEMBER,
1974 THROUGH JANUARY 1975 PERIOD.
A FAULTY INSTRUMENT PANEL WHICH
THE MANUFACTURER FOR REPAIR.
TO DATE, THE UTILITY HAS WATER T
FAN HAS BEEN TESTED AND AIR
2/75 SYSTEM
3/75 SYSTEM
4/75 SYSTEM
MAS INCORRECTLY WIRED HAS BEEN RETURNED TO
ESTED ALL THE AUXILIARY EQUIPMENT. THE ID
BALANCE HAS BEEN CHECKED.
672
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
5/75 SYSTEM
6/75 SYSTEM
7/75 SYSTEM
A COLO FLUE GAS RUN WAS SUCCESSFULLY CONDUCTED MARCH 22 AND 23. DURING
THIS PERIOD THE RUBBER-LINED PUMPS WERE REPAIRED AND THE LIMESTONE PREARA-
TION SYSTEM WAS CALIBRATED.
744
720
744
** PROBLEMS/SOLUTIONS/COMMENTS
8/75 SYSTEM
9/75 SYSTEM
THE FIRST HOT FLUE GAS RUN WAS CONDUCTED ON JUNE 22, 1975. THE RUN LASTED
FOR A PERIOD OF 22 HOURS. DURING THIS RUN, THE SCRUBBER WAS PURPOSELY
TRIPPED OFF AT LOADS OF 40 AND 80 PERCENT. THIS WAS PERFORMED TO OBSERVE
IF ANY DETRIMENTAL EFFECTS TO THE STEAM GENERATION OPERATIONS RESULTED.
NONE WERE DETECTED. THE SYSTEM WAS TAKEN OUT OF SERVICE FOLLOWING THIS
GAS RUN TO CORRECT THE FOLLOWING MAJOR OPERATION AREAS:
GAS CIRCUIT: LUGI THROAT POSITIONAL FAILURE; DETERIORATION OF THE
DAMPER SEALS; SEVERE VIBRATIONS; 502 ANALYZERS INOPERATIVE.
LIQUID CIRCUIT: FAILURE OF PH CONTROL SYSTEM; TARGET FLOW METER
TARGETS HAVE BEEN BROKEN OFF; PUMP SEAL WATER LOW FLOW ALARM TRIPS.
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
A SECOND HOT FLUE GAS RUN WAS INITIATED ON AUGUST 6 AND LASTED 27 HOURS.
THE RUN WAS TERMINATED BECAUSE OF A REHEATER THERMOCOUPLE FAILURE. A
SUBSEQUENT INSPECTION OF THE SCRUBBING SYSTEM REVEALED NO APPARENT
ABNORMALITIES OR MALFUNCTIONS.
A THIRD HOT FLUE GAS RUN OF 41 HOURS DURATION WAS COMPLETED OCTOBER 9. THE
MAIN OBJECTIVE OF THIS RUN WAS TO EVALUATE VARIOUS COMPONENTS OF THE FRESH
WATER SPRAY SYSTEM AND EFFECTS ON SYSTEM OPERATION. THE TEST RUN WAS
700
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 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
PREMATURELY TERMINATED BECAUSE OF A BOILER FEED PUMP MALFUNCTION, RESULTING
IN A REDUCED BOILER LOAD CAUSING SUBSEQUENT WEEPING OF THE WASH TRAY.
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
A FOURTH FLUE GAS RUN OF 23 DAYS DURATION WAS TERMINATED DUE TO EXCESSIVE
VIBRATION IN THE I.D. & BOOSTER FAN. ONE OTHER SCRUBBER-RELATED OUTAGE
OCCURRED WHEN THE PACKING OF ONE OF THE SCRUBBER RECIRCULATION PUMPS NEEDED
MAINTENANCE. S02 REMOVAL DURING THIS PERIOD WAS 90 PERCENT AND PARTICULATE
OUTLET LOADING WAS 0.1 IB/1000 IBS OF FLUE GAS FOR 1-3 PERCENT SULFUR COAL.
1/76 SYSTEM 744
2/76 SYSTEM 696
3/76 SYSTEM 744
4/76 SYSTEM 100.0 100.0 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE 30-DAY VENDOR QUALIFICATION RUN AND FINAL ACCEPTANCE TEST WERE
COMPLETED BY MAY 29. THE QUALIFICATION RUN WAS CONDUCTED ON A "HANDS OFF"
BASIS USING PLANT PERSONNEL EXCLUSIVELY. THE SYSTEM WAS IN SERVICE 100
PERCENT OF THE TIME THE BOILER WAS OPERATIONAL. THE FINAL ACCEPTANCE TEST
CONSISTED OF SIX 4-HR. TEST RUNS CONDUCTED IN THE SPACE OF ONE WEEK. THE
S02 REMOVAL EFFICIENCY FOR HIGH SULFUR COAL WAS 90.9 PERCENT. PARTICULATE
REMOVAL ALSO EXCEEDED DESIGN LEVELS. NO MAJOR CHEMICAL OR MECHANICAL-
RELATED PROBLEMS WERE ENCOUNTERED.
5/76 SYSTEM 744
6/76 SYSTEM 720
7/76 SYSTEM 744
8/76 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY IS NOW PREPARING TO CONDUCT A 2 MONTH MINIMUM INTERNAL SCRUBBER
DEMONSTRATION PROGRAM TO ACQUIRE OPERATING DATA AND INFORMATION. FOLLOWING
THE COMPLETION OF THIS PROGRAM THE BOILERS WILL FIRE LOW SULFUR DECKER
COAL (0.3 TO 4.0 PERCENT) TO MEET S02 EMISSION REGULATIONS. THE SCRUBBERS
WILL CONTINUE TO OPERATE IN THE PARTICULATE REMOVAL MODE.
9/76 SYSTEM 720
10/76 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE INTERNAL S02 SCRUBBING DEMONSTRATION PROGRAM COMMENCED ON OCTOBER 14.
THE SCRUBBERS OPERATED CONTINUOUSLY FOR 10 DAYS.
OPERATION ON THE DEMONSTRATION PROGRAM WAS INTERRUPTED BY A FORCED SCRUBBER
OUTAGE RESULTING FROM SCALE AND SOLIDS CARRYOVER FROM THE WASH TRAY AND
MIST ELIMINATOR TO THE SCRUBBER I.D. BOOSTER FAN ASSEMBLY, CAUSING VIBRA-
701
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
PERFORMANCE DATA
PERIOD Mt-DULE AVAILABILITY OPER*BILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
503 PART. HOURS HOURS HOURS FACTOR
TION tHO BALANCE PROBLEMS. IT WAS DECIDED TO SANDBLAST THE FAN TO REMOVE
SOLIDS BUILDUP ON THE FAN ASSEMBLY.
THE UTILITY PLANS TO MODIFY THE COMPONENT'S WASH SYSTEM FOR GREATER FLOW
CAPABILITY AFTER COMPLETION OF THE S02 SCRUBBING PROGRAM. DECO ALSO PLANS
TO CONTINUE PARTICULATE SCRUBBING FOLLOWING THE TERMINATION OF THE S02
PROGRAM BY UNCOUPLING THE SPRAY TOWERS AND MAINTAINING THE PEABODY-LURGI
VENTURI SCRUBBERS IN THE FLUE GAS STREAM. SOME LIMESTONE MAY HAVE TO BE
ADDED TO THE PARTICULATE SCRUBBING SOLUTION IN ORDER TO PREVENT LOW PH
SWINGS AND MINIMIZE THE POSSIBILITY OF ACID CORROSION DAMAGE TO THE
INTERNAL COMPONENTS.
11/76 SYSTEM 80.0 720
** PROBLEMS/SOLUTIONS/COMMENTS
FOLLOWING THE COMPLETION OF SAND BLASTING OPERATIONS TO SCRUBBER'S I.D.
BOOSTER FAN FOR REMOVAL OF SOLIDS BUILD UP, OPERATIONS RESUMED ON NOVEMBER
7 AND CONTINUED THROUGHOUT THE MONTH. THE SYSTEM'S AVAILABILITY INDEX FOR
THE MONTH WAS 80 PERCENT. THE MAJORITY OF THE OUTAGE TIME WAS CONSUMED
PROCURING SAND BLASTING SERVICES. THE OPERATION ITSELF REQUIRED ONLY 8
HOURS.
12/76 SYSTEM 51.0 7V*
** PROBLEMS/SOLUTIONS/COMMENTS
THE S02 DEMONSTRATION PROGRAM CONTINUED THROUGHOUT DECEMBER. THE SYSTEM'S
AVAILABILITY INDEX FOR THE PERIOD WAS 51 PERCENT.
SCRUBBER OUTAGES RESULTED FROM LIMESTONE FEEDER PROBLEMS.
SCRUBBER OUTAGES RESULTED FROM DENSE SLURRY TRAVERSE PUMP PROBLEMS.
SCRUBBER OUTAGES RESULTED FROM DENSE SLURRY TANK AGITATOR MALFUNCTIONS.
PH SAMPLING LINE PLUGGING RESULTED IN SOME OUTAGE TIME.
1/77 SYSTEM .0 744
2/77 SYSTEM .0 672
** PROBLEMS/SOLUTIONS/COMMENTS
THE SOZ DEMONSTRATION PROGRAM WAS OFFICIALLY TERMINATED ON DEC. 31, 1976.
THE SCRUBBER PUNT WAS SHUT DOWN AT THIS POINT AND FLUE GAS WAS BY-PASSED
AROUND THE SYSTEM.
3/77 SYSTEM .0 74*
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINS IN SERVICE, FIRING LOW SULFUR (0.3X) WESTERN COAL.
CURRENT PLANS CALL FOR THE SCRUBBER PLANT TO REMAIN OUT OF SERVICE UNTIL
MID-JUNE FOR DESIGN AND OPERATING MODIFICATIONS. RESUMPTION OF SCRUBBER
OPERATIONS WILL OCCUR IN THE PRIMARY PARTICULATE-REMOVAL MODE. THE
PEABODY-LURGI VENTURI SCRUBBERS AND SPRAY TOWER ABSORBERS WILL REMAIN IN
THE GAS STREAM. SOLUTION WILL BE CIRCULATED THROUGH THE VENTURI'S WASH
TRAYS, AND MIST ELIMINATORS. NO SOLUTION WILL BE CIRCULATED THROUGH THE
SPRAY ZONE OF THE ABSORBER TOWERS. LIMESTONE REAGENT WILL BE AbDED TO THE
SCRUBBING SOLUTION IN ORDER TO PREVENT LOW PH SWINGS AND SUBSEQUENT
MATERIALS DAMAGE TO THE SCRUBBER'S INTERNALS. S02 REMOVAL SHOULD RESIDE
IN THE 35 TO SOX RANGE IN THIS MODE OF OPERATION BECAUSE OF THE SOLUTION'S
ALKALINITY DUE TO THE FLY ASH AND LIMESTONE. ALSO DECO PLANS TO MAINTAIN
70E
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FSD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
A HIGHER L/G RATIO IN THE SCRUBBER MODULES. THIS MODE OF OPERATION IS
PROJECTED TO CONTINUE FOR A ONE TO THREE YEAR PERIOD FOLLOWING THE
MID-JUNE RESTART.
4/77 SYSTEM
5/77 SYSTEM
6/77 SYCJTEM .0
7/77 S'STEM .0
8/77 SYSTEM .0
9/77 SYSTEM .0
10/77 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
744
744
720
744
11/77 SYSTEM
12/77 SYSTEM
1/78 SYSTEM
2/78 SYSTEM
3/78 SYSTEM
4/78 SYSTEM
5/78 SYSTEM
96.0
85.6
90.0
74.6
THE UNIT MAS PULLED OFF LINE IN DECEMBER 1976 AND DID NOT RESTART UNTIL
OCTOBER 1977. WHILE THE UNIT WAS DOWN THE UTILITY INSTALLED BUILDINGS
AROUND PUMPS THAT WERE EXPOSED TO SEVERE WEATHER CONDITIONS.
720
744
744
672
744
720
744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT EXPERIENCED SPRAY HEADER PROBLEMS IN THE ABSORBER TOWER.
BROKEN NOZZLES WERE DISCOVERED.
SOME
THERE WERE SOME I.D. BOOSTER FAN PROBLEMS. THE UTILITY MUST SAND BLAST THE
FAN EVERY 4 TO 5 WEEKS WHEN THE MAGNITUDE OF VIBRATION OF THE FAN BECOMES
EXCESSIVE FROM SCALE FORMATION; HOWEVER, IN THIS INSTANCE THE PROBLEM WAS
A RESULT OF A LOW FAN OIL LEVEL.
THE UTILITY NOW OPERATES 3 RECYCLE TANK AGITATORS. PREVIOUSLY ONLY 2 WERE
OPERATED. IT WAS FELT THAT PART OF THE TANK PLUGGING WAS A RESULT OF
INSUFFICIENT AGITATION.
THE SLURRY SPRAY SURGE TANK ENCOUNTERED CONTINUAL OVERFLOW PROBLEMS WHEN
THE ABSORBER SUMP PUMP WAS OPERATING. THIS WAS BELIEVED TO BE A RESULT OF
A BROKEN SECTION IN THE SPRAY NOZZLE LINES. SPRAY WAS BEING DIRECTED
UPWARD TO THE BOTTOM OF A TRAY INSTEAD OF DOWN, COUNTERCURRENT TO THE
GAS FLOW AS INTENDED.
REHEATER PROBLEMS OCCURRED WITH THE FORMATION OF OIL CLINKERS IN THE
BURNER AREA. IT WAS DISCOVERED THAT THE AIR SUPPLY TO THE BURNER WAS
INSUFFICIENT.
SOME SPRAY HEADER PROBLEMS WERE ENCOUNTERED. THE FRP PIPING WAS RUPTURING.
IT WAS SUSPECTED THAT THE RUPTURES WERE A RESULT OF "WATER HAMMER" I.E.
703
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 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
THE SURGE THAT OCCURRS IN THE PIPE WITH A SUDDEN FLOW RATE CHANGE.
THE SPRAY HEADERS WERE PLUGGING. WHEN THE HEADERS ARE DRAINED {E.G.
SYSTEMS SHUTDOWN) SOME SLURRY SETTLES IN THE HEADER LINES ETC. RINSE LINES
ARE NOW BEING INSTALLED TO FLUSH OUT HEADERS DURING FUTURE SHUTDOWNS.
6/78 SYSTEM 87.9 720
** PROBLEMS/SOLUTIONS/COMMENTS
ONE OF THE BLADES CAME LOOSE FROM AN I.D. BOOSTER FAN AND PASSED THROUGH
THE HOUSING. REPAIRS WERE MADE WITHOUT SERIOUS COMPLICATIONS.
7/78 SYSTEM 96.0 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE INSTALLATION OF RINSE LINES HAS NOT YET BEEN COMPLETED.
PROBLEMS WITH RUPTURED SPRAY HEADER PIPING CONTINUED. IT HAS BEEN POSSIBLE
TO OPERATE THE SCRUBBER WITH THE RUPTURED LINES WITHOUT SERIOUS
CONSE3UENCES. IT IS NOT CRUCIAL THAT REPAIRS BE MADE IMMEDIATELY.
8/78 SVSTEM 90.* 744
9/78 SVSTEM 69.0 720
10/78 SYSTEM .0 744
11/78 SYSTEM .0 720
12/78 SYSTEM .0 744
1/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERIOD RECYCLE TANK AGITATORS WERE BREAKING LOOSE AND SIMILAR
PROBLEMS WERE ENCOUNTERED WITH THE SLURRY STORAGE TANK AGITATORS. THE
SCRUBBING SYSTEM WAS REMOVED FROM SERVICE FROM SEPTEMBER THROUGH JANUARY.
STEADY BEARINGS WERE INSTALLED AT THE BOTTOM OF THE RECYCLE TANK SOLVING
THE RECYCLE TANK AGITATOR PROBLEM. THE SLURRY STORAGE TANK SYSTEM ALREADY
HAD STEADY BEARINGS. THESE WERE REWORKED TO IMPROVE OPERATIONS.
2/79 SYSTEM 672
3/79 SYSTEM 744
*# PROBLEMS/SOLUTIONS/COMMENTS
SOME REHEATER PROBLEMS OCCURRED.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
704
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
DETROIT EDISON: ST. CLAIR 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM IS CURRENTLY DOWN BUT IS EXPECTED TO BE BACK ON LINE SOON. THE
SCRUBBING SYSTEM HAS OPERATED ONLY 1 WEEK SINCE MAY 18, 1979 BECAUSE OF
SUMP PROBLEMS.
THE AGITATOR BEARING SYSTEM WAS POORLY DESIGNED. THE BEARING SYSTEM HAS
NOW BEEN COMPLETELY REDESIGNED. THE AGITATORS HAVE NOW OPERATED 2000 HOURS
ON THE NEW BEARINGS. THE UTILITY WILL PROBABLY DRAIN THE TANK AFTER ABOUT
500 MORE HOURS TO INSPECT AND READJUST THE BEARINGS. THE NEW BEARING
SYSTEM IS COMPOSED OF STAINLESS STEEL PARTS.
100X OF THE ST. CLAIR FLUE GAS PASSES THROUGH THE ESP. BOX OF THAT FLUE
GAS ENTERS THE SCRUBBER. THE UNIT IS REQUIRED TO MEET A 55X OPACITY,
HOWEVER, A VARIANCE HAS BEEN GRANTED ALLOWING A 657. OPACITY UNTIL THE
SCRUBBER IS AGAIN OPERATIONAL. THE UTILITY IS PREPARING TO INSTALL A
NEW ESP WHICH WOULD BE OPERATIONAL IN Z YEARS. WHEN THE NEW ESP IS IN-
STALLED THE SCRUBBING SYSTEM AND OLD ESP WILL BE SCRAPPED. THE UNIT WILL
THEN BE REQUIRED TO MEET A 20X OPACITY.
11/79 SYSTEM 90.0 730
12/79 SYSTEM 90.0 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT CAME BACK ON LINE AROUND MID-NOVEMBER.
NEW DENVER PUMPS WITH EJECTORS WERE INSTALLED TO ASSIST THE SUMP PUMPS
UNTIL THE ESP'S COME ON LINE.
THE ABSORBER PUMPS HAVE BEEN A PROBLEM RESULTING IN A CAPACITY TURNDOWN
TO 225 MW (FROM 230 MW).
ONE OF THE COAL MILLS HAS BEEN DOWN CAUSING LIMITED OPERATIONS.
1/80 SYSTEM 744
2/80 SVSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM OPERATED WITH BETTER THAN SOX AVAILABILITY DURING THE
FIRST QUARTER OF 1980.
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 PUMPS, THE DENVER PUMPS
INSTALLED TO ASSIST THE A-S-H PUMPS NOW CARRY THE ENTIRE LOAD. THE A-S-H
PUMPS DRIVES HAVE BEEN DISCONNECTED. THE SLURRY CIRCULATES THROUGH THE
THE NON-OPERATING A-S-H PUMPS TO THE DENVER PUMPS.
THE CONTINUAL PROBLEMS WITH THE LOUVER BY PASS DAMPERS WAS SOLVED BY DIS-
CONNECTING THE EXTREME LOUVER AT EITHER END. THE DAMPERS OPERATE NOW WITH
12 OF THE 14 LOUVERS. THE UTILITY IS PLEASED WITH RECENT DAMPER
OPERATIONS.
SOME RECENT SCRUBBER OUTAGES RESULTED FROM THE OCCASIONAL UNAVAILABILITY
OF LIMESTONE.
4/80 SYSTEM 720
705
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 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 MAS 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
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS OUT OF SERVICE UNTIL MAY 21 WHEN THE FAN HOUSING REPAIR
WAS COMPLETED. THE SCRUBBER WAS SHUT DOWN AGAIN ON MAY 25 WITH A SCRUBBER
ID FAN BEARING FAILURE.
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS NOT OPERATED THROUGH JUNE BECAUSE PARTS FOR THE SCRUBBER
ID FAN HAD NOT ARRIVED AT THE PLANT. SCRUBBER SERVICE WAS NOT REQUIRED
BECAUSE OF LOW BOILER LOAD.
SCRUBBER REPAIRS AT ST. CLAIR HAVE REQUIRED A GREAT DEAL OF OUTAGE TIME
BECAUSE THE UTILITY DOES NOT STOCK A GREAT DEAL OF PARTS FOR THE SCRUBBER.
THE ST CLAIR 6 SCPUBBER IS SCHEDULED TO BE PERMANENTLY REMOVED FROM SERVICE
IN SEPTEMBER 1981 WHEN THE NEW 100X CAPACITY ESP FACILITY CURRENTLY UNDER
CONSTRUCTION IS COMPLETE. AT PRESENT BOX OF THE FLUE GAS IS SCRUBBED AND
SOX PASSES THROUGH THE ESP. DURING LOW LOAD PERIODS EITHER THE SCRUBBER OR
ESP CAN BE SHUT DOWN.
7/80 SYSTEM
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM DID NOT OPERATE DURING THE JULY THROUGH SEPTEMBER
PERIOD. THE UTILITY IS WAITING ON A UNIT OUTAGE TO PERFORM THE NECESSARY
REPAIRS ON THE BOOSTER FAN AND TO REPAIR SOME MINOR SCRUBBER INTERNAL
PROBLEMS.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
*=.-. PROBLEMS/SOLUTIONS/CO 1MENTS
THE BOOSTER FAN WAS REPAIRED DURING THE OCTOBER THROUGH DECEMBER PERIOD.
HOWEVFR, THE RECIRCULATION TANK AGITATORS ARE UNAVAILABLE AND REQUIRE RE-
PAIRS. THE UTILITY IS PRESENTLY DECIDING WHETHER THE SCRUBBING SYSTEM
REPAIRS WILL BE MADE DURING THE NEXT SCHEDULED OUTAGE IN SEPTEMBER 1981 OR
BE DECOMMISSIONED.
706
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PUNT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
»** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
J.UPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
IINER SPECIFIC MATERIAL
CAS CONTACTING DEVICE TYPE
MUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLEY GAS FLOW RATE - CU.M/S
INLFT GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
MINNESOTA POWER & LIGHT
CLAY BOSWELL
COHASSET
MINNESOTA
E
258.
1720.
******
350
364
347
350
350
( .600 LB/MMBTUJ
( 4.000 LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
613.47 (1300000 ACFM)
123.3 ( 254 F)
213. ( 700 FT)
CONCRETE
7.9 ( 26.0 FT)
COAL
SUBBITUMINOUS
19538.
9.00
4.81-16.0
26.00
24.0-28.0
.92
0.5-1.5
.01
0.0-0.07
( 8400 BTU/LB)
7500-9900
0
NONE
IMPINGEMENT TOWER
KREBS ENGINEERS
18 HIGH X 126 WIDE X 52 LON6
STAINLESS STEEL
AUSTENITIC
NONE
N/A
316L SS
1
714.4
1.1
1.0
2.4
613.5
123.3
.0
(11340 GPM)
(8.3 GAL/1000ACF)
(4.0 IN-H20)
( 8.0 FT/S)
(1300000 ACFM)
( 254 F)
707
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
MINNESOTA POWER & LIGHT: CLAY BOSWELL 3 (CONT.)
PARTICLE REMOVAL EFFICIENCY - X 98.7
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/73 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN MAY 1973 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/DRY ZONE, AND
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRUBBER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BURNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW SATURA-
TION WITH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS INCLUDED WASHING OF THE WET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PLACE OF WASHING WAS ATTEMPTED BUT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEW LOW-VELOCITY
STACK.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM 100.0 100.0 90.3 720 650 650 60.2
8/80 SYSTEM 100.0 100.0 78.0 744 580 580 52.3
9/80 SYSTEM 100.0 100.0 84.0 744 625 625 54.8
708
-------
EPA UTILITY fGD SURVEY: OCTOBER - DECEMBER 1980
MINNESOTA POWER * LIGHT: CLAY EOSWELL 3 (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 OPERATIONAL PROBLEMS WERE REPORTED FOR THE JULY THROUGH SEPTEMBER
PERIOD.
744 639 639 63.3
720 587 587 64.6
744 607 607 60.9
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER PROBLEMS WERE ENCOUNTERED DURING
THE FOURTH QUARTER 1980.
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
85.9
81.5
81.6
709
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICUL^TE EMISSION LIMITATIOT - N6/J
SOS EMISSION LIMITATION - NG/J
NOX EMS3ION LIMITATION - NG/J
NET PI ANT GENERATING CAPACITY - MM
GROSS UN:T GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
CESIGN BOILER FLUE GAS FLOW - CU.M/S
EOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
F'JEL GRADE
A/ERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
R>.NGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - •/.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
R/NGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
R/NGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
MINNESOTA POWER & LIGHT
SYL LASKIN
1
AURORA
MINNESOTA
E
258.
1720.
******
( .600 LB/MMBTU)
( 4.000 LB/MMBTU)
(*****# LB/MMBTU)
116
62
57
58
58
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 t 300000 ACFM)
171.1 ( 340 F)
91. ( 300 FT)
CONCRETE
3.2 ( 10.5 FT)
( 8800 BTU/LB)
7509-9923
COAL
SUBBITUMINOUS
20469.
9.00
4.81-16.0
26.70
24.0-28.0
1.00
.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
IMPINGEMENT TOWER
KREBS ENGINEERS
34 WIDE X 18 HIGH X 23 LONG
STAINLESS STEEL
AUSTENITIC
NONE
N/A
316 ELC SS
1
151.2 (
1.1 (
.6 (
2.1 (
137.4 (
2400 GPM)
8.3 GAL/1000ACF)
2.5 IN-H20)
7.0 FT/S)
291160 ACFM)
710
-------
EPA UTILITY FSD SURVEY: OCTOBER - DECEMBER 1980
MINNESOTA POWER & LIGHT: SYL USKIN 1 (CONT.)
INLET 6AS TEMPERATURE - C 171.1 ( 340 F)
S02 REMOVAL EFFICENCY - '/. .0
PARTICLE REMOVAL EFFICIENCY - X 97.8
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FSD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
— — — — — -. ______ ____________ ___________ ____________ ___________ v____ _____ _____ ______ _____ ______
6/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1971 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/DRY ZONE, AND
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRUBBER. DUE TO THE
CALCJUM-RICH ASH, CHARACTERISTIC Or THE WESTERN COAL BURNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBriNG SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW SATURA-
TION HTH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS IhCLUDED WASHING OF THE WET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLf.M. THE USE OF SOOT BLOWERS IN PLACE OF WASHING WAS ATTEMPTED BUT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEW LOW-VELOCITY
STACK.
THE PROBLEMS AT SYL USKIN ARE NOT AS SEVERE AS THE PROBLEMS AT CLAY
BOSWELL DUE TO THE FACT THAT THE RECYCLE LOOP IS NOT CLOSED TO THE SAME
EXTENT. THE MIST CARRYOVER PROBLEM IS LESS SEVERE OWING TO OPERATION OF
THE UNIT AT PARTIAL LOAD RESULTING IN A LOWER STACK VELOCITY.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION HAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM 100.0 100.0 100.0 56.6 744 421 421 25.2
8/80 SYSTEM 100.0 100.0 100.0 19.0 744 140 140 12.0
711
-------
EPA UTILITY FSD SURVEY: OCTOBER - DECEMBER 1980
MINNESOTA POWER i LIGHT: SYL LASKIN 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SQZ PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO BOILER OR FGD-RELATED PROBLEMS WERE ENCOUNTER-
ED DURING JULY AND AUGUST. LOW UTILIZATION FACTORS WERE DUE TO A LACK
OF POWER DEMAND.
9/80 SYSTEM 100.0 100.0 100.0 4.4 720 33 33 1.9
** PROBLEMS/SOLUTIONS/COMMENTS
NO SCRUBBER OUTAGES OCCURRED DURING SEPTEMBER. THE LOW UTILIZATION FACTOR
WAS AGAIN THE RESULT OF A LACK OF DEMAND FOR POWER.
744 o 744 .0
720 175 175 10.2
744 477 477 23.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS OCCURRED DURING
THE FOURTH QUARTER 1980. LOW UTILIZATION FACTORS WERE CAUSED BY A LACK
OF POWER DEMAND.
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
.0
24.3
64.1
712
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PUNT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/F6D - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/S
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
*# MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMT ER
TYPI:
** ESP
NjMF.ER
TYPE
** PA'ITICLE SCRUBBER
NMMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NJMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
It LET GAS FLOW RATE - CU.M/S
MINNESOTA POWER & LIGHT
SYL LASKIN
2
AURORA
MINNESOTA
E
258.
1720.
******
( .600 LB/MMBTU)
( 4.000 LB/MMBTU)
(*#»*** LB/MMBTU)
116
62
57
58
58
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 ( 300000 ACFM)
171.1 ( 340 F)
91. ( 300 FT)
CONCRETE
3.2 ( 10.5 FT)
( 8800 BTU/LB)
7509-9923
COAL
SUBBITUMINOUS
20469.
9.00
4.81-16.0
26.70
24.0-28.0
1.00
.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
IMPINGEMENT TOWER
KREBS ENGINEERS
34 WIDE X 18 HIGH X 23 LONG
STAINLESS STEEL
AUSTENITIC
NONE
N/A
316 ELC SS
1
151.2 (
1.1 (
.6 (
2.1 (
137.4 (
2400 GPM)
8.3 6AL/1000ACF)
2.5 IN-H20)
7.0 FT/S)
291160 ACFM)
713
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
MINNESOTA POWER & LIGHT: SYL USKIN 2 (CONT.)
INLET GAS TEMPERATURE - C 171.1 ( 340 F)
502 REMOVAL EFFICENCY - X .0
PARTICLE REMOVAL EFFICIENCY - X 97.8
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1971 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/DRY ZONE AND
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCRUBBER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BURNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW SATURA-
TION WITH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS INCLUDED WASHING OF THE WET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PUCE OF WASHING WAS ATTEMPTED BUT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEW LOW-VELOCITY
STACK.
THE PROBLEMS AT SYL LASKIN ARE NOT AS SEVERE AS THE PROBLEMS AT CLAY
BOSWELL DUE TO THE FACT THAT THE RECYCLE LOOP IS NOT CLOSED TO THE SAME
EXTENT. THE MIST CARRYOVER PROBLEM IS LESS SEVERE OWING TO OPERATION
OF THE UNIT AT PARTIAL LOAD RESULTING IN A LOWER STACK VELOCITY.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION MAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 7*4
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/CO1MENTS
THE UTILITY REPORTED THAT NO SCRU3BER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENER/L MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM 100.0 100.0 100.0 24.5 744 182 182 12.3
714
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
MINNESOTA POWER fc LIGHT: SYL LASKIN 2 tCONT.)
PERFORMANCE DATA
PERIOD "10DULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
502 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER DID NOT OPERATE MOST OF JULY DUE TO A BOILER INSPECTION. NO
PROBLEMS WERE ENCOUNTERED WITH THE F6D UNIT.
8/80 SYSTEM 100.0 100.0 100.0 15.0 744 115 115 5.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER OPERATED ONLY 115 HOURS DURING AUGUST DUE TO A LACK OF DEMAND.
9/80 SYSTEM 100.0 100.0 100.0 5.2 720 39 39 2.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORT THAT NO SCRUBBER OUTAGES OCCURRED DURING SEPTEMBER.
THE LOW UTILIZATION FACTOR RESULTED FROM A LACK OF DEMAND FOR
POWER.
744 195 195 15.0
720 547 547 37.2
744 527 527 34.9
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS WERE ENCOUNTERED
DURING THE FOURTH QUARTER.
10/80 SYSTEM
11/80 SYSTEM
12/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
26.3
76.0
70.8
715
-------
EPA ITILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UMIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
#* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
R£HGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - V.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY -7.
** PARTICLE SCRUBBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
MONTANA-DAKOTA UTILITIES
LEWIS & CLARK
1
SIDNEY
MONTANA
******
86.
430.
******
50
55
50
SZ
55
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
153.37
215.6
76.
NONE
( .200 LB/MMBTU)
( 1.000 LB/MMBTU)
(****** LB/MMBTU)
( 325000 ACFM)
( 420 F)
( 250 FT)
( 14.5 FT)
COAL
LIGNITE
15003. ( 6450 BTU/LB)
6200-6700
7.80
7.2-9.3
36.20
34.25-38.16
.61
.32-1.43
.03
******
MULTICLONES
WESTERN PRECIPITATION
106.2 ( 225000 ACFM)
176.7 ( 350 F)
.4 (1. IN-H20)
85.7
VENTURI TOWER
RESEARCH-COTTRELL
10.5 DIA X 27
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
CARBON STEEL WITH 1" NORTON CA-308
1
212.6 ( 3374 GPM)
1.7 (13.0 GAL/1000ACF)
3.2 (13.0 IN-H20)
148.0 ( 313730 ACFM)
215.6 ( 420 F)
716
-------
EPA UTILITY FCO SURVEY: OCTOBER - DECEMBER 1980
MONTANA-DMKOTA UTILITIES-- LEWIS & CLARK i ICONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEkABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING A SCHEDULED BOILER OUTAGE GENERAL SCRUBBER MAINTENANCE WAS
PERFORMED.
11/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING NOVEMBER THE SCRUBBER WAS TEMPORARILY BYPASSED TO ALLOW FOR REPAIRS
NECESSITATED BY A LEAK IN THE FLOODED DISC SCRUBBER.
12/79 SYSTEM 74*
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER PROBLEMS OCCURRED DURING DECEMBER.
1/80 SYSTEM 744
2/80 3YSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
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
EXTERIOR CARBON STEEL LINED COLUMN WALL SUPPORTING THE FLOODED DISC WERE
ERODING, FILLING THE INNER CHAMBER WITH SLURRY AND ULTIMATELY RENDERING THE
DISC MOVEMENT MECHANISM INOPERATIVE. THE UTILITY HAS MANAGED TO KEEP THE
SCRUBBER OPERATING AS A STOP-GAP MEASURE BETWEEN UNIT SHUTDOWNS BY INSERT-
ING A GARDEN HOSE IN THE COLUMN HOLES AND CONTINUALLY FLUSHING THE INNER
CHAMBER. THE UTILITY HAS HAD SOME SUCCESS IN OTHER EROSION AREAS BY
MAKING REPAIRS WITH A HASTELLOY MATERIAL. PLANS ARE BEING MADE TO JACKET
THE ENTIRE DISC SUPPORT COLUMN WITH HASTELLOY G.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** 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 YEARS. 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 BEEN 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
717
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
MONTANA-DAKOTA UTILITIES: LEWIS & CLARK 1 (CONT.J
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
SULFUR CONTENT. WHEN THE SULFUR CONTENT IS RELATIVELY HIGH (0.7 TO l.OX AT
LEWIS AND CLARK) THE PLUGGING DOES NOT OCCUR. LIMESTONE IS ADDED AS RE-
QUIRED TO PREVENT THE OCCURRANCE OF LOW PH LEVELS. WHEN THE SULFUR CONTENT
FALLT; TO THE o.sx RANGE THE PH RISHS AS A RESULT OF THE ALKALINE CONSTITU-
ENTS IN THE FLY ASH UNTIL SOFT SCALE PLUGGING RESULTS. THE UTILITY HAS
CONSIDERED ADDING ACID TO STABILIZE THE PH WHEN THE COAL SULFUR CONTENT
DROPS.
7/80 SYSTEM 744
*-. PROBLEMS/SOLUTIONS/CUMMENTS
DURING JULY TWO WEEKS OF DOWN TIME WAS NECESSARY TO REPLACE THE MIST
ELIMINATOR LINER.
THE PROBLEM WITH THE FLOODED DISC BUILDUP MENTIONED EARLIER CONTINUED.
THE UTILITY PERFORMS THE NECESSARY REPAIRS IN THREE TO FOUR HOURS WHEN
THIS OCCURS.
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH SCRUBBING
OPERATIONS DURING THE MONTHS OF AUGUST AND SEPTEMBER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH THE
SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER PERIOD.
SCRUBBING OPERATIONS WERE SHUTDOWN FOR ONE WEEK DURING THE LAST PART OF
OCTOBER FOR A SCHEDULED MAINTENANCE OVERHAUL AND NO PROBLEMS WERE FOUND.
718
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UHIT GENERATING CAPACITY W/FGD - MM
NET UHIT GENERATING CAPACITY WO/FGD - MW
EQUIV/LENT SCRUBBED CAPACITY - MW
** UKIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
TOILER SERVICE LOAD
CESIGN BOILER FLUE GAS FLOW - CU.M/S
EOILER FLUE GAS TEMPERATURE - C
JTACK HEIGHT - M
i,TAC", SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVEI'AGE HEAT CONTENT - J/'J
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
R4NGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
R4NGE MOISTURE CONTENT - '/.
AVERAGE SULFUR CONTENT - '/.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7,
RANGE CHLORIDE CONTENT - '/.
*** PARTICLE CONTROL
** PA3TICLE SCRUBBER
NUMBER
6£NERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LT.NER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
IK LET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
SCa REMOVAL EFFICENCY - 7.
PARTICLE REMOVAL EFFICIENCY - 7.
PACIFIC POWER & LIGHT
DAVE JOHNSTON
4
GLENROCK
WYOMING
******
90. (
215. (
******
.210 LB/MMBTU)
.500 LB/MMBTU)
(****** LB/MMBTU)
330
327
330
330
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
707.85 (1500000 ACFM)
132.2 ( 270 F)
76. ( 250 FT)
******* (***** FT)
( 7430 BTU/LB)
5,000-9,000
COAL
SUBBITUMINOUS
17282.
12.00
******
26.00
.50
.04
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CHEMICO
CARBON STEEL
AISI 1110
ORGANIC
POLYESTER
( 6500 GPM)
(13.0 GAL/1000ACF)
(15.0 IN-H20)
( 694000 ACFM)
( 275 F)
409.5
1.7
3.7
327.5
135.0
40.0
99.7
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
—— — —————— —— —— —_—.... « .. _—..__.. _
4/72 SYSTEM
719
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PACIFIC POWER & LIGHT: DAVE JOHNSTON
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER I960
PACIFIC POWER & LIGHT: DAVE JOHNSTON <* (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 UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH THE
SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER PERIOD.
7Z1
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
** ESP
TYPE
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
KUMBER OF CONTACTING ZONES
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
******
******
******
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
190
183
*****
190
COMBUSTION ENGINEERING
PULVERIZED COAL
******
******** C******* ACFM)
******* (**** F)
213. ( 700 FT)
CONCRETE
( 11700 BTU/LB)
COAL
******
27214.
14.00
******
6-7
2.00
********
COLD SIDE
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CARBON STEEL
AISI 1110
2
PERFORMANCE DATA
PERIOC 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
100.0
96.0
100.0
83.6
80.1
87.4
744 622 622
720 601 577
744 650 650
*•'• PROBLEMS/SOLUTIONS/CC^IMENTS
DURING THIS PERIOD ONLY ONE SCRUBBER RELATED OUTAGE OCCURRED. THE OUTAGE
WAS PCS AN ID FAN INSPECTION WHICH LASTED ONE DAY.
1/80 SYSTEM
100.0
100.0
100.0
744 744
744
722
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/80 SYSTEM 94.3 95.8 94.3 696 685 656
3/80 SYSTEM 100.0 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 ONLY ONE SCRUBBER OUTAGE OCCURRED. IN
FEBRUARY OUTAGE TIME WAS NECESSARY TO REPAIR A SLURRY RECYCLE LINE LEAK.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
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.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 MW) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM
PIPING.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT W1E
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTIC'JLATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UN IT GENERATING CAPACITY W/FGD - MW
NET UN:.T GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BCILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BCILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
S^ACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
******
******
******
1348
190
183
*****
190
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
******
******** (******* ACFM)
******* (**** F)
213. ( 700 FT)
CONCRETE
******* (***** FT)
COAL
******
27214.
14.00
******
********
6-7
2.00
******
********
******
( 11700 BTU/LB)
******
*** PARTICLE CONTROL
** ESP
TYPE
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
NUMBER OF CONTACTING ZONES
COLD SIDE
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CARBON STEEL
AISI 1110
2
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
96.4
100.0
97.0
88.9
100.0
744 722 722
720 664 640
744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
A ONE DAY OUTAGE OCCURRED, DUE TO A FAN LINING PROBLEM. NO OTHER
SCRUBBER UNIT PROBLEMS WERE ENCOUNTERED DURING THE PERIOD.
1/80 SYSTEM
95.4
96.4
95.4
744 736
710
724
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOM/C ELECTRIC POWER: DICKERSON 2 (CONT.)
PERFORMANCE DATA
PERIOD MHDULE AVAILABILITY OPEF.ABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*•> PROBLEMS/SO LUTIONS/Cf.MMENTS
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 100.0 100.0 100.0 696 696 696
3/80 SYSTEM 96.9 96.9 96.9 744 744 721
** PROBLEMS/SOLUTIONS/COMMENTS
IN MARCH THE SCRUBBER WAS DOWN FOR A SCRUBBER LINING WARRANTY INSPECTION.
NO REPAIR WORK WAS NECESSARY.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
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
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS WERE REPORTED.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 MW) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM
PIPING.
725
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT DUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMSSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PI ANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UMT GENERATING CAPACITY W/FGD - MW
NET Ut.'IT GENERATING CAPACITY HO/FGD - MW
EQUIWLENi SCRUBBED CAPACITY -- MW
** UNIT DATA - BOILER AND STAtK
BOI.ER SUPPLIER
BOIi.ER TYPE
EOI!.ER SERVICE LOAD
CFS^GN BOILER FLUE GAS FLf.W - CU.M/S
BOIuER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FJEL GSADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - '/.
AVERAGE SULFUR CONTENT - V.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - •/.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER SPECIFIC MATERIAL
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
******
688.
******
548
190
178
182
95
(****** LB/MMBTU)
( 1.600 LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
278.42 ( 590000 ACFM)
126.1 ( 259 F)
213. ( 700 FT)
CONCRETE
*******
(***** FT)
( 11700 BTU/LB)
******
COAL
BITUMINOUS
£7214.
14.00
******
********
6-7
2.00
******
********
******
0
NONE
0
NONE
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CHEMICO
CARBON STEEL
AISI 1110
FIBER-REINFORCED POLYESTER
2.7 (20.0 GAL/1000ACF)
2.7 (11.0 IN-H20)
139.2 ( 295000 ACFM)
126.1 ( 259 F)
99.0
726
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOURS HOURS FACTOR
9/73 SYSTEM 720
10/73 SYSTEM 744
11/73 SYSTEM 720
12/73 SYSTEM 744
1/74 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
PROBLEMS DURING THIS PERIOD RANGED FROM CORROSION LEAKS IN EXPANSION JOINTS
TO PROBLEMS IN MATERIAL HANDLING EQUIPMENT, FEEDING AND SLAKING OF MGO,
PLUGGING IN THE MGO MIX TANK AND SUCTION LINES TO THE MGO MAKE-UP PUMPS.
2/74 SYSTEM 672
3/74 SYSTEM 744
4/74 SYSTEM 720
** PROBLEMS/SOLUTIONS/CIWIENTS
MAINTENANCE AND W~ 'FICATIONS WERE PERFORMED ON THE SYSTEM. THE MAJOR
SYSTEM REVISION MAUE DURING THIS PERIOD WAS THE ADDITION OF A PRE-MIX TANK
IN THF MGO SYSTEM.
4/74 SYSTEM 720
5/74 SYSTEM 744
6/74 SYSTEM 720
7/74 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
LIMITED OPERATION OCCURRED BECAUS' «!;E UTILITY DID NOT HAVE ACCESS TO THE
EPA CALCINING FACILITY AT THE ESSEX CHEMICAL COMPANY SULFURIC ACID PLANT.
BY THE EN'D OF JUNE 1974, ALL THE MGO AT DICKERSON HAD BEEN USED AND A SILO
PLUS THREE CARS WERE FULL OF MGS03.
8/74 SYSTEM 744 87
9/74 SYSTEM 720
10/74 SYSTEM 744
11/74 SYSTEM 720
12/74 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERIOD THE SYSTEM GENERALLY OPERATED AT 75 PERCENT OF THE
DESIGN GAS
1/75 SYSTEM
727
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
PROBLEMS DEVELOPED IN THE BUCKET ELEVATOR TRANSPORTING THE MGS03 FROM THE
DRYER TO THE STORAGE SILO.
2/75 SYSTEM 672
3/75 SYSTEM 744
ft/75 SYSTEM 720
5/75 SYSTEM 744
6/75 SYSTEM 720
7/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT NO. 3 WAS TAKEN OUT OF SERVICE FOR AN 8 TO 12 WEEK TURBINE OVERHAUL.
THE SCRUBBER WAS INSPECTED, MAINTENANCE AND MODIFICATIONS WERE MADE.
8/75 SYSTEM 744
*# PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM CONSISTS OF A SINGLE, TWO-STAGE SCRUBBER/ABSORBER, WHICH
INCORPORATES AN ADJUSTABLE-THROAT VENTURI SCRUBBER FOR PARTICULATE REMOVAL
AND A SECOND STAGE ABSORBER WITH A FIXED VENTURI TO REMOVE S02. THE LIQUOR
STREAMS FOR BOTH STAGES ARE SEPARATE AND OPERATE IN A CLOSED-LOOP MODE.
UNTIL MID-1975 THE MAGNESIUM SULFITE GENERATED WAS TRANSFERRED TO AN EPA
FINANCED FACILITY AT THE ESSEX CHEMICAL COMPANY SULFURIC ACID MANUFACTURING
PLANT IN RUMFORD, RHODE ISLAND WHEFE MAGNESIUM OXIDE UAS REGENERATED AND
S02 FROM THE REGENERATION PROCESS HAS CONVERTED TO SULFURIC ACID. THE
RUMFCRD FACILITY HAS SINCE BEEN CLOSED DOWN.
CONSTRUCTION WAS COMPLETED IN AUGUST AND THE SYSTEM STARTED UP IN SEPTEMBER
1973. DURING INTERMITTENT OPERATIONS FOR SHAKEDOWN THROUGH JANUARY 1974,
THE SYSTEM'S LONGEST CONTINUOUS RUN WAS 271 HOURS. THE SYSTEM HAS RE-
STARTED FROM JULY THROUGH DECEMBER 1974, AND AGAIN ON AUGUST 11, 1975, FOR
APPROXIMATELY 87 HOURS.
FGD UNIT OUTAGES WERE CAUSED PRIMARILY BY PIPE AND PUMP CORROSION AND
MAJOR TURBINE OVERHAUL OF THE BOILER. PARTICULATE AND S02 REMOVAL
EFFICIENCY GUARANTEES WERE CORROBORATED DURING OPERATIONAL PHASES.
THE FGD SYSTEM WAS RESTARTED IN AUGUST. STEAM WAS LOST TO THE MGO MIX
TANK, RESULTING IN A VERY MOIST PRODUCT FROM THE CENTRIFUGE. CAKING IN THE
DRYER OCCURRED. AT THIS POINT, THE UTILITY DECIDED TO TEST ONLY THE FIRST-
STAGE OF THE SCRUBBING SYSTEM, TAKING GAS AHEAD OF THE PRECIPITATOR. FGD
OPERATION AT DICKERSON TERMINATED AT THIS POINT.
THE REMAINING SUPPLY OF MAGNESIUM OXIDE, ABOUT 100 TONS (10 DAYS), HAS
BEEN DEPLETED, AND THE DICKERSON UNIT HAS BEEN TERMINATED AS A FGD SYSTEM.
9/75 SYSTEM 720
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
1/76 SYSTEM 744
728
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/76 SYSTEM 696
3/76 SYSTEM " 744
4/76 SYSTEM 720
5/76 SYSTEM 744
6/76 SYSTEM 720
7/76 SYSTEM 744
8/76 SYSTEM 744
9/76 SYSTEM 720
10/76 SYSTEM 744
11/76 SYSTEM 720
12/76 SYSTEM 744
1/77 SYSTEM 744
2/77 SYSTEM 672
3/77 SYSTEM 744
4/77 SYSTEM 720
5/77 SYSTEM 744
6/77 SYSTEM 720
7/77 SYSTEM 744
8/77 SYSTEM 744
9/77 SYSTEM 720
10/77 SYSTEM 744
11/77 SYSTEM 720
12/77 SYSTEM 744
1/78 SYSTEM 744
2/78 SYSTEM 38.0 38.0 38.0 672 672 252
*>t PROBLEMS/SOLUTIONS/CO 1MENTS
THERE HAVE BEEN MANY MAINTENANCE PROBLEMS AND PROBLEMS WITH LINER FAILURES.
SINCE SHIFTING FROM S02 TO PARTICULATE SCRUBBING ONLY, PLUGGING PROBLEMS
HAVE NOT OCCURRED. LOW PH HAS CAUSED CORROSION KHICH WAS AGGRAVATED BY
PARTICULATE ERROSION. THE UTILITY WILL PROBABLY RELINE WITH A FLAKE GLASS
TYPE LINER. NO CHEMICALS (E.G. LIME) ARE ADDED TO THE CIRCULATING LIQUOR
FOR PH BALANCE.
OUTAGE TIME WAS CAUSED BY LEAK REPAIRS IN SLURRY PIPING.
3/78 SYSTEM 21.0 22.0 21.0 744 717 156
729
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME WAS DUE TO RUBBER LINING FAILURE IN THE RECYCLE PUMP DISCHARGE
LINE.
4/78 SYSTEM 80.7 79.8 76.4 720 689 550
** PROBLEMS/SOLUTIONS/COMMENTS
26 HOURS OF OUTAGE TIME WERE DUE TO SMALL LEAKS IN PIPING.
5/78 SYSTEM 84.5 82.7 74.0 744 666 551
** PROBLEMS/SOLUTIONS/COMMENTS
A LEAK OCCURRED IN A MIST ELIMINATOR DRAIN.
THERE WAS A LEAK IN A BLEED LINE FOR THE SCRUBBER RECYCLE CIRCUIT.
OUTAGE TIME WAS REQUIRED FOR BLEED LINE REPLACEMENT.
6/78 SYSTEM 100.0 90.1 68.7 720 549 495
7/78 SYSTEM 100.0 .0 .0 744 16 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE VENTURI SCRUBBER HAD AN AVAILABILITY OF 100X FOR JUNE AND JULY. THE
ONLY VENTURI OUTAGE TIME WAS IN JUNE. THE OUTAGE TIME WAS REQUIRED TO
TIE IN EQUIPMENT COMMON TO THE NEW UNIT AND UNIT 3.
THE BOILER WAS DOWN IN JULY FOR AN OVERHAUL.
THE REASON VENTURI HOURS CAN BE LOWER THAN BOILER HOURS WHEN THE VENTURI
HAS A 100X AVAILABILITY IS BECAUSE THE VENTURI IS NOT OPERATED UNDER LOW
LOAD CONDITIONS.
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
5/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
SCRUBBER OUTAGE HOURS SINCE SEPTEME.ER 1978 (I.E. SEPTEMBER 1978 THROUGH
MAY .>0, 1979) TOTAL 140. THE UTILITY INDICATED THAT IT IS NO LONGER ALLOW-
ABLE TO BYPASS THE SCRUBBER WHEN PROBLEMS OCCUR, CLEANING THE PARTICULATE
MATTER SOLELY WITH THE ESP. THE UTILITY MUST DROP THE BOILER LOAD SO THE
730
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOMA: ELECTRIC POWER: DICKERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION '/. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
UNIT REMAINS IN COMPLIANCE.
THERE HAVE BEEN NO PROBLEMS REPORTED FOR THE LAST FEW MONTHS. THE UTILITY
IS KEEPING AHEAD OF PROBLEMS WITH A CONSCIENTIOUS INSPECTION AND MAINTEN-
ANCE PROGRAM.
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 98.6 95.4 744 720 710
** PROBLEMS/SOLUTIONS/COMMENTS
A TEN HOUR OUTAGE OCCURRED FOR REPAIRS OF A LEAD LINE LEAK.
11/79 SYSTEM 95.2 88.8 720 672 640
** PROBLEMS/SOLUTIONS/COMMENTS
IN NOVEMBER, 8 HOURS OUTAGE TIME WAS REQUIRED TO REPAIR A LEAK IN A
RECYCLE LINE.
12/79 SYSTEM 96.1 93.5 744 724 696
** PROBLEMS/SOLUTIONS/COMMENTS
AN OUTAGE FOR GENERAL INSPECTION TOOK PLACE DURING DECEMBER.
1/80 SYSTEM 78.7 88.2 78.7 744 664 586
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE SCRUBBER WAS DOWN TO REPAIR THE FLAKEGLASS LINING.
2/80 SYSTEM 100.0 100.0 100.0 696 696 696
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
6/80 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.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
731
-------
EPA UFIMTY FGD SURVEY: OCTOBE ? - DECEMBER 1980
POTOMAC FLECTRIC POWER: DICXERSON 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY HAS NOT FIGURED OUT THE DEPENDABILITY FIGURES AS YET.
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY WAS REDUCED TO 1/2 LOAD DURING PART OF THE PERIOD DUE
TO THE NECESSARY PATCHING OF THE SCRUBBER LINING. THE UTILITY IS PRESENTLY
STUDYING THE POSSIBILITY OF REPLACING THE FLAKEGLASS LINER WITH A RUBBER
LINER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 KW) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM
PIPING.
UNIT 3 WILL BE SHUTDOWN ON FEBRUARY 2, 1981 TO REPLACE THE FLAKEGLASS
LINING.
732
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATOR" CLASSIFICATION
PARTICULAR EMISSION LIMITATION - N6/J
S02 EMIS!ION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS JN1T GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W, FGD - MW
NET UNTT GENERATING CAPACITY WO/FGD - MW
EQUIVA.ENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
B'JILER TYPE
BOILER SERVICE LOAD
D£SIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
R/NGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - '/.
AVERAGE SULFUR CONTENT - 7.
RAs'GE SULFUR CONTENT - 7.
AVcRAGE CHLORIDE CONTENT - '/.
PAUSE CHLORIDE CONTENT - 7.
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
PUBLIC SERVICE OF COLORADO
ARAPAHOE
DENVER
COLORADO
( .100 LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
43.
******
******
*****
112
109
*****
112
******
PULVERIZED COAL
******
245.39 ( 520000 ACFM)
143.9 ( 300 F)
****** (**** FT)
******
******* (***** FT)
COAL
SU3BITUMINOUS
23725.
9.30
******
13.70
******
.95
0.6-0.95
.01
******
COAL
BITUMINOUS
23493.
12.50
******
11.20
******
.65
******
.01
******
( 10200 BTU/LB)
******
( 10100 BTU/LB)
******
0
NONE
PACKED TOWER
MOABILE BED PACKING
733
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LIHER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L'G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
IMLET GAS FLOW RATE - CU.M/S
ISLET GAS TEMPERATURE - C
SD2 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL GRIDS, PLASTIC SPHERES
3
7.5 (56.0 GAL/1000ACF)
3.0 (12.0 IN-H20)
3.4 ( 11.0 FT/S)
345.4 ( 520000 ACFM)
151.7 ( 305 F)
30.0
93.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OFHRABILITY RELIABILITY UTILIZATION
'/. REMOVAL PER BOILER FGD CAP.
SQZ PART. HOURS HOURS HOURS FACTOR
9/77 SI STEM
** PROBLEMS/SOLUTIONS/CO-1MENTS
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
SINCE STARTUP IN SEPTEMBER 1977 SCALING AND PLUGGING AT THE WET/DRY ZONE,
ON THE FIRST STAGE GRIDS, AND IN THE REHEATERS HAVE BEEN THE MOST PROMINENT
PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL ADDITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSFHATED ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. BLOUOO'.IN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES, NO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUMULATION.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, ERCT '; OF LINING AND CORROSIVE FAILURE OF REHEATERS. THE
EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT IN THE
RECIRCULATING PUMPS.
744
720
744
** PROBLEMS/SOLUTIONS/COMMENTS
DURINS THE FOURTH QUARTER REHEATER FAILURES OCCURRED.
LEAKAGE IN THE INLINE STEAM TUBES .iAS BEEN ENCOUNTERED.
IS KNOWN TO OCCUR AFTER LEAKS ARE EXPERIENCED.
CORROSION
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
THE PRIMARY PROBLEM WITH THE SYSTEM IS THE INABILITY TO ISOLATE MODULES.
IF A PROBLEM OCCURS NO MODULE MAINTENANCE CAN BE PERFORMED UNLESS THE
UNIT LOAD IS CUT BACK OR THE UNIT IS SHUT DOWN.
744
696
744
** PROBLEMS/SOLUTIONS/CCMMENTS
THE MODULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST QUARTER OF 1980.
USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED. THE PROGRAM FOR RE-
PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY. THE UNIT IS SHUTDOWN
WHEN MAJOR SCRUBBER PROBLEMS OCCUR.
REHEATER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS. THE SIX STEAM COILS
ON THIS IN-LINE REHEAT SYSTEM, TWO OF WHICH ARE 316SS AND FOUR OF WHICH
ARE CARBON STEEL, ARE EXPERIENCING CORROSION PROBLEMS. A SOLUTION TO THE
734
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1930
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PROBLEM HAS NOT YET BEEN DETERMINED.
IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER BALLS ANT) GRIDS. THE OLD
BALLS WERE REPLACED WITH THE NEW HOLLOW HARD PLASTIC-WALLED BALLS WITH
NOTCHED SEAMS. THE GRIDS WERE ORIGINALLY 316L SS, CERAMIC, POLYPROPYLENE,
AND RUBBER LINED CARBON STEEL, BUT HAVE BEEN REPLACED WITH 317L SS GRIDS.
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER EXCEPT FOR THE
BALL AND GRID REPLACEMENT DOWNTIME.
4/80 SYSTEM 100.0 100.0 720 720 720
5/80 SYSTEM 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 720 720 720
** 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 REHEATER TUBE LEAK PROBLEM CONTINUED THROUGH
THE SECOND QUARTER. THE TUBES HILL BE ENTIRELY REPLACED WITH NEW 316L SS
BUNDLES DURING THE NEXT SCHEDULED CUTAGE IN NOVEMBER AND DECEMBER. DURING
THE SECOND QUARTER MORE TUBES WERE BLANKED OFF AFTER STEAM LEAKS OCCURRED.
TO DATE ROUGHLY 507. OF THE TUBES ARE SEALED OFF AND ARE OUT OF SERVICE
BECAUSE OF LEAKS THAT OCCURRED OVFR THE PAST MONTHS.
744 744 744
744 744 744
720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBERS OPERATED ACCEPTABLY DURING THE JULY-SEPTEMBER PER-
IOD. NO PLANS HAVE BEEN MADE TO REPAIR THE ISOLATION DAMPERS. THE FAULTY
REHEATER TUBES WILL BE REPLACED DURING THE SCHEDULED OUTAGE NOW SET FOR THE
FIRST THREE WEEKS OF DECEMBER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE REHEATER TUBES WERE NOT RE-
PLACED AND THE UNIT IS OPERATING WITHOUT REHEAT UNTIL THE NEXT SCHEDULED
OUTAGE PERIOD IN FEBRUARY 1931.
NO MAJOR SCRUBBER RELATED PROBLEMS WERE ENCOUNTERED, EXCEPT THE REPLACE-
MENT OF THE DISCHARGE VALVE ON THE RECIRCULATION PUMP.
7/80 SYSTEM
8/80 SYSTEM
9/80 SYSTEM
100.0
100.0
100.0
130.0
700.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
735
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 1*
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
F'ANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPF
** ESP
NUMF.ER
** PARTICLE SCRUBBER
NJMBER
G£NERIC TYPE
SJPPLIER
SHELL GENERIC MATERIAL
SiELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
G^S CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SJPERFICIAL GAS VELOCITY - M/S
liUET GAS FLOW RATE - CU.M/S
IULET GAS TEMPERATURE - C
SG2 REMOVAL EFFICENCY - 7.
PARTICLE REMOVAL EFFICIENCY - X
( .100 LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
******
43.
******
******
710
115
100
105
102
BABCOCK & WILCOX
PULVERIZED COAL
******
245.39
146.1
******
******
*******
( 520000 ACFM)
( 295 F)
(**** FT)
(***** FT)
COAL
BITUMINOUS
23493.
12.50
9.4-12.5
11.30
******
.65
******
.01
******
( 10100 BTU/LB)
******
0
NONE
PACKED TOWER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL, 1.5 INCH PLASTIC SPHERES
7.5
3.2
3.4
164.4
146.1
16.0
97.0
(56.0 GAL/1000ACF)
(13.0 IN-H20)
( 11.0 FT/S)
( 348400 ACFM)
( 295 F)
736
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/73 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1973 SCALING AND PLUGGING AT THE WET/DRY ZONE,
ON THE FIRST STAGE GRIDS, AND IN THE REHEATERS HAVE BEEN THE MOST PROMINENT
PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL ADDITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSPHATED ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. SLOWDOWN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES NO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUMULATION.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS. THE
EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT IN THE
RECIRCULATING PUMPS.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE PERIOD ID FAN FAILURES HAVE OCCURRED DUE TO EROSION FROM THE
FLYASH.
THE ISOLATION DAMPER HAS BEEN A PROBLEM DUE TO FREEZE UPS MAKING IT
INOPERATIVE.
REHEATER FAILURES HAVE OCCURRED DUE TO PLUGGING OF THE HOT AIR INJECTION
STEAM COILS.
THE SCRUBBER EXIT DUCTWORK WILL BE REPAIRED TEMPORARILY WITH A SPRAY ON
FIBERGLASS-LIKE MATERIAL.
1/80 SYSTEM 100.0 100.0 744 744 744
Z/&0 SYSTEM 100.0 100.0 696 696 696
3/80 SYSTEM 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
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.
IN MARCH A BOILER/SCRUBBER OVERHAU1. BEGAN. DURING THIS TIME THE CARBON
STEEL ISOLATION DAMPERS WILL BE REPLACED WITH 316 SS. THE NEW FANS
WILL HE INSTALLED IN THE OLD HOUSINGS. THE NEW HIGH STRENGTH CARBON STEEL
FANS ULL BE EQUIPPED WITH REPUCABLE CHROMIUM ALLOY WEAR PLATE BLADE
TIPS.
4/80 SYSTEM 72Q
5/80 SYSTEM 744
6/80 SYSTEM 720
737
-------
EPA ITILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 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 IB ID FAN WAS SEVERELY ERRODED. THE FAN WAS REBUILT DURING THE OUTAGE.
THE OLD CARBON STEEL ISOLATION DAMPERS WERE REPLACED WITH 316 SS DAMPERS
DURING THE CONTINUING MAY-JULY OUTAGE.
7/80 SYSTEM IV*
8/80 SYSTEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
SHAFT BEARING FAILURES ON THE RECIRCULATION PUMP CAUSED SCRUBBER SYSTEM
PROBLEMS THROUGHOUT THE JULY-SEPTEMBER PERIOD.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED NO MAJOR PROBLEMS WERE ENCOUNTERED DURING THE OCTOBER
THROUGH DECEMBER PERIOD. HOWEVER, SHAFT BEARING REPAIRS WERE MADE TO THE
RECIRCULATION PUMPS.
738
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPAf-'Y NAME
PLANT NAME
UNIT NJMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTIC'JLATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS l"NIT GENERATING CAPACITY - MW
NET UN?.T GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BCILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7,
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*#* PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
SOS REMOVAL EFFICENCY - 7.
PARTICLE REMOVAL EFFICIENCY - 7.
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
******
43. ( .100 LB/MMBTU)
****** (****** LB/MMBTU)
****** (****** LB/MMBTU)
710
375
350
375
356
COMBUSTION ENGINEERING
PULVERIZED COAL
******
717.29 (1520000 ACFM)
135.0 ( 275 F)
****** {**** FT)
******
******* (***** FT)
COAL
BITUMINOUS
( 10100 BTU/LB)
******
12.50
9.4-12.5
11.30
.65
******
.01
******
0
NONE
PACKED TOWER
MOBILE BED PACKING
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL, 1.5 INCH PLASTIC SPHERES
7.5
3.2
3.4
16.0
97.0
(56.0 GAL/1000ACF)
(13.0 IN-H20)
( 11.0 FT/S)
739
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: CKEROKEE * (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEVABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/7* SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JULY 197* SCALING AND PLUGGING AT THE WET/DRY ZONE,
ON THE FIRST STAGE GRIDS, AND IN THE CHEATERS HAVE BEEN THE MOST PROMINENT
PROBLEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL ADDITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING, INCLUDING PHOSPHATED ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. BLOMDCWN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING PURPOSES NO
CHEMICAL CONTROL METHOD HAS BEEN'USED TO CONTROL SCALE ACCUMULATION.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, EROSION OF LINING AND CORROSIVE FAILURE OF REHEATERS. THE
EROSION AND LINING FAILURE HAVE NOT BEEN A SERIOUS PROBLEM EXCEPT IN THE
RECIRCULATING PUMPS.
10/79 SYSTEM 7**
11/79 SYSTEM 720
12/79 SYSTEM 7**
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE PERIOD ID FAN FAILURES HAVE OCCURRED DUE TO EROSION FROM THE
FLYASH.
THE ISOLATION DAMPER HAS BEEN A PROBLEM DUE TO FREEZE UPS MAKING IT
INOPERATIVE.
REHEATER FAILURES HAVE OCCURRED DUE TO PLUGGING OF THE HOT AIR INJECTION
STEAM COILS.
THE SCRUBBER EXIT DUCTWORK WILL BE REPAIRED TEMPORARILY WITH A SPRAY ON
FIBERGLASS LIKE MATERIAL.
1/80 SYSTEM 7*4
2/80 SYSTEM 696
3/80 SYSTEM 7**
** PROBLEMS/SOLUTIONS/COMMENTS
THE OUTLET DUCT WORK IS BEING REBUILT INTERNALLY WITH FIBERGLASS FOR
STRUCTURAL SUPPORT AND ACID RESISTANCE. WITH REGULAR MAINTENANCE THE
UTILITY EXPECTS THIS TO PROVE TO BE A PERMANENT SOLUTION TO THE EROSION/
CORROSION PROBLEM.
THE OLD FANS ARE BEING REPLACED WITH HIGH STRENGTH CARBON STEEL FANS HAVING
REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE TIPS.
4/80 SYSTEM 720
5/80 SYSTEM 7*4
6/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE NEW FANS DESCRIBED DURING THE LAST REPORT PERIOD WERE INSTALLED IN ONE
OF THE FOUR MODULES. NEW FANS WILL BE INSTALLED IN THE OTHER THREE MODULES
DURING A SCHEDULED LATE SEPTEMBER OUTAGE UNLESS THE UTILITY HAS AN OPPOR-
7*0
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 (CONT.)
PERFORMANCE DATA
PERIOt MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
TUNITY TO MAKE THE REPLACEMENTS SOONER.
7/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE StRUBBER RETURNED TO SERVICE TN MID JULY AFTER A TWO WEEK OUTAGE.
DURING THIS TIME, THE FIBERGLASS INSIDE THE DUCTWORK WAS REPLACED, AND A
VERTICAL GRID WAS INSTALLED ON THE SECOND LEVEL OF THE MOBILE BED TOWER TO
IMPROVE SYSTEM PERFORMANCE.
8/80 S,'STEM 744
9/80 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND FGD SYSTEM WENT DOWN ON SEPTEMBER IB, 1980 FOR A SCHEDULED
OVERHAUL. DURING THIS TIME, FANS WERE INSTALLED ON MODULES A, C, AND D.
THE UTILITY IS CURRENTLY EVALUATING THE VERTICAL GRID ON THE SECOND LAYER.
IF THE GRID IMPROVES SYSTEM PERFORMANCE, THEY WILL INSTALL ANOTHER ONE
ON THE THIRD LEVEL.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 4 EXPERIENCED SOME MINOR REHEATER LEAKAGE PROBLEMS DURING THE PERIOD.
DURING THE FOURTH QUARTER OF 1980 THE UTILITY REPORTED THAT PROBLEMS WERE
ENCOUNTERED WHEN VERITICAL GRIDS WERE INSTALLED ON THE SCRUBBER BED. THIS
WAS INTENDED TO SOLVE THE PROBLEM OF KEEPING THE SCRUBBER BALLS FROM MOVING
HORIZONTALLY, RESULTING IN PILES OF SCRUBBER BALLS IN LOCALIZED AREAS, BUT
CORROSION AND SYSTEM PERFORMANCE DID NOT IMPROVE.
741
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UfHT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UMT DATA - BOILER AND STACK
EOILER SUPPLIER
EOILER TYPE
E.OILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STAC:* SHELL
TOP DIAMETER - M
PUBLIC SERVICE OF COLORADO
VALMONT
5
VALMONT
COLORADO
( .100 LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
43.
******
******
274
166
157
163
166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
436.98 ( 926000 ACFM)
126.7 ( 260 F)
****** (**** FT)
******
******* (***** FT)
** FUEL DATA
FUEt. TYPE
FUEL GRADE
AVEFAGE HEAT CONTENT - J/P
R4NOE HEAT CONTENT - BTU/iB
A'/ERAGE ASH CONTENT - 7.
RXNGE ASH CONTENT - 7.
A/ERAGE MOISTURE CONTENT - 7.
RVNGE MOISTURE CONTENT - 7.
A/ERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
R4NGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NJMBER
INLET FLUE GAS CAPACITY - CU.M/S
COAL
SUBBITUMINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.68-.73
********
******
218.5
( 10800 BTU/LB)
******
( 463000 ACFM)
** FABRIC FILTER
Nl'MBER
T1PE
** ESP
NbMBER
TKPE
INLET FLUE GAS CAPACITY - CU.M/S
** PARTICLE SCRUBBER
NU1BER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
0
NONE
COLD SIDE
218.5
( 463000 ACFM)
PACKED TOWER
MOBILE BED PACKING
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUSBER
STAINLESS STEEL, 1.5 INCH PLASTIC SPHERES
7.8
3.7
3.4
109.2
(58.3 GAL/1000ACF)
(15.0 IN-H20)
( 11.0 FT/S)
( 231500 ACFM)
742
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
INLET GAS TEMPERATURE - C 132.8 ( 871 F)
S02 REMOVAL EFFICENCY - X 45.0
PARTICLE REMOVAL EFFICIENCY - 7. 96.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/71 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST PARTICLE MATTER SCRUBBER COMMENCED OPERATION IN NOVEMBER 1971.
THE SCRUBBER WAS ORIGINALLY INSTALLED FOR PARTICLE MATTER REMOVAL SINCE THE
PLANT BURNS LOW SULFUR COAL; HOWEVER, 45X OF THE S02 IS REMOVED AS WELL
BECAUSE OF THE ALKALINITY OF THE FLYASH.
DURINS THE FIRST YEAR OF OPERATION PROBLEMS INCLUDED DIFFICULTIES WITH THE
MODULE PACKING GRID SUPPORT, GENERAL VESSEL SCALE FORMATION, FLOW DISTRI-
BUTION PROBLEMS, BALL BREAKAGE, SCALING IN THE MIST ELIMINATOR SECTION,
AND PLUGGING OF THE REHEATER. SCALE FORMATION WAS THE MOST PREDOMINANT
CONTINUING MAJOR CAUSE OF DOWNTIME IN THE SCRUBBER. SCALE ACCUMULATION
WAS NOTED ON THE WET-DRY INTERFACE IMMEDIATELY DOWNSTREAM OF THE PRESATU-
RATIOH NOZZLES. SCALE ALSO ACCUMULATED HEAVILY ON THE UNDERSIDE OF THE
FIRST LAYER OF GRID BARS.
SCALE ON THE UPPER GRID BARS WAS LESS PREVALENT AS THE ACTION OF THE "PING
PONG" BALLS TENDED TO KEEP THE SCALE OFF OF THESE SECTIONS. SCALE ALSO
COLLECTED ON THE WALLS OF THE VESSEL AND INTERMITTENTLY SLOUGHED OFF AND
FELL INTO THE SUMP IN LARGE PIECES CAUSING BLOCKAGE OF THE RECIRCULATION
PUMP SUCTION SCREENS. SCALING OF THE MIST ELIMINATOR ABATED SOMEWHAT WITH
THE INTRODUCTION OF A CLEAR RINSE WATER WASH. SCALE FORMATION IN THE RE-
HEAT SECTION SOMETIMES REQUIRED SUPPLEMENTAL CLEANING OF THE REHEATER IN
ADDITION TO THE CLEANING OBTAINED BY THE USE OF THE SOOTBLOWERS WHICH WERE
INSTALLED AS A PART OF THE REHEATER EQUIPMENT. UNDER NORMAL OPERATION,
THE POOTBLOHERS LOCATED IN THIS REtiEAT SECTION WERE FAIRLY SUCCESSFUL IN
REMOVING THE ACCUMULATION OF THE SCALE IN THE REHEATER.
ALTHOUGH MANY OF THE INITIAL START-UP PROBLEMS WERE SOLVED OVER A PERIOD
OF Tit",-., THE CALCIUM SULFATE-FLYAI,H SCALING CONTINUED TO BE A SIGNIFICANT
OPERATING PROBLEM AT THE VALMONT INSTALLATION. IN ADDITION TO THESE
SCALING RELIABILITY PROBLEMS, A WATER QUALITY CONCERN ALSO SURFACED THAT
WAS A JIRECT RESULT OF THE PARTICLE SCRUBBER OPERATION. THE RELATIVELY
HIGH CAO CONCENTRATION IN THE VALMONT FLYASH RESULTED IN FAIRLY HIGH S02
REMOVAL RATES (45-50 PERCENT) WITHIN THE UNITS. SINCE NO PH CONTROL CAPA-
BILITY FOR EITHER THE RECIRCULATING SLURRY OR THE SYSTEM BLOWDOWN SLURRY
WAS DESIGNED INTO THE SYSTEM, AN ACID CONDITION WAS CREATED IN THE SLURRY
AND THE BLOUDOWN STREAM. . PH LEVELS OF THE BLOUDOWN NORMALLY RANGED BETWEEN
1.7 AND 2.0. ALTHOUGH THE STREAM WAS NEUTRALIZED TO A DEGREE BY ALKALINE
FLYASH, PSCC FELT THAT IT WAS IMPORTANT TO INVESTIGATE VARIOUS CONTROL
MEASURES WHICH COULD BE APPLIED TO THIS STREAM. THE CALCIUM SULFATE
SCALING PROBLEM WAS THOUGHT TO BE THE RESULT OF A SUPER-SATURATED CALCIUM
SULFATE CONDITION IN THE RECIRCULATING SLURRY. BECAUSE OF THIS IT WAS FELT
THAT CONTINUOUS PH CONTROL OF THE RECIRCULATING SLURRY, CONVERSION OF THE
SYSTEM TO CLOSED LOOP OPERATION AND ESTABLISHING A HIGHER CONCENTRATION OF
SEEDING SOLIDS IN THE RECIRCULATION SLURRY (THEREBY CONTROLLING THE SCALING
PROBLEMS WITHOUT CHEMICAL ADDITIVES) WOULD BE NECESSARY MEASURES.
FOR PH CONTROL, LIMESTONE WAS TESTED INITIALLY, THEN LIME WAS UTILIZED FOR
THE ALKALI REAGENT. IN THE FIRST TEST, SINCE LIMESTONE UTILIZATION WAS A
MAJOR CONCERN, A SPECIAL EFFORT WAS MADE TO REDUCE THE POTENTIAL FOR THE
SHORT CIRCUITING OF THE ADDED LIMESTONE AND TO PROVIDE SUFFICIENT RESIDENCE
TIME IN THE REACTOR SECTION OF THE SYSTEM. BY UTILIZING FOUR REACTION MIX
TANKS IN SERIES, PLUG FLOW WAS EXPECTED TO BE MORE CLOSELY SIMULATED. TO
MAINTAIN A CLOSED LOOP SYSTEM WHERE THE QUANTITY OF WATER REMOVED FROM THE
SYSTEM WAS HELD TO A MINIMUM, FOUR SYSTEM DESIGN FEATURES WERE UTILIZED.
1. UTILIZATION OF A COMBINATION OF POND SUPERNATANT AND MAKE-UP WATER
FOR RECYCLE WATER.
2. PRESATURATION OF THE INCOMING FLUE GAS WITH RECIRCULATING SLURRY.
3. INTERMITTENT MIST ELIMINATOR WASH.
4. PROPER SELECTION OF MATERIALS OF CONSTRUCTION TO PROTECT AGAINST
743
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
__ — — ______„____„ „__...,.____ — — — — — — — — — — — •,_-.___ — — -. — — ____«. -._ — — _ _ —— — — ___«.._ — — — _— __ — — — —
ATTACK CAUSED BY HIGH CHLORIDE CONCENTRATIONS.
THE SCRUBBERS R 8 D FACILITY WAS NOT EQUIPPED WITH A MECHANICAL THICKENER
FOR CONTROL OF THE SUSPENDED SOLIDS CONCENTRATION OF THE RECIRCULATING
SLURRY (ALL PURGED MATERIAL WAS SENT TO THE SLUDGE POND). WITH A 500 PPM
S02 CONCENTRATION IN THE FLUE GAS, IT IS EXPECTED THAT THE RECIRCULATING
SLURRY SOLIDS COULD BE REALLY CONTROLLED IN THE 5 TO 7 PERCENT RANGE. DUE
TO THE MIXED FUEL FIRED AT THE UNIT DURING THE TEST PERIOD, HOWEVER, THE
S02 CONCENTRATIONS EMITTED FROM THE BOILER AND HENCE PRESENT IN THE FLUE
GAS STREAM VARIED SIGNIFICANTLY AND FINALLY FELL TO SUCH LOU LEVELS (OFTEN
100-200 PPM) THAT SUSPENDED SOLIDS CONCENTRATIONS IN THE SLURRY COULD NOT
BE MAINTAINED. IT IS ALMOST CERTAIN THAT A THICKENER, WITH THE SUBSE-
QUENT RETURN OF SOLIDS TO THE SCRUBBER LIQUOR, COULD HAVE BEEN USED TO
GOOD ADVANTAGE DURING THIS TIME PERIOD. GENERALLY SPEAKING, THE SEVERE
SCALING CONDITIONS PLAGUING THE TEST MODULE WERE INTENSIFIED DURING THESE
PERIODS OF LOW INLET S02 CONDITION.
11/7* SYSTEM 72°
12/7* SYSTEM 7
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/76 SYSTEM 720
10/76 SYSTEM 744
11/76 SYSTEM 720
12/76 SYSTEM 744
1/77 SYSTEM 744
2/77 SYSTEM 672
3/77 SYSTEM 744
4/77 SYSTEM 720
5/77 SYSTEM 744
6/77 SYSTEM 720
7/77 SYSTEM 744
8/77 SYSTEM 744
9/77 SYSTEM 720
10/77 SYSTEM 744
11/77 SYSTEM 720
12/77 SYSTEM 744
1/78 SYSTEM 744
2/78 SYSTEM 672
3/78 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THERE HAVE BEEN RECURRING PROBLEMS ASSOCIATED WITH BALL MIGRATION IN THE
BALL COMPARTMENT AS WELL AS RECIRCULATION PUMP MOTOR BEARING FAILURE, AND
WEAR AND FAILURE IN THE BALL COMPARTMENT LINING. THERE HAVE BEEN CONTINUAL
PROBLEMS WITH REHEATER PLUGGING. THERE ALSO HAVE BEEN EXPANSION JOINT
FAILURES AT BOTH THE INLET AND OUTLET OF THE SCRUBBER.
MORE RECENTLY THERE WAS A PINCH BELT FAILURE.
THE SCRUBBING SYSTEM HAS HAD AN AVAILABILITY RANGE OF 50 TO 78X WITH AN
AVERAGE OF 66X.
4/78 SYSTEM 720
5/78 SYSTEM 744
** PROBLEMS/SOLUTIONS/COKHENTS
NO SIGNIFICANT PROBLEMS WERE ENCOUNTERED.
6/78 SYSTEM 720
7/78 S\STEM 744
8/78 SYSTEM 744
745
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (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 UTILITY HAD NO COMMENTS FOR THIS PERIOD.
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
AVERAGE SCRUBBER AVAILABILITY FROM START UP THROUGH APRIL 1979 WAS 64.4ZX.
AVERAGE SCRUBBER AVAILABILITY FOR 1978 WAS 66.85X.
AVERAGE SCRUBBER AVAILABILITY FROM JANUARY 1, 1979 THROUGH MAY, 1979 WAS
APPROXIMATELY 807..
BALL MIGRATION, ALTHOUGH NOT SERIOUS, IS A CHRONIC PROBLEM FOR VALMONT 5.
EROSION AND CORROSION HAVE OCCURRED ON THE SCRUBBER GRID BAR AREA (PACKING
SUPPORT).
EROSION/CORROSION IS EVIDENT IN THE MIST ELIMINATOR SECTION.
EROSION/CORROSION OCCURRS IN THE REHEATER AREA AND SOOT BLOWER.
THE UTILITY HAD TO REPLACE INLET AND OUTLET EXPANSION JOINTS.
REHEATER PLUGGING HAS BEEN A PROBLEM.
RECYCLE PUMP BEARING FAILURES OCCURRED.
THE JACK SCREW DRIVE HAS BEEN MALFUNCTIONING ON INLET AND OUTLET ISOLATION
DAMPERS.
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE ANNUAL SHUTDOWN IN SEPTEMBER THE OLD SCRUBBER BALLS WERE
REPLACED WITH A NEW BRAND. DUE TO BALL MOTION THE RUBBER LINER ERODED.
IN THE MIST ELIMINATOR SECTION EROSION AND CORROSION OCCURRED.
10/79 SYSTEM 100.0 744
746
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
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
2/80
3/80
4/80
5/80
6/80
SYSTEM 92.3
SYSTEM 98.1
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
A
B
SYSTEM
A
B
SYSTEM
A
B
SYSTEM
98.5
98.5
98.5
84.4
94.9
89.7
90.8
87.7
89.0
ONE OF THE MAJOR SCRUBBING SYSTEM PROBLEMS IS THE SCRUBBER WALL WEAR WHICH
HAS TO BE PATCHED DURING THE SPRING AND FALL.
REHEATER PLUGGING HAS BEEN A CHRONIC PROBLEM.
THE UTILITY HAS REPORTED THE FOLLOWING ANNUAL AVAILABILITIES FOR THE UNIT.
1972 - 1978: 64.3X
1972 - 1979: 65.9X
1978: 66.8X
1979: 80.5X
744
696
744 615
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980, NO MAJOR PROBLEMS WERE ENCOUNTERED WITH
THE SCRUBBER.
A
B
SYSTEM
88.1
88.1
88.1
720 716
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER WAS SHUT DOWN ON APRIL 14 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.
A
B
SYSTEM
96.8
100.0
98.4
744 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE REPORTED FOR MAY.
A
B
SYSTEM
8.0
8.0
8.0
720 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER WAS FORCED OUT OF SERVICE WHEN AN INBOARD FAN
PEDISTLE 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-
747
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEf'ABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
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
CLEAN'cD.
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 SEATS. BECAUSE OF CONTINUOUS FLY ASH ACCUMULATION IT APPEARS
THAT THE DAMPERS MUST BE EXERCISED FREQUENTLY TO PREVENT JAMMING.
7/80 5A 48.3 46.6
SB 48.3 46.6
SYSTEM 48.3 46.6 74* 719 347
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER SYSTEM WAS SHUT DOWN BECAUSE OF SCRUBBER BOOSTER FAN
BEARING FAILURE.
8/80 5A 87.5 84.8
5B 95.6 92.6
SYSTEM 91.5 87.7 744 721 660
** PROBLEMS/SOLUTIONS/COMMENTS
THE RECIRCULATION PUMP MOTOR BEARING FAILED CAUSING SOME MINOR OUTAGE
TIME IN AUGUST.
9/80 SYSTEM .0 720 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBER WERE SHUT DOWN DURING SEPTEMBER FOR SCHEDULED
MAINTENANCE.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER REMAINED OUT OF SERVICE THROUGHOUT THE OCTOBER-DECEMBER PERIOD
AND IS EXPECTED TO START UP AT THE END OF JANUARY. LATE START UP OF THE
SCRUBBER IS DUE TO A MANPOWER SHORTAGE. THE BOILER AND TURBINE RETURNED TO
SERVICE IN MID-DECEMBER.
748
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
** UNIT DATA - BOILER AND STACK
EOI .ER SUPPLIER
BOILER TYPE
EOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLCW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FLEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RXNGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
Sl'PPLIER
IhLET FLUE GAS CAPACITY - CU.M/S
IKLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
SOUTHWESTERN PUBLIC SERVICE
HARRINGTON
AMARILLO
TEXAS
******
43.
516.
******
360
360
320
*****
360
( .100 LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
778.63 (1650000 ACFM)
176.7 ( 350 F)
76. ( 250 FT)
CONCRETE
8.2 ( 27.0 FT)
( 8400 BTU/LB)
8000-8900
COAL
SUBBITUMINOUS
19538.
5.00
4.5-6
27.10
25-30
.42
.39-.45
********
******
COLD SIDE
RESEARCH-COTTRELL
778.6 (1650000 ACFM)
168.3 { 335 F)
.1 ( 1. IN-H20)
95.0
PACKED TOWER
STATIC BED PACKING
COMBUSTION ENGINEERING
24 X 25
CARBON STEEL
AISI 1110
ORGANIC
316L SS FIBERGLASS ALLOY 20
444.1
3.1
2.4
141.6
60.0
50.0
( 7050 GPM)
(23.0 GAL/1000ACF)
( 8.0 FT/S)
( 300000 ACFM)
( 140 F)
749
-------
EPA UTILITY FGD SURVEY'- OCTOBER - DECEMBER 1980
SOUTHWESTERN 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
______ ______ ____________ — — _-. — — — — — — — ——————————— ——————————— — — — — — — — — — — — — — — — —————— — — — — — — — — — — —
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 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 (316L SS) SCREENS COVERING THE BED DRAIN
PIPES HAVE ERODED AWAY FROM BALL MOVEMENT. THE MARBLE BALLS HAVE BEEN
DROPPING INTO THE RECYCLE TANK. WHERE THE UTILITY HAS REPLACED THE METAL
SCREEN WITH EXPANDED PLASTIC SCREEN, EROSION HAS NOT OCCURRED.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SrSTEM 7*4
*t PROBLEMS/SOLUTIONS/CCMMENTS
DURING THE FIRST QUARTER OF 1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
CAUSING PLUGGING IN SCRUBBERS 4 AND 5. THE UTILITY PLANS TO REPLACE
ALL KRP 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 YET
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 HAVEfFORMED. 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 72°
** 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 AGITATORS AT THIS FACILITY ARE SIDE
MOUNTED. THE AGITATOR SHAFT ENTERS THE TANK AT ROUGHLY 12 FT BELOW THE
FLUID SURFACE. IT APPEARS THAT THE SEAL LEAKING MAY BE ATTRIBUTABLE TO
FAULTY INSTALLATION.
750
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SOUTHWESTERN 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
6/80 SYSTEM 92.1
** PROBLEMS/SOLUTIONS/COMMENTS
720 696
79.3
7/80 SYSTEM
8/80 SYSTEM
DURING JUNE THE SCRUBBER EXHIBITED AN AVAILABILITY OF 92.IX. 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 LOUER 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
NOU. 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.
744
744
9/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
THE UTILITY REPORTED THAT NO MAJOR SCRUBBING SYSTEM PROBLEMS OCCURRED
DURING THE THIRD QUARTER 1980.
THE PROBLEM REPORTED EARLIER WITH THE MIST ELIMINATOR WASH PIPING IS
PRESLNTLY BEING SOLVED BY REPLACING THE PIPING WITH CARBON STEEL.
10/80 S ,'STEM
11/80 S'STEM
12/80 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
DURING THE OCTOBER THROUGH DECEMBER PERIOD REPLACEMENT OF THE MIST ELIMI-
NATOR WASH PIPING WITH CARBON STEEL CONTINUED; AS THE OLD PIPING WEARS OUT
AND MAINTENANCE TIME PERMITS.
DURING LATE DECEMBER, THE SLURRY SPRAY PUMP HOUSING CRACKED DURING A BACK
FLUSH. THIS WAS THE SECOND TIME IN TWO YEARS THAT THIS PROBLEM HAD
OCCURRED.
751
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS LNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
CHUGOKU ELECTRIC
SHIMONOSEKI
1
SHIMONOSEKI
JAPAN
(******
( .510 LB/MMBTU)
(****** LB/MMBTU)
******
219.
******
575
175
*****
*****
175
MITSUBISHI HEAVY INDUSTRIES
PULVERIZED COAL
BASE
266.27
130.0
200.
CONCRETE
3.0
( 564255 ACFM)
( 266 F)
C 656 FT)
( 9.7 FT)
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 2
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7,
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
COAL
******
25046.
24.60
******
2.30
******
.59
.04
0.014-0.106
C 10768 BTU/LB)
******
** MECHANICAL COLLECTOR
TYPE
SUPPLIER
MULTICLONES
MITSUBISHI HEAVY INDUSTRIES
«* FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
UNER SPECIFIC MATERIAL
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
0
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
246.1 ( 521589 ACFM)
140.0 ( £84 F)
.8 ( 3. IN-H20)
SPRAY TOWER
MITSUBISHI HEAVY INDUSTRIES
66
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
1
544.3 ( 8640 GPM)
3.0 (22.5 GAL/1000ACF)
752
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC: SHIMONOSEKI i CCONT.)
SUPERFICIAL GAS VELOCITY - M/S
I.JLET GAS FLOW RATE - CU.M/S
*#* FG'J SYSTEM
*# GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S32 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SfSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UKIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUHBER
NU1BER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
PRESSURE DROP - KPA
WASH WATER SOURCE
WASH RATE - L/S
** REHEATER
GENERIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
** FANS
SUPPLIER
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
13.1
203.7
43.0 FT/S)
431725 ACFM)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
NONE
MITSUBISHI HEAVY INDUSTRIES
MITSUBISHI HEAVY INDUSTRIES
FULL SCALE
RETROFIT
85.00
I
7/79
5/79
5/77
1
0
COMBINATION
TRAY/PACKED
MITSUBISHI
131.2 HIGH
CARBON STEEL
AISI 1110
ORGANIC
RESIN
4
2722.
1.0
3.0
203.73
50.0
89.0
90.0
(43200 GPM)
( 3.9 IN-H20)
( 9.8 FT/S)
( 431725 ACFM)
( 122 F)
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
2
.1
FRESH WATER
ZOO.O
( .6 IN-H20)
( 3170 GAL/MIN)
WASTE HEAT RECOVERY
LOW-SULFUR OIL
140.0 ( 284 F)
203.73 ( 431725 ACFM)
105.0 t 221 F)
MITSUBISHI HEAVY INDUSTRIES
294.04 ( 623108 ACFM)
140.0 ( 284 F)
CENTRIFUGE
5
0
25X SOLIDS
90X SOLIDS
753
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
CHUGOKU ELECTRIC: SHIHONOSEKI i CCONT.)
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
N'JMBFR
NJMBFR OF SPARES
DIMENSIONS - FT
F£Er STREAM CHARACTERISTIC?
OUTLET STREAM CHARACTERISTCCS
*** SALEABLE BYPRODUCTS
NATIRE
FULL LOAD QUANTITY - M T/H
QUALITY - X
THICKENER
1
0
33 (DIA) X 10 (DEPTH)
57. SOLIDS
Z57. SOLIDS
GYPSUM
6.98
99.0
** WA"ER BALANCE
WATER LOOP TYPE OPEN
EVAPORATION WATER LOSS - LITER/S 3.0
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 54
MAKEUP WATER ADDITION - LITERS/S 6.8
( 7.70 TPH)
47 GPM)
( 108 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
7/79
8/79
9/79
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100
100
100
.0
.0
.0
50
100
100
.0
.0
.0
744
744
720
373
744
720
378
744
720
** PROBLEMS/SOLUTIONS/COMMENTS
COMMERCIAL OPERATIONS BEGAN IN THE MIDDLE OF JULY 1979. THE FGD UNIT HAS
OPERATED CONTINUOUSLY THROUGH THE THIRD QUARTER WITH NO PROBLEMS.
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
100.0
100.0
100.0
100.0
93.5
100.0
100.0
100.0
100.0
100.0
93.5
744
720
744
744
720
744
744
720
696
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD UNIT OPERATED CONTINUOUSLY THROUGH THE FOURTH QUARTER EXCEPT FOR A
2 DAY SHUTDOWN TO INSPECT THE GAS-GAS HEATER DURING DECEMBER. THE BOILER
WAS OPERATED FIRING A LOW SULFUR OIL DURING THE TWO DAYS.
1/80 SYSTEM 100.0 100.0 100.0 100.0
2/80 SYSTEM 100.0 100.0 100.0 53.4
*» PROBLEMS/SOLUTIONS/COMMENTS
744
696
744
372
744
372
DURING JANUARY AND THE FIRST HALF OF FEBRUARY THE FGD UNIT OPERATED WITH
NO PROBLEMS. THE BOILER WAS TAKEN OFF-LINE ON FEBRUARY 8 FOR SCHEDULED
MAINTENANCE.
.0
744
3/80 SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINED DOWN THROUGH MARCH FOR ANNUAL MAINTENANCE.
4/80 SYSTEM 100.0 100.0 100.0 182.4 720 593
593
754
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
CHUGOKU ELECTRIC: SHIMONOSEKI i (CONT.J
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** 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.
5/80 SYSTEM 100.0 100.0 100.0 90.3 744 672 672
** PROBIEMS/SOLUTIONS/CCMMENTS
THE FGJ SYSTEM OPERATED CONTINOUS'.Y WITH NO PROBLEMS. A THREE DAY
SHUTDOvJN FOR INSPECTION OF THE SC3 UNIT FROM MAY 16 TO MAY 19 WAS THE
ONLY DJWN TIME EXPERIENCED DURING MAY.
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 99.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED CONTINOUSLY WITH NO PROBLEMS DURING JUNE.
7/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 98.9
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED DURING JULY WITH NO PROBLEMS.
8/80 SYSTEM 88.7 88.7 68.7 88.7 744 744 660 99.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING AUGUST THE FGD SYSTEM WAS SHUT DOWN FOR 84 HOURS DUE TO SOME PLUG-
GING IN THE REHEATER. DURING THIS TIME THE REHEATER WAS WATER WASHED AND
THE SOOT BLOWER SYSTEM WAS IMPROVED.
9/80 SYSTEM 89.0 89.0 89.0 89.0 720 720 641 97.3
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER PROBLEMS WITH PLUGGING IN THE REHEATER RECURRED. THE
TROUBLE WAS CAUSED BY ESP PROBLEMS, BY WHICH A LARGE AMOUNT OF FLYASH
WENT INTO THE REHEATER.
10/80 SYSTEM 100.0 97.4 100.0 88.0 744 673 655 88.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THE BOILER WAS TAKEN OFF LINE FOR THREE DAYS FOR AN
INSPECTION OF THE NOX REMOVAL SYSTEM.
11/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720 99.4
12/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744 99.6
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE MONTHS OF NOVEMBER AND DECEMBER.
755
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
EOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FJEL TYPE
FUEL GRADE
Ai/ERAGE HEAT CONTENT - J/9
RANG": HEAT CONTENT - BTU/IB
AVERAGE ASH CONTENT - 7.
RANt'E ASH CONTENT - 7.
AVEF-'AGE MOISTURE CONTENT - 7.
RftNC-E MOISTURE CONTENT - 7.
Av'EFAGE SULFUR CONTENT - 7
RAN&E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
ELECTRIC POWER DEVELOPMENT CO
ISOGO
YOKOHAMA
JAPAN
******
ZO.
58.
238
265
238
*****
265
( .046 LB/MMBTU)
( .135 LB/MMBTU)
(****** LB/MMBTU)
IHI
PULVERIZED COAL
BASE
405.36 (
170.0 (
122. (
STEEL
3.7 (
859000 ACFM)
338 F)
400 FT)
12.0 FT)
COAL
******
25958.
16.00
15-17
7.00
6-8
.60
0.2 - 0.6
********
******
( 11160 BTU/LB)
11160-11520
** MECHANICAL COLLECTOR
NUMBER
T/PE
** ES-3
NUMBER
TVPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SH5LL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LIMER SPECIFIC MATERIAL
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
0
NONE
COLD SIDE
TOYO ENGINEERING
353.2 ( 748362 ACFM)
150.0 t 302 F)
98.0
1
0
VENTURI TOWER
IHI-CHEMICO
43.6 DIA X 101.4 HIGH
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
1
2194.1 (34827 GPM)
9.4 (70.0 GAL/1000ACF)
1.5 ( 5.9 IN-H20)
3.0 ( 10.0 FT/S)
424.6 ( 899864 ACFM)
756
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 1 (CONT.)
INLET GAS TEMPERATURE - C 170.0
*** FGD SYSTEM
( 338 F)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
CAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
*« MIST ELIMINATOR
FSE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
T9ADE NAME/COMMON TYPE
CONFIGURATION
NJMBtR OF STAGES
NUMBtR OF PASSES PER STAG=
PRESSURE DROP - KPA
SUPtRFICAL GAS VELOCITY - 1/S
CONSTRUCTION MATERIAL GENERIC TYPE
** RE^E/TER
GENLRIC TYPE
T,?ADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
IflLET FLUE GAS TEMPERATURE - C
** FA;JS
NJMBER
NUMBER OF SPARES
F JNCTION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
** FANS
NUMBER
NUMBER OF SPARES
APPLICATION
Fl.UE GAS FLOW RATE - CU.M/S
FlUE GAS TEMPERATURE - C
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
mi - CHEMICO
FULL SCALE
RETROFIT
7. 97.00
95.00
1
3/76
12/75
1
0
VENTURI TOWER
IHI/CHEMICO
43.5 DIA X 76.8 HIGH
CARBON STEEL
N/A
ORGANIC
FLAKEGLASS
1
2194.
1.5
3.0
566.28
55.0
(34827 GPM)
( 70.0 GAL/1000 ACF)
( 5.9 IN-H20)
( 10.0 FT/S)
(1200000 ACFM)
( 131 F)
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
HORIZONTAL
4
4
.5 (
3.0 (
PLASTIC
2.0 IN-H20)
9.8 FT/S)
DIRECT COMBUSTION
OIL
66.1 ( 151 F)
120.0 ( 248 F)
2
0
BOOSTER
362.14
170.0
( 767400 ACFM)
( 338 F)
1
0
OXIDATION BLOWER
.86 (
10.0 (
1830 ACFM)
50 F)
757
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 1 (CONT.)
** TANKS
SERVICE
OXIDATION TOWER FEED
RECYCLE
SLURRY
THICKENER OVERFLOW
FILTRATE
OXIDATION TOWER
** PUMPS
SERVICE
SLURRY MAKEUP
ABSORBER RECIRCULATION
OXIDATION TOWER SUPPLY TRANSFER
FILTRATE
*# SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
«* SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
DISPOSITION
*** SLUDGE
** TREATMENT
METHOD
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
** WfTER BALANCE
t'ATER LOOP TYPE
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S
KAKEUP WATER ADDITION - LITERS/S
NUMBER
I
****
' 1
1
1
1
NUMBER
3
8
2
2
CENTRIFUGE
18. 57. SOLIDS
90X SOLIDS
THICKENER
1
0
20 (DIA) X 10 (DEPTH)
8.5X SOLIDS
18.6Z SOLIDS
GYPSUM
4.53
MARKETED
( 5.00 TPH)
FORCED OXIDATION
PH
AUTOMATIC
FEEDBACK
OPEN
40
22.3
354 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPE3ABILITY RELIABILITY UTILIZATION '/. REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM
5/78 SVSTEM
6/78 SYSTEM
7/78 SYSTEM
720
744
720
744
758
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
____—» .._____ ______«.»_.*__ _____»_____ ____.....»___._ ______«_«_.• _____ _____ —-. — — — ____*.« -, — — — _ ______
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
100X AVAILABILITY FOR THE FGD SYSTEM WAS REPORTED DURING THE PERIOD APRIL
1978 THROUGH MARCH 1979. THE SYSTEM S02 REMOVAL EFFICIENCY WAS REPORTEDLY
AVERAGING 95X.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER FOR THE ENTIRE MONTH OF
APRIL.
5/80 SYSTEM 100.0 100.0 100.0 52.8 744 393 393
6/80 SYSTEM 100.0 100.0 100.0 10.0 720 72 72
759
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION '/. REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS SHUT DOWN FROM MAY 17 TO JUNE 27 FOR ANNUAL MAINTEN-
ANCE. THE FED SYSTEM WAS OPERATED DURING ALL OF THE BOILER OPERATION
IN MAY AND JUNE.
7/80
8/80
9/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
99.8
95.30
95.70
96.20
744
744
720
744
744
718
744
744
718
90.9
91.9
90.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER THE BOILER WAS OUT OF SERVICE FOR APPROXIMATELY TWO HOURS
TO CHANGE THE TAP ON THE MAIN TRANSFORMER.
10/80
11/80
12/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100
100
100
.0
.0
.0
91.4
100.0
100.0
96.00
95.50
95.00
744
720
744
680
720
744
680
720
744
84.5
91.7
93.2
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THROUGH DECEMBER THE FGD SYSTEM EXPERIENCED NO OPERATIONAL
PROBLEMS.
760
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
S02 EMISSION LIMITATION - N6/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UKIT GENERATING CAPACITY W/FGD - MM
NET UKIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
Fl.EL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
ELECTRIC POWER DEVELOPMENT CO
ISOGO
YOKOHAMA
JAPAN
******
20.
58.
******
238
265
238
246
265
( .046 LB/MMBTU)
( .135 LB/MMBTU)
(****** LB/MMBTU)
IHI
PULVERIZED COAL
BASE
405.36 (
170.0 (
140. (
STEEL
3.7 (
859000 ACFM)
338 F)
460 FT)
12.0 FT)
COAL
******
25958.
16.00
15-17
7.00
6-8
.60
0.2 - 0.6
********
******
0
NONE
356.6
150.0
98.0
( 11160 BTU/LB)
11160-11520
( 755654 ACFM)
( 302 F)
1
0
VENTURI TOWER
IHI-CHEMICO
43.6 DIA X 101.4 HIGH
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
1
2194.1
9.4
1.5
3.0
424.6
170.0
(34827 GPM)
(70.0 GAL/1000ACF)
(5.9 IN-H20)
( 10.0 FT/S)
( 899864 ACFM)
( 338 F)
761
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTF'IC POWER DEVELOPMENT CO: ISOGO 2 (CONT.)
*** FCD SYSTEM
** GfNERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
£02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNI. DESIGN S02 -REMOVAL EFFICIENCY - 7.
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NJMBER
KJHBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
IINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
IMLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIJT ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GfNERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
Nl'MBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
** REHEATER
GENERIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
** FANS
NUMBER
NUMBER OF SPARES
FUNCTION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
** FANS
NUMBER
NUMBER OF SPARES
APPLICATION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
IHI - CHEMICO
FULL SCALE
RETROFIT
X 97.00
95.00
1
5/76
3/76
1
0
VENTURI TOWER
IHI/CHEMICO
43.5 DIA X 76.8 HIGH
CARBON STEEL
N/A
ORGANIC
FLAKEGLASS
1
2194. (34827 GPM)
9.4 ( 70.0 GAL/1000 ACF)
1.5 ( 5.9 IN-H20)
3.0 ( 10.0 FT/S)
566.28 (1200000 ACFM)
55.0 ( 131 F)
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
HORIZONTAL
4
4
.5
3.0
PLASTIC
( 2.0 IN-H20)
( 9.8 FT/S)
DIRECT COMBUSTION
OIL
66.1 ( 151 F)
132.50 ( 280783 ACFM)
120.0 ( 248 F)
2
0
BOOSTER
362.14
170.0
( 767400 ACFM)
( 338 F)
1
0
OXIDATION BLOWER
.86 (
10.0 (
1830 ACFM)
50 F)
762
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 2 (CONT.)
** TANKS
SERVICE
OXIDATION TOWER FEED
SLURRY
THICKENER OVERFLOW
FILTRATE
OXIDATION TOWER
** PlIMPS
SERVICE
SLURRY MAKEUP
/BSORBER RECIRCULATION
CXIDATION TOMER SUPPLY TRANSFER
FILTRATE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
KUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SCLIUS CONCENTRATING/DEWATESING
DEVICE
NUMEER
NJMlsER OF SPARES
DIMENSIONS - FT
F£ED STREAM CHARACTERISTICS
OJTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
D CSPOSITION
*** SLJDGE
** TREATMENT
McTHOD
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
Pf-'OCESS CONTROL MANNER
PF.OCESS CHEMISTRY MODE
** WATER BALANCE
WATER LOOP TYPE
PCND SEEPAGE/RUNOFF WATER LOSS - LITERS/S
MAKEUP WATER ADDITION - LITERS/S
NUMBER
1
1
1
1
1
NUMBER
2
8
2
2
CENTRIFUGE
4
0
18.57. SOLIDS
90X SOLIDS
THICKENER
1
0
20 (DIA) X 10 (DEPTH)
8.5X SOLIDS
18.6X SOLIDS
GYPSUM
4.53
MARKETED
( 5.00 TPH)
FORCED OXIDATION
PH
AUTOMATIC
FEEDBACK
OPEN
40
22.3
( 354 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM
5/78 SYSTEM
6/78 SYSTEM
7/78 SYSTEM
720
744
720
744
763
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
100X AVAILABILITY FOR THE FGD SYSTEM WAS REPORTED DURING THE PERIOD APRIL
1978 THROUGH MARCH 1979. THE FGD SYSTEM LOGGED A TOTAL OF 1,689 HOURS OF
OPERATION.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SY?TEM 720
7/79 SYSTEM 744
8/79 S"STEM , 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 31.3 720 225 225
** 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 100.0 100.0 100.0 100.0 720 720 720
764
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: ISOGO 2 (CONT.)
: PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY AND JUNE THE FGD SYSTEM OPERATED WITH NO REPORTED PROBLEMS.
7/80 SYSTEM 100.0 100.0 100.0 88.2 94.90 744 656 656 82.0
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THE BOILER MAS OFF LINE APPROXIMATELY 88 HOURS FOR MAINTEN-
ANCE.
8/80 SYSTEM 100.0 100.0 100.0 100.0 96.00 744 744 744 91.9
9/80 SYSTEM 100.0 100.0 100.0 99.8 95.70 720 718 718 92.1
** PROBLEMS/SOLUTIONS/COMMENTS
APPROXIMATELY TWO HOURS OF BOILER OUTAGE TIME WAS NECESSARY TO CHANGE
THE TAP OF THE MAIN TRANSFORMER.
10/80
11/80
12/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
100.0
95.30
95.20
95.00
744
720
744
744
720
744
744
720
744
92.2
92.7
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THROUGH DECEMBER THE FGD SYSTEM OPERATED WITH NO PROBLEMS.
765
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
I.UET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINFR GENERIC MATERIAL
NUMEER OF CONTACTING ZONES
LtQL'ID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
IHLET GAS TEMPERATURE - C
Sl)2 REMOVAL EFFICENCY - 7.
ELECTRIC POWER DEVELOPMENT CO
TAKASAGO
TAKASAGO
JAPAN
******
37.
150.
******
230
250
230
238
250
( .086 LB/MMBTU)
( .350 LB/MMBTU)
(****** LB/MMBTU)
MITSUBISHI HEAVY INDUSTRIES
774000 ACFM)
310 F)
590 FT)
( 11.9 FT)
( 11160 BTU/LB)
11160-11520
BASE
365.25
154.4
ISO.
STEEL
3.6
COAL
******
25958.
22.00
******
7.00
******
1.80
******
********
******
0
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
344.3 ( 729507 ACFM)
154.4 ( 310 F)
99.5
1
0
VENTURI TOWEP
MITSUI-CHEMICO
37.7 DIA X 62.3 HIGH
CARBON STEEL
AISI 1110
CORRISION RESISTANT
1
1228.8 (19505 GPM)
6.5 (48.6 GAL/1000ACF)
1.5 ( 5.9 IN-H20)
260.5 ( 552000 ACFM)
154.4 ( 310 F)
56.0
766
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 1 (CONT.)
PARTICLE REMOVAL EFFICIENCY - 7.
*** FGD SYSTEM
** GENfRAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S0'>. REMOVAL MODE
PR3CESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - 7.
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
I UMBER OF PASSES PER STAGE
** REHEATER
NJMBER
GENERIC TYPE
T3ADE NAME/COMMON TYPE
INLET FLUE GAS TEMPERATURE - C
50.0
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
MITSUI - CHEMICO
FULL SCALE
RETROFIT
93.00
1
2/75
1
0
VENTURI TOWER
MITSUI/CHEMICO
45.0 DIA X 78.7 HIGH
CARBON STEEL
N/A
1
2566.
6.5
1.5
55.0
85.0
(40727 GPM)
( 48.6 GAL/1000 ACF)
( 5.9 IN-H20)
( 131 F)
VENTURI TOWER
MITSUI/CHEMICO
26.2 DIA X 82.3 HIGH
CARBON STEEL
N/A
1
610. ( 9689 GPM)
69.37 ( 147000 ACFM)
154.4 ( 310 F)
63.0
SPRAY TOWER
MITSUI/CHEMICO
19.7 DIA X 65.0 HIGH
CARBON STEEL
N/A
1
9986. (***** 6PM)
18.26 ( 38686 ACFM)
154.4 ( 310 F)
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
4
4
DIRECT COMBUSTION
OIL
120.0 ( 248 F)
767
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTR.tC POWER DEVELOPMENT CO: TAKASAGO 1 (CONT.)
** FA:-IS
FUNCTION
** FAi-IS
APPLICATION
** TAUKS
SERVICE
CENTRIFUGE OVERFLOW
ABSORBENT MAKEUP
CENTRIFUGE FEED
PRIMARY LIQUOR
ABSORBER FEED
** PUM^S
SERVICE
CIRCULATION
PH ADJUSTER CIRCULATION
REACTOR CIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
OUTLET STREAM CHARACTERISTICS
**# SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
*#* SLUDGE
** TREATMENT
METHOD
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
** WATER BALANCE
WATER LOOP TYPE
BOOSTER
OXIDATION BLOWER
NUMBER
NUMBER
5
3
3
CENTRIFUGE
7
90X SOLIDS
THICKENER
20X SOLIDS
GYPSUM
8.62
( 9.50 TPH)
FORCED OXIDATION
FLUE GAS VOLUME & S02 CONCENTRATION
OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 13.1
( 208 GPM)
—PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/75 SYSTEM 96.9 88.8 672 616 597
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS DOWN ONCE DUE TO A PIPING FLANGE LEAK.
3/75 SYSTEM 10C.O 48.4 744 360 360
4/75 SYSTEM 100.0 44.1 720 318 318
768
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CD: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS TAKEN OFF-LINE FOR ANNUAL MAINTENANCE DURING MARCH AND
APRIL.
5/75 SYSTEM 100.0 96.4 744 717 717
6/75 SYSTEM 97.9 97.9 720 720 705
7/75 SYSTEM 98.0 97.8 744 743 728
8/75 SYSTEM 98.0 98.0 744 744 729
9/75 SYSTEM 95.7 91.7 720 690 660
** PROBLEMS/SOLUTIONS/COMMENTS
SYSTEM DOWN TIME FROM JUNE THROUGH SEPTEMBER WAS DUE TO MIST ELIMINATOR
SCALING.
10/75 SYSTEM 95.2 95.2 744 744 708
** PROBLEMS/SOLUTIONS/COMMENTS
FAN VIBRATIONS CAUSED A SYSTEM OUTAGE DURING THE MONTH.
11/75 SYSTEM 98.5 98.5 720 720 709
** PROBLEMS/SOLUTIONS/COMMENTS
MIST ELIMINATOR SCALING WAS ENCOUNTERED IN NOVEMBER.
12/75 SYSTEM 95.9 92.2 744 715 686
1/76 SYSTEM 100.0 100.0 744 744 744
2/76 SYSTEM 95.2 90.8 696 664 632
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY, THE SYSTEM AGAIN ENCOUNTERED MIST ELIMINATOR SCALING.
3/76 SYSTEM 100.0 92.3 744 687 687
4/76 SYSTEM 100.0 30.4 720 219 219
5/76 SYSTEM 100.0 100.0 744 744 744
6/76 SYSTEM 100.0 100.0 720 720 720
7/76 SYSTEM 100.0 100.0 744 744 744
8/76 SYSTEM 744 744
9/76 SYSTEM 100.0 100.0 720 720 720
10/76 SYSTEM 91.7 91.7 744 744 682
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS TAKEN OFF-LINE FOR CLEANING OF THE FIRST STAGE SCRUBBER.
11/76 SYSTEM 99.3 99.3 720 720 715
769
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 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
REPAIR OF A DUCT FORCED ONE SYSTEM OUTAGE DURING THE MONTH.
12/76 SYSTEM 98.9 98.9 744 744 736
** PROBLEMS/SOLUTIONS/COMMENTS
A DECEflBER OUTAGE WAS DUE TO THE REPAIR OF A SPRAY PIPE.
1/77 SYSTEM 99.3 99.3 744 744 739
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS TAKEN OFF-LINE ONCE FOR CLEANING OF THE FIRST STAGE
SCRUBBER.
E/77 SYSTEM 100.0 100.0 672 672 672
3/77 SYSTEM .0 744 0 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS OFF DURING MARCH FOR ANNUAL BOILER MAINTENANCE.
4/77 SYSTEM 100.0 71.3 720 513 513
5/77 SYSTEM 98.7 98.7 744 744 734
** PROBLEMS/SOLUTIONS/COMMENTS
FAN VIBRATIONS CAUSED ONE SYSTEM OUTAGE DURING MAY.
6/77 SYSTEM 100.0 100.0 720 720 720
7/77 SYSTEM 100.0 96.4 744 717 717
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST STAGE ABSORBER WAS CLEANED DURING JULY.
8/77 SYSTEM 100.0 100.0 744 744 744
9/77 SYSTEM 100.0 100.0 720 720 720
10/77 SYSTEM 94.2 94.2 744 744 701
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS OFF LINE PART OF THIS MONTH FOR CLEANING OF THE SCRUBBERS
AND REACTORS.
11/77 SYSTEM 100.0 100.0 720 720 720
12/77 SYSTEM 100.0 100.0 744 744 744
1/78 SYSTEM 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST REACTOR WAS CLEANED THIS MONTH.
4/78 SYSTEM 720
770
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 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
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 74*
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 S' STEM 744
*« PROBLEMS/SOLUTIONS/COMMENTS
DURW. APRIL 1978 THROUGH MARCH 1979 NO FORCED OUTAGES OCCURRED. THE FGD
SYSTEM AVAILABILITY WAS 99.9X, AND LOGGED A TOTAL OF 7823.4 HOURS OF
OPERATION WITH 6.1 HOURS OF SCHEDULED OUTAGE TIME.
4/79 SYSTEM 720
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 31.1 720 224 224
** 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
771
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 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
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.
7/80
8/80
9/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
93.00
92.80
93.00
744
744
720
744
744
720
744
744
720
83.4
83.6
83.3
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE THIRD QUARTER 1980.
10/80 SYSTEM 99.5 99.5 99.5 99.5 92.70 744 744 740 85.3
** PROBLEMS/SOLUTIONS/COmENTS
THE FGD SYSTEM WAS SHUT DOWN FOR APPROXIMATELY FOUR HOURS IN OCTOBER FOR
AN INSPECTION OF THE SECOND SCRUBBER OUTLET DUCT AND THE MIST ELIMINATOR.
THE INSPECTION REVEALED THAT NO PROBLEM EXISTED.
11/80 SYSTEM 100.0 100.0 100.0 100.0 92.70 720 720 720 85.0
12/80 SYSTEM 100.0 100.0 100.0 100.0 92.70 744 744 744 89.9
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURINK NOVEMBER AND DECEMBER.
772
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
2NLE7 FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PART CLE SCRUBBER
KTJM15ER
NUMBER OF SPARES
&ENI/RIC TYPE
SUPPLIER
DIMENSIONS - FT
S.1ELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
NJMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
FSESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - 7.
ELECTRIC POWER DEVELOPMENT CO
TAKASAGO
2
TAKASAGO
JAPAN
( .086 LB/MMBTU)
( .350 LB/MMBTU)
(****** LB/MMBTU)
37.
150.
******
230
250
230
238
250
MITSUBISHI HEAVY INDUSTRIES
******
BASE
365.25
( 774000 ACFM)
( 310 F)
( 590 FT)
( 11.9 FT)
( 11160 BTU/LB)
11160-11520
180.
STEEL
3.6
COAL
******
25958.
22.00
******
7.00
******
1.80
******
********
******
0
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
344.3 ( 729507 ACFM)
154.4 ( 310 F)
99.5
1
0
VENTURI TOWER
MITSUI-CHEMICO
37.7 DIA X 62.3 HIGH
CARBON STEEL
AISI 1110
CORRISION RESISTANT
1
1542.2 (24480 GPM)
6.5 (48.6 GAL/1000ACF)
1.5 ( 5.9 IN-H20)
260.5 ( 552000 ACFM)
154.4 ( 310 F)
56.0
773
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 2 (CONT.)
PARTICLE REMOVAL EFFICIENCY - X 50.0
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - '/.
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
SOS REMOVAL EFFICIENCY - 7.
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
J.NLET GAS FLOW - CU. M/S
1.NLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
KUMBER OF STAGES
h UMBER OF PASSES PER STAGE
** REHEATER
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
MITSUI - CHEMICO
FULL SCALE
RETROFIT
93.00
1
3/76
1
0
VENTURI TOWER
MITSUI/CHEMICO
45.0 DIA X 78.7 HIGH
CARBON STEEL
N/A
1
2066.
6.5
1.5
280.24
55.0
85.0
(32801 GPM)
( 48.6 GAL/1000 ACF)
t 5.9 IN-H20)
( 593855 ACFM)
( 131 F)
VENTURI TOWER
MITSUI/CHEMICO
26.2 DIA X 82.3 HIGH
CARBON STEEL
N/A
1
743. (11799 GPM)
69.37 ( 147000 ACFM)
154.4 ( 310 F)
63.0
SPRAY TOWER
MITSUI/CHEMICO
CARBON STEEL
N/A
1
19639.
36.51
154.4
(#**** GPM)
( 77372 ACFM)
( 310 F)
GENERIC TYPE
TRAPE NAME/COMMON TYPE
INLiET FLUE GAS TEMPERATURE - C
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
4
4
DIRECT COMBUSTION
OIL
120.0 ( 248 F)
774
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 2 (CONT.)
** FANS
FUNCTION
»* FAHS
AfPLICATION
** TAMO
SERVICE
CENTRIFUGE OVERFLOW
ABSORBENT MAKEUP
CENTRIFUGE FEED
PRIMARY LIQUOR
ABSORBER FEED
** PUMPS
SERVICE
CIRCULATION
PH ADJUSTER CIRCULATION
REACTOR CIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
OUTLET STREAM CHARACTERISTICS
*** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
*** SLUDGE
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
** WATER BALANCE
WATER LOOP TYPE
BOOSTER
OXIDATION BLOWER
NUMBER
NUMBER
5
2
1
CENTRIFUGE
7
90X SOLIDS
THICKENER
20X SOLIDS
GYPSUM
8.62
( 9.50 TPH)
FLUE GAS VOLUME & S02 CONCENTRATION
OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 13.1
C 208 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/76 SYSTEM
4/76 SYSTEM
5/76 SYSTEM
6/76 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
29.0
87.8
744 744 720
720 720 720
744 216 216
720 632 632
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS DOWN FOR PART OF MAY AND JUNE FOR ANNUAL BOILER MAINTENANCE.
7/76 SYSTEM 100.0 100.0 744 744 744
8/76 SYSTEM 100.0 100.0 744 744 744
775
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/76 SYSTEM 100.0 100.0 730 720 720
10/76 SYSTEM 94.2 94.2 744 744 701
** PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME DURING OCTOBER WAS NECESSARY FOR DUCT CLEANING.
11/76 SYSTEM 100.0 100.0 720 720 720
12/76 SYSTEM 99.3 99.3 744 744 739
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS DOWN BRIEFLY FOR REPAIR OF A GYPSUM CONVEYOR.
1/77 SYSTEM 100.0 100.0 744 744 744
2/77 SYSTEM 88.2 88.2 672 672 593
3/77 SYSTEM 98.7 98.7 744 744 734
K* PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME IN FEBRUARY & MARCH HAS NEEDED FOR CLEANING OF A PH CONTROLLER.
4/77 SYSTEM 100.0 100.0 720 720 720
5/77 SYSTEM 100.0 51.6 744 384 384
6/77 SYSTEM 100.0 3.3 720 240 240
7/77 SYSTEM 100.0 100.0 744 744 744
8/77 SYSTEM 100.0 100.0 744 744 744
9/77 SYSTEM 100.0 100.0 720 720 720
10/77 SYSTEM 100.0 100.0 744 744 744
11/77 SYSTEM 89.2 89.2 720 720 642
** PROBLEMS/SOLUTIONS/COMMENTS
CLEANING OF THE PH CONTROLLER CAUSED ONE OUTAGE DURING NOVEMBER.
A REACTOR WAS ALSO CLEANED THIS MONTH.
12/77 SYSTEM 100.0 100.0 744 744 744
1/78 SYSTEM 744 744
2/78 SYSTEM 672
3/78 SYSTEM 720
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
776
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 2 (CONT.)
PERFORMANCE DATA
PERIOC MOuULE AVAILABILITY OPS:RABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE PERIOD FROM APRIL 1978 THROUGH MARCH 1979 THE FGD SYSTEM
OPERATED WITH 99.82 AVAILABILITY. THERE WERE NO FORCED OUTAGES DURING THIS
TIME. A TOTAL OF 8147.4 HOURS OF FGD SYSTEM OPERATION WERE LOGGED WITH
19.5 HOURS OF SCHEDULED OUTAGE TIME.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
** PROBLEKS/SOLUTIONS/COMMENTS
DURING APRIL AND MAY THE UTILITY EXPERIENCED NO PROBLEMS WITH THE FGD
SYSTEM.
6/80 SYSTEM 100.0 100.0 100.0 24.6 720 177 177
777
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKASAGO 2 (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 SHUTDOWN FROM JUNE 3 TO JUNE 24 FOR ANNUAL MAINTENANCE.
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER THE REMAINDER OF THE TIME.
7/80
8/80
9/80
10/80
11/80
12/80
SYSTEM
SYSTEM
SYOTEM
SYSTEM
SYSTEM
S>STEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
iOO.O
100.0
700.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
87.3
92
92
93
92
92
.80
.80
.10
.60
.60
7*4
744
720
744
720
744
744
744
720
744
720
649
744
744
720
744
720
649
83.0
83.3
83.4
85.1
84.8
78.4
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JULY THROUGH DECEMBER NO FGD-RELATED PROBLEMS WERE EXPERIENCED.
IN DECEMBER THE BOILER WAS OUT OF SERVICE APPROXIMATELY FOUR DAYS FOR
GENERAL MAINTENANCE.
778
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PUNT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
E.OILER TYPE
EOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOH - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANG;: HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RAN( E ASH CONTENT - 7.
AVEK'AGE MOISTURE CONTENT - 7.
RANCH MOISTURE CONTENT - 7.
AVEP.AGE SULFUR CONTENT - 7.
RANC-.E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ME'-'HANICAL COLLECTOR
NUMBER
TYPE
** ES3
NUMBER
TYPE
SUPPLIER
IHLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SUPPLIER
LINER GENERIC MATERIAL
NU1BER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/3 RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOH RATE - CU.M/S
INLET GAS TEMPERATURE - C
*** FGD SYSTEM
ELECTRIC POWER DEVELOPMENT CO
TAKEHARA
1
MIHARA
JAPAN
******
56.
271.
( .130 LB/MMBTU)
( .630 LB/MMBTU)
<#***** LB/MMBTU)
231
250
231
239
250
BABCOCK - HITACHI
PULVERIZED COAL
BASE
577.13 (1223000 ACFM)
140.0 ( 284 F)
201. ( 660 FT)
STEEL
3.6 ( 11.9 FT)
I 10804 BTU/LB)
10804-11520
COAL
******
25130.
23.00
9.05
2.00
.05
0
NONE
COLD SIDE
SUMITOMO HEAVY INDUSTRIES
333.2 ( 706000 ACFM)
140.0 ( 284 F)
98.0
VENTURI TOMER
HITACHI
ORGANIC
1
533.7
2.5
2.3
168.0
140.0
( 8471 GPM)
(18.7 GAL/1000ACF)
( 9.1 IN-H20)
( 356000 ACFM)
( 284 F)
779
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKEHARA 1 (CONT.)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCUUTION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
FRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TSADE NAME/COMMON TYPE
CONFIGURATION
PRESSURE DROP - KPA
UASH WATER SOURCE
KASH RATE - L/S
** REHEATER
GENEPIC TYPE
SPECIFIC TYPE
TRACE NAME/COMMON TYPE
INUT FLUE GAS TEMPERATURE - C
** FAMS
NoHE ER
FUNCTION
APPLICATION
SERVICE
** TAI-iKS
SERVICE
PrtESCRUBBER RECYCLE
SwRUBBER RECYCLE
FILTER LIQUID
SLURRY
OXIDATION TOWER
** PUMPS
SrRVICE
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
NONE
BABCOCK - HITACHI
FULL SCALE
RETROFIT
Y. 91.70
94.20
1
2/79
2/77
TRAY TOWER
BABCOCK-HITACHI
CARBON STEEL
N/A
ORGANIC
PLASTIC
5
721.
7.0
3.8
164.76
52.2
(11448 GPM)
( 52.4 GAL/1000 ACF)
(15.2 IN-H20)
( 349142 ACFM)
( 126 F)
MIST ELIMINATOR
2
IMPINGEMENT
TUBE BANK
VERTICAL PARALLEL TUBE BANK
HORIZONTAL
.1 ( .4 IN-H20)
FRESH WATER
1.3 ( 20 GAL/MIN)
DIRECT COMBUSTION
OIL FIRING
OIL
120.0 ( 248 F)
2
BOOSTER
INDUCED DRAFT
WET
NUMBER
COOLER RECYCLE
AfSORBER RECYCLE
2
2
#»#*
****
2
NUMBER
2
4
780
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKEHARA 1 (CONT.)
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
CAPACITY
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
CONFIGURATION
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*»* SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
QUALITY - Y.
DISPOSITION
*** SLUDGE
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
PROCESS CONTROL MANNER
CENTRIFUGE
9
1
4 GPM
20X SOLIDS
88X SOLIDS
THICKENER
1
HORIZONTAL
45 (DIA) X 10 (DEPTH)
12X SOLIDS
20X SOLIDS
GYPSUM
9.89
95.0
MARKETED
( 10.90 TPH)
PH, GAS FLOW
PHI PRESCRUBBER - 5.0, SCRUBBER- 6.0
AUTOMATIC
** WATER BALANCE
WATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF WATER LOSS - LITERS/S 60
MAKEUP WATER ADDITION - LITERS/S 14.9
( 237 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM
5/78 SYSTEM
6/78 SYSTEM
7/78 SYSTEM
8/78 SYSTEM
9/78 SYSTEM
10/78 SYSTEM
11/78 SYSTEM
12/78 SYSTEM
1/79 S', STEM
2/79 SI STEM
3/79 SYSTEM
720
744
720
744
744
720
744
720
744
744
672
744
781
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKEHARA 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
99.95X AVAILABILITY WAS REPORTED FOR THE PERIOD FROM APRIL 1978 THROUGH
MARCH 1979.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION WAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 87.9 100.0 100.0 87.9 90.10 720 633 633 82.4
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS OUT OF SERVICE FOR APPROXIMATELY 3 DAYS IN JUNE TO
REMOVE THE SCALE ACCUMULATION IN THE FGD OUTLET DUCT.
7/80
8/80
9/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
100.0
91.00
91.70
93.10
744
744
720
744
744
720
744
744
720
95.5
95.3
95.3
#* PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE THIRD QUARTER 1980.
10/80 SYSTEM 100.0 100.0 100.0 100.0 93.40 744 744 744 94.5
11/80 SYSTEM 100.0 100.0 100.0 100.0 93.70 720 720 720 95.2
12/80 SYSTEM 100.0 100.0 100.0 27.7 91.70 744 206 206 22.4
782
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ELECTRIC POWER DEVELOPMENT CO: TAKEHARA 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S03 PART. HOURS HOURS HOURS FACTOR
_*.«.___ ______ ____ — ,._ — — ...-_ ___________ ___________ _______.._.._ _____ _____ _____ ______ _____ ______
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER MAS OUT OF SERVICE FROM DECEMBER 1 THROUGH DECEMBER ZS FOR
SCHEDULED MAINTENANCE.
783
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FLEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANSE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - V.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SUPPLIER
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
COMMERCIAL START-UP
HOKKAIDO ELECTRIC POWER
TOMATOATSUMA THERMAL POW
1
TOMAKOMAI
JAPAN
******
******
******
(****** LB/MMBTU)
(****** LB/MMBTU)
{****** LB/MMBTU)
******
350
350
175
175
350
BABCOCK-HITACHI K.K.
PULVERIZED COAL
BASE
508.21 (1076939 ACFM)
121.1 ( 250 F)
170. ( 558 FT)
STEEL
4.5 ( 14.6 FT)
(108000 BTU/LB)
******
COAL
BITUMINOUS
******
20.50
******
7.00
******
.30
******
********
******
4
HOT SIDE
HITACHI PLANT ENG £ CONST CO
828.8 (1756252 ACFM)
363.9 ( 687 F)
.2 ( 1. IN-H20)
99.8
VENTURI TOWER
BABCOCK-HITACHI K.K.
198.7 ( 421036 ACFM)
47.2 ( 117 F)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
BABCOCK-HITACHI K.K.
FULL SCALE
RETROFIT
90.00
1
10/80
784
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
HOKKAIDO ELECTRIC POWER: TOMATOATSUMA THERMAL POW 1 (CONT.)
INITIAL START-UP 7/80
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
SUPPLIER
INLET GAS FLOW - CU. M/S
INLET 6AS TEMPERATURE - C
PARTICLE REMOVAL EFFICENC.Y - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
SPECIFIC TYPE
CONi7IGURATION
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
** FANS
NUMBER
DESIGN
SUPPLIER
FUNCTION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
** REAGENT PREPARATION EQUIPMENT
NUMBER
PPODUCT QUALITY - X SOLIDS
** SOLIDS CONCENTRATIN6/DEWATERING
DEVICE
Nl TIBER
*» SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
N'JMBER OF SPARES
*** SALEABLE BYPRODUCTS
NATURE
QUALITY - X
DISPOSITION
** WATER BALANCE
WATER LOOP TYPE
MAKEUP WATER ADDITION - LITERS/S
B-ABCOCK-HITACHI
198.69 ( 421036 ACFM)
47.2 ( 117 F)
90.0
MIST ELIMINATOR
1
SHEBURON
VERTICAL
WASTE HEAT RECOVERY
GAS-GAS
14.3
47.8 ( 118 F)
199.17 ( 422057 ACFM)
CENTRIFUGAL
HITACHI,LOT.
BOOSTER
254.47 ( 539247 ACFM)
137.2 ( 279 F)
92.0
THICKENER
2
CENTRIFUGE
3
1
GYPSUM
45.0
MARKETED
CLOSED
4.0
( 63 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/80 SYSTEM 100.0 100.0 100.0 70.3 94.40 744 523 523 46.0
** PROBLEMS/SOLUTIONS/COMMENTS
OPERATIONS AT THE TOMATOATSUMA STATION COMMENCED IN OCTOBER 1980.
11/80 SYSTEM 100.0 100.0 100.0 85.1 92.40 720 613 613 61.1
785
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
HOKKAIDO ELECTRIC POWER: TOMATOATSUMA THERMAL POW 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
18/80 SYSTEM 100.0 100.0 100.0 100.0 94.10 744 744 744 94.7
** PRQBLEMS/SOLUTIONS/COMMENTS
DURING DECEMBER SCALE FORMATION WAS OBSERVED IN THE PIPING AND IN A PUMP OF
THE WASTE WATER TREATMENT FACILITY. A WATER WASH LINE WAS INSTALLED FOR
THE PIPING AND A PUMP WAS ADDED TO ELIMINATE SCALE. THE FGD SYSTEM
OPERATION WAS NOT AFFECTED DURING THIS TIME.
786
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
* SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** EJP
** PA3TICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FG3 SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
532 REMOVAL MODE
P^OCfcSS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVILOPMENT LEVEL
NzW/RETROFIT
CURRENT STATUS
T:9MNATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5A
FARMINGTON
NEW MEXICO
21.
258.
******
2089
755
*****
755
******
PULVERIZED COAL
BASE
********
*******
******
******
*******
( .050 LB/MMBTU)
( .600 LB/MMBTU)
(****** LB/MMBTU)
(******* ACFM)
(**** F)
(**** FT)
(***** FT)
( 9700 BTU/LB)
******
COAL
SUBBITUMINOUS
22562.
24.00
******
11.00
******
.81
******
********
******
0
NONE
NONE
N/A
THROWAWAY PRODUCT
MET SCRUBBIKG
LIME
SOUTHERN CALIFORNIA EDISON
BECHTEL
EXPERIMENTAL
RETROFIT
8
**/76
2/76
787
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A (CONT.)
** ABSORBER
GENERIC TYPE
SPECIFIC TYPE
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
** FANS
NUMBER
FUNCTION
APPLICATION
CONSTRUCTION MATERIAL GENERIC TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
NUMBER
** PUMPS
SERVICE
SLURRY RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
DIMENSIONS - FT
SHELL GENERIC MATERIAL TYPE
OUTLET STREAM CHARACTERISTICS
SPRAY TOWER
OPEN COUNTERCURRENT SPRAY
60 X 28 X 17
CARBON STEEL
AISI 1110
N/A
ORGANIC
RUBBER,FLAKEGLASS,SILICA POLYESTER RESIN
5
MIST ELIMINATOR
1
IMPINGEMENT
BAFFLE
CHEVRON VANE
STAINLESS STEEL AND CARBON STEEL
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLES
1
BOOSTER
FORCED DRAFT
MANGANESE, VANADRUM STEEL
LIME SLAKING
SLAKER
1
NUMBER
12
THICKENER
1
60 - DIAMETER
CARBON STEEL
30X SOLIDS
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION '/. REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
2/76 SYSTEM
692
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT NO. 5 WAS FIRST PLACED IN COMMERCIAL OPERATION IN JULY 1970. THE FGD
SYSTEM WHICH WAS RETROFITTED ON UNIT NO. 5 WAS A WEIR HORIZONTAL CROSSFLOW
SPRAY ABSORBER WHICH WAS FORMERLY INSTALLED AND OPERATED IN A TEST PROGRAM
AT THE MOHAVE GENERATING STATION OF THE SOUTHERN CALIFORNIA EDISON COMPANY.
THE HORIZONTAL MODULE WAS A FOUR-STAGE SCRUBBING CHAMBER. EACH STAGE
CONTAINED A ROW OF 36 EXTERNALLY MOUNTED NOZZLES. THE SLURRY WAS CYCLED
THROUGH THE SCRUBBER IN A COUNTERCURRENT MANNER AT A RATE OF 36,000 GPM/
STAGE. THE FRESH LIME SLURRY WAS SPRAYED ACROSS THE FLUE GAS AT THE FOURTH
STAGE, WHICH WAS THE DISCHARGE END OF THE SCRUBBING CHAMBER. THE SCRUBBING
SOLUTION WAS THEN COLLECTED AND RECYCLED SUCCESSIVELY TO THE THIRD, SECOND,
AND FIRST STAGES OF THE SCRUBBING MODULE. THIS ALLOWED COMPLETE DEPLETION
OF ANY CONCENTRATION. THE CLEANED GASES THEN PASSED THROUGH A MIST ELIMI-
788
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
NATOR AND WERE REHEATED BEFORE BEING DISCHARGED TO THE STACK. THE SPENT
SLURRY WAS DISCHARGED FROM THE SCRUBBING SYSTEM TO A THICKENER AND THE
UNDERFLOW WAS PUMPED TO AN ON-SITE SETTLING POND. WATER WAS RETURNED TO
THE PROCESS FOR FURTHER USE.
INSTALLATION OF THE MODULE AT THE FOUR CORNERS GENERATING STATION WAS
COMPLETED AND THE SYSTEM WAS PLACED IN SERVICE ON FEBRUARY 17, 1976, FOR
INITIAL OPERATION.
3/76 SYSTEM 744
4/76 SYSTEM 720
#* PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS TAKEN OFF LINE IN MID-APRIL FOR A SCHEDULED BOILER
OVERHAUL. THE SYSTEM WAS SCHEDULED TO COME BACK ON LINE IN JULY 1976.
5/76 SYSTEM 744
6/76 SYSTEM 720
7/76 SYSTEM 744
8/76 SYSTEM 744
9/76 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM REMAINED OUT OF SERVICE THROUGH MID-APRIL 1976 DUE TO AN EXTEN-
SIVE OVERHAUL OF THE NO. 5 BOILER PLUS THE DEVELOPMENT OF PROBLEMS WITH
THE SCRUBBER MODULE'S REHEATER.
10/76 SYSTEM 744
11/76 SYSTEM 720
12/76 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE PROTOTYPE WAS IN SERVICE THROUGHOUT THE MONTH OF NOVEMBER. ON
DECEMBER 6 THE TEST PROGRAM WAS CONCLUDED AND THE UNIT WAS DISMANTLED.
789
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY KAME
PLANT NAhE
UNIT N'JMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTIC'JLATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NS/J
NOX EMISSION LIMITATION - NG/J
NET PUNT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BC'ILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUcL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
BOSTON EDISON
MYSTIC
6
CHARLESTOWN
MASSACHUSETTS
******
******
*****
150
*****
*****
150
COMBUSTION ENGINEERING
OIL FIRED
******
273.70
148.9
99.
******
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
( 580000 ACFM)
( 300 F)
( 325 FT)
(***** FT)
(****** BTU/LB)
OIL
NO. 6
******
.07
1.00
2.00
******
********
******
0
NONE
0
NONE
NONE
N/A
SALEABLE PRODUCT
WET SCRUBBING
MAGNESIUM OXIDE
CHEMICO DIVISION, ENVIROTECH
DEMONSTRATION
RETROFIT
X 55.00
90.00
8
**/7<*
4/72
790
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
BOSTON EDISON: MYSTIC 6 (CONT.)
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SHELL GENERIC MATERIAL
SHELI MATERIAL TRADE NAMF/COMMON TYPE
IINE^ GENERIC MATERIAL
LINES SPECIFIC MATERIAL
N'JMT ER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
INLET GAS FLOW - CU. M/S
INLI.T GAS TEMPERATURE - C
** MI5T ELIMINATOR
P'?E-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
NUMBER OF PASSES PER STAGE
W*SH WATER SOURCE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
** FANS
NUMBER
APPLICATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
SHELL GENERIC MATERIAL TYPE
FEED STREAM CHARACTERISTICS
** PRO"ESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
** WATER BALANCE
WATER LOOP TYPE
4/72
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CARBON STEEL.
N/A
ORGANIC
EPOXY
1
945. - (15000 GPM)
4.4 ( 33.0 GAL/1000 ACF)
200.56 ( 425000 ACFM)
148.9 ( 300 F)
MIST ELIMINATOR
1
IMPINGEMENT
BAFFLE
6
FRESH
0
NONE
N/A
N/A
INDUCED DRAFT
CENTRIFUGE
1
CARBON STEEL
107. SOLIDS
PH, FLUE GAS INLET TEMP., SCRUBBER OUTLET TEMP.
PH - 6.8
PH - BLEED LINE FROM ABSORBER TO CENTRIFUGE
MANUAL
FEEDBACK
CLOSED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
'/. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/72 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
THIS EXPERIMENTAL MAGNESIUM OXIDE SCRUBBING UNIT WAS RETROFITTED ON A 155
MW, OIL FIRED BOILER. THE SULFUR DIOXIDE AND PARTICLE MATTER REMOVAL
OCCURRED IN THE VENTURI SCRUBBER MODULE. THE S02 WAS CAPTURED AND CON-
VERTED TO MAGNESIUM SULFITE IN THE VENTURI. THE PRODUCT SLURRY WAS THEN
FILTERED AND DRIED. THE DRY MATERIAL CALCINED AT HIGH TEMPERATURES TO
DRIVE OFF THE S02 AND REGENERATE MAGNESIUM OXIDE. THE SOS STREAM WAS
PROCESSED IN A SULFURIC ACID PLANT TO PRODUCE SULFURIC ACID. THE UTILI-
TY AND THE EPA PROVIDED THE MAJOR PORTION OF THE FUNDING FOR THIS
791
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
BOSTON EDISON: MYSTIC 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SOS PART. HOURS HOURS HOURS FACTOR
REGENERABLE DEMONSTRATION PROJECT.
5/73 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
FROM INITIAL STARTUP IN APRIL 1972 UNTIL MAY 1973 THE SCRUBBER OPERATED
INTERMITTENTLY BECAUSE OF MECHANICAL DIFFICULTIES. THE MAJOR PROBLEM
ENTAILING DESIGN AND OPERATION OF THE MAGNESIUM SULFITE CRYSTAL DRYER,
APPARENTLY WAS RESOLVED BY REDESIGN AND FUEL CHANGE.
6/73 SYSTEM 67.9 55.8 720 592 402
7/73 SYSTEM 61.0 47.2 744 575 351
** PROBLEMS/SOLUTIONS/COMMENTS
DURINw JUNE AND JULY THE LONGEST PERIOD OF CONTINUOUS OPERATION OCCURRED.
THE SYSTEM OPERATED 7.5 DAYS.
8/73 SYSTEM .0 744 0
*» PROBLEMS/SOLUTIONS/CfJMMENTS
DURING AUGUST THE BOILER WAS TAKEN OFF-LINE FOR AN ANNUAL OVERHAUL.
9/73 SYSTEM 38.1 33.8 720 637 243
10/73 SYSTEM 60.1 50.7 744 627 377
** PROBLEMS/SOLUTIONS/COMMENTS
DURING SEPTEMBER AND OCTOBER HEAVY EROSION/CORROSION IN THE LIQUOR RECIR-
CULATION PUMPS AND CENTRIFUGE DECREASED THE AVAILABILITY OF THE FGD SYSTEM.
11/73 SYSTEM 25.6 22.5 720 629 162
12/73 SYSTEM 13.1 11.6 744 658 86
1/74 SYSTEM 27.4 20.4 744 555 152
2/74 SYSTEM 25.5 20.5 672 541 138
** PROBLEMS/SOLUTIONS/COMMENTS
IN JANUARY AND FEBRUARY FREQUENT SHUTDOWNS DUE TO BOILER-RELATED PROBLEMS
LIMITED SYSTEM OPERATION.
3/74 SYSTEM 86.5 47.4 744 408 353
** PROBLEMS/SOLUTIONS/COMMENTS
SINCE FEBRUARY 1974 THE AVAILABILITY OF THE BOILER HAS INCREASED.
4/74 SYSTEM 80.5 65.4 720 585 471
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL, TWO 7-DAY CONTINUOUS OPERATION PERIODS OCCURRED.
5/74 SYSTEM 57.4 37.6 744 488 280
792
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
BOSTON EDISON: MYSTIC 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
508 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY, A TWO WEEK OUTAGE OF THE ACID PLANT WAS THE CAUSE OF A LOW
FGD SYSTEM OPERABILITY FIGURE.
6/74 SYSTEM 51.5 40.0 720 559 288
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE 1974 THE DEMONSTRATION PROGRAM WAS COMPLETED AND THE FGD
SYSTEM WAS SHUTDOWN. EPA FUNDING OF THE CALCINING PORTION OF THIS OPERA-
TION EXPIRED. THERE WERE NO DEFINITE PUNS FOR RESTARTING THIS UNIT.
MAJOR PROBLEM AREAS ENCOUNTERED DURING THE OPERATION OF THIS PROTOTYPE
UNIT INCLUDED TRIHYDRATE INSTEAD OF HEXAHYDRATE SULFITE CRYSTAL FORMATION,
DUST PROBLEMS IN THE DRYER, LACK OF STACK GAS REHEAT CAUSING CONDENSATION
IN THE STACK, LOUVER DAMPER PROBLEMS,' EROSION OF PUMPS, PIPING, AND
CENTRIFUGE, AND MINOR ANCILLARY EQUIPMENT FAILURES.
793
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
MIMBER
TYPE
** FABRIC FILTER
KUMBER
TYPE
** ESP
NUM1.-ER
7YP1-:
SUPPLIER
INLKT FLUE GAS TEMPERATURF - C
PARTICLE REMOVAL EFFICENCf - X
** PARTICLE SCRUBBER
NJMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
COMMONWEALTH EDISON
WILL COUNY
1A
ROMEOVILLE
ILLINOIS
******
86.
774.
******
1147
167
137
( .200 LB/MMBTU)
( 1.800 LB/MMBTU)
(****** LB/MMBTU)
167
BABCOCK *
CYCLONE
CYCLING
363.36
179.4
107.
******
3.8
WILCOX
( 770000 ACFM)
( 355 F)
( 350 FT)
( 12.4 FT)
COAL
22260. ( 9570 BTU/L3)
9,100 - 10,500
7.40
3-16
********
1.50
0.3 - 4.5
0
NONE
0
NONE
COLD SIDE
WESTERN PREC. DIVISION, JOY
179.4 I 355 F)
90.0
VENTURI TOWER
VARIABLE-THROAT/SIDE-MOVABLE BLADES
BABCOCK 4 WILCOX
8 X 26 X 16 (THROAT 21 X 1.8)
CARBON STEEL
AISI 1110
ORGANIC,INORGANIC
VINYL ESTER, HYDRAULICALLY-BONDED CEMENT
365.4 ( 5800 GPM)
2.4 (18.0 GAL/1000ACF)
2.2 ( 9.0 IN-H20)
794
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: WILL COUNY 1A (CONT.)
SUPERFICIAL GAS VELOCITY - M/S 36.6
INLET GAS FLOW RATE - CU.M/S 181.7
INLET GAS TEMPERATURE - C 179.*
PARTICLE REMOVAL EFFICIENCY - X 98.0
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PROOUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
«* DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
WMBER OF STAGES
MJMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
WASH WATER SOURCE
kASH RATE - L/S
** REHEATER
KUMBFR
6ENEHIC TYPE
SPECIFIC TYPE
TEMPERATURE INCREASE - C
INL(;T FLUE GAS FLOW RATE - CU. M/S
INLFT FLUE GAS TEMPERATURE - C
( 120.0 FT/S)
( 385000 ACFM)
( 355 F)
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
BABCOCK & WILCOX
BECHTEL
FULL SCALE
RETROFIT
7. 98.00
76.00
8
**/77
3/73
2/72
TRAY TOWER
BABCOCK & WILCOX
16 X 24 X 60
CARBON STEEL
HIGH STRENGTH LOW ALLOY
COR-TEN
ORGANIC
RUBBER
PERFORATED TRAYS
2
411000 GPM)
( 35.0 GAL/1000 ACF)
(10.0 IN-H20)
( 10.0 FT/S)
( 385000 ACFM)
t 355 F)
693.
4.7
2.5
3.0
181.68
179.4
76.0
MIST ELIMINATOR
2
IMPINGEMENT
BAFFLE
CHEVRON VANE
HORIZONTAL
3
3.05 (10.0 FT)
3.8 ( 1.50 IN)
45
.2 ' ( 1.0 IN-H20)
FIBERGLASS REINFORCED PLASTIC
FRESH & POND WATER
71.0 ( 1125 GAL/MIN)
2
IN-LINE
STEAM
11.1
179.32
53.3
( 52 F)
( 380000 ACFM)
( 128 F)
CONSTRUCTION MATERIAL GENERIC TYPE
CARBON STEEL
795
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
COMMONIIEALTH EDISON: HILL COUNY 1A (CONT.)
** FANS
NUMBER
FLECTION
APPLICATION
FLUE GAS TEMPERATURE - C
** REA3ENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
NUMBER
FULL LOAD DRY FEED CAPACITY - M.TONS/HR
PRODUCT QUALITY - X SOLIDS
** TANKS
SERVICE
VENTURI RECYCLE
** PUMPS
SERVICE
VENTURI RECIRCULATION
ABSORBER RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
CONFIGURATION
DIMENSIONS - FT
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
CAPACITY
*** SLUDGE
** TREATMENT
METHOD
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
LOCATION
** DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
PROCESS CONTROL MANNER
** WATER BALANCE
WATER LOOP TYPE
2
BOOSTER
INDUCED DRAFT
82.2 ( 180 F)
L/S GRINDING
BALL MILL
Z
10.9 ( 12 TPH)
27.5
NUMBER
2
NUMBER
6
8
THICKENER
1
CIRCULAR, SLOPED BOTTOM
65* DIA. X 15' HIGH
VACUUM FILTER
1
90 TPD
FLYASH/LIME STABILIZATION
CHICAGO ADMIXTURES
INTERIM
EMERGENCY CLAY-LINED POND
ON SITE
FINAL
LANDFILL
OFF SITE
TRUCK
PRESSURE, LIMESTONE FEED, PH
AUTOMATIC
CLOSED
796
-------
EPA UTILITY FGD SURVEY! OCTOBER - DECEMBER 1980
COMMONWEALTH EDISON: HILL COUNY 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOa PART. HOURS HOURS HOURS FACTOR
0/72 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR MILL COUNTY LOCATED IN
SECTION IA OF THIS REPORT.
797
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAKE
UNIT N'JMI.ER
CITY
STATE
REGULATOFY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMCSSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PUNT GENERATING CAPACITY - MM
GROSS 'JNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
B3ILER TYPE
B1ILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RA'^IGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RAMGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
** ESP
NUMBER
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
»* GENERAL DATA
SALEABLE PRODUCT/THROMAMAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
DAIRYLAND POWER COOP
ALMA
5
ALMA
WISCONSIN
******
******
******
******
210
80
*****
80
******
******
******
*******
******
******
3t Kit Jf StJt^f
(****** LB/MMBTU)
<****** LB/MMBTU)
(****** LB/MMBTU)
COAL
******
******
12 - 20
********
3.0 - 3.5
********
(******* ACFM)
(**** F)
I**** FT)
(***** FT)
(****** BTU/LB)
10,500 - 11,000
NONE
N/A
THROMAHAY.PRODUCT
WET SCRUBBING
LIME
FOSTER WHEELER
EXPERIMENTAL
RETROFIT
32.50
8
**/7
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
DAIRYUNO POWER COOP: ALMA 5 ICONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
6/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
THIS EXPERIMENTAL WET LIME FURNACE SYSTEM COMMENCED OPERATIONS IN JUNE
1971 AND WAS OPERATIONAL FOR PERIOCS UP TO 30 DAYS. IN AUGUST 1974 THE
UNIT WAS TESTED FOR TWO DAYS USING WESTERN LOW-SULFUR COAL. THE TEST
SHOWErt ABOUT BOX SOZ REMOVAL EFFICIENCY, BUT ESP PERFORMANCE WAS ADVERSELY
AFFECTED. THE FGD PROJECT HAS BEEN SHUT DOWN INDEFINITELY SINCE AUGUST
1974, WD THERE ARE NO PLANS FOR FUTURE OPERATION.
799
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MH
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVEFAGE HEAT CONTENT - J/G
RWOE HEAT CONTENT - BTU/LJ
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
R\NGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FAtiRIC FILTER
NUMBER
TYPE
** ESF
NLMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SH'iLL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
DETROIT EDISON
ST. CLAIR
6A
BELLE RIVER
MICHIGAN
C
86.
1376.
******
1798
325
15*
163
163
COMBUSTION ENGINEERING
******
PEAK
465.77
132.2
130.
******
( .200 LB/MMBTU)
( 3.200 LB/MMBTU)
(****** LB/MMBTU)
( 987000 ACFM)
( 270 F)
( 425 FT)
(***** FT)
( 9600 BTU/LB)
9,500 - 9,600
COAL
SUBBITUMINOUS
22330.
4.00
3.0-4.0
22.60
22 - 24
.35
0.3 - 0.4
********
0
NONE
0
NONE
WHEELABRATOR-FRYE
90.0
VENTURI TOWER
VARIABLE-THROAT/ADJUSTABLE DRUM
PEABODY-LURGI
STAINLESS STEEL
AUSTENITiq
ORGANIC
RUBBER
RUBBER LINED CARBON STEEL & 316L SS
278.5 ( 4420 GPM)
2.7 (20.0 GAL/1000ACF)
3.5 (14.0 IN-H20)
28.3 ( 93.0 FT/S)
116.6 ( E47000 ACFM)
800
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
DETROIT EDISON: ST. CLAIR 6A (CONT.)
INLET GAS TEMPERATURE - C 132.2
»*» FGD SYSTEM
( 270 F)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
G4S CONTACTING DEVICE TYPE
L/G RATIO - L/CU.M
G*S-SIDE PRESSURE DROP - KPA
SJPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
SOS REMOVAL EFFICIENCY - 7.
** MIST ELIMINATOR
P^E-FIST ELIMINATOR/MIST ELIMINATOR
NJMBFR PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRACE NAME/COMMON TYPE
CONFIGURATION
FREEBOARD DISTANCE - M
DISTANCE BETWEEN VANES - TM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
** REMEATER
NUMBER
GiINERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
P1RCENT GAS BYPASSED - AVG
Ti-MPERATURE INCREASE - C
IIILET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
** FANS
Nl TIBER
SUPPLIER
FUNCTION
APPLICATION
SE7VICE
CONSTRUCTION MATERIAL GENERIC TYPE
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
BECHTEL
DEMONSTRATION
RETROFIT
X 99.70
90.00
8
**/76
9/75
6/75
SPRAY TOWER
PEABODY PROCESS SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 316L
NONE
N/A
N/A
NONE
( 80.0 GAL/1000 ACF)
(10.0 IN-H20)
( 9.5 FT/S)
( 215000 ACFM)
( 118 F)
.7
.5
10.
2.
2.9
101.46
90.0
MIST ELIMINATOR
2
CENTRIFUGAL
RADIAL VANE
RADIAL BAFf-LE
HORIZONTAL
1.37 (
20.3 (
45
.0 (
3.0 (
316 L SS
4.5 FT)
8.00 IN)
.Z IN-H20)
10.0 FT/S)
DIRECT COMBUSTION
EXTERNAL COMBUSTION CHAMBER
OIL
.0
10.0 ( 50 F)
187.20 ( 396700 ACFM)
50.0 ( 122 F)
PEABODY ENGINEERING
BOOSTER
INDUCED DRAFT
WET
316L SS
801
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
DETROIT EDISON: ST. CLAIR 6A (CONT.)
** REAGENT PREPARATION EQUIPMENT
NUMBER
PRODUCT QUALITY - 7. SOLIDS
** PUMPS
SERVICE
VENTURI RECIRCULATION
SPRAY TOWER RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
*** SLUDGE
** DISPOSAL
NATURE
TYPE
SITE TRANSPORTATION METHOD
SITE TREATMENT
SITE SERVICE LIFE - YRS
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
** WATER BALANCE
WATER LOOP TYPE
35.0
NUMBER
3
6
NONE
0
FINAL
POND
PIPE LINE
CLAY LINED
1
PH, SOLIDS
PH- 5.8-6.0,SOLIDS- 15JC MAX.
RECIRCULATION TANK
AUTOMATIC
FEEDBACK
OPEN
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
SOa PART. HOURS HOURS HOURS FACTOR
0/75 SYSTEM
»* PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR ST. CLAIR 6 LOCATED IN
SECTION 14 OF THIS REPORT.
802
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
UNER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
*** FGO SYSTEM
** GENERAL DATA
SALEABLE PROOUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NiW/KETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
GULF POWER
SCHOLZ
1A
SNEADS
FLORIDA
C
516.
******
80
48
40
*****
BABCOCK £ WILCOX
PULVERIZED COAL
BASE
********
146.1
******
******
*******
(****** LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
(******* ACFM)
( 295 F)
(**** FT)
(***** FT)
COAL
******
****** (****** BTU/LB)
********
******
********
5.00
******
0.15 MAX.
COLD SIDE
BUELL DIVISION* ENVIROTECH
99.5
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
ADL/COMBUSTION EQUIP ASSOCIATES
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BONDED CEMENT
THROWAWAY PRODUCT
WET SCRUBBING
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
PROTOTYPE
RETROFIT
'/. 99.70
95.00
8
803
-------
EPA U.'ILITY FGD SURVEY: OCTOBER - DECEMBER 1980
6ULF POWER: SCHOLZ 1A (CONT.)
TERMINATION
COMMERCIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
GENERIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SH'HLL SPECIFIC MATERIAL
SH:LL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LIUER MATERIAL TRADE NAME/COMMON TYPE
** REHEATER
NUMBER
PERCENT GAS BYPASSED - AVG
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
CONFIGURATION
SHELL SPECIFIC MATERIAL TYPE
*** SLUDGE
** DISPOSAL
NATURE
TYPE
LOCATION
** WATER BALANCE
WATER LOOP TYPE
**/76
2/75
VENTURI TOWER
COMBUSTION EQUIP ASSOCIATES
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
HEIL
5.0
VACUUM FILTER
1
ROTARY DRUM
PLASTIC & FIBERGLASS
FINAL
LINED POND
ON SITE
CLOSED
j. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
•/. REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
2/75 SYSTEM 98.9
** PROBLEMS/SOLUTIONS/COMMENTS
67.6
672 459
454
3/75 SYSTEM
4/75 SYSTEM
5/75 SYSTEM
6/75 SYSTEM
THIS PROTOTYPE FGD SYSTEM INSTALLED AT THE SCHOLZ STEAM PLANT WAS IN-
STALLED ON THE NO. 1 BOILER. THE SYSTEM WAS DESIGNED TO HANDLE APPROXI-
MATELY 50X OF THE FLUE GAS FROM THE BOILER. THE BOILER WAS RETROFITTED
WITH A SECTIONALIZED, HIGH EFFICIENCY ESP INSTALLED UPSTREAM OF THE FGD
SYSTEM AND CAPABLE OF 99.7X PARTICLE MATTER REMOVAL.
THE PROTOTYPE SYSTEM INCORPORATED A HIGH DEGREE OF FLEXIBILITY FOR GENERA-
TION OF DESIGN AND OPERATING INFORMATION FOR A WIDE VARIETY OF APPLICA-
TIONS. ALTHOUGH THE BASIC MODE OF SYSTEM OPERATION WAS DUAL ALKALI WITH
LIME REGENERATION, THE SYSTEM WAS DESIGNED TO ACCOMMODATE LIMESTONE
REGENERATION AND LIME/LIMESTONE REGENERATION. THE SYSTEM CONSISTED OF A
VENTURI SCRUBBER AND AN ABSORPTION TOWER, WITH AN ADDITIONAL STORAGE SILO
FOR LIMESTONE, A MIX TANK, AND OTHER ASSORTED TANKS, PUMPS, CONTROLLERS,
PIPING, AND A LINED DISPOSAL POND.
THE PROTOTYPE DUAL ALKALI SCRUBBING SYSTEM WAS COMPLETED AND PUT IN
OPERATION IN EARLY FEBRUARY 1975.
95.7
55.6
62.7
100.0
65.2
46.7
50.4
100.0
744 507
720 604
744 598
720 720
485
336
375
720
804
-------
EPA UTILITY «GD SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
so2 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
7/75 SYSTEM 32.4
** PROBLEMS/SOLUTIONS/COMMENTS
89.7
683
221
THE SYSTEM WAS OPERATED FROM FEBRUARY 8, 1975 UNTIL JULY 18 WHEN IT WAS
TAKEN OUT OF SERVICE FOR TWO MONTHS FOR MODIFICATIONS, REPAIRS AND REPLACE-
MENT OF PARTS. THE SYSTEM WAS UNAVAILABLE FOR A 491 HOUR PERIOD DUE TO
SOME NECESSARY ADJUSTMENTS AND MODIFICATIONS FOR A FORMAL EPA TEST PRO-
GRAM IN MID-MAY.
8/75 SYSTEM .0
9/75 SYSTEM 44.0
•w PROBLEMS/SOLUTIONS/COMMENTS
.0
35.3
744 744
720 577
0
254
THE SYSTEM WAS SHUT DOWN FROM MID-JULY TO MID-SEPTEMBER FOR A MECHANICAL
OVERHAUL -INVOLVING REPLACEMENT OF VALVE PARTS THAT HAD FAILED. THE SYSTEM
WAS PUT BACK IN OPERATION ON SEPTEMBER 16.
10/75 SYSTEM 100.0
** PROBLEMS/SOLUTIONS/COMMENTS
75.1
744 559
559
FROM MID-SEPTEMBER UNTIL MID-OCTOBER THE AIR PREHEATER WAS REPAIRED AND
BOILER OPERATION WAS ADJUSTED TO REDUCE OXYGEN LEVELS IN THE FLUE GAS TO
THE 5-6X RANGE. THE SYSTEM OPERATED APPROXIMATELY 800 HOURS DURING THIS
PERIOD.
11/75 SYSTEM 90.3
12/75 SYSTEM 100.0
1/76 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
77.8
98.4
720 620 560
744 732 732
744
THE SYSTEM RAN CONTINUOUSLY FOR THE REMAINDER OF THE TEST PERIOD THROUGH
JANUARY 2, 1976. S02 LEVELS DURING THIS PERIOD RANGED FROM 800 TO 1700
PPM. THE SYSTEM OPERATED IN THE CONCENTRATED MODE THROUGHOUT THE REMAINDER
OF THE TEST PERIOD. IN THE PERIOD FROM MID-SEPTEMBER TO JANUARY 2, 1976
THE SYSTEM OPERATED ABOUT 2100 HOURS, WITH AN OPERABILITY FACTOR OF 97X.
2/76 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
696
THE FGD SYSTEM AND BOILER WERE SHUT DOWN FOR A SCHEDULED OVERHAUL. THE
SYSTEM WAS SCHEDULED TO RESTART IN MID-MARCH AND WAS TO CONTINUE UNTIL
JUNE. DURING THIS OPERATING PERIOD HIGH-SULFUR COAL (3.5-4.OX) WAS TO
BE BURNED TO ALLOW EVALUATION OF SYSTEM PERFORMANCE ON HIGH SULFUR COAL.
3/76 SYSTEM 60.0
** PROBLEMS/SOLUTIONS/COMMENTS
59.8
744 742
445
THE SYSTEM WAS RETURNED TO SERVICE ON MARCH 12, 1976.
A TOTAL OF 445 HOURS.
THE SYSTEM OPERATED
5/76 SYSTEM
88.6
87.5
744 735
651
805
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY DURABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*J PROBLEMS/SOLUTIONS/CO 1MENTS
DURING APRIL AND MAY SOME MINOR MECHANICAL PROBLEMS WITH THE AGITATOR
SHAFT ,-IERE ENCOUNTERED.
SOME PROBLEMS WERE EXPERIENCED WITH THE CONTROL VALVES DURING APRIL AND MAY
ACCOUNTING FOR SOME FGD OUTAGE TIME.
SINCE THE SYSTEM RESTART IN MARCH, S02 INLET CONCENTRATION LEVELS RANGED
FROM 2000 TO 2500 PPM DUE TO THE BURNING OF HIGH SULFUR COAL.
6/76 SYSTEM 97.7 89.0 720 656 641
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST PHASE OF OPERATION, THE SYSTEM WAS TREATING FLUE GAS OF
VARYING PARTICULATE MATTER LOADS. THE UPSTREAM ESP WAS SELECTIVELY DE-EN-
ERGIZED, BOTH PARTIALLY AND TOTALLY, WITH NO MAJOR UPSETS IN THE PROCESS
CHEMISTRY RESULTING. BOILER LOAD VARIATION RANGED FROM 30 TO 100X.
7/76 SYSTEM 100.0 7.3 744 54 54
** PROBLEMS/SOLUTIONS/COMMENTS
ON JULY 3, 1976 THE PROTOTYPE TEST PROGRAM WAS CONCLUDED.
806
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMSSION LIMITATION - NG/J
NOX 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 WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
EOILFR SUPPLIER
BOILFR TYPE
BOILER SERVICE LOAD
DESrGN BOILER FLUE GAS FLC'-J - CU.M/S
BOIt.ER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STAC.K TOP DIAMETER - M
** FU*EL DATA
FUEL TYPE
F'JEL GRADE
A/ERAGE HEAT CONTENT - J/G
RVNGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RXNGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
A/ERAGE CHLORIDE CONTENT
RANGE CHLORIDE CONTENT -
V
/•
- 7.
7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SLPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PROOUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
GULF POWER
SCHOLZ
1B.2B
SNEADS
FLORIDA
C
******
516.
******
80
48
40
(****** LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
48
BABCOCK & WXLCOX
PULVERIZED COAL
BASE
(******* ACFM)
( 295 F)
( 76 FT)
(***** FT)
(****** BTU/LB)
146.1
23.
NONE
*******
COAL
******
******
********
******
********
5.00
******
0.15 MAX.
COLD SIDE
BUELL DIVISION, ENVIROTECH
99.5
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CHIYODA INTERNATIONAL
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BONDED CEMENT
THROWAWAY PRODUCT
WET SCRUBBING
THOROUGHBRED 101
CHIYODA INTERNATIONAL
PROTOTYPE
RETROFIT
7. 99.70
90.00
8
807
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1B,ZB (COKT. )
TERMINATION
COMMERCIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
** REHEATER
PERCENT GAS BYPASSED - AVG
** SOLIDS CONCENTRATING/DEWATERING
KUMBER
CONFIGURATION
** WATER BALANCE
fcATER LOOP TYPE
**/77
2/75
PACKED TOWER
CHIYODA INTERNATIONAL
STAINLESS STEEL
AUSTENITIC
TYPE 316L
NONE
N/A
N/A
MIST ELIMINATOR
2
IMPINGEMENT
BAFFLE
CHEVRON VANE
5.0
CONTINUOUS SCREW-DECANTER/SOLID BOWL
OPEN
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/75 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
672 672
THE FGD SYSTEM AT SCHOLZ IB AND 2B WAS DESIGNED FOR TESTING AND PROCESS
DEMONSTRATION OF THE THROUGHBRED 101 PROCESS ON A COAL-FIRED APPLICATION.
THE PROCESS IS USED IN JAPAN EXCLUSIVELY ON OIL-FIRED AND GAS-FIRED BOIL-
ERS, AND TAIL SAS FROM CLAUS UNITS. THE SYSTEM WAS DESIGNED TO HANDLE
SOX OF THE LOAD FROM EITHER OF THE TWO BOILERS. VARIOUS TEST COALS WITH
SULFUR CONTENTS RANGING UP TO 5X WERE SCHEDULED FOR BURNING.
THE PARTICLE MATTER LOADS FROM THE ESP RANGED FROM 0.02 TO 0.1 GR/SCF.
FLUE GAS FROM THE ESP WAS QUENCHED WITH COOLING WATER TO REMOVE ADDITIONAL
FLY ASH AND TO COOL THE SAS BEFORE IT ENTERED THE ABSORBER. THE S02 WAS
ABSORBED IN WATER AND CATALYTICALLY OXIDIZED WITH AIR TO FORM SULFURIC
ACID. THE DILUTE ACID WAS RECIRCULATED THROUGH THE ABSORBER. A PORTION
OF THE ACID WAS NEUTRALIZED WITH LIMESTONE TO PRODUCE GYPSUM AS A BY-
PRODUCT.
THE INITIAL SHAKEDOWN AND DEBUGGING OPERATIONS AT THIS PILOT PLANT SIZE
DEMONSTRATION UNIT COMMENCED ON FEBRUARY 11, 1975. PROBLEMS ENCOUNTERED
INCLUDED CRACKS IN THE FRP LINING AT THE OXIDIZING TOWER.
3/75 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
AFTER INITIAL OPERATION FOR BREAK-IN TESTS IN MARCH, THE SYSTEM WAS
SHUTDOWN FOR INTERNAL INSPECTION.
4/75 SYSTEM
5/75 SYSTEM
27.8
13.4
27.8
13.4
720 720 200
744 744 100
808
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1B.2B (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
6/75 SYSTEM 100.0 95.1 720 685 685
7/75 SYSTEM 83.9 83.9 744 744 624
** PROBLEMS/SOLUTIONS/COMMENTS
RELIABILTY TESTS MERE PERFORMED IN JULY ALTHOUGH EMISSION TESTS HAD NOT
BEEN RUN AT THIS TIME.
BAD C3471 ****
BAD C3471 ****
UP TO THIS POINT, SOME PUMP AND INSTRUMENTATION FAILURES HAD OCCURRED.
DURING JULY ONE CENTRIFUGE BECAME UNBALANCED, REQUIRING THE SPARE TO BE
PLACED IN SERVICE.
8/75 SYSTEM 744
9/75 SYSTEM 46.8 46.8 720 720 337
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE MONTH OF AUGUST BOTH CENTRIFUGES BECAME UNBALANCED REQUIRING
A FORCED OUTAGE WHICH EXTENDED INTO MID-SEPTEMBER.
THE UNIT OPERATED AT A 95X S02 REMOVAL EFFICIENCY DURING THE MONTH OF
SEPTEMBER.
10/75 SYSTEM 100.0 100.0 744 744 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE DISCHARGE OF WASTE WATER FROM THIS SYSTEM HAS A CONTIUOUS PROBLEM
AREA.
11/75 SYSTEM 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
A MINCR OUTAGE OF LESS THAN ONE HOUR WAS NECESSARY TO REPAIR A PINHOLE
IN THE PRESCRUBBER FRP LINER AND TO REPAIR A BROKEN FLUE GAS BLOWER INLET
VANE.
12/75 SYSTEM 97.6 97.6 744 744 726
** PROBLEMS/SOLUTIONS/COMMENTS
SCRUBBER OUTAGES DURING DECEMBER RESULTED FROM CONTINUING REPAIRS TO THE
PINHOLE IN THE PRESCRUBBER FRP LINER.
1/76 SYSTEM 66.2 60.5 744 680 450
2/76 SYSTEM 11.2 11.1 696 690 77
** PROBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME IN JANUARY AND FEBRUARY WAS PRIMARILY FOR REPAIR AND MODIFI-
CATION OF THE SUCTION AND DISCHARGE PIPING ON THE ABSORBENT CIRCULATING
PUMPS. THESE FRP LINES FAILED IN JANUARY AT SOME WEAK JOINTS.
S02 REMOVAL EFFICIENCY UP TO THIS PERIOD HAS BEEN AS HIGH AS 95X.
3/76 SYSTEM '99.6 99.6 744 744 741
809
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1B.2B (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/76 SYSTEM 14.0
** PROBLEMS/SOLUTIONS/COMMENTS
14.0
720 720
101
THE SYSTEM WAS SHUTDOWN ON APRIL 5 TO ALLOW SYSTEM MODIFICATIONS FOR
REDUCING THE QUANTITY OF LIQUID WASTE FROM THE SYSTEM.
THE SYSTEM WAS SHUTDOWN ON APRIL 24 BECAUSE OF EXTENSIVE FIRE DAMAGE IN
THE OXIDIZING TOWER. THE FIRE, CAUSED BY A WELDING ACCIDENT, DAMAGED FRP
AND POLYPROPYLENE COMPONENTS IN THE OXIDIZING TOWER.
5/76
6/76
7/76
SYSTEM
SYSTEM
SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
.0
.0
.0
744
720
744
THE SYSTEM REMAINED OUT OF SERVICE DURING MAY, JUNE AND JULY TO REPAIR THE
FIRE DAMAGED AREAS.
8/76 SYSTEM 66.1
** PROBLEMS/SOLUTIONS/COMMENTS
66.1
744 744
492
THE SYSTEM CAME BACK ON LINE IN AUGUST; BUT, WAS BROUGHT DOWN DURING THE
MONTH TO COMPLETE ADDITIONAL REPAIRS WHICH WENT UNDETECTED DURING THE
PREVIOUS OUTAGE. THESE ADDITIONAL REPAIRS ACCOUNTED FOR APPROXIMATELY 24£
HOURS OF OUTAGE TIME.
THE WATERS SAVINGS PROGRAM WAS TESTED DURING AUGUST. THE TEST PROGRAM
CALLED FOR A REDUCTION IN WASTEWATER SLOWDOWN AND FRESH WATER MAKEUP
REQUIREMENTS BY RECYCLING THE MOTHER LIQUOR BLEED BACK TO THE PROCESS FOR
ADDITIONAL SERVICE.
9/76 SYSTEM 99.3 68.9
** PROBLEMS/SOLUTIONS/COMMENTS
99.3
68.9
720 720
496
THE SYSTEM WAS FORCED OUT OF SERVICE APPROXIMATELY FIVE HOURS DURING
SEPTEMBER.
10/76 SYSTEM 70.6 48.0
** PROBLEMS/SOLUTIONS/COMMENTS
62.0
48.0
744 744
357
11/76
12/76
SYSTEM
SYSTEM
DURING OCTOBER SYSTEM DOWN TIME AMOUNTED TO APPROXIMATELY 387 HOURS. OF
THIS TOTAL 218 HOURS WERE REPORTED TO REPAIR ANTICIPATED DAMAGES INCURRED
IN "IHE PRESCRUBBER RESULTING FROM (.PERATIONS IN THE WATER SAVINGS PROGRAM.
SPECIFICALLY, THE LINING HAD SUFFERED FROM EXTENSIVE CORROSION DAMAGE
BECAUSE OF HIGH ACID CONCENTRATIONS WHICH DEVELOPED IN THE SCRUBBER
SOLUT.'ON.
DURING OCTOBER SYSTEM DOWN TIME AMOUNTED TO APPROXIMATELY 387 HOURS. OF
99.6 99.6 99.6 99.6 720 720 717
99.6 99.6 99.6 99.6 744 744 741
810
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ IB.eB (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
DURING NOVEMBER AND DECEMBER SCRUBBER OUTAGES TOTALLED 6.5 HOURS. PROBLEMS
INCLUDED A MALFUNCTION OF A LEVEL INDICATOR, A BROKEN GUIDE VANE, AND AN
OPERATOR ERROR RESULTING IN A LEAK OF SLURRY INTO THE WATER HEADER.
7
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT .MME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PL*NT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BCILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
AVERAGE MOISTUSE CONTENT - 7.
RANGE MOISTURE CONTENT - V.
AVERAGE SULFUR CONTENT - '/.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SOa REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
INITIAL START-UP
GULF POWER
SCHOLZ
1,2
SNEADS
FLORIDA
C
******
******
******
80
23
23
*****
23
BABCOCK & WILCOX
PULVERIZED COAL
BASE
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
(******* ACFM)
(**** F)
( 76 FT)
(***** FT)
( 1E500 BTU/LB)
******
********
*******
23.
FRP
COAL
BITUMINOUS
29075.
11.00
******
5.00
******
£.50
2.5-5.0
********
******
COLD SIDE
BUELL DIVISION, ENVIROTECH
151.7 ( 305 F)
99.5
NONE
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE/THOROUGHBRED 121
NONE
CHIYODA INTERNATIONAL
CHIYODA CHEMICAL ENG'R & CONST. CO.
PROTOTYPE
RETROFIT
7. 99.50
90.00
8
**/79
8/78
812
-------
GULF POWE3: SCHOLZ 1,2 (CONT.)
EPA UTILITY FfiD SURVEY: OCTOBER - DECEMBER 1980
»* DESIGN AND OPERATING PARAMETERS
** ABSOFBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TUADE NAME/COMMON TYPE
SUPPLIER
DCMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NJMBER OF CONTACTING ZONES
I(LET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PfE-MIST ELIMINATOR/MIST ELIMINATOR
NU1BER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NU1BER OF PASSES PER STAGE
PRESSURE DROP - KPA
** REHEATER
GFNERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
** FANS
NUKBER
APPLICATION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
*** SALEABLE BYPRODUCTS
NATURE
DISPOSITION
*** SLUDGE
** PROCESS CONTROL AND INSTRUMENTATION
PROCESS CONTROL MANNER
** WATER BALANCE
WATER LOOP TYPE
MECHANICALLY-AIDED TOWER
GAS SPARGER
JET BUBBLER REACTOR
CHIYODA INTERNATIONAL
24 FT DIA.
STAINLESS STEEL
AUSTENITIC
ORGANIC
FIBER-REINFORCED POLYESTER
SPARGER
1
37.75 t 80000 ACFM)
148.9 ( 300 F)
95.0
MIST ELIMINATOR
1
IMPINGEMENT
BAFFLE
CHEVRON VANE
VERTICAL
2
2
.2 ( 1.0 IN-H20)
NONE
N/A
N/A
FORCED DRAFT
25.01 (
148.9 (
GYPSUM
STACKED IN POND
MANUAL
CLOSED
53000 ACFM)
300 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/78 SYSTEM
813
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1,2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
OPERATION BEGAN ON AUGUST 30, 1970.
NO INITIAL OPERATIONAL PROBLEMS fr'ERE REPORTED.
9/78 SYSTEM 720
10/78 SYSTEM 300.0 720
** PROBLEMS/SOLUTIONS/COHMENTS
NO MAJOR OPERATIONAL PROBLEMS WERE REPORTED.
A 130 HOUR SCHEDULED OUTAGE OCCURRED IN OCTOBER.
11/78 SYSTEM 94.8 720
12/78 SYSTEM 100.0 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
THERE WERE NO UNPLANNED SHUTDOWNS DURING DECEMBER AND JANUARY.
THE SYSTEM WAS BETS'G OPERATED IN WHAT WAS CALLED PHASE II OF THE TESTING.
THE SYSTEM WAS DL T'5ERATELY BEING UPSET FROM EQUILIBRIUM (PH, OXIDIZING AI
INPUT, ETC.) TO SEE HOW IT RESPONDED.
744 0
672 672 661
744 744 744
720 720 720
** PROBLEMS/SOLUTIONS/COMMENTS
ONE PUMP FAILURE CAUSING A B MINUTE OUTAGE WAS REPORTED BY THE UTILITY.
HIGH PARTICULATE LOADING TESTS WERE DONE IN APRIL. THE ESP WAS TOTALLY
SHUT DOU'N. THE S02 REMOVAL WAS NOT AFFECTED BUT THE GYPSUM PRODUCT WAS
TEMPORARILY AFFECTED. HIGH CHLORIDE TESTS WERE ALSO PERFORMED BY ADDING
CALCIUM CHLORIDE TO THE SYSTEM. A RESULTANT CONCENTRATION OF 6000 PPM
CHLORIDE WAS FOUND IN THE UNDERFLOW. NO SIGNIFICANT SCALING WAS ENCOUNT-
ERED.
5/79 SYSTEM 744
6/79 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
BAD C3471 ****
THE FGD SYSTEM OPERATED THROUGH THE 24TH OF MAY WHEN THE SYSTEM WAS RE-
MOVED FROM SERVICE BECAUSE THE EPRI STUDIES WERE COMPLETED.
JUNE:
AFTER SHUTDOWN THE UNIT WAS MODIFIED TO SIMULATE A SMALLER JET BUBBLER
REACTOR WITH THE SAME AMOUNT OF FLUE GAS. THIS WAS DONE BY PLUGGING SOME
OF THE SPARGERS AND RISER TUBES. THE UNIT WAS OPERATED LIKE THIS FROM
JL'NE 8 UNTIL JUNE 29 WITH RESULTS THAT INDICATED SLIGHTLY REDUCED REMOVAL
EFFICIENCIES. DURING THE 21 DAYS OF OPERATION THE UNIT WAS DOWN ONLY
ONCE FOR NINE HOURS FOR ROUTINE INSPECTION.
814
1/79 SYSTEM
2/79 SYSTEM
3/79 SYSTEM 100.0
4/79 SYSTEM 100.0
100.0
98.3
100.0 100.0
100.0 100.0
98.4
100.0
100.0
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 1,2 (CONT.)
------------------------------------------ PERFORMANCE DATA ------------------------------------------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
DURING THE EPRI STUDY A TOTAL OF Wt8 HOURS OF OPERATION WERE LOGGED WITH
A TOTAL OF 123.3 HOURS OF SHUTDOWN. THE AVERAGE AVAILABILITY FOR SIX
MONTHS WAS 99.53X.
ALL STUDIES WERE COMPLETED AND THE SYSTEM HAS BEEN TERMINATED.
815
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
GULF POWER
SCHOLZ
2A
SNEADS
FLORIDA
C
******
******
******
80
48
40
*****
48
<****** LB/MMBTU)
<****** LB/MMBTU)
(****** LB/MMBTU)
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FU£L DATA
FUEL TYPE
FJEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - 7.
RWGE MOISTURE CONTENT - 7.
A/ER/GE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANCE CHLORIDE CONTENT - 7.
*** PAKTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
T-'PE
** ESP
NUMBER
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FG!) SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROMAMAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
BABCOCK & HILCOX
PULVERIZED COAL
BASE
(******* ACFM)
( 295 F)
(**** FT)
(***** FT)
(****** BTU/LB)
146.1
******
******
COAL
BITUMINOUS
******
********
******
3.50
******
********
0.15 MAX.
0
NONE
NONE
N/A
SALEABLE PRODUCT
DRY ADSORPTION
ACTIVATED CARBON
FOSTER WHEELER/BERGBAU
DEMONSTRATION
RETROFIT
7. 99.70
74.50
8
2/76
2/76
8/75
1/73
816
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 2A (CONT.)
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PACKED TOWER
FOSTER WHEELER/BERGBAU
0
NONE
N/A
N/A
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
5/75 SYSTEM
744
»* PROBLEMS/SOLUTIONS/COMMENTS
THE DEMONSTRATION SYSTEM AT SCHOLZ 2A CONSISTED OF A 20-MW ADSORBER SECTION
AND A 47.5 MW REGENERATION AND REDUCTION SECTION. THE 20 MW ADSORBER
WAS DESIGNED TO HANDLE SOX OF THE MAXIMUM FLUE GAS FLOW. THE PURPOSE OF
THE ADSORPTION SECTION OF THE DRY REMOVAL SYSTEM WAS TO REMOVE SULFUR
DIOXIDE; NITROGEN OXIDES, AND PARTICLE MATTER FROM THE FLUE GAS WITH
ACTIVATED CHAR, CONVERTING THE CAPTURED POLLUTANTS TO SULFURIC ACID.
REGENERATION SECTION PROVIDED CONTINUOUS ON-SITE REGENERATION OF THE CHAR,
WHICH WAS LOADED WITH SULFUR DIOXIDE IN THE FORM OF SULFURIC ACID. THE
REGENERATED CHAR AND A LOW VOLUME, SULFUR DIOXIDE-RICH OFF-GAS STREAM WAS
FED TO A RESOX REACTOR, WHICH REDUCED THE SULFUR DIOXIDE STREAM
TO GASEOUS ELEMENTAL SULFUR THAT WAS COLLECTED AND STORED IN AN INSULATED
TANK.
THE
6/75 SYSTEM
7/75 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
COMPLETION OF CONSTRUCTION WAS FOLLOWED BY A THREE MONTH COMMISSIONING
PERIOD DURING WHICH VARIOUS PIECES OF EQUIPMENT WERE OPERATED INDIVIDUALLY
AND THEN IN COMBINATIONS TO SIMULATE SUBSYSTEM OPERATION.
8/75 SYSTEM
744
** PROBLEMS/SOLUTIONS/COMMENTS
SUBSYSTEM OPERATIONS WERE INTEGRATED INTO SECTION OPERATIONS AND FLUE GAS
WAS PASSED THROUGH THE ABSORBER AND REGENERATOR FOR A TEN DAY PERIOD
BEGINNING AUGUST 11. RESOX CONSTRUCTION WAS INCOMPLETE AT THIS TIME.
9/75 SYSTEM
10/75 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
744
11/75 SYSTEM
12/75 SYSTEM
1/76 SYSTEM
DURING OCTOBER TWO CONSECUTIVE RUNS WERE CONDUCTED ON THE RESOX PORTION OF
THE SYSTEM ON FRONT-END PROCESS OFF-GAS AT FULL OPERATING TEMPERATURES.
THIS OPERATIONAL PERIOD LASTED FIVE DAYS.
720
744
744
817
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
GULF POWER: SCHOLZ 2A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
A PROGRAM OF MODIFICATIONS ON THE SYSTEM BEGAN IN LATE AUGUST 1975 AND
CONTINUED THROUGH JANUARY 1976, WITH THE EXCEPTION OF FIVE DAYS OF RESOX
OPERATION IN OCTOBER.
2/76 SYSTEM 696
** PROBLEMS/SOLUTIONS/COMMENTS
MODIFICATIONS WERE COMPLETED AND PRE-STARTUP TESTING WAS CONDUCTED IN LATE
JANUARY AND EARLY FEBRUARY. A THREE DAY CONTINUOUS RUN WAS SUCCESSFULLY
COMPLETED.
DURING FEBRUARY THE MATERIALS HANDLING LOOPS AND THE RESOX LOOPS MERE
OPERATED AT FULL OPERATING TEMPERATURES AND PRESSURES. REINTRODUCTION OF
FLUE GAS INTO THE SYSTEM COMMENCED, AND A FOUR MONTH FORMAL TEST PROGRAM
CONDUCTED BY SOUTHERN SERVICES AND FOSTER WHEELER BEGAN.
3/76 SYSTEM 744
4/76 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
THREE OPERATIONAL PERIODS WERE LOGGED BY THE PROTOTYPE SYSTEM DURING MARCH
AND APRIL. THE RESOX SECTION OPERATED INTERMITTENTLY BECAUSE OF PLUGGING
PROBLEMS IN THE SULFUR CONDENSER. ALSO, THE FRONT END OF THE SYSTEM WAS
TAKEN OUT OF SERVICE AT ONE POINT DUE TO FREQUENT HIGH TEMPERATURE
EXCURSIONS. THIS PROBLEM WAS CORRECTED BY MODIFYING SYSTEM OPERATING
PROCEDURES. WORK BEGAN ON THE SOLUTION OF THE SULFUR CONDENSER PROBLEM.
5/76 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM COMPLETED AN OPERATIONAL PERIOD IN EARLY MAY WHICH HAD
COMMENCED ON APRIL 26. THE SYSTEM WAS TAKEN OUT OF SERVICE AT THIS POINT
DUE TO THE DEPLETION OF CHAR SUPPLY, HIGH CHAR CONSUMPTION RATES DUE TO
MECHANICAL ATTRITION AND TO CORRECT/MODIFY THE CHAR/SAND SCREEN SEPARATOR.
DURING MAY A DECISION WAS MADE TO PREMATURELY TERMINATE THE SYSTEM
DEMONSTRATION PROGRAM RATHER THAN SHUT DOWN, DEBUG AND RESTART THE SYSTEM
AGAIN. THE SYSTEM SUPPLIER WAS PURSUING ADDITIONAL FUNDING FOR THE
CONTINUATION OF THE PROTOTYPE DEMONSTRATION PROGRAM.
818
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANK NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - '/.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
ILLINOIS POWER COMPANY
MOOD RIVER
EAST ALTON
ILLINOIS
D
******
774.
******
651
110
103
*****
110
(****** LB/MMBTU)
( 1.800 LB/MMBTU)
(****** LB/MMBTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
******** (******* ACFM)
154.4 ( 310 F)
76. ( 250 FT)
******
XJCX**XX ( XK XNJf FT )
COAL
25121.
10.00
******
4.30
******
3.10
( 10800 BTU/LB)
0
NONE
RESEARCH-COTTRELL
99.6
NONE
N/A
SALEABLE PRODUCT
WET SCRUBBING
CATALYTIC OXIDATION
MONSANTO ENVIRO CHEM SYSTEMS
DEMONSTRATION
RETROFIT
7. 99.90
85.00
8
819
-------
EPA UflLITY FGD SURVEY: OCTOBER - DECEMBER 1980
ILLINOIS POWER COMPANY: HOOD RIVER 4 (CONT.)
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DE.SIGN AND OPERATING PARAMETERS
**/74
10/72
9/72
6/70
** ABSORBER
NUMBER
GENERIC TYPE
DIMENSIONS - FT
SHELL GENERIC MATERIAL
S\ ELL SPECIFIC MATERIAL
ShELL MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
DISTANCE BETWEEN GAS CONTACTING ZONES
GAS-SIDE PRESSURE DROP - KPA
INLET GAS TEMPERATURE - C
SOZ REMOVAL EFFICIENCY - X
** ABSORBER
NUMBER
GENERIC TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
** REHEATER
NUMBER
GENERIC TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
** FANS
NUMBER
APPLICATION
** FANS
CONSTRUCTION MATERIAL GENERIC TYPE
** DUCTWORK
LINER GENERIC MATERIAL TYPE
»* TANKS
SERVICE
PRODUCT ACID
** PUMPS
SERVICE
PACKED TOWER
30 FT DIA X 65 FT
CARBON STEEL
AISI 1110
N/A
VANADIUM PENTOXIDE
8
CM 30.5 ( 12.0IN)
1.0 ( 4.0 IN-H20)
454.4 ( 850 F)
85.0
PACKED TOWER
CARBON STEEL
AISI 1110
N/A
INORGANIC
ACID-RESISTANT BRICK ft MORTAR
PREFIRED BRICK
121.X ( 250 F)
MIST ELIMINATOR
1
IMPINGEMENT
MESH
KNITTED WIRE MESH PAD
4.5 (18.0 IN-H20)
HIGH ALLOY
1
IN-LINE
14.5
E30.0 ( 446 F)
176.7 ( 350 F)
INDUCED DRAFT
STAINLESS STEEL
STAINLESS STEEL
NUMBER
2
NUMBER
ACID RECIRCULATION
PRODUCT ACID
****
820
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
ILLINOIS POWER COMPANY: WOOD RIVER 4 tCONT.)
** SOLID:, CONCENTRATING/DEWAVERINS
NUMBtR 0
** PROCI.SS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS TEMPERATURE, ASH LOADINGS, ACID CONCENTRATION
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
9/72 SYSTEM 33.9 720 244
** PROBLEMS/SOLUTIONS/COMMENTS
THE EMISSION CONTROL EQUIPMENT AT THE WOOD RIVER SITE INCLUDED MECHANICAL
COLLECTORS, A HIGH EFFICIENCY ESP, AND A MONSANTO CATALYTIC OXIDATION
(CATOX) FGD SYSTEM FOR THE CONTROL OF PARTICLE MATTER AND SULFUR DIOXIDE.
FOLLOWING PASSAGE THROUGH THE PARTICLE MATTER REMOVAL SYSTEM, THE FLUE GAS
ENTERED THE SCRUBBING SYSTEM AND WAS HEATED TO A TEMPERATURE OF 850F AND
THEN PASSED THROUGH A VANADIUM PENTOXIDE FIXED-BED CATALYTIC CONVERTER,
WHERE THE SULFUR DIOXIDE WAS OXIDIZED TO SULFUR TRIOXIDE. THE GAS THEN
FLOWED THROUGH AN ACID ABSORPTION TOWER, WHERE THE SULFUR TRIOXIDE IN THE
GAS WAS CONVERTED TO SULFURIC ACID. AN ACID MIST ELIMINATOR ENSURED
REMOVAL OF ENTRAINED ACID MIST FROM THE GAS STREAM. THE CLEANED GAS WAS
DISCHARGED TO THE STACK AND THE PRODUCT ACID WAS COOLED AND STORED IN
TANKS.
10/72 SYSTEM 23.9 744 178
** PROBLEMS/SOLUTIONS/COMMENTS
THE WOOD RIVER SYSTEM WAS STARTED-UP IN SEPTEMBER 1972 BUT WAS SHUTDOWN
ALMOST IMMEDIATELY (IN OCTOBER) TO CONVERT THE BURNERS TO OIL FIRING.
7/73 SYSTEM 21.2 744 158
** PROBLEMS/SOLUTIONS/COMMENTS
IN JUNE 1973 THE CONVERSION TO OIL FIRING WAS COMPLETED AND A SUCCESS-
FUL PERFORMANCE TEST WAS MADE. A CATALYST PLUGGING HAZARD CAUSED THE
SYSTEM TO SHUTDOWN AGAIN TO INSTALL AN EXTERNAL BURNER SYSTEM.
IN APRIL 1974 THE INSTALLATION OF THE EXTERNAL BURNERS WAS COMPLETED.
VARIOUS OTHER PROBLEMS OCCURRED, WITH THE RESULT THAT ONLY 657 HOURS
OF OPERATING TIME WAS LOGGED IN TWO YEARS.
SEVERAL OTHER MAJOR PROBLEM AREAS ENCOUNTERED DURING THE INTERMITTENT
OPERATION OF THIS REGENERABLE SYSTEM INCLUDED: FROZEN DAMPERS ON REHEAT
BURNERS, CRACKS IN THE TEFLON LINER ON THE ACID PUMP'S DISCHARGE HEADER
CRACKS IN THE REHEAT DUCTING, FALL OF REFRACTORY BRICKS FROM THE REHEATER
BURNER DOME, AND NEED FOR REINFORCEMENT OF THE STRUCTURE SUPPORTING THE
HIGH TEMPERATURE FLUEGAS DUCT TO THE CATALYTIC CONVERTER.
821
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPAKf NAME
PUNT NAME
UNIT hUMBER
CITY
STATE
REGUUTORY CUSSIFICATION
PARTICUUTE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY i-l/FGD - MW
NET UNIT CENERATING CAPACITY UO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STAC<
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DcS.IGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FU£L DATA
FUEL TYPE
F'JEL GRADE
AVERAGE HEAT CONTENT - J/G
R4NGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RJNGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NU1BER
PRcSSURE DROP - KPA
** FABRIC FILTER
NU1BER
TYPE
** ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
KEY WEST UTILITY BOARD
STOCK ISUND
1
KEY WEST
FLORIDA
******
473.
42
42
37
(****** LB/MMBTU)
( 1.100 LB/MMBTU)
I****** LB/MMBTU)
37
ERIE CITY
OIL FIRED
BASE
********
*******
34.
GUNNITE
OIL
NO. 6
.04
(******* ACFM)
{**** F)
( 110 FT)
(***** FT)
(****** BTU/LB)
2.01
2-3
( 3. IN-H20)
0
NONE
0
NONE
NONE
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
ZURN AIR SYSTEM
DEMONSTRATION
NEW
X 90.00
65.00
8
822
-------
EPA UTILITY FSD SURVEY: OCTOBER - DECEMBER 1980
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)
TERMINATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
IAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEADER
NUMBER
GEWRIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
** FANS
NUMBER
APPLICATION
*** SL'JDGE
** DISPOSAL
NATURE
TrPE
«* PRDCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
** HATER BALANCE
WATER LOOP TYPE
**/75
10/73
VENTURI TOWER
ZURN AIR SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 304L
NONE
N/A
N/A
SCRUBBING TUBE
25. (
1.5 (
58.04 (
62.8 (
400 GPM)
6.0 IN-H20)
123000 ACFM)
145 F)
MIST ELIMINATOR
IMPINGEMENT
CURVED DEFLECTOR PLATE
GULL MING
FIBERGLASS
0
NONE
N/A
N/A
INDUCED DRAFT
FINAL
POND
TEMPERATURE. PARTICLE LOADING, PH
OPEN
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
8/73 SYSTEM 3.6
** PROBLEMS/SOLUTIONS/COMMENTS
744
THE EMISSION CONTROL SYSTEM AT THE STOCK ISLAND PLANT CONSISTED OF A
MULTIPLE TUBE MECHANICAL COLLECTOR INSTALLED UPSTREAM OF TWO SULFUR DIOXIDE
WET SCRUBBERS. THIS DEMONSTRATION FACILITY EMPLOYED LIMESTONE IN A SEAWATER
SOLUTION FOR THE REMOVAL OF S02. THE LIMESTONE ABSORBENT WAS OBTAINED
FROM CORAL DREDGED FROM THE OCEAN. THE CORAL CONSISTED PRIMARILY OF
CAC03 WITH LITTLE OR NO MGC03. THE CORAL WAS GROUND TO A FINE POWDER IN A
HAMMERMILL CRUSHER TO 90X MINUS 325 MESH AND SLURRIED IN SEAWATER.
823
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
THE SCRUBBING SYSTEM MAS SCHEDULED TO START UP IN JULY 1972, BUT DID NOT
OPERATE UNTIL AUGUST 1973. DURING THE INTERIM, THE PRIMARY CRUSHING
SYSTEM BECAME FROZEN BECAUSE OF SALT AIR CORROSION TAKING PLACE FROM
DISUSE.
9/73 SYSTEM .0 720
10/73 SYSTEM 4.6 74*
11/73 SYSTEM 5.8 720
12/73 SYSTEM 9.7 744
** PROBLEMS/SOLUTIONS/COMMENTS
FROM STARTUP IN AUGUST 1973 UNTIL DECEMBER 10, 1973 THE LONGEST SCRUBBER
RUN WAS FIVE DAYS; ASIDE FROM THAT, THE SCRUBBER WAS UP AND DOWN ONE
DAY AT A TIME FOR SHAKEDOWN TESTING.
ON DECEMBER 12 A HIGH PRESSURE DROP (15 IN. H20) CAUSED THE SCRUBBER TO
SHUTDOWN.
A CHANGE IN THE BOILER LOAD, PROBLEMS WITH THE GRID, AND A HIGH PRESSURE
DROP CAUSED THE SYSTEM TO SHUTDOWN ON DECEMBER 17. THE SYSTEM REMAINED
DOWN THROUGH THE END OF THE MONTH SO THE SYSTEM COULD BE CLEANED.
1/74 SYSTEM 33.5 744
** PROBLEMS/SOLUTIONS/COMMENTS
ON JANUARY 2 THE 1A SCRUBBER EXPERIENCED PLUGGING CAUSING THE SYSTEM TO
SHUTDOWN.
A HIGH PRESSURE DROP CAUSED SOME OUTAGE TIME IN JANUARY.
THE ENTIRE PLANT SHUTDOWN FOR SEVEN DAYS DURING JANUARY DUE TO A MAIN
BEARING FAILURE.
THE HISH PRESSURE ALARM AND THE SENSING DEVICE TRIPPED DUE TO SLUDGE
BUILDUP. THIS KEPT THE SYSTEM OUT OF SERVICE FOR APPROXIMATELY FOUR DAYS.
ON JANUARY 22 THE SYSTEM WAS TAKEN OUT OF SERVICE FOR ABOUT THREE HOURS
DUE TO A RUPTURED LINE ON ONE OF THE PUMPS AND A DECREASE IN THE PRESSURE
DROP. CORRODED LOOSE NUTS AND BOLTS WERE FOUND IN THE LINE.
ON JANUARY 28 THE SYSTEM WAS SHUTDOWN FOR MODIFICATIONS WHICH INCLUDED;
REPLACEMENT OF THE CYCLONE BY A BAGHOUSE AND REPLACEMENT OF THE VIBRATORY
FEEDER BY A SCREW FEEDER.
2/74 SYSTEM .0 672
3/74 SYSTEM .0 744
4/74 SYSTEM .0 720
5/74 SYSTEM .0 744
6/74 SYSTEM .0 720
7/74 SYSTEM .0 744
8/74 SYSTEM 4.4 744
9/74 SYSTEM .0 720
624
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
KEY WEST UTILITY BOARD: STOCK ISLAND 1 CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/74
11/74
12/74
1/75
SYSTEM
SYSTEM
SYSTEM
SYSTEM
37.5
43.1
16.1
.0
744
730
744
744
** PROBLEMS/SOLUTIONS/COMMENTS
AFTER STARTUP IN AUGUST 1973, ENSUING OPERATION PROCEEDED ON AN INTERMIT-
TENT BASIS. THE MAJOR PROBLEM AREAS ENCOUNTERED INCLUDED:
*SEVERE CORROSION OF THE GAS QUENCH DUCT AND DAMPER SEALING FANS ON
THE INLET AND OUTLET OF THE SCRUBBERS
^PLUGGING AT THE BOTTOM OF THE SCRUBBER TUBES
*LIQUID LEVEL CONTROL FAILURES IN THE SCRUBBER MODULES
*POOR LIMESTONE UTILIZATION (APPROXIMATELY 20Z)
*INDUCED DRAFT FAN REPAIRS
*REPLACEMENT OF INTERNAL STAINLESS STEEL PARTS WITH MONEL COMPONENTS
*BOILER FOUNDATION AND BOILER TUBE PROBLEMS
^LIMESTONE SUPPLY SHORTAGES
AS OF MARCH 1977 IT HAD NOT BEEN DECIDED WHETHER THERE WOULD BE FUTURE
FGD OPERATIONS AT THE STOCK ISLAND PLANT. DURING OPERATION THE SCRUBBING
SYSTEM LOGGED 1579 HOURS FOR A TOTAL OPERABILITY OF 8X.
825
-------
EPA UTILITY FGD SURVEY! OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC F6D SYSTEMS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - '/.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
** ESP
NUMBER
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
WELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
NUMBER OF CONTACTING ZONES
l/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
** PARTICLE SCRUBBER
KUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
EDDYSTONE
PENNSYLVANIA
D
****** (****** LB/?JMBTU)
****** (****** LB/liMBTU)
****** (****** LB/MNBTU)
1395
120
120
*****
120
COMBUSTION ENGINEERING
BASE
437.45 (
157.2 C
76. (
CONCRETE
5.6 ( 18.5 FTJ
927000 ACFtt)
315 F)
249 FT)
COAL
BITUMINOUS
31634.
9.40
( 13600 BTU/LB)
5.90
******
2.60
VENTURI TOMER
VARIABLE-THROAT/VERTICALLY-ADJUSTABLE ROD DECKS
ENVIRONEERING
14 X 25 X 53 HIGH
STAINLESS STEEL
AUSTENITIC
NONE
N/A
1
.6 (
.0 (
145.8 (
157.2 (
4.8 GAL/IOOOACF)
.1 IN-H28J
309000 ACFM)
315 F)
VENTURI TOWCR
VARIABLE-THROAT/ADJUSTABLE DRUM
PEABODY-LURGI
14 X 25 X 53 HIGH
826
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
L::NER SPECIFIC MATERIAL
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
IHLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAHAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
CONSTRUCTION MATERIAL GENERIC TYPE
WASH WATER SOURCE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
STAINLESS STEEL
AUSTENITIC
NONE
N/A
X
.6
.0
145.8
157. a
( 4.8 GAL/1000ACF)
( .1 IN-H20)
( 309000 ACFM)
( 315 F)
SALEABLE PRODUCT
WET SCRUBBING
MAGNESIUM OXIDE
NONE
UNITED ENGINEERS
UNITED ENGINEERS & CONSTRUCTORS
DEMONSTRATION
RETROFIT
7. 99.00
90.00
8
**/79
9/75
9/75
PACKED TOWER
GRID PACKING
ENVIRONSERING, RILEY STOKER
14 X 25 X 53
CARBON STEEL
HIGH STRENGTH LOW ALLOY
COR-TEN
ORGANIC
POLYURETHANE
ROD DECKS
Z
843. (13384 GPM)
6.5 ( 48.5 GAL/1000 ACF)
2.5 (10.0 IN-H20)
126.47 ( 268000 ACFM)
51.7 ( 125 F)
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
VERTICAL
2
2
2.44 ( 8.0 FT)
FIBERGLASS
STRAINED RIVER WATER
DIRECT COMBUSTION
IN-LINE BURNER
OIL
39.4 ( 103 F)
51.7 ( 125 F)
827
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
** FANS
NJMBER
SUPPLIER
FJNCTION
APPLICATION
SHRVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
** DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
«* DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
** PUUPS
SERVICE
ABSORBER RECIRCULATION
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
DIMENSIONS - FT
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
** WATER BALANCE
WATER LOOP TYPE
MAKEUP WATER ADDITION - LITERS/S
** FGD SPARE CAPACITY INDICES
ABSORBER - X
** FGD SPARE COMPONENT INDICES
ABSORBER
BUFFALO FORGE
BALANCED DRAFT
INDUCED DRAFT
DRY
126.47
107.2
( 268000 ACFM)
( 225 F)
316L SS WITH CARPENTER 20 HUB
SCRUBBER INLET
316L SS
NONE
SCRUBBER OUTLET
316L SS
NONE
NUMBER
2
THICKENER
1
40 DIA
25X SOLIDS
CENTRIFUGE
1
OPEN
8.3
.0
.0
( 132 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
SO2 PART. HOURS HOURS HOURS FACTOR
11/74 SYSTEM
720
»* PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBING SYSTEM AT THIS PLANT CONSISTS OF THREE PARALLEL SCRUBBING
TRAINS INCORPORATING THREE WET PARTICULATE SCRUBBERS AND ONE S02 ABSORBER
MODULE. THERE WAS A BRIEF OPERATING PERIOD ON THE PARTICULATE SCRUBBERS
FROM MID-NOVEMBER 1974 TO MARCH 1975. PROBLEMS ENCOUNTERED CENTERED AROUND
THE SCRUBBER BOOSTER FANS AND THE FLUE GAS AND LIQUID CONDITIONS. THE
B-SIDE BOOSTER FAN DEVELOPED HIGH SHAFT VIBRATION WHEN STARTED FOR THE
FIRST TIME. THIS PROBLEM WAS DESIGN-RELATED, INVOLVING AN EXCESSIVE CLEAR-
ANCE AREA BETWEEN THE SHAFT AND WHEELHUB. ALSO, EXTENSIVE CORROSION
DEVELOPED IN THE C-SIDE PARTICLE SCRUBBER INTERNALS. THIS WAS CAUSED BY
LOW SCRUBBING SOLUTION PH LEVELS AND CHLORIDE LEVELS AS HIGH AS 2000 PPM.
THESE CONDITIONS COUPLED WITH THE THERMAL SHOCK OF A HOT START PROCEDURE
CAUSED THE CORROSION. THIS PROBLEM WAS AMELIORATED BY CAUSTIC ADDITION,
HIGHER SLOWDOWN AND EMPLOYING A COLD START PROCEDURE. AT APPROXIMATELY
THIS TIME, A CHECKOUT OF THE SOS SYSTEM WAS CONDUCTED. BLISTERING AND
828
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (COKT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OFERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
PEEL.-.NG OF THE POLYURETHANE COATINGS WERE DETECTED AND CORRECTED BY
RECOATING WITH FLAKEGLASS.
12/74 SYSTEM 744
1/75 SYSTEM 744
2/75 SYSTEM 672
3/75 SYSTEM 744
4/75 SYSTEM 720
5/75 SYSTEM 744
6/75 SYSTEM 720
7/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE C-SIDE PARTICULATE SCRUBBER RESTARTED ON JULY 23i 1975. THE TWO
OTHER TRAINS, B-SIDE AND A-SIDE, WERE PUT INTO OPERATION ON AUGUST 15 AND
OCTOBER 2, RESPECTIVELY. THE S02 ABSORBER MODULE IN THE C-SIDE SCRUBBING
TRAIN WAS INITIALLY PLACED IN SERVICE OCTOBER 2, 1975. THE OLIN CHEMICAL
MGO REGENERATION FACILITY FIRST PROCESSED MAGNESIUM SULFITE FROM THE EDDY-
STONE SCRUBBER ON OCTOBER 28, 1975. THE C-SIDE PARTICULATE SCRUBBER OPERA-
TED A TOTAL OF 2831 HOURS THROUGH JANUARY 31, 1976, FOR AN OPERABILITY OF
70X. THE B-SIDE TRAIN HAS OPERATED A TOTAL OF 1933 HOURS THROUGH
JANUARY 31, 1976 FOR AN OPERABILITY OF 55X. THE A-SIDE TRAIN OPERA-
TED A TOTAL OF 626 HOURS THROUGH JANUARY 31, 1976, FOR AN OPERABILITY OF
24X. THE C-SIDE S02 ABSORBER WAS IN SERVICE A TOTAL OF 556 HOURS
THROUGH DECEMBER 31, 1975, WITH AN OPERABILITY OF 33X SINCE START
UP. PROBLEMS ENCOUNTERED IN THE OPERATION OF THE THREE SCRUBBING TRAINS
INCLUDED UNDER-DESIGNED RECIRCULATION PUMPS, MALFUNCTION OF THE FLUE GAS
BY-PASS DAMPER DRIVE UNITS AND FAILURE OF THE DOUBLE-BRICK REFRACTORY
LINING IN THE REHEAT COMBUSTION CHAMBER.
8/75 SYSTEM 744
9/75 SYSTEM 720
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
OPERATION OF THE S02 SCRUBBING SYSTEM AT EDDYSTONE WAS TEMPORARILY HALTED
BECAUSE THE ACID PLANT REGENERATION FACILITY AT THE OLIN CHEMICAL SULFURIC
ACID PUNT IN PAULSBORO, NEW JERSEY PERMANENTLY CEASED OPERATIONS. THE
UTILITY WAS INVESTIGATING ALTERNATIVE REGENERATION SITES. A MINIMUM
PERIOD OF SIX MONTHS WAS REQUIRED FOR RELOCATION ONCE A CHOICE WAS MADE.
THE UTILITY ANNOUNCED PLANS FOR RELOCATION OF THE REGENERATION FACILITY AT
THE ESSEX CHEMICAL PLANT IN NEWARK, NEW JERSEY.
THE PARTICULATE SCRUBBERS WERE CONTINUING TO OPERATE AND THESE UNITS
WEREARE CONTINUING TO EXPERIENCE PROBLEMS WITH THE FANS, REHEAT BURNERS,
DAMPERS AND EXPANSION JOINTS.
1/76 SYSTEM 744
2/76 SYSTEM 696
829
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (COKT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
3/76 SYSTEM 744
4/76 SYSTEM 720
5/76 SYSTEM 744
6/76 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
RESUMPTION OF 502 SCRUBBING OPERATIONS WAS SCHEDULED FOR DECEMBER
197t. THE RELOCATION OF THE REGENERATION FACILITY WAS IN PROGRESS. THE
PARTrCULATE SCRUBBERS WERE OPERATIONAL. THE C-SIDE BOOSTER FAN DEVELOPED
A MATERIALS FAILURE BETWEEN THE KUB AND SHAFT (IDENTICAL TO THE
B-SIO£ UNIT MENTIONED EARLIER).
7/76 S> STEM 744
8/76 SYSTEM 744
9/76 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
ALL THREE BOOSTER FANS DOWNSTREAM OF THE REHEATERS DEVELOPED MATERIALS
FAILURE BETWEEN THE HUB AND SHAFT (AS IDENTIFIED EARLIER FOR THE B-SIDE
UNIT). THESE UNITS WERE RETURNED TO THE MANUFACTURER FOR MODIFICATIONS
AND REPAIRS. ONE OF THE PARTICULATE SCRUBBERS WAS IN THE FLUE 6AS
STREAM. TO DATE, THE THREE WET PARTICULATE SCRUBBERS HAD ACHIEVED
LITTLE SIMULTANEOUS SERVICE TIME.
10/76 SYSTEM 744
11/76 SYSTEM 720
12/76 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
MGO SCRUBBING OPERATIONS WERE SCHEDULED TO RESTART IN MAY 1977. RE-
GENERATION FACILITY RELOCATION WAS BEING COMPLETED, AND MODIFICATIONS TO
THE ID BOOSTER FANS BEING EFFECTED CONSISTED OF CONVERSION FROM A
SLIP FIT TO A SHRINK FIT. THESE MODIFICATIONS WERE EXPECTED TO ELIMINATE
RECURRING VIBRATION PROBLEMS.
1/77 SYSTEM 744
E/77 SYSTEM 672
3/77 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE MGO SCRUBBING SYSTEM AT EDDYSTONE 1A WAS STILL SCHEDULED FOR
RESTART IN MAY 1977. THE START-UP OF THE NEW MAGNESIUM SULFITE REGENER-
ATION FACILITY AT THE ESSEX CHEMICAL PLANT AT NEWARK, N.J. WAS ALSO SCHED-
ULED FOR MAY 1977. THE THREE PARALLEL VENTURI SCRUBBERS CONTROLLING PAR-
TICULATE EMISSIONS ON EDDYSTONE 1 WENT BACK INTO SERVICE IN MARCH 1977.
4/77 SYSTEM 720
5/77 SYSTEM 744 206
830
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
RESUMPTION OF MAGNESIUM OXIDE SCRUBBING OPERATIONS OCCURRED DURING THE
REPORT PERIOD. THE UTILITY REPORTED THAT S02 SCRUBBING OPERATIONS WERE
NOT CONTINUOUS THROUGHOUT THE PERIOD. THE ABSORBER WAS IN SERVICE APPROXI-
MATELY 206 HOURS DURING MAY. REGENERATION OPERATIONS AT THE ESSEX FACILITY
WERE NOT CONDUCTED DURING THE PERIOD. PECO PLANNED TO INITIATE S02 RE-
COVERY AND MAGOX REGENERATION OPERATIONS DURING THE MONTH OF JUNE. THE S02
MODULE CONTAINED TWO ABSORBER SECTIONS IN SERIES (EACH SECTION CONSISTING
OF AN ADJUSTABLE ROD DECK WITH UNDERSPRAYS). ONLY ONE OF THE ABSORBER
SECTIONS WAS BEING USED FOR S02 REMOVAL. S02 REMOVAL EFFICIENCY WAS NOT
MEASURED. MAGNESIUM OXIDE LOSSES IN THE SYSTEM (ABSORPTION AND
REGENERATION) WERE ESTIMATED AT 10X.
6/77 SYSTEM 720
7/77 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
FAILURE OF MINOR ANCILLIARY EQUIPMENT CAUSED SOME SCRUBBER SHUTDOWNS.
LATER, THE BOILER ITSELF WAS SHUT DOWN. OVER THIS PERIOD THE ROTARY VALVE
ON THE MAG SULFITE DRIER DISCHARGE PLUGGED REPEATEDLY. ALSO THE BELTS ON
THE AGITATOR OF THE MAG-OX PRESLAHER FAILED.
8/77 SY'oTEM 744
9/77 S1 STEM 720
** PROBLEMS/SOLUTIONS/CO1MENTS
THE ROTARY VALVE PROBLEM APPEARED TO BE SOLVED. CUMULATIVE OPERABILITY
SINCE MAY WAS ESTIMATED TO BE ROUGHLY 33X. PECO REPORTED 131 HOURS OF
CONTINUOUS OPERATION FOR THE SCRUBBER AND THICKENER CENTRIFUGE DRYING
LOOP. DURING THE AUGUST-SEPTEMBER REPORT PERIOD CONTINUAL PROBLEMS WITH
THE GLAND PACKING ON THE FGD SYSTEM CIRCULATION PUMPS (STUFFING BOX) WERE
ENCOUNTERED. PECO CHANGED THE GLAND CONFIGURATION. THERE ALSO WAS A
PROBLEM WITH HIGH SOLIDS FORMATION IN THE THICKENER.
10/77 SYSTEM 41.0 744
11/77 SYSTEM 41.0 720
** PROBLEMS/SOLUTIONS/COMMENTS
CUMULATIVE OPERABILITY FOR MAY THROUGH NOVEMBER 1977 WAS 39X. DURING THE
OCTOBER-NOVEMBER PERIOD THE FGD SYSTEM ACHIEVED A 213 HOUR CONTINUOUS
RUN. THIS WAS THE LONGEST CONTINUOUS RUN SINCE MAY 1977.
GLAND PACKING PROBLEMS PERSISTED AND MECHANICAL SEALS WERE BEING
CONSIDERED AS POSSIBLE ALTERNATIVES. EVEN WITH HEAT TRACING THE SEAL
WATER FROZE-UP CAUSING ROTAMETERS TO BURST. HIGH SOLIDS ACCUMULATION IN
THE THICKENER WAS STILL A PROBLEM AREA.
12/77 SYSTEM 41.0 744
1/78 SYSTEM 744 0
» PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT WAS SHUT DOWN DECEMBER 22 FOR A TURBINE OVERHAUL. DURING THE
OUTAGE MAINTENANCE AND MINOR MODIFICATIONS WERE BEING MADE ON THE SCRUB-
BERS. THE UNIT WAS EXPECTED TO BE BACK ON LINE THE FIRST WEEK IN MARCH.
831
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
THE CUMULATIVE OPERABILITY FACTOR FOR THE FOURTH QUARTER OF 1978 WAS 41X.
DURING THIS PERIOD SOME OF THE HEAT TRACING FAILED AND OTHER PROBLEMS
OCCURRED WHEN LINES FROZE AT THE ACID PLANT CAUSING THE FACILITY TO BE
OPERATED INTERMITTENTLY. THE GLAND PACKING PROBLEMS HAD NOT BEEN
SOLVED AND MECHANICAL SEALS WERE STILL BEING CONSIDERED.
THE UTILITY WAS STUDYING THE MAG-SULFIDE TO MAG-OXIDE RECOVERY EFFICIENCY.
2/78 SYSTEM .0 672 0
3/78 SYSTEM .0 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE TURBINE OVERHAUL CONTINUED DURING THE FEBRUARY-MARCH PERIOD. DURING
THE SHUTDOWN PERIOD IT WAS FOUND THAT SOME HIGH PRESSURE STEAM TUBES
WERE CRACKED, SO UNIT MAINTENANCE TOOK LONGER THAN EXPECTED. SOME
MINOR FGD SYSTEM MODIFICATIONS WERE INCORPORATED IN THE COURSE OF
THE SHUTDOWN PERIOD. START UP WAS EXPECTED IN MID-APRIL 1978.
4/78 SYSTEM .0 720 0
5/78 SYSTEM .0 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT CAME BACK ON LINE JUNE 1 AFTER AN EXTENSIVE SYSTEM MODIFICATION
OUTAGE WHICH BEGAN DECEMBER 22. THE UNIT WAS EXPECTED BACK ON LINE IN MID-
APRIL, BUT THERE WAS A PROBLEM WITH A SUPER PRESSURE STEAM TURBINE.
6/78 SYSTEM 49.0 720
7/78 SYSTEM 51.0 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE FGD SYSTEM ACHIEVED A 49X OPERABILITY. OPERABILITY FOR
JULf WAS SIX. PROBLEMS OCCURRED IN LATE JUNE WITH THE MGS03 SLURRY
CIRCULATION PUMP WHEN THE UTILITY DISCOVERED THE RUBBER LINER WAS TORN
AWAY. THERE WERE SOME PROBLEMS WITH THE MGO SECTION WHERE THE MGO
MIXES WITH THE SYSTEM LIQUOR. FIRE BRICK WAS REMOVED FROM THE FLUID BED
REACTOR CHAMBER TO REPLACE THE Af.ID BARRIER PLATES k'HICH WERE FAILING.
THE F[RE BRICK WAS THEN REPLACED. THE SLOW PIECE BY PIECE PROCEDURE WAS
TIME CONSUMING AND ACCOUNTED FOR MOST OF THE REGENERABLE FACILTY DOWN
TIME vMOST OF JUNE AND JULY). MAJOR PROBLEMS WERE SOLVED ON THE REGENER-
ATIVL FACILITY OVER THE PERIOD RESULTING IN IMPROVED AVAILABILITY OF THE
FACILITY.
8/78 SYSTEM 38.0 32.0 744 631 240
9/78 SYSTEM 78.0 56.0 720 516 402
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE MONTH OF AUGUST SCRUBBER CIRCULATING PIPING PROBLEMS WERE
ENCOUNTERED. A BUTTERFLY CONTROL VALVE WAS NOT FULLY OPEN AND A SECTION
OF PIPE DOWNSTREAM AT A 90 DEGREE BEND ERODED AWAY. TO CORRECT THE PROBLEM
THE BUTTERFLY VALVE WAS TAKEN OUT AND REPLACED WITH A RESTRICTION ORIFACE.
THE CIRCULATION PUMPING RATE WAS ALSO REDUCED.
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED DURING THE
MONTH OF SEPTEMBER. CERTAIN MECHANICAL PROBLEMS WERE RESOLVED WHICH
RESULTED IN AN IMPROVEMENT IN THE OPERABILITY FIGURE.
10/78 SYSTEM 23.0 744
832
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/78 SYSTEM 720
12/78 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS SHUT DOWN FOR AN APPRECIABLE TIME DURING THE LAST
QUARTER OF 1978 DUE TO MODIFICATIONS TO THE MGO SLAKING EQUIPMENT.
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
9/79 SYSTEM 720
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION FOR THIS UNIT HAD NOT BEEN AVAILABLE SINCE OCTOBER 1978.
1/80 SYSTEM 744 Q
2/80 SYSTEM 696 0
3/80 SYSTEM 744 o
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND TURBINE WERE DOWN DURING THE FIRST QUARTER 1980 FOR TURBINE
MAINTENANCE.
OPERATION OF THIS PROTOTYPE MAGNESIUM OXIDE SYSTEM, WHICH TREATED ONE
THIRO OF THE FLUE GAS FROM THE EDDYSTONE 1 BOILER, WAS TERMINATED.
THE =02 REMOVAL EQUIPMENT WILL BE PEPLACEO WITH A SIMILAR MAG-OX SYSTEM
DESIGNED TO TREAT 100X OF THE BOILER FLUE GAS. THE EXPECTED START
DATE tF THIS SYSTEM IS DECEMBER 1932. CURRENT REGULATIONS DO NOT
REQUIR- CONTROL OF S02 EMISSIONS l.NTIL THE NEW SCRUBBER IS AVAILABLE
FOR OPiRATION.
833
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NU1BER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOH - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - '/.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
S32 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SrSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NSW/RETROFIT
POTOMAC ELECTRIC POWER
DICKERSON
3A
DICKERSON
MARYLAND
(****** LB/MMBTU)
( 1.600 LB/MMBTU)
(****** LB/MMBTU)
******
688.
******
548
190
178
182
95
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
278.42 ( 590000 ACFM)
126.1 ( 259 F)
122. ( 400 FT)
******
******* (***** FT)
COAL
BITUMINOUS
27214. ( 11700 BTU/LB)
14.00
******
********
6-7
2.00
******
********
0
NONE
0
NONE
RESEARCH-COTTRELL
97.5
NONE
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
SALEABLE PRODUCT
WET SCRUBBING
MAGNESIUM OXIDE
NONE
CHEMICO DIVISION, ENVIROTECH
CHEMICO
DEMONSTRATION
RETROFIT
834
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKERSON 3A (CONT.)
WIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
** DEJIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SH-.LL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SH:.LL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
S02 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
** FANS
NUMBER
FUNCTION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** TANKS
SERVICE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
MONITOR LOCATION
PROCESS CONTROL MANNER
PROCESS CHEMISTRY MODE
- X 99.30
90.00
8
**/75
7/74
9/73
7/71
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
CHEMICO DIVISION, ENVIROTECH
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
5.3 ( 40.0 GAL/1000 ACF)
2.2 ( 9.0 IN-H20)
90.0
MIST ELIMINATOR
Z
IMPINGEMENT
BAFFLE
CHEVRON VANE
3
2
5.1 ( 2.00 IN)
45
.2 ( 1.0 IN-H20)
3.0 ( 10.0 FT/S)
FIBER-REINFORCED POLYESTER
0
NONE
N/A
N/A
1
UNIT
WET
HIGH ALLOY
NUMBER
1
THICKENER
2
PH, PRESSURE DROP
PH-75 H20-11"
IN SECOND STAGE SYSTEM
AUTOMATIC
FEEDBACK
835
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
POTOMAC ELECTRIC POWER: DICKER.'ON 3A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAIUBILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
0/75 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR DICKERSON 3 LOCATED IN
SECTION 14.
836
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT KUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/rGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - 1W
** UNCT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BHLER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FJEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - Y.
R/NGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
R/NGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - '/,
RANGE CHLORIDE CONTENT - 7.
PUBLIC SERVICE OF COLORADO
VALMONT
5A
VALMONT
COLORADO
( .100 LB/MMBTU)
(****** LB/MMBTU)
(****** LB/MMBTU)
43.
******
******
274
166
157
163
166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
436.98 ( 926000 ACFM)
126.7 ( 260 F)
****** (**** FT)
******
******* (***** FT)
COAL
SUBBITUMINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.68-.73
********
******
( 10800 BTU/LB)
******
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NLViBER
INLET FLUE GAS CAPACITY - CU.M/S
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
TYPE
INLET FLUE GAS CAPACITY - CU.M/S
** PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
218.5
0
NONE
COLD SIDE
218.5
t 463000 ACFM)
( 463000 ACFM)
PACKED TOWER
MOBILE BED PACKING
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL, 1.5 INCH PLASTIC SPHERES
3
7.8 (58.3 6AL/1000ACF)
3.7 (15.0 IN-H20)
3.4 ( 11.0 FT/S)
109.2 ( 231500 ACFM)
837
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5A (CONT.)
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
*** FGD SYSTEM
13Z.8
45.0
96.0
( 271 F)
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
503 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SlfSTEM SUPPLIER
/,-E FIRM
EEVELOPI1ENT LEVEL
hEU/RETROFIT
LMIT DESIGN PARTICLE REMOVAL EFFICIENCY
LMIT DESIGN SOZ REMOVAL EFFICIENCY - X
CURRENT STATUS
TERMINATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
MJMB-R
NUMBER OF SPARES
GEN' RIC TYPE
SPECIFIC TYPE
TRACE NAME/COMMON TYPE
SUPPLIER
S.iEI.L GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
SJ2 REMOVAL EFFICIENCY - X
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
W/.SH WATER SOURCE
** REPEATER
NIM3ER
GENERIC TYPE
SPECIFIC TYPE
TEMPERATURE INCREASE - C
** FAN3
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE/ALKALINE FLYASH
NONE
UOP/PUBLIC SERVICE OF COLORADO
STEARNS-ROGER
EXPERIMENTAL
RETROFIT
X 95.00
85.00
8
**/75
10/7*
1
0
PACKED TOW>:R
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
N/A
ORGANIC
SYNTHETIC RUBBER
NEOFRENE
77.5
MIST ELIMINATOR
IMPINGEMENT
BAFFLE
CHEVRON VANE
HORIZONTAL
2
7
.1 ( .5 IN-H2O)
STAINLESS STEEL
SUPERNATANT
1
IN-LINE
STEAM
18.3 ( 65 F)
BOOSTER
FORCED DRAFT
DRY
CARBON STEEL
OUTLET
CARBON STEEL
NONE
838
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
PUBLIC SERVICE OF COLORADO: VALMONT 5A (CONT.)
** TANKS
SERVICE
RECYCLE WATER
*** SLUDGE
«* DISPOSAL
NATURE
TYPE
** WATER BALANCE
WATER LOOP TYPE
EVAPORATION WATER LOSS - LITER/S
NUMBER
1
FINAL
POND
CLOSED
5.5 ( 88 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOURS HOURS FACTOR
10/74 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
REFER TO PERFORMANCE UPDATE INFORMATION FOR VALHONT 5 LOCATED IN SECTION
1* OF THIS REPORT.
839
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN EOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
h'ANGE CHLORIDE CONTENT - 7.
*** P/RTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** .F/BRIC FILTER
hUMBER
TYPE
** ESP
NUMT'ER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PA^T:.CLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FG3 SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SD2 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
SEW/RETROFIT
b «T DESIGN PARTICLE REMOVAL EFFICIENCY
CURRENT STATUS
SOUTHERN CALIFORNIA EDISON
MOHAVE
1A
UUGHLIN
NEVADA
B
28.
( .064 LB/MMBTU)
( .150 LB/MMBTU)
{****** LB/MMBTU)
1580
790
790
790
170
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
******** {******* ACFM)
132.2 ( 270 F)
152, I 500 FT)
******
******* (***** FT)
( 11500 BTU/LB)
11000-12000
COAL
******
26749.
10.00
******
********
******
.40
******
********
******
0
NONE
0
NONE
RESEARCH-COTTRELL
97.2
NONE
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
PROTOTYPE
RETROFIT
X 97.20
8
840
-------
EPA UTILITY FGQ SURVEY? OCTOBER - DECEMBER 1980
SOUTHERN CALIFORNIA EDISON! MOHAVE 1A (CONT.)
TERMINATION
COMMERCIAL START-UP
** DESIGN AND OPERATING PARAMETERS
** ABSORBER
NUMBER
GENERIC TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
SOS REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - 7.
** MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
**/75
PACKED TOWER
AIR CORRECTION DIVISION, UOP
18 X 40 X 90
CARBON STEEL
AISI 1110
N/A
ORGANIC
RUBBER
'PING PONG BALLS'
11.1 (
3.8 (
£12.35 (
95.0
93.0
MIST ELIMINATOR
83.0 GAL/1000 ACF)
12.6 FT/S)
450000 ACFM)
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
** FANS
NUMBER
APPLICATION
** REAGENT PREPARATION EQUIPMENT
NUMBER
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
**# SLUDGE
** TREATMENT
I;ETHOD
PROPRIETARY PROCESS
** DISPOSAL
LOCATION
SITE TRANSPORTATION METHOD
1
IN-LINE
STEAM
13.8
51.7
1
BOOSTER
CENTRIFUGE
THICKENER
VACUUM FILTER
POZ-0-TEC
IUCS
ON-SITE
TRUCKED
( 55 F)
( 125 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/74 S STEM
744
841
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SOUTHERN CALIFORNIA EDISON: MOHAVE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
** PROBLEMS/SOLUTIONS/COMMENTS
TKO PROTOTYPE SULFUR DIOXIDE ABSORBER MODULES WERE INSTALLED IN 1973 AT
THE MOHAVE GENERATING STATION. THE VERTICAL MODULE, A UNIVERSAL OIL PRO-
DUCTS TURBULENT CONTACT ABSORBER (TCA) WAS TESTED IN TWO MODES; FIRST AS
A TCA UNIT, FROM NOVEMBER 2, 1974 TO APRIL 30, 1975, AND SECOND AS A POLY-
GRID PACKED ABSORBER (PPA), WHEN THE "PING PONG BALLS" WERE REPLACED WITH
A PLASTIC "EGGCRATE" PACKING WITH TESTING CONTINUOUS TO JULY 2, 1975.
STARTUP OF THE MOHAVE 1A EXPERIMENTAL SYSTEM COMMENCED ON OCTOBER 31, 1974
AND OPERATED WITH AN AVAILABILITY OF 72X THROUGH EIGHT MONTHS OF TESTING.
THROUGH THE EIGHT MONTHS OF OPERATION, THE SYSTEM WAS OUT OF SERVICE
APPROXIMATELY 1585 HOURS. THE OUTAGE TIME WAS CAUSED BY NECESSARY REPAIRS
TO THE GRIDS, NOZZLES, TRAP-OUT TRAY .AND TO REPAIR/REALIGN PPA PACKING.
ADDITIONAL OUTAGE TIME WAS NECESSARY TO REDISTRIBUTE THE TCA BALLS, CLEAN
SCALE FROM THE SCRUBBER INTERNALS, CORRECT BOOSTER FAN TRIP PROBLEMS,
CONDUCT INSPECTIONS FOR EXTENDED OPERATIONS AND REMOVE A HARDHAT FROM
THE THICKENER.
SYSTEM OPERATIONS WERE TERMINATED ON JULY 2, 1975. UP TO THIS TIME,
THE SYSTEM LOGGED 4228 HOURS OF OPERATION.
842
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT '-IAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS LNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY KO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MU
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DE'JIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
** FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
** FABRIC FILTER
NUMBER
TYPE
** ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGD SYSTEM
** GENERAL DATA
SALEABLE FRODUCT/THROWAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEU/RETKOFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
SOUTHERN CALIFORNIA EDISON
MOHAVE
2A
LAUGHLIN
NEVADA
B
28.
( .064 LB/MMBTU)
( .150 LB/MMBTU)
(****** LB/MMBTU)
1580
790
790
790
160
ENGINEERING
PULVERIZED COAL
BASE
******** (******* ACFM)
132.2 ( 270 F)
152. ( 500 FT)
******
******* (***** FT)
( 11500 BTU/LB)
11000-12000
COAL
******
26749.
10.00
******
********
******
.40
******
********
******
0
NONE
0
NONE
RESEARCH-COTTRELL
97.2
NONE
N/A
THROWAWAY PRODUCT
WET SCRUBBING
LIME
SO. CALIFORNIA EDISON/STEARNS-
STEARNS-ROGER
PROTOTYPE
RETROFIT
7. 97.20
843
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SOUTHERN CALIFORNIA EDISON: HOHAVE 2A (CONT.)
CURRENT STATUS
TERMINATION
COMMLRCIAL START-UP
** DE3ION AND OPERATING PARAMETERS
** ABSORBER
N JMBER
GENERIC TYPE
SPECIFIC TYPE
TDADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
L/G RATIO - L/CU.M
SUPERFICAL GAS VELOCITY - M/SEC
IULET GAS FLOH - CU. M/S
S02 REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICENCY - x
** MIST ELIMINATOR
PPE-MIST ELIMINATOR/MIST ELIMINATOR
CONFIGURATION
NLMBER OF STAGES
** REHEATER
NU1BER
GEMERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INI.ET FLUE GAS TEMPERATURE - C
*# FAN3
NUMBER
APPLICATION
*** SLUDGE
** TREATMENT
METHOD
PROPRIETARY PROCESS
** DISPOSAL
TYPE
** WATER BALANCE
WATER LOOP TYPE
8
**/75
11/73
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
WEIR HORIZONTAL SPRAY CHAMBER
SCE/STEARNS-ROGER
15 X 30 X 60
CARBON STEEL
AISI 1110
N/A
4
6.6
212.35
95.0
93.0
( 30.0 GAL/1000 ACF)
( 21.6 FT/S)
( 450000 ACFM)
MIST ELIMINATOR
VERTICAL
1
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLES
12.8 ( 55 F)
48.9 t 120 F)
1
BOOSTER
CALCILOX
DRAVO
LINED POND
CLOSED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
•/. REMOVAL
S02 PART.
PER BOILER FGD CAP.
HOURS HOURS HOURS FACTOR
11/73 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
TWO PROTOTYPE SULFUR DIOXIDE ABSORBER MODULES WERE INSTALLED IN 1973 AT THE
MOHAVE GENERATING STATION. A FOUR-STAGE HORIZONTAL CROSSFLOW SPRAY
SCRUBBER WAS INSTALLED ON UNIT 2.
IN NOVEMBER 1973 THE UTILITY OPERATED THE FGD SYSTEM AT MOHAVE £A IN A
SHORT SERIES OF STARTUP TESTS THAT ENDED ON JANUARY 16, 1974 WHEN A FORMAL
844
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1980
SOUTHERN CALIFORNIA EDISON: MOHAVE 2A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
TEST PROGRAM WAS INITIATED TO ACCESS PERFORMANCE AND RELIABILITY
CHARACTERISTICS OF THE SCRUBBING SYSTEM.
DURING THE 13 MONTHS OF EXPERIMENTAL OPERATION THE SYSTEM EXPERIENCED A
NUMBER OF PROBLEMS WHICH ACCOUNTED FOR APPROXIMATELY 1757 HOURS OF OUTAGE
TIME. THESE OUTAGES WERE CAUSED BY PUMP REPAIRS, HOPPER LEAKS, BOOSTER
FAN 3ALANCE PROBLEMS, MODIFICATIONS AND REPAIR OF THE PLASTIC MIST
ELIMINATOR BLADES, SPRAY NOZZLE REPLACEMENT, GAS INLET FLOW DISTRIBUTION
MODIFICATIONS, SLAKING WATER MODIFICATIONS FOR SCALE PREVENTION, AN INSPEC-
TION hOR EXTENDED OPERATIONS AND REMOVAL OF A HARDHAT FROM THE THICKENER.
THE TE>T PROGRAM WAS TERMINATED OU FEBRUARY 9, 1975 FOLLOWING 5927 HOURS
OF OPERATION. THE MODULE WAS SUBSEQUENTLY DISMANTLED, TRANSPORTED, AND
REASSEMBLED AT THE FOU3 CORNERS PLANT OF ARIZONA PUBLIC SERVICE WHERE
ADDITIONAL TESTING WAS CONDUCTED AND COMPLETED (DECEMBER 1976).
845
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PUNT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
TENNESSEE VALLEY AUTHORITY
SHAWNEE
IOC
PADUCAH
KENTUCKY
******
516.
******
1750
10
( .100 LB/MMBTU)
( 1.200 LB/MMBTU)
(****** LB/MMBTU)
*****
10
BABCOCK & WILCOX
PULVERIZED COAL
BASE
********
*******
244.
******
*******
(******* ACFM)
(**** F)
( 800 FT)
(***** FT)
** FU?L DATA
FJEL TYPE
FUEL GRADE
AVEP4GE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/UJ
AVERAGE ASH CONTENT - 7,
R\NGE ASH CONTENT - 7.
A'-'cRAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - '/.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
R,\NGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FGP SYSTEM
** GEI- ERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SO2 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DE/ELOPMENT LEVEL
NEd/RETROFIT
CURRENT STATUS
TERMINATION
INITIAL START-UP
** DES'CGN AND OPERATING PARAMETERS
** ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
INLET GAS FLOW - CU. M/S
COAL
BITUMINOUS
****** (****** BTU/LB)
******
********
******
********
******
2.90
******
********
******
PACKED TOWER
MOBILE BED PACKING
THROWAWAY PRODUCT
WET SCRUBBING
LIME/LIMESTONE
COMBUSTION ENGINEERING
BECHTEL
PROTOTYPE
RETROFIT
8
**/73
4/72
PACKED TOWER
STATIC BED PACKING
MARBLE-BED SCRUBBER
3/4 IN. GLASS SPHERES
14.16 ( 30000 ACFM)
846
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
TENNESSEE VALLEY AUTHORITY: SHAWNEE IOC (CONT.)
** REHEATER
GENERIC TYPE DIRECT COMBUSTION
TRADE NAME/COMMON TYPE OIL
** SOLIDS CONCENTRATING/DEWATERINS
DEVICE VACUUM FILTER
*** SLUDGE
** DISPOSAL
NATURE FINAL
TYPE LANDFILL
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/72 SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
IN JUNE 1968, THE EPA INITIATED A PROGRAM TO TEST PROTOTYPE WET LIME AND
LIMESTONE SCRUBBING SYSTEMS FOR REMOVAL OF SULFUR DIOXIDE AND PARTICLE
MATTER FROM FLUE GAS. THREE PARALLEL WET SCRUBBER SYSTEMS WERE SELECTED
FOR THE TEST PROJECT: 1) A VEHTURI WITH A SPRAY TO'.SER AFTER THE ABSORBER;
2) A TURBULENT CONTACT ABSORBER (TCA); AND 3) A MARBLE-BED ABSORBER.
THE MARBLE-BED ABSORBER TESTED ON SHAWNEE IOC USED A PACKING OF 3/4 INCH
GLASS MARBLE SPHERES AND A TURBULENT LAYER OF LIQUID AND GAS ABOVE THE
MARBLE LAYER TO ENHANCE MASS TRANSFER.
THE TEST FACILITY WAS DESIGNED SO THAT MODIFICATIONS AND VARIATIONS OF
SCRUBBER INTERNALS AND PIPING COULD BE READILY EMPLOYED FOR EACH SCRUBBER
SYSTEM.
THE MARBLE BED ABSORBER AT SHAWNEE IOC COMMENCED OPERATIONS IN APRIL
1972.
THIS MARBLE-BED ABSORBER WAS DISCONTINUED EARLY IN THE TEST PROGRAM, JULY
1973, BECAUSE OF CONTINUED OPERATING PROBLEMS WITH NOZZLE FAILURE AND
SUBSEQUENT PLUGGING OF THE MARBLE-BED.
847
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGD - MW
NET UNIT GENERATING CAPACITY WO/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MW
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
UNION ELECTRIC
MEREMAC
Z
******
MISSOURI
******
******
******
******
4135
140
\Z5
*****
140
******
PULVERIZED COAL
BASE
********
*******
******
******
*******
(****** LB/MMBTU)
(****** LB/MMBTU)
(****** 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 - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
** P/RTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
*** FG3 SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SOE REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVHL EFFICIENCY -
UNIT DESIGN SOZ REMOVAL EF :ICIENCY - 7.
C.JRRENT STATUS
TERMINATION
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
f****** BTU/LB)
******
COAL
******
******
********
******
********
******
3.40
******
********
******
PACKED TOWER
STATIC BED PACKING
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
FULL SCALE
RETROFIT
7. 99.00
83.00
6
**/69
3/68
** ABSORBER
GENERIC TYPE
** WATER BALANCE
WATER LOOP TYPE
PACKED TOWER
CLOSED
848
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
UNION ELECTRIC: MEREMAC 2 CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
3/68 SYSTEM 7
-------
APPENDIX A
FGD SYSTEM COST DATA: OPERATIONAL AND NONOPERATIONAL SYSTEMS
A-l
-------
INTRODUCTION
The cost of flue gas desulfurization (FGD) systems is an
area of intense interest and substantial controversy and few
realistic cost figures have been established. Many cost figures
(both capital and annual) are largely site-sensitive values.
Such figures cannot be compared from one system to another be-
cause they refer to different FGD battery limits and different
years in which the expenditures were made. This cost analysis
was undertaken because of these concerns and the lack of compar-
able cost data.
Analysis is made only for operating FGD systems in this
study because they potentially have complete and accurate econom-
ic data. Adjustments are made to provide comparable, accurate
cost data for the sulfur dioxide portion of the emission control
system. This, in effect, eliminates much of the confusion that
exists concerning the reported data, and it provides a common
basis for the reported costs.
The reported figures are acquired from various sources. The
most reliable information was obtained from a previous cost study
initiated by PEDCo Environmental in March 1978. In this first
study each utility having at least one operational FGD system at
A-2
-------
the time 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. The PEDCo
Environmental staff made a follow-up visit to complete and verify
the data collected. Results of the cost analysis were then
forwarded to each participating utility for final review and
comment.
For this cost analysis, the primary source of reported cost
information was the 1978 DOE Form 67. Utilities are generally
required to complete this form, which includes capital and annual
costs, once per year for operating stations. The 1978 forms were
the most recent forms available. Although the information in-
cluded in the DOE Form 67 is not as specific and is formatted
differently than the PEDCo forms, the figures were fitted as well
as possible.
Some costs were also taken from FGD cost survey question-
naires developed by Edison Electric Institute. The EEI forms
contain useful capital cost information, however, in some cases
the costs were projections rather than actual dollar expendi-
tures .
In addition to the sources just mentioned, some 1978 and
1979 annual costs were made available by a few utilities via
written transmittals and telephone communications.
It is assumed that the figures collected from all these
sources provided a firm base to make adjustments. In general, it
was possible to determine the scope of the reported costs so that
A-3
-------
estimates could be made for missing costs, and non-FGD-related
costs could be deleted. In cases where this was not possible,
assumptions were made as to what items were and what were not
included in the total figures, and the adjustments were based on
these assumptions.
The adjustment procedure is summarized below:
CAPITAL COSTS
0 All costs associated with control of particulate matter
emissions are deducted.
0 Capital costs for modifications necessitated by instal-
lation of an FGD system are added if they were not in-
cluded in the reported costs.
0 Sludge disposal costs are adjusted to reflect a 20-year
life span for retrofit FGD systems and a 30-year life
span for new FGD systems.
0 Any unreported direct and indirect costs incurred are
estimated and included.
0 All capital costs are escalated to 1980 dollars.
0 All $/kW values reflect the gross generating capacity
of the unit.
ANNUAL COSTS
0 All non-labor costs are adjusted to a common 65 percent
capacity factor.
0 Direct costs that were not reported are estimated and
added.
0 Overhead and fixed costs that were not reported are
estimated and added.
0 All annual costs are escalated to 1980 dollars.
0 The final mills/kWh figure for each cost study is based
on a standard 65 percent capacity factor and the net
generating capacity of the unit.
A-4
-------
A more complete description of the cost adjustment procedure
may be found in the section titled Cost Adjustment Procedure and
Background of this Appendix (Page A-9). The results of the cost
analysis are listed in the section that follows. Section A-l
summarizes the reported and adjusted capital and annual costs for
all the operational FGD systems that were addressed in the cost
study. Also included in this section are the standardized ad-
justed annual costs (see Page A-18). Section A-2 summarizes
available cost data for nonoperational FGD systems.
A-5
-------
RESULTS OF THE COST ANALYSIS
The results of the operational FGD system survey are sum-
marized in Tables A-l and A-2. Table A-l summarizes the reported
and adjusted capital and annual costs for all the operational FGD
systems addressed in the survey. Table A-2 provides 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.
A-6
-------
TABLE A-l. REPORTED AND ADJUSTED CAPITAL AND ANNUAL COSTS
FOR OPERATIONAL F6D SYSTEMS
Alabama Electric
~o<~^'3bee 2
Tombigbee 3
Arizona Electric Power
Apache 2
Apache 3
Arizona Public Service
Cholla 1
Cholla 2
Central Illinois Light
Duck Creek 1
Central Illinois Public Service
Hewton 1
Columbus & Southern Ohio Electric
Conesville 5
Conesvil'e 6
t^esne Light
Elrama 1-4
Phillips 1-6
Indianapolis Power & Light
Petersburg 3
Kansas City Power s Light
Hawthorn 3
Hawthorn 4
LaCygoe 1
Kansas Power & Light
Jef'rey 1
Green Plver 1-3
Louisville Gas & Electric
Cane Run 4
Cane Run 5
Cane Run 6
Hill Creek 3
Paddy's Run 6
Mmn«ota Power Cooperat .ve
Milton R. Young 1
Monongahela Power
Pleasants 1
Montana Power
Colstrip 1
Colstrip 2
Nevada Power
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
northern Indiana Public Service
Dean H Muchel 1 11
Northern states Power
Sherburne 1
Sherburne 2
Pacific Power & Light
Jim Bridger 4
Pennsylvania Power
Bruce Mansfield 1
Bruce Mansfield 2
Public Strvu* Company of New
Mexico
San Juan 1
San Juan 2
South Carolina Public Service
Authority
Ulnyah 2
South Mississippi Electric
R.D. Morrow 1
R.O- Morrow 2
Southern Illinois Power Coop
Marlon 4
Southern Indiana G«s I Electric
A.B. Brown 1
Springfield City Utilities
Southwest 1
Tennessee Valley Authrolty
Widows Creek 8
Utah Power I Light
Hunter 1
Huntlngton 1
Re
Cat" ul
6.992.100
6,992.100
B. 143. 069
7,214.052
6.550,000
44.352.000
31,125,000
107,831,000
20.663,500
20,663.500
61.320,000
52.055,000
S/ku
27.4
27.4
41 8
37.0
52.0
168.0
78.4
174.3
50.3
50.3
120 2
127.0
55.820,000 104.9
3,:?o ooo ?9 4
3, 2::, 000
46.90C.OOO
27.306,900
3,966.155
12.647,000
13.759.000
20.596.900
18. 846.o30
4.320,000
44.119.600
65,693,100
36.500.000
36,500.000
S, 363. 375
5,363.375
12. 599,160
18,192.040
34.982,020
34.982,020
49,643,000
110.639,000
110.639.000
47,944.400
47,985.000
6,646.098
10.896.000
10.896.000
15,200,930
12,495.000
16,744.500
47,900.000
24.400.000
27,090.000
xlrted
Annual
434.929
434,929
51 ,784
51,784
NA
1, 003. 568
10.851,000
NA
8.670,530
8,670,530
21,027,451
18.301,000
NA
346,441
29 « ' 346.441
53 7
37 9
62 0
66 6
66 8
71.5
42.6
61 7
IOC 3
106 3
101 4
101.4
42 9
42.9
IOC 8
157 4
49 3
49 3
90 3
120.7
120 7
132.8
137 1
23.7
53.7
53.7
87.9
47.2
86.3
87.1
56.7
63.0
8,060,047
Mllls/kUh
0.33
0.33
0.05
0.05
NA
0.75
5.04
NA
5.52
5 52
7.18
11.32
NA
1 15
1.15
5.38
321 ,000
364,005
960.301
763.443
NA
321,463
NA
754,445
9.015,379
6.128.000
6.128.000
251.514
251.514
131.324
2,414.539
2,716,759
2.716.759
NA
9,979.900
9.979,900
NA
NA
527,000
NA
NA
859.453
1.850,565
778,749
14.576.400
NA
2,946,400
0 11
5.20
1.29
0.92
NA
1.25
NA
0.53
2.73
2.97
2.97
0 46
0 46
0 23
13 02
0 75
0 75
NA
3.2B
3.28
HA
NA
0.29
NA
NA
0.98
1.30
1.20
7.76
NA
1.27
Adjusted
Capital
8.949,750
8,949,750
12,081.900
11.380.300
9.400,200
39.243,800
58.416,200
149.380,600
37,473.700
37,473.700
37,849.400
78,991,900
SAW
35.1
35.1
62.0
58.4
74.6
148 7
140.4
242.1
91.2
91 2
172 3
192.7
79,103.100 ! 148.7
1
6.329.650
6.329,650
80.279.100
36.178,300
6.916.800
20.073.300
18.7C3.000
23.204.500
26.751,200
8,540,200
62,072,700
70,058,000
48,183,200
48,183.200
9,993,000
•9. 99;, 000
17,307.000
26,999,900
67,996,050
67,996,050
59,732.500
121,30fc,350
121,306.350
92,034,200
90,608.100
12,060.100
22.056,750
22,056,750
19,177,500
21,477,900
25,904,900
79.765.300
29,625,000
35.498,200
57 5
57 5
91 9
50 2
10C.1
105 7
93 9
80.6
60 5
122.0
142 9
113.4
133 0
133 8
79.9
79 9
138.5
233.6
94.4
94.4
108.6
132 3
132.3
254 9
258.9
43.1
10J.7
103.7
HO. 9
81.0
133. S
145.1
68 9
82.6
Annual
3.896,950
3,396,950
3,431,400
3,431.400
3,034,800
10,099.300
17,143,200
42,020.300
13,357,600
13,357,600
32,916,500
31.025,700
Mllls/kUh
2.91
2.91
3 44
3 44
4 23
7.55
7.96
12.33
6.26
6 26
11.87
16.27
26,275.600 ! 8.96
2,612.450
4.71
2.612,450 j 4 71
48,739.200 10.44
1
8,528.400
3.467,900
5,448,000
5,314.600
9.133,500
8,833.500
4,079.300
13,743,100
26.14a.300
14,398,500
14.39i>,500
3,314.750
3.3U.750
4.247.300
9,991.300
19,333.820
19,333,820
17,854,100
50.794.SOO
50,794,500
27.227,100
26,352.900
2.476.200
6.513.850
6.513.850
6.525,500
6.534,600
7,490,000
19,572.000
9.740,100
12,317,200
2.20
10.15
5 26
4 B7
5.96
3.70
11 28
5.75
7.92
7 62
7 62
5 29
5.29
6.78
18 67
4 99
4 99
6 71
10 81
10 SI
15.23
15 41
1.69
6 36
6 36
7.12
4.39
7.60
6.66
4.28
5.41
NA - Annual costs not available from the utility.
A-7
-------
TABLE A-2. CATEGORICAL RESULTS OF THE REPORTED AND ADJUSTED
CAPITAL AND ANNUAL COSTS FOR OPERATIONAL FGD SYSTEMS
All
New
Retrofit
Saleable
Throwaway
Alkaline
flyash/liroe
Alkaline flyash/
limestone
Dual alkali
Line
Limestone
Sodium carbonate
Mellman Lord
Reported
Capital
Range, $/kW
23.7-243.0
23.7-243.0
29.4-157.4
132.8-185.0
23.7-243.0
100.3-101.4
49.3-49.3
47.2-174.8
29.4-243.0
23.7-168.0
42.9-100.8
132.8-185.0
Average,
$/kW
79.1
77.5
83.2
153.0
73.7
101.0
49.3
97.8
80.1
65.0
69.2
153.1
o
45.4
47.2
41.4
23.8
41.8
0.6
0.0
67.7
50.6
34.9
30.7
23.8
Annual
Range,
mills/kWh
0.05-13.02
0.05-5.52
0.46-13.02
13.02-13.02
0.05-11.32
0.53-2.97
0.75-0.75
1.30-1.30
0.92-11.32
0.05-7.76
0.23-0.46
13.02-13.02
Average,
mills/kWh
2.64
1.84
4.54
13.02
2.35
2.16
0.75
1.30
3.65
1.78
0.38
13.02
o
3.14
1.84
4.64
0.0
2.65
1.41
0.0
0.0
3.02
2.54
0.13
0.0
Adjusted
Capital
Range, S/kW
35.1-358.9
35.1-242.1
57.5-258.9
233.6-258.9
35.1-242.1
133.8-142.9
94.4-94.4
80.6-242.1
57.5-192.7
35.1-148.7
79.9-138.5
233.6-258.9
Average,
$/kW
113.5
103.8
132.3
249.1
104.2
136.8
94.4
134.6
105.1
93.4
101.7
249.1
0
54.6
43.3
69.4
13.6
42.5
5.2
0.0
93.1
39.1
42.5
28.0
13.6
Annual
Range,
mills/kWh
1.69-18.67
1.69-12.83
4.23-18.67
15.23-18.67
1.69-16.27
5.75-7.62
4.99-4.99
4.59-12.83
3.70-16.27
1.69-10.44
5.29-6.78
15.23-18.67
Average,
mills/kWh
7.27
6.31
9.12
16.44
6.64
6.99
4.99
7.79
7.79
5.61
5.88
16.44
o
3.82
2.68
4.99
1.94
3.03
1.08
0.0
4.41
3.63
2.65
0.73
1.94
I
CO
-------
COST ADJUSTMENT PROCEDURE AND BACKGROUND
The cost data were treated solely to establish accurate
costs for FGD systems, on a common basis, not to critique the
design or reasonableness of the costs reported by any utility.
Adjustments focus primarily on the following items:
0 All capital costs are adjusted to mid-1980 dollars
using the escalation factors shown in Table A-3.
Actual costs were reported by utilities in dollar
values for years 1970 to 1980. The total figure is
broken down into dollars/year and each year total is
escalated to 1980 dollars and totaled again. All
capital costs, represented in dollars/kilowatt ($/kW),
are expressed in terms of gross megawatts (MW).
0 Gross unit capacity is used to express all FGD capital
expenditures because the capital requirement of an FGD
system is dependent on actual boiler size before derat-
ing for auxiliary and air quality control power re-
quirements .
0 Particulate control costs are deducted. Since the pur-
pose of the study is to estimate the incremental cost
for sulfur dioxide control, particulate control costs
deducted using either data contained in the costs
breakdowns or as a percentage of the total direct cost
(capital and annual). The percentage reduction varies
depending upon system design and operation.
0 The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, are included
(e.g., stack lining, modification to existing ductwork
or fans, etc.).
0 Indirect charges are adjusted to provide adequate funds
for engineering, field expenses, legal expenses,
insurance, interest during construction, allowance for
startup, taxes, and contingency expenditures.
A-9
-------
TABLF A-3.
ESCALATION FACTORS
Year3
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
Capital
investment
0.537
0.576
0.600
0.624
0.738
0.825
0.875
0.934
1.000
1.090
1.188
1.295
1.412
1.539
1.677
1.828
Utilities0
0.238
0.277
0.321
0.372
0.496
0.665
0.762
0.873
1.000
1.100
1.210
1.331
1.464
1.611
1.772
1.949
Chemicals
0.550
0.584
0.603
0.624
0.733
0.819
0.866
0.928
1.000
1.075
1.156
1.242
1.335
1.436
1.543
1.659
O&M
1 abore
0.540
0.583
0.630
0.681
0.735
0.794
0.857
0.926
1.000
1.080
1.166
1.260
1.360
1.470
1.587
1.714
Construction
laborf
0.542
0.613
0.669
0.704
0.768
0.824
0.887
0.937
1.000
1.080
1.166
1.260
1.360
1.470
1.587
1.714
aCost index is for mid year (June).
Reference: Marshall and Swift.
clncludes fuel and electricity; reference:
Reference: Bureau of Mines.
eReference: Department of Labor.
Reference: Engineering News Record.
Department of Commerce.
A-10
-------
All annual costs, represented in mills/kilowatt-hour
(mills/kWh), are expressed in terms of net megawatts
(MW) .
Net unit capacity is used to express all FGD annual
expenditures because the annual cost requirement of an
FGD system is dependent on the actual number of kilo-
watt-hours (kWh) produced by the unit after derating
for auxiliary and air quality control power require-
ments.
All non-labor annual costs are adjusted to a common 65
percent capacity factor.
Replacement power costs for retrofitted FGD systems*
are not included since only a few utilities reported
such costs and these were presented using a variety of
methods.
Sludge disposal costs are adjusted to reflect the costs
of sulfur dioxide waste disposal only (i.e., excluding
fly ash disposal except where usable as a sludge stabi-
lizing agent) and to provide for disposal over the
anticipated lifetime of the FGD system. ^his latter
correction is necessary since several utilities report-
ed costs for sludge disposal capacity that would last
only a fraction of the FGD system life. The adjust-
ments are 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 is assumed for all process and economic
considerations for all new systems that were installed
for the life of the unit. A 20-year life is assumed
for all process and economic considerations for retro-
fit systems that were installed for the remaining por-
tion of the life of the unit.**
*If an FGD system is retrofitted to an existing boiler the new
electrical power demand of the FGD equipment will decrease the
boiler net MW rating. Since the boiler was originally sized
and designed to accommodate a certain grid demand, the utility
may be forced to buy make-up power from the grid and/or in-
crease the design capacity of planned boilers.
**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 retrofit systems
A-ll
-------
0 Regeneration and by-product recovery facility costs are
added for those regenerable systems not reporting such
costs.
To the extent possible, all cost adjustments are made using
the previous assumptions developed by PEDCo Environmental. When
cost data are inadequate, adjustments are made using process
design data in conjunction with the previous cost assumptions.
In some cases, adjustments are not possible because of insuffi-
cient data.
DESCRIPTION OF COST ELEMENTS
Capital costs consist of direct costs, indirect costs, and
other capital costs (including contingency). Direct costs in-
clude the "bought-out" cost of the equipment, the cost of instal-
lation, and site development. Indirect costs include interest
during construction, contractor's fees and expenses, engineering,
legal expenses, taxes, insurance, allowance for start-up and
shakedown, and spares. Contingency costs include those costs
resulting from malfunctions, equipment alterations, and similar
unforeseen sources. Other capital costs include the nondepreci-
able 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
A-12
-------
various capital and annual cost components are discussed and de-
fined in greater detail in the text that follows.
CAPITAL COSTS
Direct Capital Costs
The direct capital costs include the following elements:
0 Equipment required for the FGD system. Table A-4 pro-
vides a summary of the major process equipment used in
FGD 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, build-
ings, piping, and other equipment, painting and piling.
0 Site development may include clearing and grading, con-
struction of access roads and walkways, establishment
of rail, barge, and/or truck facilities, and parking
facilities.
Indirect Capital Costs
Indirect capital costs include the following elements:
° Interest accrued on borrowed capital during construc-
tion.
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;
modeling; pilot plant studies (if required because of
A-13
-------
TABLE A-4.
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
(continued)
Equipment for the handling and transfer of
raw materials includes unloading facili-
ties, 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
return 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 acces-
sories
Equipment to handle the boiler flue gas in-
cludes booster fans, ductwork, flue gas
bypass system, turning vanes, supports,
platforms, and related accessories
FGD systems that do not generate a salable
product require solids/water separation
equipment such as clarifiers, vacuum fil-
ters, centrifuges, sludge fixation equip-
ment, and related accessories
Equipment to supply power and water to the
FGD equipment consists of switch-gear,
breakers, transformers, piping, and related
accessories
Equipment for processing the by-product of
regenerable FGD systems may include a ro-
tary kiln, fluid bed dryer, conveyor,
storage silo, vibrator, combustion equipment
and oil storage tanks, waste heat boilers,
hammer mills, evaporators, crystallizers,
strippers, tanks, agitators, pumps, com-
pressors, sulfuric acid absorber and cooling,
mist eliminator, pumps, acid coolers, tanks,
etc.
A-14
-------
TABLE A-4 (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 equip-
ment and oil storage tanks, waste heat
boiler, hammer mill, evaporators, crystal-
lizers, strippers, tanks, agitators, pumps,
compressors, sulfuric acid absorber and
cooling, mist eliminator, pumps, acid
coolers, tanks, etc.
Equipment for the removal of purge material
(e.g., sodium sulfate) includes refrigera-
tion, 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 system, the
costs are prorated to the boiler and FGD
system
A-15
-------
process design or application novelty); royalty pay-
ments during construction; training of plant personnel;
field engineering; safety engineering; and consultant
services.
0 Legal expenses, including those fax securing permits,
right-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.
° 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
Other capital costs include the following elements:
0 Contingency funds set aside for any necessary repairs
and/or modifications not covered in projected direct
expenditures.
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, fin-
ished products in stock, and unfinished products in the
process of being manufactured; accounts receivable;
cash kept on hand for payment of operating expenses
such as salaries, wages, and raw materials purchases;
accounts payable; and taxes payable.
ANNUAL COSTS
The annual cost of an FGD system includes the following
direct, fixed and overhead charges:
Direct Costs
0 Raw materials, including those required by the FGD
process for sulfur dioxide control, absorbent
A-16
-------
regeneration, 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 steam for processing.
Operating labor, including supervision, 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.
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 include administra-
tive, safety, engineering, legal and medical services; pay-
roll; employee benefits; recreation; and public relations.
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,
personel injury or death, property damage, explosion,
lightning, or other natural phenomena.
Taxes - including franchises, excise, and property
taxes levied by a city, county, state, or Federal
government.
Interest - on borrowed funds.
A-17
-------
Table A-5 provides a summary of the means used to deter-
mine 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).
STANDARDIZED ADJUSTED ANNUAL COST
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
replacement, taxes, insurance, and capital costs). The newly
adjusted total fixed annual cost rate was applied to the total
adjusted capital cost in each case and a standardized adjusted
annual cost was obtained.
A-18
-------
TABLE A-5.
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:
Contingency9
Direct annual costs:
Raw materials:
Fixation chemicals
Lime
Lime (magnesium promoted)
Limestone
Magnesium oxide
Sodium carbonate
Salt cake (credit)
Sulfur (credit)
Sulfuric acid (credit)
Utilities:
Electricity
Water
Steam
(continued)
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
$3.50/ton
$46/ton
$61/ton
$52/tonc
$11.60/ton
$266/ton
$110/ton
$60/ton
$87/ton
$35/ton
$30 mills/kWh
$0.24/103 gal
$1.45/106 Btu
A-19
-------
TABLE A-5 (continued)
Category
Value
Operating labor:
Direct labor
Supervision
Maintenance:
Labor and materials
Supplies
Overhead:
Plant
Payroll
Fixed annual costs:
Depreciation
Interim replacement
Taxes
Insurance
Capital costs
$13.30/man-hour
15% of direct labor 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%
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.
Estimated cost for carbide lime used by Louisville Gas and Electric was
$13.30/ton in 1978. This was escalated to $15.40/ton for 1980.
Long term contract (e.g., Dravo contract).
Some system components have life spans less than the expected service life
of the system. Interim replacement is an allowance factor used in estimat-
ing 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-20
-------
EPA UTILITY
SURVEY: OCTOBER - DECEMBER 1980
SECTION A-l
COSTS FOR OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
ALABAMA ELECTRIC COOP
TOHBIGBEE
2
255MW (GROSS)
179MW (ESC)
ALABAMA ELECTRIC COOP
TOMBIGEEE
3
255MW (GROSS)
179MW (ESC)
ARIZONA ELECTRIC POWER COOP
APACHE
2
195MW (GROSS)
98MW (ESC)
ARIZONA ELECTRIC POWER COOP
APACHE
3
195MW (GROSS)
98MW (ESC)
ARIZONA PUBLIC SERVICE
CHOLLA
1
119MW (GROSS)
119MW (ESC)
ARIZONA PUBLIC SERVICE
CHOLLA
Z
264MW (GROSS)
264MW (ESC)
COST DESCRIPTION
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, SXKW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
REPORTED
65
5826750.
1165350.
**********
27.4(1978)
434929.
**********
Jf JtS( M^^t^tX^^f
.3(1978)
65
5826750.
1165350.
**********
27.4(1978)
**********
434929.
**********
.3(1978)
65
6154982.
1895044.
78949.
41.8(1977)
48237.
3547.
**********
******( 1979)
65
5449433.
1677814.
69899.
37.0(1977)
48237.
3547.
**********
******( 1979)
***
**********
**********
**********
52.0(1973)
**********
**********
**********
******( 1978)
65
**********
**********
**********
168.0(1977)
1003568.
**********
**********
.8(1978)
___— . cn^T— — — — .
ADJUSTED
65
**********
**********
**********
35.1(1980)
203S050.
307900.
1551000.
2.9(1980)
65
**********
**********
**********
35.1(1980)
2038050.
307900.
1551000.
2.9(1980)
65
**********
**********
**********
62.0(1980)
1437300.
20300.
1973800.
3.4(1980)
65
**********
**********
**********
58.4(1980)
1437300.
20300.
1973800.
3.4(1980)
65
**********
**********
**********
74.6(1980)
1322600.
346500.
1365700.
4.2(1980)
65
**********
**********
**********
148.7(1980)
2785200.
512300.
6801800.
7.5(1980)
STANDARDIZED
ADJUSTED
65
**********
**********
**********
35.1(1980)
2036050.
307900.
1551000.
2.9(1980)
65
**********
**********
**********
35.1(1980)
2038050.
307900.
1551000.
2.9(1980)
65
**********
**********
**********
62.0(1980)
1437300.
20300.
1973800.
3.4(1980)
65
**********
**********
**********
58.4(1980)
1437300.
20300.
1973800.
3.4(1980)
65
**********
**********
**********
74.6(1980)
1322600.
346500.
1213700.
4.0(1980)
65
**********
**********
**********
148.7(1980)
2785200.
512300.
6801800.
7.5(1980)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 21
-------
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EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
SALT R^VER PROJECT
CORONAUO
2
350MW (GROSS)
280MW (ESC)
SOUTH CAROLINA PUBLIC SERVICE
WINY AH
2
280MH (GROSS)
140MW (ESC)
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
1
200MW : GROSS)
124MW (ESC)
SOUTH MISSISSIPPI ELEC PWR
R.D. MORROW, SR.
2
200MW (GROSS)
124MW (ESC)
SOUTHERN ILLINOIS POWER COOP
MARION
ft
173MW (GROSS)
173MW (ESC)
SOUTHERN INDIANA GAS & ELEC
A.B. BROWN
1
265MW (GROSS)
265MW (ESC)
COST DESCRIPTION
CAPACITY FACTOR, 7.
DIRECT CAPITAL, S
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, S
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
REPORTED
***
25900000.
**********
**********
74.0(1978)
**********
**********
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80
6026098.
520000.
100000.
23.7(1976)
527000.
**********
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.3(1978)
***
10250000.
646000.
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53.7(1975)
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646000.
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63
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859453.
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1.0(1978)
65
12495000.
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47.2(1978)
1850565.
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1.3(1978)
ADJUSTED STANDARDIZED
ADJUSTED
65 65
********** **********
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******( 0 ) ******( 0 )
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65 65
9463800. 9463800.
2452300. 2452300.
144000. 144000.
43.1(1980) 43.1(1980)
552000. 552000.
135700. 135700.
1788500. 2090000.
1.7(1980) 1.9(1980)
65 65
17176000. 17176000.
4880750. 4880750.
********** **********
108.7(1980) 108.7(1980)
3194750. 3194750.
650250. 650250.
2668850. 3822400.
6.4(1980) 7.5(1980)
65 65
17176000. 17176000.
4880750. 4880750.
********** **********
108.7(1980) 108.7(1980)
3194750. 3194750.
650250. 650250.
2668850. 3822400.
6.4(1980) 7.5(1980)
65 65
********** **********
********** **********
********** **********
110.9(1980) 110.9(1980)
2475100. 2475000.
727000. 727000.
3323500. 3323500.
7.1(1980) 7.1(1980)
65 65
15019500. 15019500.
6458400. 6458400.
********** **********
81.0(1980) 81.0(1980)
2530300. 2530300.
282200. 282200.
3722100. 3722100.
4.6(1980) 4.6(1980)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 29
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S1S03
0861 a3aW333d - H390130 :A3AanS Q9J
Vd3
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
ARIZONA PUBLIC SERVICE
CHOLLA
4
375MW (GROSS)
126MW (ESC1
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
1
440MW (GROSS)
440MK (ESC)
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
2
440MW (GROSS)
440MW (ESC)
BASIN liLECTRIC POWER COOP
LARAMI^ RIVER
2
570MW (GROSS)
570MW (ESC)
BASIN ELECTRIC POWER COOP
LARAMIK RIVER
3
570MW (GROSS)
570MW (ESC)
BOSTON tDISON
MYSTIC
6
150MW (GROSS)
150MW (ESC)
COST DESCRIPTION
CAPACITY FACTOR f X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAF)
CAPACITY FACTOR, X
)IRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, SXKW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, S
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, S
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, S
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
REPORTED
***
28000000.
*«*«*%«»««
**********
80. 0( 0)
**********
**********
**********
******( 0 )
75
**********
**********
**********
75.2(1981)
**********
**********
**********
.8(1981)
***
47960000.
**********
**********
109. 0( 0)
1797596.
**********
**********
.8(7800)
***
33600000.
**********
**********
56.0(1980)
2818530.
**********
**********
.9(7800)
75
**********
**********
**********
83.0(1981)
**********
**********
**********
.6(1981)
***
**********
**********
**********
63.4(1972)
**********
**********
**********
3.0(1974)
ADJUSTED STANDARDIZED
ADJUSTED
65 65
********** **********
********** **********
********** **********
******( 0 ) ******( Q )
********** **********
********** **********
********** **********
******( 0) ******( 0)
65 65
********** **********
********** **********
********** **********
******( 0) ******( 0)
********** **********
********** **********
********** **********
******( 0 ) ******( 0 )
65 65
********** **********
********** **********
********** **********
******( 0) ******( 0)
********** **********
********** **********
********** **********
******( o ) ******( 0 )
65 65
********** **********
********** **********
********** **********
******( 0) ******( 0)
********** **********
********** **********
********** **********
******( 0) ******( 01
65 65
********** **********
********** **********
********** **********
******( o ) ******( o )
********** **********
********** **********
********** **********
******( 0) ******( 0)
65 65
********** **********
********** **********
********** **********
******( 0) ******( 0)
********** **********
********** **********
********** **********
******( 0) ******( 0)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 31
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
CINCINNATI GAS & ELECTRIC
EAST BEND
2
650MW (GROSS)
650MW (ESC)
COMMONWEALTH EDISON
WILL COUNY
1A
167MW (GROSS)
167MW (ESC)
DETROIT EDISON
ST. CUIR
6A
325M1S (GROSS)
163MK (ESC)
HOOSIER ENERGY
MEROM
1
490MW (GROSS)
441MW ( 1 SC )
HOOSIE:? ENERGY
MEROM
2
490MW (GROSS)
441MW (ESC)
ILLINOIS POWER COMPANY
WOOD RIVER
4
11QMW (GROSS)
110MW (ESC)
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
*** 65 65
78000000. ********** **********
********** ********** **********
********** ********** **********
120. 0( 0) ******( 0) ******( 0)
11718252. ********** **********
********** ********** **********
********** ********** **********
3.4(7800) ******( 0) ******( 0)
49 65 65
********** ********** **********
********** ********** **********
********** ********** **********
113.0(1972) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
13.1(1975) ******( 0) ******( 0)
*** 65 65
********** ********** **********
********** ********** **********
********** ********** **********
80.3(1976) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
9.6(1976) ******( 0) ******( 0)
*** 65 65
24500000. ********** **********
********** ********** **********
********** ********** **********
50. 0( 0) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( 0) ******( 0) ******( 0)
*** 65 65
24500000. ********** **********
********** ********** **********
********** ********** **********
50. 0( 0) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( 0) ******( 0) ******( 0)
*** 65 65
********** ********** **********
********** ********** **********
********** ********** **********
82.5(1972) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( 0) ******( 0) ******( 0)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 32
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION A-2
COSTS FOR NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
LAKELAND UTILITIES
MCINTOSH
3
364MW (GROSS)
364MW (ESC)
MONTANA POWER
COLSTRIP
3
700MW (GROSS)
700MW (ESC)
MONTANA POWER
COLSTRIP
4
700MW (GROSS)
700MW (ESC)
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
120MVI (GROSS)
120M1' (ESC)
PUBLIC. SERVICE OF COLORADO
VALMOhT
5A
166MV. (GROSS)
166Mk< (ESC)
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
500MW (GROSS)
500MW (ESC)
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGED, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
REPORTED ADJUSTED STANDARDIZED
ADJUSTED
*** 65 65
11775400. ********** **********
********** ********** **********
********** ********** **********
32. 4( 0) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( o ) ******( 0 ) ******( 0 )
*** 65 65
766*3000. ********** **********
********** ********** **********
********** ********** **********
109. 5( 0) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
.********** ********** **********
******( 0) ******( 0) ******( 0)
*** 65 65
70686000. ********** **********
********** ********** **********
********** ********** **********
101. 0( 0) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( Q) ******( 0) ******( 0)
65 65 65
********** ********** **********
********** ********** **********
********** ********** **********
285.7(1973) 187.1(1980) 187.1(1980)
********** 2527900. 2527900.
********** ********** **********
********** 3768500. 35018'00.
6.4(1979) 10.5(1980) 10.1(1980)
*** 65 65
********** ********** **********
********** ********** **********
********** ********** **********
87.0(1974) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( Q) ******( 0) ******( 0)
*** 65 65
********** ********** **********
********** ********** **********
********** ********** **********
40. 0( 0) ******( 0) ******( 0)
********** ********** **********
********** ********** **********
********** ********** **********
******( 0) ******( 0) ******( 0)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 33
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1980
SECTION A-Z
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
SOUTH CAROLINA PUBLIC SERVICE
CROSS
2
500MW (GROSS)
500MW (ESC)
TENNESSEE VALLEY AUTHORITY
PARADISE
1
704MW (GROSS)
704MW (ESC)
TENNESSEE VALLEY AUTHORITY
PARADISE
2
704MW (GROSS)
704MH (ESC)
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
575MM (GROSS)
575MW (ESC)
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, S
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH (YEAR)
REPORTED
***
**********
**********
**********
40.01 0)
**********
**********
**********
******( 0 )
***
52500000.
*K**K«K)H(«
)H(«KKK)(*««
~l<\. 6( 0)
KX**W*M(KK
*«*««X»*«»
»**»*««««»
******( Q )
**»
52500000.
»**%K*«««*
**********
74. 6( 0)
**********
**********
**********
******( 0)
***
25875000.
^(9f Jf$t^tX^("X^f*
**********
45. 0( 0)
**********
**********
**********
******( 0 )
ADJUSTED
65
**********
**********
**********
******( 0 )
**********
**********
**********
******( 0)
65
**********
**********
**********
******( 0)
**********
9f 9HHt^t^^f XJfJf
**********
******( 0 )
65
**********
**********
**********
******( 0 )
**********
**********
**********
******( 0 )
65
**********
**********
**********
******( 0 )
**********
**********
**********
******( 0)
STANDARDIZED
ADJUSTED
65
**********
**********
**********
******( 0)
**********
**********
**********
******( 0)
65
**********
**********
**********
******( 0)
**********
**********
**********
******( 0 )
65
**********
**********
**********
******( 0 )
**********
**********
**********
******( o )
65
**********
**********
**********
******( 0 )
**********
**********
**********
******( 0 )
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 34
-------
APPENDIX B
DEFINITIONS
B-l
-------
DEFINITIONS
Boiler Commercial Service Date
Byproduct Nature
Commercial Service Date
(FGD System)
Company Name
Disposal
Efficiency:
Total Unit Design Particle
Removal Efficiency
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: interim and
final disposal sites and
disposal type (minefill,
landfill, etc.) as well as
disposal location and site
capacity.
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.
Total Unit SC>2 Design
Removal Efficiency
B-2
The actual percentage of SC-2
removed from the flue gas by
the FGD system.
-------
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
Sludge
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 not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
B-4
-------
Recoverable Byproduct
Energy Consumption, %
Equivalent Scrubbed Capacity
(ESC)
FGD Status:
Category 1
Category 2
Category 3
Cateogry 4
Category 5
products must be disposed in
an environmentally acceptable
fashion.
The SO2 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
ammonium sulfate, sodium sul-
fate).
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
Initial Start-Up (FGD System)
New
Plant Name
Process Additives
Process Type
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation,
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.
Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.
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 S02
removal efficiency).
Company name if process is
patented. Generic name if
several companies have similar
processes (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .
B-6
-------
Regulatory Class
Retrofit
A. Unit(s) subject to Federal
New Source Performance
Standards (NSPS) promul-
gated in June 1979.
B. Unit(s) subject to Federal
New Source Performance
Standards (NSPS) promul-
gated in December 1971.
C. Unit(s) subject to stan-
dard (s) more stringent
than NSPS (6/79).
D. Unit(s) subject to stan-
dard (s) more stringent
than NSPS (12/71), but
not more stringent than
NSPS (6/79)
E. Unit(s) subject to stan-
dard (s) equal to or less
stringent than NSPS
(12/71).
FGD unit will be/was added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.
SC>2 Removal Mode
Spare Capacity Index - %
Spare Component Index
System Supplier
Total Controlled Capacity
(TCC)
The manner in which the SO2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.
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
B-7
-------
Unit Rating
Gross
Net w/FGD
Net w/o FGD
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
the gross unit rating if the
system is not meant to bring.
the facility into compliance
with SC>2 emission standards.
Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
B-8
-------
APPENDIX C
TABLE OF UNIT NOTATION
C-l
-------
TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Mass/Weight
Pressure
Temperature
Volume
English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre- feet
Symbol
acre
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
(actual)
Ib
t
in. H20
oF
ft3
Acre-ft
Survey Report
Notation
ACRE
SQ.FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
LB
T
IN. H20
F
CU.F
ACRE-FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Joules per
gram
Meter
Centimeter
Kilometer
Liters per cubic
meter
Kilogram
Megagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
M2
M2
g/m3
ppm
ng/J
m3/.
liter/a
kg/s
M t/d
M t/h
J/g
m
cm
km
liter /m3
kg
Mg
kPa
•c
"3
mj
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/CD. M
KG
MG
KPA
C
CU.M
CU.M
ro
-------
APPENDIX D
F6D PROCESS FLOW DIAGRAMS
D-l
-------
I
to
LIMESTONE SLURRY PUMPS
(TWO TOTAL)
HASTE-1
SLURRY
SUMP
HASTE SLURRY
PUMPS
(TVO TOTAL)
MS TO STACK
FROM UNIT 3
LIMESTONE SLURRY
TO UNIT 3
SCRUBBER HASTE
STORAGE POND
Alabama Electric,
Simplified Process Flow Diagram for Tombigbee 2 and 3
-------
o
I
U)
SINGLE LOUVER
DAMPER
DOUBLE LOUVER
DAMPER
TO PROCESS
SEAL WATER
(SERVICE WATER)
TOTAL PROCESS
MAKE-UP WATER
(COOLING TOWER
SLOWDOWN)
SLURRY
SUMP PIT
SEAL WATER
I BOOSTER
I PUMPS
r i
^j r" t_
J ^
v- ••••
ABSORBER
FEED TANK
r
*-
i
r i
i
•i J
1
* ^"
,
WP rn »
ABSORBER1"* '
TOWER |
i
H
U^r"
VMILL
T SLURRY
PUMPS
"*O c='=l
>V' AB!
\ RE
. \Sl
i . \
*. rn UNIT un i
.ORBER
AGENT
URRY
TANK
ABSORBER REAGENT^1
FEED PUMPS
WE
GRI
— MILL
SLURRY
SUMP
WET LIMESTONE
GRINDING SYSTEM
Arizona Electric Power Coop, Apache 2 and 3
Process Flow Diagram
-------
fr-d
3 N
T3 O
— ' 3
_i. CU
fO C
Q. CT
-s o
o
o c/i
(D fD
t/i ~S
to <
-n o"
—< n>
o ••
o
O) -J
CQ —•
-S O)
o>
-------
WKEUP
WATER '
O
I
en
TRANSFER
PUMPS
RECIRCULATION
PUMPS
Central Illinois Light,
Simplified Process Flow Diagram of Duck Creek 1
Power Plant and Emission Control System
-------
1 BOOSTER FAN
2 CHLORIDE/FLYASH PRECOOLER
3 FLYASH THICKENER
4 ABSORBER
5 NEUTRALIZE
6 REACTOR-CLARIFIER
7 CAUSTICIZERS
8 THICKENER
9 HORIZONTAL BELT FILTER
10 REHEAT FACILITY (EXPERIMENTAL)
o
I
Central Illinois Public Service, Newton 1:
Simplified Process Flow Diagram Showing One of Four Absorbers
-------
MAKEUP HATER
(POND HATER)
O
I
LIME FROM
STORAGE
TO STACK - FLUE GASES
MIST ELIMINATOR
f*
1
1 TO OTHER
<~^J RECYCLE TANK
-------
To Stack
a
i
oo
Bypass
1
!!•• .1^
St\ /r\ /f\ A
Jf\ /f\ ^ /
^\ /T^ ^\ /
Mist Eliminator
M.E. Wash Make Up
Lime Silo
Flyash Wet'G
Tank
Reaction Tank
In-Tank
Lime
Feed Tank
From
Precipitator
Strainer
To Disposal
Cooperative Power Association, Coal Creek 1 and 2:
Simplified Process Flow Diagram
-------
o
i
BOILER
1ST STAGE
ADJUSTABLE VENTURI
FOR FLY ASH/S02
RECYCLE RETURN SYSTEM
CaS03/S04
FLY ASH SLURRY
RETURN TO POND
"THICKENER
ASH POND
TO
STABILIZATION
FACILITIES
2ND STAGE
S02 ABSORBER SCRUBBER
Duquesne Light, F. R. Phillips FGD System:
General Diagram.
-------
OT-d
T3
CO -".
O -5
O
3- o
l/l CD
. tn c
ro TI -h
tn — 1
r-t- o -o
o s o
3 s
fD a ro
o &> >.
C U3
O) -S C/J
— ' 01 n
3 3-
J= O
— ' O — '
7T -h IM
QJ
ro
-o
-^ C 1
o ro
o 3
ro o
l/l 3
to (/>
rt-
QJ
o
zs
-------
AMBIENT
AIR FAN
MIST
ELIMINATOR
AIR
HEATER
MOBILE PACKING
PRE-SATURATION SPRAY
FLUE GAS IN
TO STORAGE AREA
CLEAN GAS OUT TO STACK
MIST ELIMINATOR
WASH
WASTE
SLURRY TANK
PUMP
Indianapolis Power and Light, Petersburg 3:
Simplified Process Flow Diagram for One of Four Absorbers
D-ll
-------
STACK
D. FAN
D
I
j-j
to
COAL
SUPPLY
FEEDER
PULVERIZER
STACK GAS
REHEATER
AIR HEATER
DEMISTER-
STACK GAS
SCRUBBER
LIME
PREPARATION
TANK
RECYCLE
PUMP
Kansas City Power and Light, Hawthorn Units 3 and 4:
Simplified Process Flow Diagram of the Lime Scrubbing Process
CLARIFIER
MAKE UP
WATER
TO ASH DISPOSAL
POND
-------
o
I
M
u>
ABSORBER
REJCIRCULATION
PUMPS
LIMESTONE
SLURRY
STORAGE
160 ACRE
SETTLING POND
BOILER
WET BALL
MILL
Kansas City Power and Light,
LaCygne 1 FGD System: General Diagram
-------
FURNACE
DAMPERS
ONE
STACK
TWO PRECIPITATORS
FOUR I.D. FANS
WATER RETURN TO
REACTION TANKS
BLEED PUMP
SPRAY PUMP TRANSFER TANK
FOUR,
REACTION
TANKS
.""V
SLUDGE DISPOSAL
POND
Kansas Power and Light,
Schematic of Jeffrey Steam Generator and Emission Control Equipment
-------
DILUTION WATER
(fROH RECIRCULATION TANK)
HILL
SLURRV PUMPS
TO OTHER
SCRUBBER NODULE
I
M
Ui
STACK I POND RETURN
(MAKE-UP)
I WATER
WEIR
OVERFLOW
|Hr] »• SETTLING
THICKENER POND
UNDERFLOW PUMPS
Kansas Power and Light,
Lawrence 4 Operational FGD System:
Simplified Process Flow Diagram
-------
WTEB fOf
DILUTIOH WTER (FRO"
ADDITIVE STORAGE REC1RCULATIO* TWt I
T»N« 60 SOLIDS
ONE OF TWO MODULES
O
I
f-1
(Ti
FLUE GAS FROM
AIR PREHEATER
|
I
Kansas Power and Light,
Lawrence 5 Operational FGD System:
Simplified Process Flow Diagram
-------
o
I
I-1
\ SETTLING .
\ POND A
U-i_
7^-
^
MAKEUP MATERX-/
FROM
POND j j j j
|[ t— Jt-D e=»
BLEED TO POND
RE/
L .
_,. , ,-r
REACTANT ADDITION
MAKEUP MATER
MAKEUP MATER
RECYCLE r-"» MIX/HOLD TANK
\.J
SPARE
SPARE
SPARE
Kentucky Utilities,
Green River FGD System: General Process Diagram
-------
QUENCHER
O
I
(-1
oo
ELECTROSTATIC
PRECIPITATOR
BOILER
FLUE
GAS
MIST
ELIMINATOR
(CHEVRON)
CONTACTOR
SCRUBBER
~~ MODULE
REACTION
TANK
CONTACTOR
SCRUBBER
MODULE
MIST
ELIMINATOR
(CHEVRON)
Louisville Gas and Electric, Cane Run 4
FGD System: Simplified Process Flow Diagram
-------
-IN LINE REHEATER (STEAM)
1
I.D. BOOSTER FANSv
-------
COMBUSTION AIR
REACTANT
(LIME SLURRY)
FEED TANK
TO ABSORBER
A-201
Louisville Gas and Electric, Cane Run 6
Dual Alkali FGD System: Simplified Process Flow Diagram
D-20
-------
GAS TO STACK
D
I
ro
GAS REHEATERS
MIST ELIMINATOR
HASHERS
DRY CA(OH)2
ADDITIVE SYSTEM
GAS INLET
FRESH WATER
pH 6 OR HIGHER
GAS INLET , ^p_
STEAM BLOUERS T"
pH ELECTRODE STRAINERS
ASSEMBLY
H1XERD I \ /'
COMHINUTOR
REACT 10 SPRpA,LTER
SURGE TANK PUMPS
FUmR I CONNFE0CRTION I FLAPPER
AGITATOR * FOR
SOLIDS TO
CONVEYOR =i DISPOSAL
Louisville Gas and Electric,
Paddys Run 6 FGD System:
Simplified Process Flow Diagram
-------
TREATED-GAS
DUCT
SPRAY TOWER
ABSORBER
"WET" VENTURI
SCRUBBER
Minnesota Power and Light, Clay Boswell 4:
General Diagram
D-22
-------
REHEAT BY-PASS
BOOSTER
FAN
—€7
D
I
to
to
FILTER CAKE
Minnkota Power Cooperative, Milton R. Young 2:
Simplified Process Flow Diagram for One of Two Absorbers
-------
D
I
N)
S02 BOOSTER FANS
FLUE GAS)
"QUENCHER
LIME FEED
SYSTEM
fHYDRQCLQNE
^
D
RECYCLE TANK
TO STACK
WASH TRAY
-ABSORBER TRAY
RECYCLE
LIQUOR "*"
*- TO EMERGENCY
DUMP POND
TO DISPOSAL SITE
Monongahela Power, Pleasants 1 and 2:
Simplified Process Flow Diagram for One of Four Modules for Either Unit
-------
o
i
to
PLENUM
EMERGENCY WATER
MIST
ELIMINATORS
WASH TRAY
VI
RECYCLE PUMPS
U VJ
W"'^
»*CLEAN FLUE GAS
{XKSEAL WATER SUPPLY
.UNDERSPRAY __ MAKEUP
WATER
£7
V
^
FLY ASH POND
~-^
TRAY RECYCLE
7
WASH TRAY POND
POND
RETURN
Montana Power, Col strip 1 and 2:
Process diagram of a given FGD module.
-------
PULYERUER
o
I
TO CHIMNEY
FURNACE
MECHANICAL
OUST
COLLECTOR
(MULTICLONES)
Vi
AIR
HEATER
BYPASS
EVAPORATION PONDS
ON HESA
HATER
TEAM
BOILER
I.D. FAN
REHEATER AIR FAN
MATER FROM
f~ASH PONO
-TZJ
BOILER
.0. FAN
piiarr
TWIN f"7"* «••
YENTURI 1
THROAT I 1 I
SCRUBBERU—J ' L
soz
T ^
VENTURI RECYCLE
PUMP Q_
« —
ABSORBER
I
YCNTURI
RECYCLE
TO ASH PONO Q
ASH PONO PUMP
T
X*
t — i^r ~
R
TRJ
EC
TRAY RECYCLE PUMP "^
SOOA ASH
H*KEUP
(y^~
iU
ASH
<2
»
'CIS
kNK>
ASH PONO
ol"1
MAKEUP
NK>
caa
SODA ASH
SLURRY PUMP
ASH AND HATER
Nevada Power, Reid Gardner 1,2 and 3:
Process diagram of a given FGD system.
-------
DISCHARGE
TO STACK
PRESCRUBBER
(VARIABLE-THROAT
VENTURI)
D
I
NJ
-J
FLUE GAS FROM
UNIT #11
1
TRA'l
I l™
CONDENSER
TRAY TOWER
ABSORBER
±1
MAKE-UP•
> > » > >
FLY ASH PURGE TO POND
TREATED
PURGE STREAM
STORAGE
BIN
Y
DRIED
SULFATE
PRODUCT
CENTRIFUGE
SODIUM SULFATE
CAKE
CRYSTALLIZER
•STEAM
EVAPORATOR/
VCRYSTALLIZER
PURGE
STREAM
TO S02
REDUCTION
PLANT-*—IXI
COMPRESSOR
Northern Indiana Public Service,
D. H. Mitchell 11 Weilman_ Lord/Allied System:
General Process Diagram.
-------
FLUE GAS FROM BOILER
Northern States Power, Riverside 6 and 7:
General Diagram
D-28
-------
FLUE GAS
TO
SCRUBBER
FIRST
STAGE
OOO
o
i
K>
VD
REHEATER
_ FLUE GAS
TO STACK
RIVER
MAKEUP
WATER
LIMESTONE —i
MIST
ELIMINATOR
OVERFLOW POTS
AND MARBLE BED
r \
OXIDIZER
REACTION
TANK
WEIR
THICKENER
RECIRC
TANK
THICKENER
UNDERFLOW
PUMP
SPRAY
PUMP ,
SLURRY
TANK
SLURRY
PUMP
ASH POND
ASH POND
RETURN PUMP
Northern States Power, Sherburne 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
TRANSFER HOUSE 1
d
i
uo
o
•OILER CLEW Rltttt
DCHIHEMLIZER RIHSE
HASH-TW* OMIN
FLUSH
KSH-HOPPER MERF
DEUITEfrlW BINS
LOS PUWHQUSE SUMP
SUP£RWT»tn fiETUHN PUMPS (3)
«1¥E« OlSCHABGf PUMPS
TO LIMt AREA FLUSH
-*• TO BOTTW-ASH STSTEH
TO SCKUBBER/USOHBER
AREA FLUSH
_». TO THICKENER AREA
FLUSH
Pennsylvania Power, Bruce Mansfield FGD System:
Process Flow Diagram for Unit 1 or 2
-------
FLUE GAS FROM
UPPER ESP
u
i
OJ
FLUE GAS FROM
LOWER ESP
HOT RFHFAT RAS
PLENUM
EXHAUST
ISOLATION
DAMPERS
(4 PER UNIT)
INLET
PLENUM
STACK INLET
DAMPERS (2)
(1 EACH SIDE)
INLET ISOLATION
DAMPERS (4 PER UNIT)
BOOSTER FAN FLOW
CONTROL DAMPERS
STACK
ABSORBERS (4 PER UNIT)
(4 PER UNIT)
BOOSTER FANS
(4 PER UNIT)
Public Service of New Mexico, San Juan 1, 2, and 3*
FGD System Flue Gas Flow Path
*San Juan 3 is identical except that only one scrubbing
train is operational.
-------
From tans
o
I
to
Mist-eliminator
wash tank A
To
scrubber-B
booster Ian
To teal-water system
To flush connections •
To alkali-preparation'
system
Tostack
From
scrubber B
I Makeup water
To scrubber B
To scrubber B
Limestone-slurry
makeup
From
scrubberB
Flocculent
addition
To sludge
storage tanks
Byptntfuet ftutgulrom
ttfctroittlic
prtcipiMon
V
Rtictiorr
mi* link
Pntiturttor
Bootttrtvu
Salt River Project, Coronado 1 and 2:
Simplified Process Flow Diagram
-------
BOILER
EXISTING
ELEC.PRECIP.
\/
U)
U)
fl
VENTURI SORBER
SCRUBBERTM
(ONE IN USE)
LIMESTONE
FEED BIN
(ONE IN USE
FOR TWO
BOILERS)
MIST ELIMINATOR
| PUMP
(ONE IN USE
ONE
MAKEUP WATER
I MIST,*
ELIMINATOR
I TANK (ONE 1
USE)
I.D. FAN
(TWO IN USE)
WEIGH FEEDER
(ONE IN USE)
WET BALL MILL
(ONE IN USE)
MIXER—-v
(ONE IN USE)
P MIXER
(ONE IN USE)
FROM THICKENER
rn » *"ur-»ir-n fc>*1
TO THICKENER..
SLURRY STORAGE
HILL SLURRY
TAN?
I nnr. / nuc tu I ICC
(ONE IN USE) VoJ^ SPARE) (ONE IN USE>
SLURRY
PUMP
(ONE IN USE
ONE SPARE)
RECYCLE TANK
(ONE IN USE)
RECYCLE
PUMP
(TWO IN USE
ONE SPARE)
THICKENER
SUPPLY
TANK
(ONE IN USE)
PUMP
(ONE IN USE
ONE SPARE)
South Mississippi Electric, R.D. Morrow 1 and 2:
Simplified Process Flow Diagram
-------
D
I
OJ
SODA ASH
STORAGE
LIME
STORAGE
USE /SLAKER Ca(OH)2
WATER
CaS03/Na2S03 THICKENER
cTnri/ BOOSTER
STACK pAN
SULFUR DIOXIDE ABSORPTION
Na?S03 + S02 + HoO -2 NaHSO-3 SURGE
— - * ^zgJJlTANK
CaS03/CaS04
FILTER
SODIUM REGENERATION CAKE
2 NaHS03 + Ca(OH)2 " CaS03 ' 1/2 H20 + Na2S03 + 1-1/2 H20
Southern Indiana Gas and Electric, A.B. Brown 1:
Dual Alkali FGD System Simplified Process Flow Diagram
-------
SCRUBBER INLET
TEST PORT LOCATION
TOP OF STACK
ELEVATION 1645'
PRECIPITATOR
INLET TEST
PORT LOCATION
D
I
oj
Ln
"B" ABSORBER
MODULE
TEST PORT
ELEVATION 1516
1 TOP OF OUTLET BREECHING
ELEVATION 1372'-2 3/8"
U-TOP OF BYPASS BREECHING
ELEVATION 1307'- 8 1/2"
BYPASS DUCT \
SHADE ELEVATION 1261'
A" ABSORBER
MODULE
SCRUBBER INLET
TEST PORT LOCATION
Springfield City Utilities, Southwest 1:
Simplified Process Diagram
-------
H2S GENERATION
METHANE/
CARBON MONOXIDE
BOILER
PREHEATER
LIME
NEUTRALIZER
PRECONDITIONING AND
S02 ABSORPTION
CRYSTALLIZER
SULFUR
SLURRY
SULFUR
FLOTATION
SULFUR
PRODUCT
SULFUR PRECIPITATION
AND RECOVERY
St. Joe Zinc, G.F. Weaton 1:
Citrate FGD System Simplified Process Flow Diagram
D-36
-------
o
U)
I AIR
IFUEL OIL>— »|REHEATER[— i
TCA
SCRUBBERV Y/<
-------
FLUE GAS
o
i
oo
oo
SPRAY TOWER EFFLUENT
HOLD TANK
VENT AIR
A
OXIDATION
TANK
D
CLARIFIED LIQUOR
WATER
:z>
c=>
t- ,*
__j» r^f.
r
t
^
!
r-
~>
. /c
DESUPERSATURATION
TANK
BLEED TO
DEWATERING
-. SYSTEM
Tennessee Valley Authority, Shawnee 10B Prototype Test Unit:
Modified Venturi/Spray Tower System for 2-Stage Oxidation Testing.
-------
o
i
U)
I.D. FAN
SAMPLE POINTS
OGAS COMPOSITION
®PARTICULATE COMPOSITION & LOADING
®SLURRY OR SOLIDS COMPOSITION
GAS STREAM
LIQUOR STREAM
PROCESS
WATER
HOLD TANK
SETTLING POND
Tennessee Valley Authority, ShawneelOB Prototype Unit:
General Process Diagram.
-------
G
I
*>
o
TO ASH
^ FROM
. URAINS
fB,C, AND D
"1
REHEATER
STEAM
ENTRAPMENT
SEPARATOR
DISPOSAL POND
TO STACK PLENUM
FROM ESP
FAN
- FROM B. C, AND D TRAIN
VENTURI CIRCULATION TANKS] '
TO SETTLING POND
SLURRY PUMP
SEAL WATER
. HEADER
VENTURI
CIRCULATION
TANK AND
PUMPS
ABSORBER
CIRCULATION
TANK AND
PUMPS
EFFLUENT SLURRY
SURGE TANK AND PUMPS
TO TRAINS
B,C, AND Dl
DRIVER WATER
PUMPS'
<: FROM POND WATER
RECYCLE PUMPS
FROM LIMESTONE SLURRY
TO TRAINS
B,C, AND D1
LIMESTONE SLURRY
STORAGE TANK
LIMESTONE SLURRY
FEED PUMPS
Tennessee Valley Authority, Widows Creek 8 FGD System:
Process Flow Diagram for One of the Four Scrubber Trains
-------
FAN OUTLET DAMPER^
- TOWER INLET DAMPER
FROM BOILER
AIR PREHEATERS
ABSORBER
r^W PACKING
PUMPS
(ONE SPARE)
PUMP SEAL
HATER TO
QUENCHER
BLOWDOHN PUMPS
INE^LUS
PUMP SEAL HATER,
BALL MILL COOLING
AND HOSE STATIONS
MAKEUP WATER TO
LIMESTONE AREA
SERVICE WATER ASH POND
(LAKE WATER) RETURN WATER
(RECYCLE WATER)
Simplified Process
Texas Utilities,
Flow Diagram for One of
Martin Lake FGD Systems
the Three Identical
-------
o
I
,>.
tsj
BYPASS
TO SPRAY TOWER 301
BYPASS
FROM SPRAY TOWER 301 f_
FROM SPRAY TOWER 201 £_
BYPASS
_ SERVICE WATER
MIST ELIMINATOR
WASH WATER
TO SPRAY TOWER 201
TO SPRAY TOWER 201
TO SPRAY TOWER 301
TO SPRAY TOWER 201
TO SPRAY TOWER 301
TO SPRAY TOWER 201
TP SPRAY TOWER 301
TO SPRAY TOWER 201
TO SPRAY TOWER 301
TO SPRAY TOWER 201
TOTAL PUMP SEALS AND
INSTRUMENT PURGE WATER
LIMESTONE GRINDING
SYSTEM
LIMESTONE SLURRY
TANK AGITATOR
FROM SPRAY TOWER 301
TO SPRAY TOWER 301 FROM SPRAY TOWER J01 TQ ASH AR£A
TOWER DRAIN TO
DISPOSAL
FROM
LIMESTONE STORAGE
SO, REMOVAL AREA
SUMP PUMPS
LIMESTONE
SLURRY
TANK
FROM ASH WATER
RETENTION POND
Texas Utilities,
Simplified Process Flow Diagram for Monticello 3
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse be/ore completing!
1. REPORT NO.
EPA-600/7-81-012 a
2.
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: October - December 1980
Volume I. Categorical Summaries of FGD Systems
5 REPORT DATE
January 1981
6. PERFORMING ORGANIZATION CODE
3 RECIPItNT'S ACCESSION NO.
7. AUTHOR(S)
M. Smith, M. Melia, N. Gregory, K. Scalf
8. PERFORMING ORGANIZATION REPORT NO.
PN 3560-2-6
9. PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
10. PROGRAM ELEMENT NO.
1NE828
11. CONTRACT/GRANT NO.
68-02-3173, Task 17
12. SPONSORING AGENCY NAME AND ADDRESS
13. TYPE OF REPORT AND PERIOD COVERED
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, N.C. 27711
Quarterly; 10-12/80
14. SPONSORING AGENCY CODE
EPA/600/13
15. SUPPLEMENTARY NOTES
IERL-RTP Project Officer is Norman Kaplan, Mail Drop 61, 919/541-2556.
reports are in the EPA-600/7-80-029 and EPA-600/7-79-022 series.
Related
16. ABSTRACT
This report is the first full compilation (not a supplement) since the October-
December 1979 report (EPA-600/7-80-029a). Because the next three reports are to
be supplements, this issue should be retained for reference throughout the year.
The report, which is generated by a computerized data base system, presents a
survey of operational and planned domestic utility flue gas desulfurization (FGD)
systems, terminated domestic utility FGD systems, operational domestic particle
scrubbers, and Japanese coal-fired utility boiler FGD installations. It sum-
marizes 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 dependability
parameters and discusses problems and solutions associated with the boilers and
FGD systems. Process flow diagrams and FGD system economic data are appended.
Section 3 of this report, because of its length, appears in Volume II (EPA-600/7-
81-012b).
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS C. COS AT I 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 (ThisRtport)
Unclassified
21. NO. OF PAGES
353
20. SECURITY CLASS (Thispage)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73)
D-43
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