PB83-168054
EPA (Environmental Protection Agency)
Utility FGD (Flue Gas Desulfurization) Survey
Volume I. Categorical Summaries of FGD Systems
PEDCo-Enviromnental, Inc.
Cincinnati, OH
Prepared for
Industrial Environmental Research Lab,
Research Triangle Park, NC
Sep 82
U.S. DEPARTMENT OF COMMERCE
National Technical Information Service
-
-------
EPA-600/7-82-05 8a
September 1982
EPA UTILITY FGD SURVEY
OCTOBER - DECEMBER 1981
VOLUME I. CATEGORICAL SUMMARIES
OF FGD SYSTEMS
By
Melia, M.T. and N.G. Bruck
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246-0100
Contract No. 68-02-3173
Task 71
EPA Project Officer: N. Kaplan
Industrial Environmental Research Laboratory
Office of Environmental Engineering and Technology
Research Triangle Park, North Carolina 27711
Prepared for
U.S. ENVIRONMENTAL PROTECTION AGENCY
Office of Research and Development
Washington, DC 20460
-------
TECHNICAL REPORT DATA
(Please rtad Inunctions on the reverse before completing)
i REPORT NO.
EPA-600/7-82-058a
3.
TITLE AND SUBTITLE
EPA Utility FGD Survey: October-December 1981
Volume I. Categorical Summaries of FGD Systems
3 RECIPIENT'S ar.rpecin«»w«i
3 i 680?
_
5 REPORT OATE
September 1982
6. PERFORMING ORGANIZATION CODE
7 AUTHORIS)
M.Melia and N.Brack
8 PERFORMING ORGANIZATION REPORT NO
9 PERFORMING ORGANIZATION NAME AND ADDRESS
PEDCo Environmental, Inc.
11499 Chester Road
Cincinnati, Ohio 45246
10. PROGRAM ELEMENT NO
11 CONTRACT/GRANT NO
68-02-3173, Task 71
12 SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
Industrial Environmental Research Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Quarterly; 10-12/81
14 SPONSORING AGENCY CODE
EPA/600/13
is. SUPPLEMENTARY NOTES IERL-RTP project officer is Norman Kaplan, iMail Drop 61, 919/541-
2556. Related reports are in the~EPA-600wC?-S&-029 -and -&lr-612. series.
16 ABSTRACT Th{i report is the first full compilation (not a supplement) since the
October-December 1980 report (EPA-600/7-81-012a and -12b). Because the next three
reports are to be supplements, this issue should be retained for reference throughout
the year. The report, generated by a computerized data base system, presents a survey
of operational and planned domestic utility flue gas desulfurization (FGD) systems.
It summarizes information contributed by the utility industry, process suppliers,
regulatory agencies, and consulting engineering firms. Domestic FGD systems are tabu-
lated 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. Process flow diagrams and FGD system economic data are ap-
pended. Section 3 of the report, because of its length, appears in Volume II.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
c COSATi Held,Group
Pollution
Flue Gases
Desulfurization
Electric Utilities
Waste Disposal
Boilers
Maintenance
Pollution Control
Stationary Sources
Utility Boilers
I3B
21B
07A.07D
15E
13A
13 DISTRIBUTION STATEMENT
Release to Public
19 SECURITY CLASS (THu Report)
Unclassified
21 NO OF PAGES
392
2O SECURITY CLASS fThtt pagt)
Unclassified
22 PRICE
EPA Form 2220-1 (9-731
-------
NOTICE
This report (prepared by PEDCo Environmental, Inc., Cincin-
nati, Ohio under EPA Contract No. 68-02-3173, Task No. 71) is
provided as an information transfer document. Data in this
report are supplied voluntarily by utility representatives; flue
gas desulfurization (FGD) system suppliers and designers; regula-
tory agencies; and others. Neither EPA nor the designated con-
tractor warrants the accuracy or completeness of information
contained in this report.
Distribution of a project summary will be made to organiza-
tions and individuals indicating a specific interest in the field
of FGD technology. Those interested can get on the mail list for
the project summary by contacting Norm Kaplan, Industrial Envi-
ronmental Research Laboratory, at 919/541-2556, or the Emission
and Effluent Technology Branch secretary at 919/541-2578. Copies
of the full report and preceding issues can be purchased from
National Technical Information Service,1 Springfield, Virginia,
22161.
This report presents a summary of the FGD system design and
performance data from a computerized data based called, "Flue Gas.
Desulfurization Information System" (FGDIS). Access to the FGDIS
is available to the public (subject to the limitations expressed
in the paragraph above) through the National Technical Informa-
tion Service (NTIS) for a non-profit usage charge. Users have
the capability of accessing 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 allows
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. .
Those interested should contact Walter Finch (NTIS) at 703/487-
4808.
This document has been reviewed in accordance with
U.S. Environmental Protection Agency policy and
approved for publication. Mention of trade names
or commercial products does not constitute endorse-
ment or recommendation for use.
ii
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USE OF THIS REPORT
This report is the first in a series of four issues. The
succeeding three issues will be supplemental in nature. This
report is the first full compilation since the October-December
1980 report (EPA-600/7-8L-012a&b). Because 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
1983.- 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 information.
This report contains a number of tables presenting tabula-
tions of some of the key data for S02 control systems on utility
boilers (e.g., categorical summaries by FGD system supplier, FGD
system status,, disposal practices, etc.). Detailed design and
performance data for operational FGD systems (Section 3) appears
in Volume II of this report. Design and performance data for
operational Japanese FGD systems and domestic particle scrubbers
are included in this report (Volume I); however, the information
was not updated during 1981. A section is also included for
terminated FGD systems. These are experimental or demonstration
FGD systems that were eventually shut down or FGD systems applied
to boilers that were later retired. The Executive Summary con-
tains the number and capacity of FGD systems as of the end of
December 1981, future projections (December 1999) of controlled
and uncontrolled generating capacity, and unit by unit summaries
of status changes (e.g., contract awarded, under construction,
operational, etc.) and performance (e.g., FGD system availability)
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 system process
flow diagrams.
iii
-------
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 eco-
nomic data, definitions, and a glossary of terms are appended to
the report. Current data for domestic FGD systems show 94 sys-
tems in operation, 40 systems under construction, and 88 planned
systems. Projected 1999 FGD controlled capacity in the U.S. is
107,351 MW.
iv
-------
CONTENTS
Notice
Use of This Report
Abstract
Tables
Executive Summary and Highlights
Section 1 Summary List of FGD Systems
Section 2 Status of FGD Systems
Section 3 Design and Performance Data for Operational
FGD Systems
Alabama Electric
Tombigbee 2
Tombigbee 3
Arizona Electric Power
Apache 2
Apache 3
Arizona Public Service
Cholla 1
Cholla 2
Cholla 4
Four Corners 1
Four Corners 2
Four Corners 3
Basin Electric Power
Laramie River 1
Laramie River 2
Big Rivers Electric
Green 1
Green 2
Central Illinois Light
Duck Creek 1
Central Illinois Public Service
Newton 1
Cincinnati Gas & Electric
East Bend 2
Colorado Ute Electric
Craig 1
Craig 2
*Section 3, pages 47-851, appear In Volume II.
Pace
ii
iii
iv
xi
xii
1
9
47*
47*-
56*
63*
73*
81*
99*
105*
108*
112*
116*
120*
127*
131*
138*
143*
159*
167*
171*
178*
-------
Merom 2 284*
Petersburg 3 287*
CONTENTS (continued)
Page
Columbus & Southern Ohio Electric
Conesville 5 187*
Conesville 6 200*
Commonwealth Edison
Powerton 51 210*
Cooperative Power
Coal Creek 1 215*
Coal Creek 2 222*
Delmarva Power & Light
Delaware City 1 227*
Delaware City 2 233*
Delaware City 3 239*
Duquesne Light
Elrama 1-4 245*
Phillips 1-6 261*
Hoosier Energy
Merom 2
Indianapolis Power & Light
Petersburg 3
Kansas City Power & Light
Hawthorn 3 296*
Hawthorn 4 307*
LaCygne 1 319*
Kansas Power & Light
Jeffrey 1 342*
Jeffrey 2 349*
Lawrence 4 354*
Lawrence 5 366*
Kentucky utilities
Green River 1-3 377*
Louisville Gas & Electric
Cane Run 4 387*
Cane Run 5 397*
Cane Run 6 406*
Mill Creek 1 413*
Mill Creek 2 418*
Mill Creek 3 422*
Paddy's Run 6 430*
Minnesota Power & Light
Clay Boswell 4 442*
Minnkota Power
Milton R. Young 2 449*
Monongahela Power
Pleasants 1 463*
Pleasants 2 469*
Montana Power
Colstrip 1 474*
Colstrip 2 482*
*Section 3, pages 47-851, appear In Volume II.
vi
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CONTENTS (continued)
Pace
Montana-Dakota Utilities
Coyote 1 490*
Nevada Power
Reid Gardner 1 493*
Reid Gardner 2 509*
Reid Gardner 3 528*
Northern Indiana Public Service
Dean H. Mitchell 11 543*
Northern States Power
Riverside 6-7 555*
Sherburne 1 560*
Sherburne 2 578*
Pacific Power & Light
Jim Bridger 4 592*
Pennsylvania Power
Bruce Mansfield 1 598*
Bruce Mansfield 2 612*
Bruce Mansfield 3 621*
Public Service Company of New Mexico
San Juan 1 626*
San Juan 2 637*
San Juan 3 649*
Salt River Project
Coronado 1 656*
Coronado 2 662*
San Miguel Electric
San Miguel 1 667*
Sikeston Board of Municipal Utilities
Sikeston 1 671*
South Carolina Public Service Authority
Winyah 2 675*
Winyah 3 684*
Winyah 4 690*
South Mississippi Electric
R.D. Morrow, Sr. 1 693*
R.D. Morrow, Sr. 2 702*
Southern Illinois Power Coop
Marion 4 71°*
Southern Indiana Gas & Electric
A.B. Brown 1 719*
Springfield City Utilities
Southwest 1 729
Springfield Water, Light & Power
Dallman 3 74S
St. Joe Zinc
G.F. Weaton 1 753*
*Sectlon 3, pages 47-851, appear in Volume II.
vii
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Section 4
Section 5
Section 6
Section 7
Section 8
Section 9
Section 10
Section 11
Section 12
Section 13
Section 14
CONTENTS (continued)
Page
Tennessee Valley Authority
Shawnee 10A 760*
Shawnee 10B 763*
Widows Creek 7 732*
Widows Creek 8 786*
Texas Power & Light
Sandow 4 801*
Texas Utilities
Martin Lake 1 805*
Martin Lake 2 813*
Martin Lake 3 820*
Monticello 3 826*
Utah Power & Light
Hunter 1 833*
Hunter 2 838*
Huntington 1 842*
Naughton 3 849*
Summary of FGD Systems by Company 852
Summary of FGD Systems by System Supplier 854
Summary of FGD Systems by Process 856
Summary of Operating FGD Systems by
Process and Unit 857
Summary of End-Product Disposal
Practices for Operational FGD Systems 860
Summary of FGD Systems in Operation 862
Summary of FGD Systems Under Construction 867
Summary of Contract Awarded FGD Systems 869
Summary of Planned FGD Systems 870
Total FGD Units and Capacity (MW)
Installed by Year 874
Design and Performance Data for
Operational Particle Scrubbers 875
Commonwealth Edison
Will County 1 875
•Section 3, pages 47-851, appear in Volume II.
Vila.
-------
CONTENTS (continued)
Section 15
Section 16
Detroit Edison
St. Clair 6
Minnesota Power and Light
Clay Boswell 3
Syl Laskin 1
Syl Laskin 2
Montana-Dakota Utilities
Lewis & Clark 1
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
Pace
901
910
913
917
921
925
928
931
934
941
945
948
951
958
962
962
967
973
979
987
994
999
1002
1006
1010
1014
ix
-------
CONTENTS (continued)
Appendix A
Appendix B
Appendix C
Appendix D
Detroit Edison
St. Clair 6A
Gulf Power
Scholz 1
Scholz 1A
Scholz IB, 2B
Scholz 1, 2
Scholz 2A
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
Page
1017
1021
1025
1030
1035
1039
1043
1047
1051
1060
1063
1066
1069
1072
1075
A-l
A-2
A-6
A-9
A-21
A-33
B-l
C-l
D-l
-------
TABLES
No. Pace
I Number and Total Capacity of FGD Systems xii
II Summary, of Changes, October-December 1981 xiv
III Performance of Operational Units,
October-December 1981 xv
FIGURE
No. Page
1 Computerized Data Base Structure Diagram xiii
xi
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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 of the
U.S. Environmental Protection Agency. It is generated by a
computerized data base system, the structure of which is illus-
trated in Figure 1.
Table 1 summarizes the status of FGD systems in the United
States at the end of December 1981. Table 2 lists the units
that have changed status during the fourth quarter 1981, and Table
3 shows the performance of operating units during this period.
TABLE 1. 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
94
40
17
10
10
51
222
Total
controlled
capacity, MW*
35,931
17,386
10,035
7,643
5,630
30,726
107,351
Equivalent
scrubbed A
capacity, MW'
32,683
16,666
9,819
7,585
5,630
30,398
102,781
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).
The summation of the effective scrubbed flue gas in equivalent MW based
on the percent of flue gas scrubbed by the FGD system(s).
xii
-------
X
H-
1 1
TUJlxnl
Iftao)
Diinui
IJJOOI
Figure 1. Computerized data base structure diagram.
-------
TABLE 2. SUMMARY OF CHANGES OCTOBER - DECEMBER 1981
FGO status report
September 3171481
East Kentucky Power
J.K. Smith 1
Louisville Gas I Electric
HI 11 Creek 2
Hoosler Energy
Hero* 2
Total
Opej
3?-
»i
»i
94
it tonal
3,792"
350
441
32.683
Ui
cons
8-
-1
-1
40
ider
ruction
MM*
17.457
350
441
16.666
Contract
awarded
No.
16
*l
17
W
9.169
650
9.819
it
of
ft"
-1
10
tter
ntent
MM*
8.235
650
7.585
Requesting/
eval. bids
No.
10
10
MM*
5.630
5.630
Const
f
no.
51
51
tiering
60 .
nr
30.398
30.398
Ti
no.
222
222
tal ,
"•" k
102.781°
102.781
Equivalent scrubbed capacity.
This value was •odlfled slightly due'to • KM correction.
'-ontinued
-------
TABLE 3. PERFORMANCE OF OPERATIONAL UNITS
OCTOBER-DECEMBER 1981
Plant
Alabana Electric
Toablgbee 2
ToBhlgbee 3
Arizona electric
Power
Apache Z
Apache 3
Arizona Public
Service
Choi la 1
Choi la 2
Choi la 4
Four Corners 1
Four Corners 2
Four Comers 3
Basin Electric Power
La rani e Rl*er 1
la ramie River t
Big Rivers Electric
Green 1
Green 2
Central Illinois Light
Duck Creek 1
Central Illinois Public
Service
Newton 1
Cincinnati Gas I
Electric
East Bend 2
Colorado Ute Electric
Craig 1
Craig 2
Colunbus 1 Southern
Ohio Electric
Conesvllle 5
Coneirllle 6
FGD systea
capacity.
ma
179
i;g
98
98
119
?64
126
I7S
I7S
229
570
570
242
242
416
617
650
410
410
411
411
Flue gas
I scrubbed
70
70
50
SO
100
100
3)
100
100
100
100
100
100
100
100
100
100
90
90
100
100
FGD
capacity
on line
during
period
hV.°
179
179
98
98
570
570
242
242
416
617
650
410
410
411
411
No Information
for this
period. MM*
119
264
126
175
175
229
Shut down
throughout
P^od.
October 1981
Dependability Ic>e
AVI
17
97
100
96
100
100
75
76
0
100
14
100
100
ion
OCR
52
SB
100
98
96
98
96
0
14
99
0
0
RCL
52
SB
100
96
100
98
96
0
14
99
0
0
UTL
9
57
42
96
0
95
75
73
0
0
14
99
0
0
Hovenber 1981
Dependability Ic>(
AVI
41
99
65
100
100
100
-
96
63
31
98
80
21
27
27
OPR
79
76
64
100
61
98
95
87
79
69
BO
47
0
0
RCL
79
76
65
89
100
100
95
87
91
85
80
52
0
0
UTl
36
59
64
89
59
98
9S
45
26
69
80
21
0
0
Decc-twr 1981 , .
Dependability tc>e
A»L
100
96
100
100
99
100
80
100
84
69
84
Bf»
OPR
54
57
78
93
98
98
82
es
84
69
8?
R3
Rtl
54
52
100
too
97
98
83
100
84
70
86
93
UTL
54
52
78
75
98
87
69
82
84
68
n
66
X
(continued)
-------
TABLE 3 (continued)
Plant
Comnwealth Edison
Powerlon SI
Cooperative Power
Association
Coal Creek 1
Coal Creek 2
Delaarva Power 1 light
Delaware City 1
Delaware City 2
Delaware City 3
Duquesne Light
El rani 1-4
Phillips 1-6
Hoosler Energy
Heron 2
Indianapolis Power
1 Light
Petersburg 3
Kansas City Power
1 Light
Hawthorn 3
Hawthorn 4
La Cygne 1
Kansas Power 1 Light
Jeffrey 1
Jeffrey 2
Lawrence 4
Lawrence 5
Kentucky Utilities
Green River 1-3
Louisville Gas 1
Electric
Cane Run 4
Cane Run S
Cane Run 6
Hill Creek 1
HIM Creek 2
Hill Creek 3
Paddy's Run 6
Minnesota Power 1 Light
Clay Botwell 4
F6D sy steal
capacity.
HU»
4SO
321
327
60
60
60
510
408
441
532
to
90
874
540
490
125
420
64
188
200
299
3S8
350
427
72
47S
Flue gas
S scrubbed
100
60
60
100
100
100
100
100
90
too
100
100
100
75
70
100
100
100
100
100
100
100
100
too
100
85
FCO
capacity
on line
during
period
Hua.b
450
327
327
60
60
60
510
408
441
874
540
490
125
420
188
200
358
350
427
475
Ito Information
for this .
period. MT
532
90
90
Shut down
throughout
period,
MM'
64
299
72
October 1981 , .
Dependability Ic'e
AVL
30
100
78
95
85
51
100
65
91
100
40
41
100
100
OPR
54
76
57
100
86
77
59
98
93
ion
41
90
95
REL
71
100
86
94
83
98
93
100
41
90
100
UTL
0
15
76
23
100
78
77
59
35
0
65
58
0
40
41
0
95
Noveaber 1981 .
Dependability Ic'e
AVL
70
89
42
100
74
94
100
99
89
100
37
32
100
94
OPR
57
67
70
69
69
77
41
100
100
100
40
37
96
REL
70
89
89
100
72
92
100
100
40
37
100
UTL
47
67
70
89
42
77
41
72
0
99
57
0
37
31
0
73
December 1981 „
Dependability I
AVL
73
99
95
100
73
100
65
99
100
76
100
41
ion
100
OPR
60
67
08
99
95
60
49
100
99
29
75
41
90
RU
68
99
95
100
73
100
99
29
75
43
100
UTL
J2
45
67
59
99
95
60
49
0
65
99
0
76
100
41
0
90
(continued)
-------
TABLE 3 (continued)
Plant
Nlnnkota Power
Milton R. Young 2
Honongahela Power
Pleasants 1
Pleasants 2
Montana Power
Colstrlp 1
Col strip 2
Montana -Dakota
Utilities
Coyote 1
Nevada Power
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Northern Indiana Public
Service
DeanH. Mitchell 11
Northern States Power
Riverside 6-7
Sherburne 1
Sherbume 2
Pacific Power 1 Light
JlB Brldger 4
Pennsylvania Power
Bruce Mansfield 1
Bruce Mansfield 2
Bruce Mansfield 3
Publ Ic Service of New
Mexico
San Juan 1
San Juan 2
San Juan 3
Salt River Project
Coronado 1
Coronado 2
San Miguel Electric
San Hlguel 1
FGD lysten
capacity.
MM* '
185
668
668
360
360
440
125
125
125
115
110
740
740
S50
917
917
917
361
350
534
280
280
400
Flue gas
I scrubbed
42
100
100
100
100
100
100
100
100
99
100
100
100
100
100
100
100
100
100
100
80
80
inn
rcn
capacity
on line
during
period
185
360
360
125
125
125
740
740
917
917
917
361
350
534
280
280
400
Ho information
for this
period. MM* .
668
668
440
110
550
Shut down
throughout
period,
Hua
115
October 1981
Dependability Ic>*
AVL
100
98
98
0
100
100
100
100
100
100
98
99
100
65
98
OPR
100
99
99
0
100
100
96
62
84
REL
100
99
99
100
100
100
61
91
UTL
66
0
86
94
0
92
100
96
45
62
Hoveoter 1981
Dependability Xc>e
AVL
100
93
93
95
100
98
100
100
100
9B
94
100
100
93
94
OPR
98
78
100
98
0
100
100
95
71
90
DEL
99
61
100
98
100
100
100
90
93
UTL
89
9
47
98
0
95
100
Bl
59
69
December 1981
Dependability tc-e
AVI
100
97
96
100
95
99
100
100
100
99
95
100
99
95
ion
OPR
100
96
74
98
0
100
100
78
89
9?
REl
100
96
69
97
100
100
100
95
98
UTl
100
100
56
49
0
100
100
25
89
89
K"-
H-
(continued)
-------
TABLE 3 (continued)
Plint
Sikeston Board or
Municipal Utilities
SUeston 1
South Carolina Public
Service
Ulnyah 2
Ulnyih 3
Ulnyah 4
South Mississippi
Electric Power
R.D. Morrow. Sr. 1
R.O. Morrow. Sr. 2
Southern Illinois Power
Marlon 4
Southern Indiana Gas
1 Electric
A.B. Brown 1
Springfield City
Utilities
Southwest I
Springfield Miter.
Light I Power
Dal loan 3
St. Joe Zinc
C.f We* ton 1
Tennessee Valley Author
Shaxnee IDA
Shaxnee 108
Widows Creek 7
UidOHS Creek 8
Texas Power I light
SandOM 4
Texas Utiltllei
Martin lake 1
Martin Lake 2
Martin lake 3
Honllcello 3
TGO system
capacity,
HW»
23S
140
280
280
124
124
173
265
194
IBS
60
ty
10
10
S7s
650
382
595
595
595
800
Flue gas
t scrubbed
100
SO
100
100
62
62
100
100
100
90
100
d
»/*d
N/A"
100
100
70
75
75
75
100
fGO
capacity
on line
during
period
HW'.b
23S
140
?BO
280
124
124
26S
194
IBS
60
S75
550
Ho Information
for this ,
period. HH°
173
10
10
382
S9S
S9S
595
800
Shut down
throughout
period,
HMa
October 1981 , .
Dependability T '
AVL
32
96
75
100
98
47
94
12
OPR
71
96
99
100
94
87
68
12
DEL
72
97
99
100
94
98
84
12
UTL
30
96
72
100
84
45
S3
12
November 1981
Dependability t '
AVL
82
96
52
100
32
93
0
55
OPR
88
94
S3
99
99
91
SS
HI
88
95
54
99
99
91
SS
UTl
82
84
52
98
32
91
0
SS
December 1981
Dependability I '
AVL
81
97
100
100
98
78
1
OPR
82
97
100
99
63
82
1
1
RCL
81
97
100
99
63
96
1
UTl
55
97
100
94
38
66
•
(continued)
-------
TABLE 3 (continued)
Plant
Utah POMCT i Light
Hunter 1
Hunter 2
Huntlngton 1
Mtughton 3
TOTAL
FGO systcn
capacity.
HU*
160
360
366
330
32.683
Flue gas
I scrubbed
90
90
as
100
FCD
capacity
on line
during
period
Hwa.b
23.371
Mo Information
for this .
period. HH
360
360
366
330
8,81?
Shut down
throughout
period.
HW>
550
October 1981 , .
Dependability tc>e
AVL
OPR
•
DEL
OIL
November 1981
Dependability Xc>e
AVL
OPR
DEL
UTL
Decenber 1981
Dependability Xc>*
AVL
OPR
REL
UTL
X
H-
X
e Equivalent scrubbed capacity.
b This category Includes the flue gas capacity being handled by the FCO systw it leatt part of the tie* during the report period.
c The percent figures 11tied are average values fcr all systes) scrubbing trains during the period.
d Flue gat X scrubbed for prototype and demonstration units Is not applicable unless the systesi Is designed to bring a unit Into compliance irith
standard.
a Availability, operablllty, reliability, and utllliatlen as defined In Appendla C of this report.
esjlstlon
-------
Current projections indicate that the total power generating
capacity of the U.S. electric utility industry will be approxi-
mately 831 GW by the end of 1999. (This value reflects the
annual loss resulting from the retirement of older units, which
is considered to be 0.4% of the average generating capacity at
the end of each year.lrZ) Approximately 373 GW or 45% of the
1999 total will come from coal-fired units. The distribution pf
power generation sources, both present (December 1980) and future
(December 1999) is shown in Table 4.1
TABLE 4. POWER GENERATION SOURCES: PRESENT AND FUTURE
December 1980
December 1999
Coal
41%
45%
Nuclear
10%
15%
Oil
24%
19%
Hydro
12%
11%
Gas
12%
9%
Other
n
1%
GW (total)
616
831
Based on the known commitments to FGD by utilities as presented
in Table 1, the percentage of electrical generating capacity
controlled by FGD for both the present (December 1981) and the
future (December 1999) is shown in Table 5.
TABLE 5. FGD CONTROLLED GENERATING CAPACITY: PRESENT AND FUTURE
December 1981*
December 1999
Coal -fired generating
capacity controlled
by FGD, %
14.2
28.7
Total generating
capacity controlled
by FGD, %
5.8
12.9
The number of committed FGD systems is as of December 1981; however, the
figure used for the total generating capacity and coal-fired generating
capacity is based on the available December 1980 figures.
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 50 to 60 systems repre-
senting approximately 29,000 to 31,000 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, Table 6 gives a current (December 1981) and a projected
(December 1999) breakdown of throwaway product systems versus
salable product systems as a percent of the total known commit-
ments to FGD as of the end of the fourth quarter 1981:
x x
-------
TABLE 6. SUMMARY OF FGD SYSTEMS BY PROCESS
Throwaway product process
°Wet systems
L1me
Limestone
Dual alkali
Sodium carbonate
NA*
°Dry systems
Lime
Lime/Sodium carbonate
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
We 11 man Lord Elemental sulfur
Process undecided
Total
Percent of total MW
December
1981
38.1
47.8
3.6
3.8
-
0.3
-
1.3
_
0.2
.
-
-
-
2.3
2.6
-
100.0
December
1999
December
1999
( Projected )|° ( Norma 1 1 zed )c
13.0
31.5
1.2
2.7
7.6
4.8
0.1
-
0.1
0.1
0.1
0.2
0.7
1.0
0.5
0.2
36.2
100.0
23.1
56.0
2.1
4.8
-
8.5
0.2
-
0.2
0.2
0.2
0.4
1.2
1.8
0.9
0.4
-
100.0
- Not available (these systems are committed to a throwaway product
process; however, the actual process is unknown at this time).
These values are based solely on information actually reported by utilities.
This breakdown could change significantly as specific processes are chosen
for plants now in the very early planning stages of development.
cThe effect of those systems listed as "NA" and "Process undecided" is
removed.
HIGHLIGHTS: OCTOBER - DECEMBER 1981
The following paragraphs highlight FGD system developments during
the fourth quarter 1981.
xxi
-------
Alabama Electric announced that the Tombigbee 3 FGD system
achieved availabilities of 97%, 99%, and 96% for the months of
October, November, and December, respectively. No major FGD
related problems were noted during the three-month period.
Arizona Electric Power reported that the Apache 3 FGD system
achieved 96% and 100% availabilities for the months of October
and November, respectively. Information for December was not
available for this report.
Basin Electric Power reported availabilities of 100%, for the
Laramie River 1 and 2 FGD systems during the months of October,
November and December. No major FGD-related problems were en-
countered during the fourth quarter.
Big Rivers Electric reported that the Green 1 FGD system achieved
96% and 99% availabilities for the months of November and Decem-
ber, respectively. Operations at the beginning of the fourth
quarter were restricted due to piping and damper problems.
The Newton 1 FGD system of Central Illinois Public Service
achieved availabilities of 100%, 98%, and 100% for the months of
October, November and December. No major FGD-related problems
were encountered during the fourth quarter.
Delmarva Power & Light announced that the FGD system installed on
Delaware 2 achieved availabilities of 100%, 89%, and 99% during
the fourth quarter. Some ESP and presaturator problems were
noted during the three-month period.
Duquesne Light reported that the FGD system installed at Elrama
achieved 95%, 100%, and 100% availabilities for the months of
October, November, and December, respectively. During the
period the recycle pumps of one of the five modules were replaced.
Due to the spare capacity, the system operation was not hindered.
East Kentucky Power announced that a contract has been awarded to
Babcock & Wilcox for the installation of a lime FGD system to
control S02 emissions from J.K. Smith 1. This new unit will be
rated at 650 MW (gross) and will fire coal with an average
sulfur content of 1.5%. FGD systems startup is scheduled for
August 1987.
The Merom 2 FGD system of Hoosier Energy began initial operations
on December 30. Merom 2 is rated at 490 MW (gross) and fires
coal with an average sulfur content of 3.50%. The limestone FGD
system, which was supplied by Mitsubishi Heavy Industries, con-
sists of a cold-side ESP upstream of a grid tower absorber. The
scrubbed gas is heated by a flue gas bypass before exiting a 700-
foot stack.
xxii
-------
Louisville Gas & Electric reported availabilities of 93%, 89%,
and 99% for the Cane Run 5 FGD system during the months of Octo-
ber, November, and December, respectively. No major FGD-related
problems were encountered during the three-month period.
Initial operations of the Mill Creek 2 FGD system of Louisville
Gas & Electric began during December. Mill Creek 2 is rated at
350 MW (gross) and fires coal with an average sulfur content of
3.75%. The lime FGD system, which was supplied by Combustion
Engineering, consists of two absorber modules. Two hot side
ESP's are included for primary particle removal. Availability of
the FGD system during the month of December was 100%.
Minnesota Power & Light reported availabilities of 100%, 94%, and
100% for the Clay Boswell 4 FGD system during the months of
October, November, and December, respectively. No major FGD-
related problems were encountered during this period.
Minnkota Power announced that the FGD system installed on Milton
R. Young 2 achieved 100% availability for the months of October,
November and December. No FGD-related problems were reported for
the three-month period.
Nevada Power reported that the Reid Gardner 1 FGD system achieved
95% and 100% availabilities for the months of November and Decem-
ber, respectively. The system was not available during October
due to scheduled scrubber/boiler overhaul. The Reid Gardner 2
FGD system achieved 100%, 100% and 95% availabilities for the
same three-month period. The Reid Gardner 3 FGD system achieved
availabilities of 100%, 98%, and 99% during the three-months with
only minor problems being encountered.
The Sherburne 1 -and 2 FGD systems of Northern States Power
achieved 100% availability during the months of October, Novem-
ber, and December* No FGD-related problems were encountered
during the three-month period.
Pennsylvania Power reported availabilities of 100%, 98%, and 99%
for the Bruce Mansfield 1 FGD system during the months of October,
November, and December, respectively. Bruce Mansfield 2 achieved
availabilities of 98%, 94%, and 95% during the same three-month
period. Bruce Mansfield 3 achieved availabilities of 99%, 100%,
and 100% during the same period. Some minor ID fan problems and
general maintenance were encountered.
Public Service Company of New Mexico reported that the San Juan 1
FGD system achieved availabilities of 100%, 100%, and 97% during
the months of October, November, and December, respectively. San
Juan 2 achieved 93% and 95% availabilities for the months of No-
vember and December, respectively. Low availability in October
resulted from necessary mist eliminator maintenance. San Juan 3
achieved availabilities of 98%, 94%, and 100% during the same
three-month period. Operation of an additional module on San
Juan 3 commenced during the period.
xxiii
-------
South Carolina Public Service reported that the Winyah 3 FGD
system achieved availabilities of 96%, 96%, and 97% for the
months of October, November, and December, respectively. Some
absorber pump problems were reported during the period.
Southern Indiana Gas & Electric reported availabilities of 98%,
93%, and 98% for the A.B. Brown 1 FGD system during the months
of October, November, and December, respectively. Some damper
problems were noted throughout the three-month period.
South Mississippi Electric Power reported availabilities of 100%
for the R.D. Morrow 1 FGD system during the months of November
and December. Low availability for October was due to a scrubber
duct inspection.
References
1. 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, 1980 Annual. Publ. No. DOE/EIA-0095
(80) .
2. Herman, Ira M. New Generating Capacity; When, Where, and
by Whom. Power Engineering 85(4)72. April 1981.
xxiv
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 1
SUMMARY LIST OF FGO SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC
TOMSIGBEE
TOM3IGBEE
ARIZONA ELECTRIC POWER
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER
ANTELOPE VALLEY
ANTELOPE VALLEY
LARAI1IE RIVER
LARAMIE RIVER
LARAMIE RIVER
BIG RIVERS ELECTRIC
O.B. WILSON
D.B. WILSON
GREEN
GREEN
CAJUN ELECTRIC POWER
CHICOT
CHICOT
CHICOT
CHICOT
OXBOW
OXBOW
CENTRAL ILLINOIS LIGHT
OUCK CREEK
DUCK CREEK
UNIT NO.
2
3
2
3
1
2
4
1
2
3
4
5
3
1
1
2
1
2
3
1
2
1
2
1
2
3
4
1
2
1
2
UNIT LOCATION
LEROY
LEROY
COCHISE
COCHISE
JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIHGTON
FARMINGTON
FARMINGTON
FARMINGTON
FARMINGTON
MOBERLY
MILLVILLE
BEULAH
BEULAH
WHEATLAND
HHEATLAND
WHEATLAND
CENTERTOUN
CENTERTOMN
SEBREE
SEBREE
COUSHATTA
COUSHATTA
COUSHATTA
COUSHATTA
DE SOTQ PARISH
COSHATTA
CANTON
CANTON
ALABAMA
ALABAMA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
HEW MEXICO
NEW MEXICO
NEW MEXICO
MISSOURI
NEW JERSEY
NORTH DAKOTA
NORTH DAKOTA
WYOMING
WYOMING
WYOMING
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
ILLINOIS
ILLINOIS
START-UP
DATE
9/79
6/79
8/73
6/79
10/73
4/78
3/81
11/79
11/79
11/7°
12/84
12/84
1/82
1/88
10/83
10/85
7/80
7/81
11/82
7/84
O/ 0
12/79
11/80
0/86
0/88
0/92
0/94
0/85
0/85
7/76
1/87
STATUS
1
1
1
1
1
1
1
1
1
1
2
2
2
6
2
2
1
1
2
2
3
1
1
6
6
6
6
5
6
1
6
REG
CLASS
B
3
D
D
C
C
C
C
C
C
C
C
A
C
D
C
C
C
C
A
A
B
B
A
A
A
A
A
A
B
A
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
CENTRAL MAINE POWER
SEARS ISLAND 1
NEWTON
ILLINOIS
PENOBSCOT BAY MAINE
9/79
11/89
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 SI STEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPSC6/79)
B. FEDERAL NSPSt12/71)
C. STANDARD(S) MOPE STRINGENT THAN NSPS(6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSI12/71) BUT NOT MORE STRINGENT THAN NSFS(6/79)
E. STANDARO(S) EQUAL TO OR LESS STRINGENT THAN HSPSdZ/71)
-------
EPA UTILITY FGD SURVEY: CCTCSER - DECEMBER 1981
SECTION 1
SUMMARY LIST OF F60 SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
PES
STATUS CLASS
CENTRAL POWER & LIGHT
COLETO CREEK
CINCINNATI GAS
EAST BEND
EAST BEND
* ELECTRIC
COLORADO UTE ELECTRIC
CRAIG
CRAIG
CRAIG
COMMONWEALTH EDISON
POWERTON
OELMARVA POWER ft LIGHT
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
VIENNA
DESERET GEN t TRANS
BONANZA
BONANZA
DUQUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER
J.K. SMITH
SPURLOCK
FLORIDA POWER £ LIGHT
MARTIN
MARTIN
GENERAL PUBLIC UTILITIES
COAL
COAL
COAL
COAL
SEUARD
COLUMBUS I SOUTHERN OHIO ELEC
COHESVILLE 5
COHESVILLE 6
POSTON 5
POSTOM 6
51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COAL CREEK 2
1-4
1-6
FANNIN
RABBITHASH
RABBITHASH
CRAIG
CRAIG
CRAIG
CONESVILLE
COMESVILLE
NELSOMVILLE
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
WINCHESTER
MAYSVILLE
MARTIN COUNTY
MARTIN COUNTY
UTAH
UTAH
PENNSYLVANIA
PENNSYLVANIA
KENTUCKY
KENTUCKY
FLORIDA
FLORIDA
1
2
3
4
7
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
EAST WHEATFI
UNDECIDED
UNDECIDED
UNDECIDED
UNDECIDED
ELOPENNSYLVAI
9/92
0/83
3/81
10/80
12/79
4/83
1/77
6/7S
8/85
0/89
4/80
7/79
7/80
5/80
5/80
5/80
5/90
9/84
0/88
10/75
7/73
8/87
1/83
0
0
A
B
0/87
0/89
5/
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 1
SUMMARY LIST OF FC-D SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP 3ES
DATE STATUS CLASS
GRAND HAVEH BRD OF LIGHT t PUR
J.B. SIMS 3
GRAND HAVEN
MICHIGAN
HOOSIER ENERGY
MEKOM
MERCM
HOUSTON LIGHTING & POWER
LIMESTONE
LIMESTONE
M.A. PARISH
INDIANAPOLIS POWER t LIGHT
PATRIOT
PATRIOT
PATPIOT
PETERSBURG
PETERSBURG
ICWA ELECTRIC LIGHT &
GUTHRIE CO.
PUR
JACKSONVILLE ELEC AUTHORITY
ST.JOHNS RIVER PUR PARK
ST.JOHNS RIVER PUR PARK
KANSAS CITY POWER t LIGHT
HAUTHCRN
HAUTKCRN
LA CYGNE
1
2
6
KANSAS POWER & LIGHT
JEFFREY 1
JEFFREY Z
LAURENCE 4
LAURENCE 5
KENTUCKY UTILITIES
GREEN RIVER 1-3
HANCOCK 1
HANCOCK 2
LAKELAND UTILITIES
MCINTOSH 3
LANSING BOARD OF MATER £ LIGHT
ERICKSON 2
LOS ANGELES DEPT OF HTR & PUR
INTERMOUNTAIN 1
INTERMOUNTAIN 2
INTERMOUNTAIN 3
INTERMOUMTAIN 4
MEPOM
MEROM
JEWETT
JEUETT
BOOTH
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
INDIANA
INDIANA
TEXAS
TEXAS
TEXAS
INDIANA
INDIANA
INDIANA
INDIANA
INDIANA
PANORA
IOWA
EAST PORT SITE FLORIDA
EAST PORT SITE FLORIDA
KANSAS CITY
KANSAS CITY
LA CYGIIE
WAMEGO
WAMEGO
LAURENCE
LAURENCE
MISSOURI
MISSOURI
KANSAS
KANSAS
KANSAS
KANSAS
KANSAS
CENTRAL CITY KENTUCKY
HAUESVILLE KENTUCKY
HAUESVILLE KENTUCKY
LAKELAND
FLORIDA
DELTA TOWNSHIP MICHIGAN
DELTA
DELTA
DELTA
DELTA
UTAH
UTAH
UTAH
UTAH
1/83
5/82
12/81
12/86
12/87
11/82
0/87
O/ 0
O/ 0
12/77
10/84
11/87
12/85
6/87
11/72
8/72
2/73
8/78
1/60
1/77
4/78
9/75
4/89
4/94
1/82
1/87
0/66
0/87
0/88
0/89
A
A
A
C
C
C
3
3
A
A
E
A
A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
4. PUNNED - LETTER OF INTENT SIGNED
5. PLANNED - REQUESTING/EVALUATING BIOS
6. PLANNED - CONSIDERING ONLY FGO SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSC12/71)
C. STANDARD!S) MORE STRINGENT THAN NSPSC6/79)
0. STANDARD(S) MORE STRINGENT THAN NSPSt12/71) BUT NOT MORE STRINGENT THAN NSPSC6/79)
E. STANDARD!S) EQUAL TO OR LESS STRINGENT THAN NSPSt12/71)
-------
EPA UTILITY F60 SURVEY: OCTC3ER - DECEMBER 1981
SECTION 1
SUMMARY LIST OF F60 SYSTEMS
COMPANY NAME/
UNIT NAME
LOUISVILLE GAS & ELECTRIC
CANE RUM
CANE RUN
CANE RUN
MILL CREEK
MILL CREEK
MILL CREEK
MILL CREEK
PACOY'S RUN
THIMBLE COUNTY
TRIMDLE COUNTY
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
MARCUETTE BOARD OF LIGHT t PMR
SHIR AS
MICHIGAN SO CENTRAL PUR AGENCY
PROJECT
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
ARKANSAS LIGNITE
UN ASSIGNED
UNASSIGNED
UILTCN
WILTON
MINNESOTA POWER S LIGHT
CLAY BOSHELL
UNIT NO.
4
5
6
1
2
3
4
6
1
2
3
3
1
5
6
1
2
1
2
4
UNIT LOCATION
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
LOUISVILLE
BEDFORD
BEDFORD
LA GRANGE
HAHQUETTE
LITCHFIELD
CONVENT
CONVENT
COHASSET
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
TEXAS
MICHIGAN
MICHIGAN
ARKANSAS
ARKANSAS
LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
MINNESOTA
START-UP
DATE
8/76
12/77
4/79
12/30
12/81
6/78
6/82
4/73
7/85
7/89
0/83
9/82
6/82
0/90
0/92
0/89
0/93
0/83
0/91
4/80
STATUS
1
1
1
1
1
1
2
1
5
5
6
2
2
4
4
4
4
4
4
1
=513
CLASS
0
D
D
E
E
D
3
E
C
C
A
A
A
A
A
A
A
A
A
A
MINNKOTA POWER
MILTON R. YOUN5 2
MCN'CMGAHELA POWER
PLEASANTS 1
PLEASANTS 2
MONTANA POWER
COLSTRIP 1
COLSTRIP 2
COLSTRIP 3
COLSTRIP 4
MONTANA-DAKOTA UTILITIES
COYOTE 1
MUSCATINE POWER i WATER
MUSCATINE 9
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
CENTER
NORTH DAKOTA
WILLOW ISLAND WEST VIRGINIA
WILLOW ISLAND WEST VIRGINIA
COLSTRIP
COLSTRIP
COLSTRIP
COLSTRIP
BEULAH
MUSCATINE
SARGENT
MONTANA
MONTANA
MONTANA
MONTANA
NORTH DAKOTA
IOWA
NEBRASKA
9/77
3/79
10/80
9/75
5/76
10/83
0/84
4/81
9/82
3/92
B
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 FGO SYSTEMS; ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSt12/71)
C. STANOARD(S) MORE STRINGENT THAN NSPSI6/79)
0. STANDARD(S) MORE STRINGENT THAN NSPS(12/711 BUT NOT MORE STRINGENT THAN NSPSt6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSI12/71)
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY HAME/
UNIT NAME
NEVADA POWER
HACRY ALLEN
HARRY ALLEN
HARRY ALLEN
HARRY ALLEN
REID GARDNER
REID GARDNER
REID GARDNER
REID GARDNER
UNIT NO.
1
2
3
4
1
2
3
4
UNIT LOCATION
US VEGAS
LAS VEGAS
LAS VEGAS
LAS VEGAS
MOAPA
MOAPA
MOAPA
MOAPA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
START-UP
DATE
6/86
6/67
6/38
6/69
3/74
4/74
6/76
4/83
STATUS
6
6
6
6
1
1
1
4
PEG
CLASS
A
A
A
A
B
3
3
A
NEW YORK STATE ELEC & GAS
SOMERSET
NIAGARA MOHAWK POWER
CHARLES R. HUNTLEY
NORTHERN INDIANA PL'S SERVICE
DEAN H. MITCHELL
SCHAHFER
SCHAHFER '
NORTHERN STATES POWER
METRO COAL
RIVERSIDE
SHEREURNE
SHERBURNE
SHERBURNE
PACIFIC GAS &
MOHTEZUMA
MONTEZUMA
ELECTRIC
PACIFIC POWER & LIGHT
JIM BRIDGER
JIM BRIDGER
JIM ERIDGER
JIM BRIDGER
JIM BRIDGER
PENNSYLVANIA POWER
BRUCE MANSFIELD
BRUCE MANSFIELD
ERUCE MANSFIELD
PHILADELPHIA ELECTRIC
CBOM3Y
EDDYSTONE
EDDYSTONE
PLAINS ELECTRIC GST
PLAINS ESCALANTE
PLATTE RIVER POWER AUTHORITY
RAWHIDE
66
11
17
18
1
6-7
1
1
2
2A
3
4
SOMERSET
BUFFALO
NEW YORK
NEW YORK
6/84
4/82
GARY
WHEATFIELD
WHEATFIELO
UNDECIDED
MINNEAPOLIS
BECKER
BECKER
BECKER
COLLINSVILLE
COLLINSVILLE
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
ROCK SPRINGS
SHIPPINGPORT
SHIPPINGPORT
SHIPPINGPORT
PHOENIXVILLE
EDDYSTONE
EDDYSTONE
INDIANA
INDIANA
INDIANA
UNDECIDED
MINNESOTA
MINNESOTA
MINNESOTA
MINNESOTA
CALIFORNIA
CALIFORNIA
WYOMING
WYOMING
WYOMING
WYOMING
WYOMING
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
PENNSYLVANIA
7/76
6/83
6/85
0/90
11/80
3/76
3/77
0/85
6/93
6/94
0/83
0/90
1/32
0/86
9/79
12/75
7/77
6/80
5/83
12/82
12/82
PREWITT
FT. COLLINS
NEW MEXICO
COLORADO
12/83
12/83
A
E
0
D
C
c
C
A
A
A
A
D
B
C
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 FGO SYSTEMS! ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSt12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
0. STANOARD(S) MORE STRINGENT THAN NSPSI12/71) BUT NOT MORE STRINGENT THAN NSPSt6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSt 12/71)
-------
ErA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
UNIT NO. UNIT LOCATION
START-UP
DATE
RES
STATUS CLASS
PUBLIC SERVICE INDIANA
GIBSON 5
PUSLIC SERVICE OF NEW MEXICO
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
SAN JUAN 4
PMR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORCNADO
COHONADO
CCRCNAOO
SAN MIGUEL ELECTRIC
SAN MIGUEL
SEMINOLE ELECTRIC
SEMINOLE
SEMINOLE
SIERRA PACIFIC POWER
VALMY
SIKESTCN BRD OF MUNICIPAL UTIL
SIKESTCH
SOUTH CAROLINA PUBLIC SERVICE
CROSS
CROSS
UINYAH
UINYAH
WINYAH
SOUTH MISSISSIPPI ELEC PUR
R.D. MORROW, SR.
R.D. MORPOW, SR.
SOUTHERN ILLINOIS POWER
MARION
SOUTHERN INDIANA GAS £
A.3. BPOWN
A.B. BROWN
ELEC
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
DOLET HILLS
HENRY W. PIRKEY
SOYLAND POWER
SOYLAND
PRINCETON
MATERFLOW
MATERFLOW
WATERFLOW
MATERFLOW
NEW YORK
ST. JOHNS
ST. JOHNS
ST. JOHNS
SAN MIGUEL
PALATKA
PALATKA
INDIANA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW YORK
ARIZONA
ARIZONA
ARIZONA
TEXAS
FLORIDA
FLORIDA
8/82
4/78
3/73
12/79
6/82
4/87
11/79
7/80
0/89
8/81
3/83
1/85
MANSFIELD
MANSFIELD
HALLSVILLE
UNDECIDED
LOUISIANA
LOUISIANA
TEXAS
ILLINOIS
3/86
0/83
12/84
6/87
A
A
2
1
1
2
2
3
4
1
2
4
1
2
VALMY
SIKESTON
CROSS
CROSS
GEORGETOWN
GEORGETOWN
GEORGETOWN
HAITI ESBUHG
HATTIESBURG
MARION
WEST FRANKLIN
WEST FRANKLIN
NEVADA
MISSOURI
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
ILLINOIS
INDIANA
INDIANA
8/84
6/81
5/38
11/83
7/77
5/80
7/81
8/73
6/79
5/79
3/79
i/as
7
1
3
2
1
1
1
1
1
1
1
5
A
B
A
A
B
B
A
B
B
B
B
A
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTPACT AWARDED
4. PUNNED - LETTER OF INTENT SIGNED
5. PUNNED - REQUESTING/EVALUATING BIDS
6. PLANNED - CONSIDERING ONLY FGO SYSTEMS
7. PLANNED - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHG3S
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPS(12/71)
C. STANDARD1S) MOPE STRINGENT THAN NSPSC6/79)
D. STANDARD(S) MORE STRINGENT THAN NSPSC12/71) BUT NOT MORE STRINGENT THAN NSPSJ6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSt12/71)
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEH3ER 1<=31
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY NAME/
UNIT NAME
SPRINGFIELD CITY UTILITIES
SOUTHWEST
SPPIN5FIELD MATER. LIGHT & PUR
OALLMAN
ST. JOE ZINC
G.F. WEATON
SUNFLOWER ELECTRIC
HOLCOMB
TAMPA ELECTRIC
BIG BEND
TENNESSEE VALLEY AUTHORITY
PARADISE
PARADISE
SHAKNEE
SHAKNEE
WIDOWS CREEK
WIDOWS CREEK
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK
TEXAS POWER & LIGHT
SANOOH
TWIN OAKS
TWIN OAKS
TEXAS UTILITIES
FOREST GROVE
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MAPTIN LAKE
MILL CREEK
MILL CREEK
MONTICELLO
TUCSON ELECTRIC POWER
SPRIMGERVILLE
SPRINGERVILLE
UNITED POWER ASSOCIATION
STANTON
UTAH POWER t LIGHT
HUNTER
HUNTER
HUNTER
HUNTER
HUNTINGTON
NAUGHTON
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSt 12/71)
C. STAMDARO(S) MORE STRINGENT
0. STANOARO(S) MORE STRINGENT
UNIT
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
1
3
4.
5.
6.
7.
THAN
THAN
NO. UNIT LOCATION
SPRINGFIELD
SPRINGFIELD
MONACA
HOLCOMB
TAMPA
PARADISE
PARADISE
PAOUCAH
PAOUCAH
BRIDGEPORT
BRIDGEPORT
CARLOS
ROCKDALE
BREMOND
BREHONO
ATHENS
TATUM
TATUM
TATUM
TATUM
HENDERSON
HENDERSON
MT. PLEASANT
SPRINGERVILLE
SPRINGERVILLE
STANTON
CASTLE DALE
CASTLE DALE
CASTLE DALE
CASTLE DALE
PRICE
KEMMERER
MISSOURI
ILLINOIS
PENNSYLVANIA
KANSAS
FLORIDA
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
ARIZONA
ARIZONA
NORTH DAKOTA
UTAH
UTAH
UTAH
UTAH
UTAH
WYOMING
START-UP
DATE
ft/77
is/eo
11/79
9/83
3/85
0/83
0/83
4/72
4/72
3/61
5/77
10/82
12/80
8/85
8/87
0/87
4/77
5/78
2/79
0/89
0/87
0/88
5/78
2/85
3/87
6/82
5/79
6/80
6/83
6/85
5/78
9/81
STATUS
1
1
1
2
3
2
*»
1
1
1
1
2
1
3
3
5
1
1
1
3
6
6
1
3
3
2
1
1
2
2
1
1
= ES
CLASS
3
B
B
A
A
E
E
E
£
E
E
A
3
A
A
A
B
B
3
A
A
A
B
B
3
A
B
3
A
A
B
C
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTING/EVALUATING BIDS
PLANNED - CONSIDERING ONLY FGD SYSTEMS
PLANNED - CONSIDERING FGD SYSTEMS!
NSPSC6/79)
NSPSJ 12/71) BUT NOT MORE STRINGENT
ALSO ALTERNATIVE
METHODS
THAN NSPSI 6/79)
E. STANOARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSt 12/71)
-------
EPA UTILITY FC-D SUSVEY: CCTC3ER - CECEKBER 1981
SECTION 1
SUMMARY LIST OF FGD SYSTEMS
COMPANY Hi '£/
UNIT N- =
UNIT NO. UNIT LOCATION
START-UP
DATE
REG
STATUS CLASS
WASHINGTON HVTER POWER
C3ESTCN COAL
C=ESTCN COAL
CRESTCN COAL
CRESTCN COAL
WEST PENN POWER
MITCHELL
WEST TEXAS UTILITIES
OKLAUNION
OKLAUNION
33
CRESTON
CRESTON
CRESTON
CRESTON
COURTNEY
OKLAUNION
OKLAUNION
WASHINGTON
WASHINGTON
WASHINGTON
WASHINGTON
PENNSYLVANIA
TEXAS
TEXAS
0/87
0/87
0/87
0/87
8/82
12/86
0/90
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 FGO SYSTEMS
7. PLANNED - CONSIDERING FGO SYSTEMS! ALSO ALTERNATIVE METHODS
A. FEDERAL NSPS(6/79)
B. FEDERAL NSPSI12/71)
C. STANDARD(S) MORE STRINGENT THAN NSPSC6/79)
0. STANDARD(S) MORE STRINGENT THAN NSPSC12/71) BUT HOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSI12/71)
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1«81
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ALABAMA ELECTRIC
TCMBIGBEE
2
NEW 255 MM (CROSS)
179 MM (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
FEA30DY PROCESS SYSTEMS
EHE=GY CONSUMPTION: s.ix
STATUS 1 STARTUP 9/78
TOMBIGBEE Z OF ALABAMA ELECTRIC COOP IS A PULVERIZED COAL BOILER LOCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLCW Or =53,000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFU? CONTENT OF 1.15X AND
AN AVERAGE HEAT CCNTENT OF 11,500 BTU/LB. THE UNIT S02 EMMISSIGM LIMITA-
TION VALUE IS 1.2 LB/MM3TU. PRIMARY PARTICULATE MATTER CCNTROL IS P.'CVID-
ED BY A HOT SIDE ESP. THE S02 REMOVAL EQUIPMENT CONSISTS OF TW3 SFPAf
TOWERS SUPPLIED BY PEABOOY PROCESS SI STEMS WHICH UTILIZE A LIMESTONE REA-
GENT. A CHEVRON MIST ELIMINATOR IS INCLUDED FOR EACH TCXcS AND THE FLU:
GAS IS REHEATED WITH BYPASSED GAS BEFORE BEING VENTED TO A «0 FC2T ACID-
BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN UATER LOOP MODE AND
SPENT ABSORBENT IS DISPOSED OF IN AN ON-SITE LINED POND.
ALABAMA ELECTRIC
TOMBIGBEE
3
NEW 255 MM (GROSS)
179 MM (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 LCCATED
IN LEROY, ALABAMA. THE BOILER GENERATES A MAXIMUM FLUE GAS FLCH Or 953.000
ACFM AND BURNS BITUMINOUS COAL WITH AN AVERAGE SULFUR CCNTENT OF 1.15X AMD
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB. THE UNIT S02 EMISSION LIMITATION
VALUE IS 1.2 LB/MMBTU. PRIMARY PARTICULATE CCNTROL IS PROVIDED BY A HOT
SIDE ESP. THE SOS REMOVAL EQUIPMENT CONSISTS OF TWO SPRAY TONERS SUPPLIED
BY PEABCOY 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 ERICK LINED
STACK. THE SYSTEM OPERATES IN AN OPEN MATER LOOP MODE. AND SPENT ABSORBENT
IS DISPOSED IN AN ON-SITE LINED POND.
ARIZONA ELECTRIC POWER
APACHE
2
NEW 195 MM (GROSS)
98 MM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.ix
STATUS 1 STARTUP 8/78
APACHE 2 OF ARIZONA ELECTRIC POMER COOP IS LOCATED IN COCHISE, ARIZONA AND
IS A DRY BOTTOM PULVERIZED COAL FIRED UNIT WITH A FLUE GAS FLOM OF 735,000
ACFM. BITUMINOUS COAL WITH A HEATING VALUE OF 10,000 BTU/LB, A SULFUR CCN-
TENT OP 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 RESEARCH-COTTRELL PACKED TOWERS EMPLOYING LIMESTONE
ABSORBENT AND HAVING A DESIGN S02 REMOVAL OF 65X. MIST ELINIMATICN
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 MATER LOOP MODE AND WASTE MATERIAL IS DISPOSED OF IN OFF-SITE
SLUDGE PONDS. OPERATIONS COMMENCED IN AUGUST 1978.
ARIZONA ELECTRIC POMER
APACHE
3
NEM 195 MM (GROSS)
98 MM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.1X
STATUS 1 STARTUP 6/79
APACHE 3 OF ARIZONA ELECTRIC POMER COOP IS A DRY BOTTOM, PULVERIZED COAL
FIRED UNIT IN COCHISE, ARIZONA. LOM (0.55X1 SULFUR BITUMINOUS COAL WITH AH
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 TWD
RESEARCH COTTRELL PACKED TOWERS. WHERE LIMESTONE IS USED TO REMOVE 85X OF
THE S02. THE GAS EXITS A HORIZONTAL CHEVRON MIST ELIMINATOR INTO ITS OHM
CEILCOTE LINED FLUE IN THE 400 FOOT STACK IT SHARES WITH UNIT 2. THE FGO
SYSTEM 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 MITH 20 YEARS EXPECTED LIFESPAN. TUO ADDITIONAL PONDS ARE
PLANNED, MHICH MOULD ADO ANOTHER 20 YEARS OF DISPOSAL CAPACITY.
ARIZONA PUBLIC SERVICE
CHOLLA
1
RETROFIT 119 MM (GROSS)
119 MM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENEPGY CONSUMPTION: 3.4X
STATUS 1 STARTUP 10/73
ARIZONA PUBLIC SERVICE'S CHOLLA 1 IS LOCATED IN JOSEPH CITY, ARIZONA AMD
IS A TANGENTIALLY FIRED, MET BOTTOM PULVERIZED COAL UNIT. IT IS FUELED BY
BITUMINOUS COAL THAT HAS A SULFUR CONTENT OF 0.5X AND A KEATINS VALUE OF
10,150 BTU/LB. PARTICULATE MATTER IS CONTROLLED BY TWO FLOODED DISC SCRUB-
BERS. THE FGO SYSTEM STARTED UP IN OCT03ER, 1973 AND IS MCW OPERATIONAL.
502 IS CONTROLLED BY ONE TOWER MITH MUNTERS PACKING EMPLOYING A LIMESTONE
ABSORBENT. THE UNIT, SUPPLIED BY RESEARCH COTTRELL. HAS A DESIGN S02 RE-
REMOVAL EFFICIENCY OF 92X. CHEVRON MIST ELIMINATORS ARE LCCATED F3IO
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FSO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ARIZCMA PUBLIC SEPVICE
CHOLLA
•»
MEM 375 MM (GROSS)
126 MM (ESC)
COAL
.50 XS
LIMESTONE
FESEARCH-COTTSELL
EHEPGY CONSUMPTION: ****/:
STATUS 1 STARTUP 3/81
CHOLLA 4 CF ARIZONA PUBLIC SERVICE IS LOCATED IN JOSEPH CITY, ARIZCMA.
THE PULVERIZED COAL (0.5X S. 10150 BTU/LB) PIPED BOILER EXHAUSTS FLUE
GAS THROUGH AN ESP TO A DOUBLE LOOP COMBINATION TOWER (RHSEARCH-COTTSELL
DESIGN) WHICH TREATS 36X OF THE GAS WITH LIMESTONE. OPERATIONS COMMENCED
IN MARCH, 1981.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT 175 MM (GROSS)
175 MM (ESC)
COAL
.75 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
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
SOS REMOVAL. THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SUB-
BITUMINOUS, 0.75X S, 6650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 GEESI VENTURI SCRU23ERS PER UNIT FOP PRIMARY PARTICLE CCNTPOL
AND APPROXIMATELY 30X S02 REMOVAL USING ALKALINE FLY ASH. THE DESIGN S02
REMOVAL EFFICIENCY SINCE THE CONVERSION TO LIME AN3 ALKALINE FLY ASH
SCRUBBING IS 67.5X. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
2
RETROFIT 175 MM (GROSS)
175 MM (ESC)
COAL
.75 XS SU5BITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
ENEPGY CONSUMPTION: ***«x
STATUS 1 STARTUP 11/79
ARIZONA PUBLIC SERVICE HAS UPGRADED THE OPERATIONAL PARTICULATE SCRUS3ERS
AT FOUR CORNERS 1,2, AND 3 IN FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SL3-
BITUMINOUS. 0.75X S, 8650 BTU/LB) UNITS 1 AND 2 SUPPLY 814,000 ACFM EACH
INTO 2 GEESI VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICLE 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
3
RETROFIT 229 MM (GROSS)
229 MM (ESC)
COAL
.75 XS SUB3ITUMINOUS
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
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 FAPMIN5TON, NEW MEXICO TO HANDLE ADDITIONAL
S02 REMOVAL. THE FRONT FIRED, DRY BOTTOM, PULVERIZED COAL (SU3-
BITUMINOUS, 0.75X S, 6650 BTU/LB) UNIT 3 SUPPLIES 1,033,000 ACFM INTO 2
INTO 2 GEESI VENTURI SCRUBBERS PER UNIT FOR PRIMARY PARTICLE CONTROL
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 MM (GROSS)
755 MM (ESC)
COAL
.75 XS
LIME
BABCOCK £ HILCOX
ENERGY CONSUMPTION: »***X
STATUS 2 STARTUP 12/84
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO BABCOCK £ MILCOX F03 A LIME
FGO SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FC'J=! CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. ALTHOUGH INITIAL PLANS CALLED FOR THE IN-
STALLATION OF HORIZONTAL ABSORBERS, THE B £ M SYSTEM WILL INCLUDE VERTICAL
SPRAY TOWERS TO CONTROL EMISSIONS FROM THESE COAL (0.75X S, SS50 BTU/LB)
FIRED UNITS. THE PARTICULATE EMISSIONS ARE HANDLED BY AN ESP. START-UP IS
EXPECTED IN DECEMBER 1984.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5
RETROFIT 755 MM (GROSS)
755 MM (ESC)
COAL
.75 XS
LIME
BABCOCK £ WILCOX
ENERGY CONSUMPTION: «cn»X
STATUS 2 STARTUP 12/84
ARIZONA PUBLIC SERVICE AWARDED A CONTRACT TO BABCOCK £ MILCOX FC° A LIME
FGD SYSTEM TO BE RETROFITTED ONTO UNITS 4 AND 5 AT ITS FOUR CORNERS STA-
TION IN FARMINGTON, NEW MEXICO. ALTHOUGH INITIAL PLANS CALLED FOR THE IN-
STALLATION OF HORIZONTAL ABSORBERS, THE B £ M SYSTEM WILL INCLUDE VERTICAL
SPRAY TOWERS TO CONTROL 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 DECEMBER 1984.
10
-------
EPA UTILITY F6D SURVEY: OCTOBER - OECEMSER 1981
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ASSOCIATED ELECTRIC
ThCMAS HILL
3
MEM 730 KM (GROSS)
670 MW (ESC)
COAL
4.60 XS
LIMESTONE
H.U. KELL05S
ENERGY CONSUMPTION: *««*X
STATUS 2 STARTUP 1/82
THOMAS HILL 3 OF ASSOCIATED ELECTRIC COOP IS A FULVEFIZE3 COAL (4.6X S,
9,700 BTU/LB) FIRED UMIT UNDER CONSTRUCTION IN KC3ERLY, MISSC'JPI. TV.O COLO
SIDE ESP'S HILL PRECEDE THE FOUR 91.5X EFFICIENT M. U. KELLC33 HCRIZCN-
TAL WEIR FGO MODULES USIN3 MAG-PROMOTED LIMESTONE AS THE AgSC'BHNT. THE
CLEANED GAS WILL PASS THROUGH A VERTICAL CHEVRCN MIST ELIMINATCR TO A eJO
FOOT BRICK LINED STACK. REHEAT MILL BE ACCOMPLISHED 3Y FLUE GAS 3YPASS.
FIXATED SLUDGE WILL BE TRUCKED TO AN ACTIVE STFIP MINE. THE SfSTEM WILL
OPERATE IN A CLOSED MATER LOOP. THE FGD SYSTEM IS UNDE1? CONSTRUCTION AND
START-UP IS EXPECTED IN JANUARY 1982.
ATLANTIC CITY ELECTRIC
CUMBERLAND
1
HEM 330 MM (GROSS)
330 MM (ESC)
COAL
3.25 XS BITUMINOUS
PPCCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««»X
STATUS 6 STARTUP 1/88
CUMBERLAND 1 IS A PULVERIZED COAL (3.25X S) FIRED BOILER TO B£ LCCATED IN
MILVILLE, HEM JERSEY. THE UTILITY IS CONSIDERING A TKRCHAWAY PRODUCT
FGO SYSTEM FOR 502 CONTROL. OPERATIONS ARE SCHEDULED TO BEGIN IN
JANUARY 1988.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
1
NEM 440 MM (GROSS)
440 MM (ESC)
COAL
.68 XS LIGNITE
LIME/SFRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ««*«X
STATUS 2 STARTUP 10/83
UNIT 1 OF BASIN ELECTRIC POMER COOP'S ANTELOPE VALLEY PLANT IS PRESENTLY
UNDER CONSTRUCTION IN BEULAH. NORTH DAKOTA. THIS UNIT MILL BURN PULVERIZED
COAL (0.68X S, 6600 BTU/LB LIGNITE) AND SUPPLY 2.055,000 ACFM TO A D"5Y
LIME FGD SYSTEM SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM MILL CONSIST OF 5 NIRO ATOMIZER SPRAY DRYERS AND TWO BAG-HOUSES.
THE CLEANED GAS. ALONG WITH A 4X BYPASS REHEAT, WILL EXIT A 600 FOOT
PVC LINED STACK. THE DRY POWDER GENERATED BY THIS CLOSED MATER LCCP
SYSTEM WILL BE USED FOR LANDFILL IN A COAL MINE. START-UP IS EXPECTED
IN OCTOBER 1963.
BASIN ELECTRIC POWER
ANTELOPE VALLEY
2
NEM 440 MM (GROSS)
440 MM (ESC)
COAL
.68 XS LIGNITE
LIME/SFRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****X
STATUS 2 STARTUP 10/85
ANTELOPE VALLEY 2 OF BASIN ELECTRIC POMER COOP HILL BE LOCATES IN BEULAH,
NORTH DAKOTA. JOY/NIRO HAS BEEN AWARDED A CONTRACT FOR THIS LIGNITE
(0.68X S, 6600 BTU/LB) FIRED UNIT. THE UNIT HILL BE REQUIRED TO CCM°LY
WITH STATE EMISSIONS STANDARDS VIA BEST AVAILABLE CONTROL TECHNCLC5Y.
START-UP IS SCHEDULED FOR OCTOBER 1985.
BASIN ELECTRIC POWER
LARAMIE RIVER
1
NEM 570 MW (GROSS)
570 MM (ESC)
COAL
.81 XS SU3BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: ***»•/.
STATUS 1 STARTUP 7/80
BASIN ELECTRIC POWER COOP'S LARAMIE RIVER 1 IS A PULVERIZED COAL
(0.9X S, 8139 BTU/LB) FIRED UNIT LCCATED IN U'HEATLAND, 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 CHEVSCN
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT IS
USED. THE FLYASH FIXATED SLUDGE IS OEWATEREO TO 83X SOLIDS BEFCRE BEING
LAMDFILLED. AND THE SYSTEM EMPLOYS A CLOSED HATER LOOP. OPERATIONS
BEGAN ON JULY 1, 1980.
BASIN ELECTRIC POWER
LARAMIE RIVER
2
HEW 570 MM (GROSS)
570 MM (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: »»«*X
STATUS 1 STARTUP 7/81
BASIN ELECTRIC POMER COOP'S LARAMIE RIVER 2 IS A NEM UNIT LOCATED
IN WHEATLAND, WYOMING. THE PULVERIZED COAL (0.81X S, 8139 BTU/LB)
FIRED BOILER FEEDS 2,300,000 ACFM OF FLUE GAS THROUGH A COLO SIDE
ESP TO FIVE RESEARCH-COTTRELL LIMESTONE PACKED TOWER MODULES, UHICH
REMOVE 90X OF THE S02. THE CLEANED GAS EXITS FRCM A VERTICAL CHEVCN
MIST ELIMINATOR INTO A 600 FOOT ACID BRICK LINED STACK. NO REHEAT IS
USED. THE FLYASH FIXATED SLUDGE IS DEMATEREO TO 83X SOLIDS 5EFOSE
BEING LANOFILLED IN THIS CLOSED MATER LOOP SYSTEM. START-UP TCOK PLACE
IN JULY 1981.
11
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
B4SIH ELECTRIC FCWER
LAPAMIE RIVER
3
NEW 570 MM (GROSS)
570 MM (ESC)
COAL
.54 XS SU33ITUMINOUS
LI-IE/SFRAY D5YIN3
BASCOCK & UILCCX
ENERGY CONSUMPTION: ****•/.
STATUS 2 STARTUP 11/82
LAHAMIE RIVER 3 OF BASIN ELECTRIC POUER CCOP IS UNDER CONSTRUCTION IN
UHEATLAN3, WYOMING, AND WILL UTILIZE FOUR DRY LIM£ INJECTION ."Cr'JLES,
AND A COLD SIDE ESP. THE BOILER WILL FIRE PULVERIZED COAL (3.5« S.
81CO BTU/LB) AMD WILL SUPPLY 2,SCO,000 ACFM OF FLUE GAS TO THE FC-D
SYSTEM, WHICH HILL REMOVE 85X OF THE S02 BEFCBE THE GAS EXITS TH?CL'3H
A 600 FOOT ACID BRICK LIKED STACK. A 3X BYPASS MILL BE USE9 FCR REHEAT.
THE SYSTEM WILL OPERATE IN A CLOSED KATES LOOP. AN3 THE DRY PC'-DE1? WASTE
WILL BE LANOFILLEO. OPERATIONS ARE SCHEDULED TO COMMENCE IN NOV. ISSC.
BIG RIVERS ELECTRIC
O.B. WILSON
1
NEW 440 KM (GROSS)
440 MM (ESC)
COAL
•»»-*•* XS BITUMINOUS
LIMESTONE
M.M. KELLOS3
ENERGY CONSUMPTION: **»*x
STATUS 2 STARTUP 7/84
BIG RIVERS ELECTRIC HAS PLANS FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS MILL HAVE A MM RATING C.: 440 EACH.
THE WET LIMESTONE FGO SYSTEM FOB UNIT 1 IS CURRENTLY UNDER CONSTRUCTION.
START-UP IS SCHEDULED FCR JULY 1984.
BIG PIVERS ELECTRIC
D.B. WILSON
2
NEW 440 MM (GROSS)
440 MM (ESC)
COAL
**«»» XS BITUMINOUS
LIMESTONE
M.H. KELLOGG
ENERGY CONSUMPTION: »**»X
STATUS 3 STARTUP O/ 0
BIG RIVERS ELECTRIC HAS PUNS FOR TWO NEW UNITS, O.B. WILSON 1 AND 2.
THE PULVERIZED COAL FIRED BOILERS MILL HAVE A MM RATING CF 440 EACH.
tl. M. KELLOG HAS BEEN AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM. START-UP HAS BEEN DEFERRED INDEFINITELY.
BIG RIVERS ELECTRIC
GREEN
1
NEH 242 MM (GROSS)
242 MM (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 REMOVE 90X CF 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 HATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN DECEMBER 1979.
BIG RIVERS ELECTRIC
G'EEN
NEW 242 MM (GROSS)
242 MM (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 SESREE,
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 TOWEPS WHICH REMOVE 90X CF THE
S02. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AMD
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
CHICOT
1
NEM 562 MM (GROSS)
562 MM (ESC)
LIGNITE
1.70 XS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6 STARTUP 0/86
CAJUN ELECTRIC POWER CCOP HAS PLANS FOR A NEM 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 1986.
12
-------
EPA UTILITY F60 SURVEY: OCTOBER - CECEK2ER 1981
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CAJUN ELECTRIC POKER
CHICOT
Z
NEM 562 MM (G=OSS)
562 MM (ESC)
LIGNITE
1.70 XS
PROCESS NOT SELECTED
VEUDO1? NOT SELECTED
ENERGY CONSUMPTION: *«*»X
STATUS 6 STARTUP 0/88
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A NEH UNIT, CHICOT 2, TC 5=
LOCATED IN SHREVEPCRT, LOUISIANA. THE UTILITY IS CCNS:2E.-ZN5 A C-f
SCPUE3IN3 F6D SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FISEO EXILES.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 19S8.
CAJUN ELECTRIC POWER
CHICOT
3
HEM 562 MM (GROSS)
562 MM (ESC)
LIGNITE
1.70 XS
PROCESS MOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6 STARTUP 0/93
CAJUN ELECTRIC POWER COOP HAS PLANS FOR A HEW UNIT, CHICOT 3, 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 1992.
CAJUN ELECTRIC POWER
CHICOT
4
HEW 562 MM (GROSS)
562 MM (ESC)
LIGNITE
1.70 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »«»»X
STATUS 6 STARTUP 0/94
CAJUN ELECTRIC POMER COOP HAS PLANS FOR A NEM UNIT, CHICOT 4, TO GE
LOCATED IN SHREVEPORT, LOUISIANA. THE UTILITY IS CONSIDERING A CRY
SCRUBBING FGD SYSTEM FOR EMISSION CONTROL FROM THE LIGNITE FIRED BOILER.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1994.
CAJUN ELECTRIC POWER
OXBOM
1
NEM 540 MM (GROSS)
540 MM (ESC)
COAL
.60 XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 5 STARTUP 0/85
CAJUN ELECTRIC HAS PLANS TO CONSTRUCT A 540 MM UNIT, OXBOW 1, TO EE LCCAT-
ED IN OE SOLO PARISH, LOUISIANA. THE UTILITY IS REQUESTING BIDS FCR A DRY
SCRUBBING PROCESS TO CONTROL EMISSIONS FROM THE PULVERIZED COAL FIPED
BOILER. THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN 1965.
CAJUN ELECTRIC POMER
OXBOM
2
NEM 540 MM (GROSS)
540 MM (ESC)
COAL
.60 XS LIGNITE
FPCCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »**»X
STATUS 6 STARTUP 0/85
CAJUN ELECTRIC HAS PLANS TO CONSTRUCT A 540 MM UNIT, OXECV4 2, TO BE
LOCATED IN OE SOLO PARISH, LOUISIANA. THE UTILITY IS PRESENTLY CONSIDER-
ING A DRY SCRUBBING PROCESS TO CONTROL EMISSIONS FROM THE PULVERIZED
COAL FIRED BOILER. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1985.
CENTRAL ILLINOIS LIGHT
DUCK CREEK
1
NEM 416 KM (GROSS)
416 MM (ESC)
COAL
3.66 XS BITUMINOUS
LIMESTONE
ENVIPONEERING. RILEY STOKER
ENERGY CONSUMPTION: 2.9X
STATUS 1 STARTUP 7/76
DUCK CREEK 1 OF CENTRAL ILLINOIS LIGHT IS LOCATED IN CANTCN. ILLINOIS. THE
BALANCED DRAFT, FRONT FIRED, DRY BOTTOM UNIT BURNS PULVERIZED BITUMINOUS
COAL (3.66X S, 10,500 BTU/LB) AND SUPPLIES 2,415,000 ACFM OF FLUE GAS TO
TWO COLD SIDE ESP'S FOLLOWED BY FOUR RILEY STCKER/ENVIRCNEEPIN3 EC3 CECK
SPRAY TCMER MODULES. THE FGO SYSTEM HAS BEEN OPERATIONAL (AT LEAST CNE
MODULE) SINCE JULY, 1976. IT IS DESIGNED TO REMOVE 85X OF THE S02. HC=I-
ZONTAL CHEVRON MIST ELIMINATORS FOLLOW THE ABSORBERS, AND THE CLEANED GAS
EXITS TO A 500 FOOT CEILCOTE LINED STACK HITHOUT REHEAT. THE SYSTEM OPER-
ATES A CLOSED MATER LOOP, AND THE SLUDGE IS DISPOSED OF IN AN ON-SITE CLAY
LINED POND.
13
-------
EPA UTILITY FGO SURVEY: OCT03ER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
CENTRAL ILLINOIS LIGHT
DUCK CREEK
2
HEW 450 MM (G°OSS)
450 MM (ESC)
COAL
5.30 XS BITUMINOUS
LI11ESTCNE
VEIJ30R NOT SELECTED
ENERGY CONSUMPTION: «»»«X
STATUS 6 STARTUP 1/87
CENTRAL ILLINOIS LIGHT IS CURRENTLY INVESTIGATING A LIMESTONE CR DUAL
ALKALI FGD SYSTEM FOR UNIT 2 AT ITS DUCK CREEK STATION. THE 3ITUMIN3US
COAL FIRED BOILER MILL FEED ITS FLUE GAS THROUGH A COLD SIDE ESP. THE
SYSTEM MILL OPERATE IN A CLOSED WATER LOOP AND IS SCHEDULED TO BEGIN
OPERATIONS IN JANUARY 1987.
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
1
MEM 617 MM (GROSS)
617 MM (ESC)
COAL
2.25 XS BITUMINOUS
DUAL ALKALI
GE ENVIRONMENTAL SERVICES
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/L3) FIRED UNIT
LOCATED IN NEHTON, ILLINOIS. A COLO SIDE ESP RECEIVES 2,165,460 ACrM
OF FLUE GAS AND FEEDS IT TO FOUR GEESI POLYSPHERE PACKED TRAY TCHES
ABSORBERS FOLLOMED BY TWO VERTICAL MIST ELIMINATORS PER MODULE. THE
CLEANED GAS IS BOOSTED 25 DEC F BY A COMBINATION OF TWO DIFFERENT TYPES
OF IN-LINE REHEATERS PLUS BYPASS REHEAT, AND THEN EXITS A 530 FCOT
PRECRETE-LINEO STACK. THE WATER LOOP IS CLOSED, AND THE SLL3GE IS
POZ-0-TEC TREATED.
CENTRAL MAINE POWER
SEARS ISLAND
1
NEM 600 MM (GROSS)
600 MM (ESC)
COAL
2.23 XS BITUMINOUS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»*«X
STATUS 6 STARTUP 11/89
SEARS ISLAND 1 IS A PLANNED UNIT TO BE BUILT ON PENOBSCOT BAY BY CENTRAL
MAINE POWER. BECAUSE OF THE DISCOVERY OF A GEOLOGICAL FAULT CN SEARS
ISLAND, PLANS FOR A 1150 MM NUCLEAR POWER PLANT HAVE BEEN REPLACED WITH
PLANS FOR A 600 MM COAL FIRED PLANT. LIME AND LIMESTONE SCRU3BIN3 ARE
THE PRIMARY METHODS BEING CONSIDERED FOR COMPLIANCE WITH THE NSPS. IT
MILL BE TWO YEARS BEFORE ALL PERMITS REQUIRED HAVE BEEN RECEIVED. START-
UP IS SCHEDULED FOR NOVEMBER 1939.
CENTRAL POWER t LIGHT
COLETO CREEK
2
NEM 720 MM (GROSS)
720 MM (ESC)
COAL
.39 XS SUBSITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»»*X
STATUS 6 STARTUP 9/92
COLETO CREEK 2 OF CENTRAL POWER AND LIGHT IS A COAL (.39X5) FIRED UNIT
PLANNED FOR CONSTRUCTION IN FANNIN, TEXAS. THE UNIT MILL BE BUILT 3Y
CENTRAL AND SOUTHWEST SERVICES, BUT MILL BE OPERATED BY CENTRAL POWER AND
LIGHT. ONLY DRY SCRUBBING IS BEING CONSIDERED FOR S02 CCMTROL. START-UP
IS TENTATIVELY SCHEDULED FOR SEPTEMBER 1992.
CINCINNATI GAS & ELECTRIC
EAST BEND
1
NEM 650 MM (GROSS)
650 MM (ESC)
COAL
4.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.9X
STATUS 6 STARTUP 0/88
CINCINNATI GAS AND ELECTRIC HAS PLANS FOR A NEM 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 MM. THE UNIT IS
SCHEDULED TO START-UP IN 1988.
CINCINNATI GAS t
EAST BEND
2
NEW
ELECTRIC
650 MM (GROSS)
650 MM (ESC)
COAL
3.00 XS
LIME
BABCOCK i MILCOX
ENERGY CONSUMPTION: 2.9X
STATUS 1 STARTUP 3/81
EAST BEND 2 OF CINCINNATI GAS AND ELECTRIC IS A PULVERIZED COAL (5X S,
DESIGN) FIRED BOILER LOCATED IN RABBITHASH, KENTUCKY. THE EMISSION CON-
TROL SYSTEM CONSISTS OF A HOT SIDE ESP FOLLOWED BY THREE BA5CCCK AND~«ILCO
LIME FGD MODULES. THE CLEANED GAS. «7X S02 REMOVAL. PASSES THROUGH A J
CHEVRON MIST ELIMINATOR BEFORE BEING HEATED BY AN INDIRECT HOT AIR -
REHEATER AND EXITS THROUGH A BRICK LINED 650 FOOT STACK. THE SLUDGE FROM
THIS CLOSED HATER LOOP IS POZ-0-TEC STABILIZED BEFORE DISPOSAL IN AN ON-
SITE LANDFILL. OPERATIONS COMMENCED IN MARCH 1981.
14
-------
EPA UTILITY FGD SUPVEY: OCTC3EH - DECEMBER 1931
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
COLORADO UTE ELECTRIC
CRAIG
1
NEW 455 MM (GROSS)
410 MH (ESC)
COAL
.45 XS SU3SITUMINOUS
LIMESTONE
PEA30DY PROCESS SYSTEMS
ENE=GY CONSUMPTION: i.ix
STATUS 1 STARTUP 10/80
THE COLORADO UTE ELECTRIC ASSN HAS CONSTRUCTED A NEW UNIT, CPAIG 1, LCCAT-
ED IN CRAIG. COLORADO. BOTH UNITS FIRE PULVERIZED SVSSITUMIf^'JS CCAL
(0.45X S, 10,000 BTU/LB). THE EMISSION CCMTPOL SYSTEM FC3 THIS UNIT CON-
SISTS OF A HOT SICE ESP AND FOUR LIMESTONE SF3AY TCWE=S rCR PEKOVAL OF
PARTICULATE MATTER AND 85X OF THE SOI. THE SCPUEEER EXHAUST IS HEATE3 3Y
A BYPASS REHEATER AND PASSES THROUGH A 600 FCOT ACID LIMES STACK. THE
SYSTEM OPERATES IN A CLOSED MATER LOOP AND THE STABILIZED SLUCGE IS CIS-
FOSED OF IN AN OFF-SITE MIHEFILL. UNIT 1 START-UP IS EXPECTED IN CCTC3ER
1930.
COLORADO UTE ELECTRIC
CRAIG
2
HEW 455 MM (GROSS)
410 MV1 (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
FEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: -2.OX
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 (0.4SXS, 10,COO BTU/LB).
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP AND
FOUR LIMESTONE SPRAY TOUERS FOR REMOVAL OF PARTICULATE MATTER A.'iO 85X
OF THE 502. THE SCRUBBER EXHAUST IS HEATED BY A BYPASS REHEATED AND
PASSES THROUGH A 600 FOOT ACID BRICK LINED STACK. THE Si STEM OFHPATES IN
A CLOSED LOOP, AND THE STABILIZED SLUDGE IS DISPOSED OF IN AN OFF-SITE
MINEFILL. START-UP OF UNIT 2 MAS IN DECEMBER 1979.
COLORADO UTE ELECTRIC
CRAIG
HEM 447 MM (GROSS)
447 MM (ESC)
COAL
.45 XS SUBBITUMINOUS
LIME/SPRAY CRYING
BABCOCK & MILCOX
ENEPGY CONSUMPTION: «i«*X
STATUS 2 STARTUP 4/B3
CRAIG 3 OF COLORADO UTE ELECTRIC ASSN. IS UNDER CONSTRUCTION IN CRAIG,
COLORADO. THE UNIT HILL FIRE PULVERIZED SU3BITUMIHOUS COAL (0.45X S.
10,000 BTU/LB). THE DRY SCRUBBING SYSTEM UTILIZIMS LIME INJECTION WILL
BE SUPPLIED BY BABCOCK AND MILCOX. THE UNIT MILL HAVE A FABRIC FILTER FOR
PARTICULATE MATTER CONTROL. OPERATION OF THE FGO SYSTEM IS SCHEDULED TO
COMMENCE IN 1983.
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE
5
HEM 411 MM (GROSS)
411 MM (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.9X
STATUS 1 STARTUP 1/77
CONESVILLE 5 OF COLUM&US AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,650 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLO SIDE ESP RECEIVES 1.393,893 ACFM OF FLUE
GAS AN3 PASSES IT TO TWO THIOSORBIC LIME TCA MODULES SUPPLIED BY UCP.
THE S02 REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH BEGAN INITIAL
OPERATION IN JANUARY 1977, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAPMENT SEPARATOR AND TMO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT ACID BRICK LINED STACK. THE
POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AH CN-SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN MATER LOOP.
COLUMBUS & SOUTHERN OHIO ELEC
CONESVILLE
6
HEM 411 MM (GROSS)
411 MM (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 3.9X
STATUS 1 STARTUP 6/78
CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC IS A DRY BOTTOM,
PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB) FIRED UNIT LOCATED
IN CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES 1,393,893 ACFM OF FLUE
GAS AND PASSES IT TO TMO THIOSCRBIC LIME TCA MODULES SUPPLIED BY UOP.
THE S02 REMOVAL EFFICIENCY OF THE TMO MODULES, WHICH BEGAN INITIAL
OPERATION IN JUNE 1978, IS 89.5X (DESIGN). EACH MODULE HAS ONE
BULK ENTRAINMENT SEPARATOR AND TMO CHEVRON MIST ELIMINATORS. THE
CLEANED GAS EXITS THROUGH AN 800 FOOT ACID BRICK LINED STACK. THE
POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON-SITE DIKED LAND-
FILL. THE SYSTEM OPERATES IN AN OPEN MATER LOOP.
COLUMBUS I SOUTHERN OHIO ELEC COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FOR TMO NEM UNITS, POSTON S
POSTON
5
NEW 425 MM (GROSS)
375 MM (ESC)
COAL
***** XS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
STATUS 6 STARTUP 8/86
AW 6, TO BE LOCATED IN ATHENS, OHIO. THE COAL (2.5X S. 11,000 BTU/LB)
FIRED UNITS HILL UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI FGD
SYSTEM. START-UP OF UNIT 5 IS EXPECTED IN 1986.
15
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UHIT IDENTIFICATION
ABSTRACT
COLUMBUS « SOUTHERN OHIO ELEC
PQSTCN
6
tiZU 425 HW (GPOSS)
375 MM (ESC)
COAL
2.50 y.S
FPCCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 4.7X
STATUS 6 STARTUP 0/89
COLUMBUS AND SOUTHERN OHIO ELECTRIC HAS PLANS FC3 TUO NEW UNITS, FCSTCN 5
AND 6, TO BE LOCATED IN ATHENS. OHIO. THE COAL (2.5X S. 11,000 BTU/LB)
FIRED UNITS MILL UTILIZE EITHER A LIME, LIMESTONE, CR DUAL ALKALI FGD
SYSTEM. START-UP OF UNIT 6 IS EXPECTED IN 1939.
COMMONWEALTH EDISON
PCWERTON
51
RETROFIT 450 MM (GROSS)
450 KM (ESC)
COAL
3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: s.ex
STATUS 1 STARTUP 4/80
COMMONWEALTH EDISON HAS RETROFITTED BOILER NUMBER SI AT ITS PCWERTOH
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 AM ESP
TO 3 TCA MODULES WHICH ARE DESIGNED TO REMOVE 7«»X OF THE SQZ. 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 FOZ-0-TEC STABILIZED AND DISPOSED OF IN A LANDFILL.
THE FGD SYSTEM COMMENCED OPERATION IN APRIL, 1980.
COOPERATIVE POWER ASSOCIATION
COAL CREEK
1
NEM 545 MM (GROSS)
327 MM (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****•/.
STATUS 1 STARTUP 7/79
COAL CREEK 1 AND 2 ARE TWO PULVERIZED LIGNITE (0.63/C S, 6253 BTU/LS) 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 EHTRAIISIEHT
SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
IS PROVIDED BEFORE THE CLEANED GAS EXITS THE 650 FOOT ACID ERICK
LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN HATER 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
NEH 545 MM (GROSS)
327 MM (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****x
STATUS 1 STARTUP 7/80
COAL CREEK 1 AND 2 ARE TUO PULVERIZED LIGNITE (0.63X S, 6258 BTU/LB) FIRED
UNITS OWNED BY THE COOPERATIVE POWER ASSN AMD UNITED POWER. A COLD SIC'
ESP RECEIVES 2,200,000 ACFM OF FLUE GAS AND EXHAUSTS IT TO FCUR 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 502 REMOVAL EFFICIENCY IS 90X. THE SYSTEM
OPERATES IN AN OPEN HATER 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 MM (GROSS)
60 MM (ESC)
COKE
7.00 XS BITUMINOUS
MELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: ***»/£
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AMD 3 OF DELMARVA POWER AND LIGHT ARE THREE RETRO-
FITTED COKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF SOCK
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES 295,000 ACrM OF FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUS3ER FCR P4RTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMIKATCR
TO A WET ESP FOR BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
WELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL. IS USED FGR SC2 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 HATER SYSTEM. THE SYSTEM BECAME OPERATIONAL IN MAY 1960.
OELMARVA POWER t LIGHT
DELAWARE CITY
2
RETROFIT 60 MM (GROSS)
60 MM (ESC)
CCKE
7.00 XS BITUMINOUS
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 CCKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF 5COK
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 SCRUSSER FOR PARTICULATE
CCNTPOL. THE FLUE GAS THEN PASSES THRCU3H A CHEVRON TYPE MIST ELIKINATCR
TO A WET ESP F03 BOTH PARTICULATE AND ACID MIST REMOVAL. A FOUR STAGE
WELLMAN-LORD SYSTEM, WHICH IS DESIGN FOR 90X REMOVAL. IS USED FCR SC2 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 MATER SYSTEM. THE SYSTEM BECAME OPERATIONAL IN MAY 1980.
16
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1931
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
OELMARVA POWER I LIGHT
DELAWARE CITY
3
RETPOFIT 60 MW (GPOSS)
60 MW (ESC)
COKE
7.30 XS BITUMINOUS
HELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: ****•/.
STATUS 1 STARTUP 5/80
DELAWARE CITY 1, 2, AND 3 OF DELMARVA POWER AND LIGHT ARE THPEE =ET=0-
FITTED COKE (7-8X S) FIRED BOILERS WHICH HAVE A STEAM CAPiCITf Or ECCK
LB/HR EACH. THE BOILERS GENERATE STEAM AS WELL A3 ELECTRICITY FC? GETTY
REFINING AND MARKETING. EACH BOILER SUPPLIES £95,000 ACFM Or FLUE GAS TO
A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCFU=BEH F03 PARTICULATE
CONTROL. THE FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE MIST ELIMIS'ATCR
TO A WET ESP FOR BOTH PAPTICULATE AND ACID MIST REMOVAL. A FO'JP. STASE
WELLMAN-LOHD SYSTEM, WHICH IS DESIGN F0° 90X REMOVAL, IS USED FCR SC2 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 rCKEE. IT IS A
CLOSED LOOP MATER SYSTEM. THE SYSTEM BECAME OPERATIONAL IN MAY 19SO.
DELMARVA POWER & LIGHT
VIENNA
9
NEU 550 MM (GROSS)
550 MW (ESC)
COAL
2.50 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 2.7X
STATUS 6 STARTUP 5/90
DELMARVA POWER AND LIGHT IS PLANNING A NEW 550 MW (GROSS) UNIT, VIENNA 9,
BE CONSTRUCTED IN VIENNA, MARYLAND. THE UTILITY IS PRESENTLY CONSIDERING
A LIMESTONE FGD UNIT FOR EMISSION CONTROL. THE PULVERIZED COAL FIRED UNIT
WILL BURN COAL WITH AN AVERAGE SULFUR CONTENT OF 2.7X AND IS EXPECTED TO
COMMENCE OPERATIONS IN MAY 1990.
DESERET GEN & TRANS
BONANZA
1
NEW 410 MW (GROSS)
410 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
COMSUSTICN ENGINEERING
ENERGY CONSUMPTION: »*»»X
STATUS 2 STARTUP 9/84
BONANZA (FORMERLY MOON LAKE) 1 IS A PULVERIZED COAL (.57. S, 10,500 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN VERNAL. UTAH. THE FGD SYSTEM IS BEINS
SUPPLIED BY COMBUSTION ENGINEERING. THE WET LIMESTONE SCRUS3ING SYSTEM
WILL HAVE AN S02 REMOVAL EFFICIENCY OF 95X. THE SYSTEM WILL FEATURE A
BAGHOUSE SUPPLIED BY ECOLAIRE TO REMOVE 99.6X OF THE PARTICULATE MATTES.
THE UNIT WILL OPERATE IN A CLOSED WATER LOOP WITH SLUDGE DISPOSAL GN-SITE
IN A LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN SEPTEMBER 1984.
OESERET GEN
BONANZA
2
NEW
& TRANS
410 MW (GROSS)
410 MW (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»«*x
STATUS 5 STARTUP 0/88
BONANZA (FORMERLY MOON LAKE) 2 IS A PULVERIZED COAL ( .5X S, 10.500 BTU/LB)
FIRED UNIT PLANNED BY DESERET GENERATION t TRANS. COOP TO BE LCCATED IN
VERNAL, UTAH. THE UTILITY IS ERESENTLY REQUESTING BIDS FOR A WET LIME-
STONE SCRUBBING SYSTEM HAVING AN 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.
OUQUESNE LIGHT
ELRAMA
1-4
RETROFIT
510 MM (GROSS)
510 MW (ESC)
COAL
XS
LIME
GE ENVIRONMENTAL SERVICES
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 GEESI. WHICH ARE DESIGNED TO REMOVE 83X OF THE SC2 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.
CUQUESNE LIGHT
PHILLIPS
1-6
RETROFIT 408 MW (GROSS)
408 MM (ESC)
COAL
2.05 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
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 FGO MODULES SUPPLIED BY GEESI
ARE DESIGNED TO REMOVE 83X OF THE S02 FROM THE FLUE GAS. TWO CHEVPCN MIST
ELIMINATORS/MODULE ARE FOLLOWED BY A DIRECT OIL FIRED REHEATER kHICH RAIS-
ES THE GAS TEMPERATURE BY 20 CE6 F BEFORE IT LEAVES VIA A 340 FCOT TALL
ACID BRICK LINED STACK. THE SYSTEM OPERATES IN AN OPEN WATER LCOP, AND
THE POZ-0-TEC STABILIZED SLUDGE IS TRUCKED TO AN OFF-SITE LANDFILL. THE
SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1973.
17
-------
EPA UTILITY FGO SURVEY: OCT03ER - DECEMBER 1931
SECTION 2
STATUS OF F6D SYSTEMS
UNIT I3ENTIFICATION
ABSTRACT
EAST KENTUCKY POWER
J.K. SMITH
1
MEW 650 MW (GROSS)
650 MM (ESC)
COAL
1.50 XS BITUMINOUS
LIME
BABCOCK & MILCOX
ENERGY CONSUMPTION: »«»*x
STATUS 3 STARTUP 8/87
THE EAST KENTUCKY POWER COOP HAS PLANS TO FIRE TU'O HEM UNITS, J.K. SKITH
1 AND Z. A CONTRACT MAS AWARDED TO BABCCCK AND UILCOX FC= A MET
LIME PROCESS TO CONTROL EMISSIONS. THE SYSTEM HILL OPERATE IN A CLOSED
MATER LOOP MODE. START-UP FCR UNIT 1 IS EXPECTED IN 1937.
EAST KENTUCKY POWER
SPURLOCK
2
HEM 500 MM (GROSS)
500 KU (ESC)
COAL
3.50 XS
LIME
THYSSEN/CEA
ENERGY CONSUMPTION: *»*»X
STATUS Z STARTUP 1/83
SPURLOCK 2 OF EAST KENTUCKY POWER COOPERATIVE IS A BALANCED CRAFT PULVER-
IZED COAL (3.5X S, 11 • 000 BTU/LB) FIRED UNIT UKDER CONSTRUCTION IN MAYS-
VILLE, KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF AN ESP FOL-
LOWED BY A THYSSEN/CEA LIME FGD SYSTEM (90X DESIGN S02 REMOVAL Err).
FLUE GAS FROM UNIT ONE WILL BE USED TO REHEAT THE CLEANED GAS. THE CLOSED
WATER LOOP SYSTEM, SLATED FOR START-UP IN 1983, WILL EMPLOY A POZ-0-TEC
SLUDGE STABILIZATION FACILITY.
FLORIDA POWER 4 LIGHT
MARTIN
3
NEW 800 MW (GROSS)
800 MW (ESC)
COAL
«**** xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENEPGY CONSUMPTION: ****•/.
STATUS 6 STARTUP 0/87
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
MILL HAVE A MM RATING OF 800 EACH. THE UTILITY IS PRESENTLY CONSIDERING
ONLY FGO AS THE EMISSION CONTROL STRATEGY. THE START-UP FCR UNIT 3 IS
PROJECTED FOR 1937.
FLOPIDA POWER I LIGHT
MARTIN
4
NEW 800 MM (GROSS)
800 MM (ESC)
COAL
*««*» XS
PROCESS NOT SELECTED
VENCCR NOT SELECTED
ENERGY CONSUMPTION: ««»»X
STATUS 6 STARTUP 0/89
FLORIDA POWER AND LIGHT HAS PLANS FOR TOO NEW UNITS, MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA. THE PULVERIZED COAL FIRED BOILERS
MILL HAVE A MW RATING OF 800 EACH. THE UTILITY IS PRESENTLY CONSIDERING
ONLY FGD AS THE EMISSION CONTROL STRATEGY. THE START-UP FCR UNIT * IS
PROJECTED FOR 1989.
GENERAL PUBLIC UTILITIES
COAL
1
NEW 625 MW (GROSS)
625 MW (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT "ELECTED
ENERGY CONSUMPTION: »*»*X
STATUS 5 STARTUP 5/91
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 625 MM UNIT, COAL 1.
THE UTILITY IS PRESENTLY REQUESTING/EVALUATING BIDS FOR AN FGO 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 MM (GROSS)
625 MM (ESC)
COAL
3.SO XS
PROCESS NOT SELECTED
VECTOR NOT SELECTED
ENERGY CONSUMPTION: nviHtx
STATUS 6 STARTUP 5/93
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 625 MM UNIT, COAL 2.
THE UTILITY IS PRESENTLY CONSIDERING DHL FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1993.
18
-------
EPA UTILITY FGO SURVEY: CCTC3ER - DECEMBER 1931
SECTION 2
STATUS OF F63 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
GENERAL PU3LIC UTILITIES
COAL
3
NEW 6£5 KM (GROSS)
625 ru (ESC)
COAL
3.50 XS
PSCCESS NOT SELECTED
VEK3C3 NOT SELECTED
ENERGY CONSUMPTION: wnn»X
STATUS 6 STARTUP 5/95
GENERAL PUBLIC UTILITIES IS PLANNING TO CONSTRUCT A 615 rw UNIT. CC1L 3.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGO AS THE EKISSIC'J CCNT=CL
STPATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COGENCE OPZrATICNS
IN 1995.
GENERAL PUBLIC UTILITIES
COAL
4
HEM 625 MM (GROSS)
6Z5 KM (ESC)
COAL
3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»*»X
STATUS 6 STARTUP 5/96
GENERAL PUBLIC UTILITIES HAS PLANS TO CONSTRUCT A 6£5 KM UNIT, COAL 4.
THE UTILITY IS PRESENTLY CONSIDERING ONLY FGO AS THE EKIS5ICN CCHTPOL
STRATEGY. THE COAL FIRED (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1996.
GENEPAL PUBLIC UTILITIES
SEMARD
7
NEW 690 KM (GROSS)
690 KM (ESC)
COAL
***»* XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 9.4X
STATUS 5 STARTUP 5/39
GENERAL PUBLIC UTILITIES IS PLANNING A NEM UNIT, SEWAHO 7. TO BE SUILT IN
SEMARD, PENNSYLVANIA. THE UTILITY IS PRESENTLY REQUESTING BIDS FC3 AN FGO
SYSTEM, WITH NON-SLURRY TYPE LIKE AND LIKESTONE SYSTEMS BEING THE
PRIMARY CONSIDERATION. START-UP IS EXPECTED IN MAY 1939.
GRAND HAVEN BRO OF LIGHT t
J.B. SIMS
3
NEM 65 KM (GROSS)
65 KM (ESC)
COAL
2.75 XS BITUMINOUS
LIME
BABCOCK & UILCOX
ENERGY CONSUMPTION: »«*»x
STATUS 2 STARTUP 1/83
PMR THE GRAND HAVEN BOARD OF LIGHT AND POWER'S J.B. SIMS 3 IS A BITU.1INIOUS
COAL (2.75X S, 11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN GPAKD
HAVEN, MICHIGAN. A CONTRACT HAS BEEN AMAROEO TO BAECCCK AMD UILCOX TO
SUPPLY TWO SPRAY TOWERS TO CONTROL 502 EMISSIONS. EACH SCRUBBER SYSTEM
MILL UTILIZE A CHEVRON MIST ELIMINATOR AND AN IN-LINE REHEATER. THE SYS-
TEM MILL OPERATE IN A CLOSED WATER LOOP MODE AND THE SLUDGE HILL BE DIS-
POSED OF IN AN OFF-SITE LANDFILL. START-UP IS SCHEDULED FOR JAN. 1983.
HOOSIER ENERGY
RERCM
1
HEM 490 KM (GROSS)
441 KM (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: *«»*X
STATUS 2 STARTUP 5/82
MEROM 1 AND 2 ARE TWO NEM UNITS BEING BUILT BY HC3SIER ENERGY IN SULLIVAN.
INDIANA. THESE PULVERIZED COAL (3.5X S) FIRED UNITS WILL FHCDL'CE 1,732,000
ACFM OF FLUE GAS WHICH MILL BE CLEANED BY A COLO SIDE ESP UPSTREAM OF A
MITSUBISHI LIKESTONE GRID TOMER ABSORBER (90X DESIGN S02 REMOVAL). THE
SYSTEM MILL UTILIZE BYPASS REHEAT AND A 700 FOOT STACK. THE SLUC3E WILL
BE STABILIZED AND LAMDFILLED, AND THE SYSTEM MILL OPERATE IN A CLOSED
MATER LOOP KOOE. START-UP OF UNIT 1 IS SCHEDULED FCR KAY 1982.
HOOSIER ENERGY
MEROM
2
NEM 490 KM (GROSS)
441 KM (ESC)
COAL
3.50 XS
LIKESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ««»»x
STATUS 1 STARTUP 12/81
MEROM 2 IS A NEM UNIT BUILT BY HOOSIER ENERGY IN SULLIVAN. INDIANA. THIS
PULVERIZED COAL (3.5X S) FIRED UNIT PRODUCES 866,000 ACFM OF FLUE GAS
WHICH IS BEING CLEANED BY A COLD SIDE ESP UPSTREAM OF A MITSUBISHI
LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE SYSTEM
UTILIZES BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDGE IS BEING
STABILIZED AND LANOFILLED, AND THE SYSTEM OPERATES IN A CLOSED MATER
LOOP KOOE. UNIT 2 COMMENCED OPERATIONS IN DECEK5ER 1981.
19
-------
EPA UTILITY FGD SURVEY: OC7C3ER - DECEMBER 1981
SECTION 2
STATUS OF F5D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
HOUSTON LIGHTING & POWER
LIMESTONE
1
MEW 750 MH (GPOSS)
750 MM (ESC)
COAL
1.03 XS LIGNITE
LIMESTONE
CCMSUSTION ENGINEERING
ENE=GY CONSUMPTION *-m»Z
STATUS 3 STARTUP 12X86
HOUSTON LIGHTING AMD POWER CO HAS PLANS FOR TWO NEH UNITS, LIfSSTCME 1
AHO 2, TO BE LOCATED IN JEHITT, TEXAS. THE PULVERIZED COAL (l.CSX S,
6177 BTU/LB) FIRED BOILER MILL UTILIZE A WET LIMESTONE SCPU33IN3 PROCESS
FOR PRIMARY S02 COLLECTION. A COLO SIDE ESP WILL ALSO Be USED FC3 PRIMARY
PARTICLE CONTROL. THE UTILITY HAS AWARDED A CONTRACT TO CCrSUSTION ENGI-
NEERING FOR THE INSTALLATION OF THIS SYSTEM. UNIT 1 IS SCHEDULED TO COM-
MENCE OPERATIONS IN 1936.
HOUSTON LIGHTING t POWER
LIMESTONE
2
NEW 750 MM (GROSS)
750 MM (ESC)
COAL
1.08 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »««»X
STATUS 3 STARTUP 12/87
HOUSTON LIGHTING AMD POWER CO HAS PUNS 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 HILL UTILIZE A MET LIMESTONE SCRU33ING PROCESS
FOR PRIMARY S02 COLLECTION. A COLD SIDE ESP MILL 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 1987.
HOUSTON LIGHTING & POWER
M.A. PARISH
8
NEW 600 MM (GROSS)
492 MM (ESC)
COAL
.60 XS SUSBITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****x
STATUS 2 STARTUP 11/82
M.A. PARISH 8 OF HOUSTON LIGHTING t POMER IS A PULVERIZED COAL (0.6X S.
8700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN THOMPSONS. TEXAS. GEESI
MILL SUPPLY A LIMESTONE FGD SYSTEM WHICH MILL REMOVE 82X OF THE FLUE
GAS S02. REHEAT MILL BE PROVIDED BY BYPASSING 18X OF THE PARTICULATE
CLEANED FLUE GAS. SLUDGE MILL BE DEWATERED, BLENDED MITH FLYASH, AND
DISPOSED OF IN AN ON-SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE
IN NOVEMBER 1982.
INDIANAPOLIS POWER & LIGHT
PATRIOT
1
NEM 650 MM (GROSS)
650 MM (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6 STARTUP 0/87
INDIANAPOLIS POMER AND LIGHT HAS PLANS FOR THREE NEM UNITS. PATRIOT 1. 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS CN UTILIZING
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POMER & LIGHT
PATRIOT
2
NEM 650 MM (GROSS)
650 MM (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »»*»x
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POWER AND LIGHT HAS PLANS FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS TO UTILIZE
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS POMER ft LIGHT
PATRIOT
3
NEM 650 MM (GROSS)
650 MM (ESC)
COAL
3.50 XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »K*«X
STATUS 6 STARTUP O/ 0
INDIANAPOLIS POMER AND LIGHT HAS PLANS FOR THREE HEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED IN PATRIOT, INDIANA. THE UTILITY PLANS ON UTILIZING.
A LIMESTONE FGD PROCESS FOR EMISSION CONTROL.
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEASES 1931
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
INDIANAPOLIS POU'ER 4 LIGHT
PETERSBURG
3
(JEW 532 MM (GROSS)
532 MM (ESC)
COAL
3.25 7.3 BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X
STATUS 1 STARTUP 12/77
PETERSBURG 3 OF INDIANAPOLIS POWER ANO LIGHT IS LOCATED IN PETc"S5l'=S,
INDIANA, AND BURNS 3.25X S BITUMINOUS COAL (11,000 BTL'/LB). TWO COLD SIOS
ESP'S ARE LOCATED UPSTREAM OF FOUR 85X EFFICIENT UOP LIMESTONE TCA
MODULES. A HORIZONTAL MIST ELIMINATOR PRECEDES AN INDIRECT HOT Al
-------
EPA UTILITY FGO SU=VEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KANSAS CITY POWER & LIGHT
HAWTHC3N
4
RETROFIT 90 MW (GROSS)
90 KH (ESC)
COAL
.60 XS BITUMINOUS
LIKE
CCM2USTICN ENGINEERING
EHE°GY CONSUMPTION: 2.2X
STATUS 1 STARTUP 8/72
HAWTHORN 4 OF KANSAS CITY POWER AND LIGHT IS A DRY BOTTCM PULVERISED
BITUMINOUS COAL (0.6X S, 9800 BTU/LB) FIRED UNIT LOCATED IN KANSAS CITY.
MISSOURI, WHICH HAS CONVERTED FROM LIMESTONE FURNACE INJHCTICN At.3 TAIL
END SCRUBBING TO A LIME SLUPRY SYSTEM. TWO COM3USTICN EKSII.'c£3INS MAS3LE
BED ABSORBERS. WHICH WERE DESIGNED TO REMOVE 70X OF THE FLUE GAS SC2.
BEGAN OPERATION IN JANUARY 1977. ONE HORIZONTAL CHEVHCN MIST ELIMINATOR
PER MODULE IS LOCATED UPSTREAM OF AN IN-LINE FINNED TUEE REKEAT5R, WHICH
RAISES THE TEMPERATURE OF THE CLEANED GAS BEFORE IT EXITS THECUSH A GUNITE
LINED 200 FOOT STACK. THE FLYASH STABILIZED SLUDGE IS DEPOSITED IN AM
UNLINEO SLUDGE POND. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MC3E.
KANSAS CITY POWER & LIGHT
LA CYGNE
1
NEW 874 MM (GROSS)
874 MW (ESC)
COAL
5.39 XS SUSBITUMINOUS
LIMESTONE
BABCOCK & WILCOX
ENERGY CONSUMPTION: 3.2X
STATUS 1 STARTUP 2/73
LA CYGNE 1 IS A WET BOTTOM, CYCLONE FIRED PULVERIZED SUBSITUMINOUS COAL
(5.39X S, 9421 BTU/LB) FIRED UNIT OF KANSAS CITY POWER AMD LIGHT, LOCATED
IN LA CYGNE, KANSAS. THE EMISSION CONTROL SYSTEM CONSISTS OF EI3HT VARIA-
BLE THROAT VENTURI/LIMESTCNE SIEVE TPAY TOWER TRAINS SUPPLIED BY SAECOCK
AND WILCOX. EACH 80X (S02 REMOVAL, DESIGN) EFFICIENT TRAIN is FOLLOWED BY
A COMBINATION SIEVE TRAY AND CHEVRON MIST ELIMINATOR. AKO AH INDI-
RECT REHEATER. THE CLEANED GAS EXITS THROUGH A 700 FOOT STEEL LINED STACK.
THE SYSTEM OPERATES IN A CLOSED MATER LOOP, AND THE SCRUESER SLUCGE IS
DISPOSED IN AN UNLINED POND. INITIAL OPERATIONS OF THE FGO SYSTEM BEGAN IN
FEBRUARY 1973.
KANSAS POWER
JEFFREY
1
NEW
& LIGHT
720 MW (GROSS)
540 MM (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: «***X
STATUS 1 STARTUP 6/78
KANSAS CITY POWER AND LIGHT'S JEFFREY 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (0.32X S, 8125 BTU/LB) UNIT IN WAMEGO. KANSAS. THE EMISSION CONTROL
SYSTEM FOR THIS UNIT CONSISTS OF A COLO SIDE ESP FOLLOWED BY SIX (ONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN S02 REMOVAL EFFICIENCY IS SOX (INCLUDING A 30X BYPASS REHEAT).
THE UNIT HAS BEEN OPERATIONAL SINCE AUGUST 1»78.
KANSAS POWER t LIGHT
JEFFREY
2
NEW 700 MW (GROSS)
490 MW (ESC)
COAL
.30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *»**X
STATUS 1 STARTUP 1/80
UNIT 2, PRESENTLY OPERATING AT KANSAS POWER AND LIGHT'S JEFFREY ENERGY
CENTER IN JEFFREY, KANSAS, BURNS 0.3X S PULVERIZED COAu (81CO BTU/LB).
THIS UNIT'S EMISSION CONTROL SYSTEM CONSISTS OF A COLO SIDE ESP
AND COMBUSTION ENGINEERING LIMESTONE SPRAY TOWERS. A 30X FLUE GAS
BYPASS PROVIDES REHEAT OF THE CLEANED GAS BEFORE IT EXITS TK=.CUGH A
600 FOOT STACK. THE SYSTEM OPERATES IN A CLOSED WATER LOOP MCOE, 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 4 LIGHT
LAURENCE
4
RETROFIT 125 MM (G°OSS)
1Z5 MM (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *«*«X
STATUS 1 STARTUP 1/77
LAURENCE 4 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 MA?BLE 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 CHEVP.CNS AND CN£ BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 20 OES F BEFOPE
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 MATER LOOP.
KANSAS POWER & LIGHT
LAURENCE
5
RETROFIT 420 MM (GROSS)
420 MM (ESC)
COAL
.55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »»*»X
STATUS 1 STARTUP 4/78
LAURENCE 5 OF KANSAS POWER AND LIGHT IS A BALANCED DRAFT, TANGENTIAL FIRED
PULVERIZED COAL (0.55X S, 10,000 BTU/LB) UNIT LOCATED IN LAWRENCE, KANSAS.
A NEW COMBUSTION ENGINEERING LIMESTONE ROD DECK/SPRAY TOWER SYSTEM
REPLACED THE EXISTING MARBLE BED TAIL END SCRUBBER IN APPIL 1*73. THE
SYSTEM TREATS 403.000 ACFM OF FLUE GAS, WITH A DESIGN S02 REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TWO CHEVRONS AND CNE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TWO MODULES. A FINNED TUBE
REHEATER BOOSTS THE TEMPERATURE OF THE CLEANED GAS BY 23 DEG F BEFCRE
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 HATER LOOP.
22
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1°81
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
KENTUCKY UTILITIES
GSEEH RIVER
1-3
RETROFIT 64 MM (GROSS)
64 MM (ESC)
COAL
4.00 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3.1X
STATUS 1 STARTUP 9/75
GREEN RIVER 1-3 OF KENTUCKY UTILITIES ARE THREE DRY BOTTOM FULVE=IZ£D
BITUMINOUS COAL (4X S. 11.000 BTU/LB) PIPED UNITS LOCATED IN CEMTPAL
CITY, KENTUCKY. EACH BOILER SUPPLIES 360.OCO ACFM OF FLUE GAS TO A
VARIABLE THROAT VEHTU3I FOLLOWED BY AN AMERICAN AIR FILTER LL"= MC3ILE
BED CONTACTOR (BOX DESIGN S02 REMOVAL EFFICIENCY). A PAOIAL VANE MIST
ELIMINATOR IS FOLLOWED BY A STEAM TU3E REHEATER AN3 A 165 FOOT STACK.
SLUCGE IS DISPOSED IN AH CM-SITE UNLItJED POND, AND THE SI STEM OFEFiTES
IN A CLOSED WATER LOOP. THE SYSTEM HAS BEEN OPERATIONAL SINCE SEPTEMBER
1975.
KENTUCKY UTILITIES
HANCOCK
1
NEU 706 MM (GROSS)
650 MM (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
BABCOCK t MILCOX
ENERGY CONSUMPTION: »*»*X
STATUS 4 STARTUP 4/89
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO HEW 650 MM (NET) PULVERIZED
COAL (3.5X S, 10,500 BTU/LB) FIRED BOILERS. THE UNITS, HANCCCK 1 AK3 2,
ARE TO BE LOCATED IN HAUESVILLE, KENTUCKY. THE UTILITY HAS SIGNED A LET-
TER OF INTENT WITH B & M FOR A MET LIMESTONE SCRU23INS SYSTEM WHICH MILL
OPERATE IN A CLOSED MATER LOOP MODE TO CONTROL EMISSIONS. HANCCCK 1 AND 2
ARE SCHEDULED TO COMMENCE OPERATION IN 1939 AND 1994. RESPECTIVELY.
KENTUCKY UTILITIES
HANCOCK
2
MEW 708 MM (GROSS)
650 MM (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »»*«X
STATUS 6 STARTUP 4/94
KENTUCKY UTILITIES HAS PLANS TO CONSTRUCT TWO NEW 650 MM (NET) PULVERIZED
COAL (3.5X S. 10,500 BTU/LB) FIRED BOILERS. THE UNITS, HANCCCK 1 AND 2,
ARE TO BE LOCATED IN HAUESVILLE, KENTUCKY. THE UTILITY IS PRESENTLY
INVESTIGATING A MET LIMESTONE SCRUBBING SYSTEM WHICH MILL OPERATE IN A
CLOSED MATER LOOP MODE TO CONTROL EMISSIONS. HANCOCK 1 AND 2 ARE SCHED-
ULED TO COMMENCE OPERATION IN 1988 AND 1994, RESPECTIVELY.
LAKELAND UTILITIES
MCINTOSH
3
NEW 364 MM (GROSS)
364 MM (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BAGCOCK & UILCOX
ENERGY CONSUMPTION: *»»»X
STATUS 2 STARTUP 1/82
MCINTOSH 3 OF LAKELAND UTILITIES IS BEING CONSTRUCTED IN LAKELAND,
FLORIDA. BABCOCK AND MILCOX HAS BEEN AMARDED A CONTRACT TO SUPPLY AN
85X EFFICIENT (S02) LIMESTONE FGD SYSTEM FOS THIS UNIT. THE EMISSION CON-
TROL SYSTEM MILL CONSIST OF A COLO SIDE ESP FOLLOWED BY TWO PARALLEL FGD
MODULES AND A 250 FOOT ACID BRICK LINED STACK. THE SYSTEM MILL OPERATE IN
A CLOSED MATER LOOP, AND THE POZ-0-TEC STABILIZED SLUDGE MILL BE USED AS
A CONSTRUCTION BASE. CONSTRUCTION BEGAN IN NOVEMBER 1979 AND START-
UP IS SCHEDULED TO BE IN JANUARY 1982.
LANSING BOARD OF MATER I LIGHT THE ERICKSON 2 STATION OF THE LANSING BOARD OF MATER AND LIGHT IS A
ERICKSON
2
NEW
160 MM (GROSS)
160 MM (ESC)
CCM.
PLANNED UNIT TO BE LOCATED IN DELTA TOWNSHIP, MICHIGAN. THE UNIT WILL
HAVE A MU 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.
XS
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««H(X
STATUS 6 STARTUP 1/87
LOS ANGELES OEPT OF WTR » PWR
INTERMOUNTAIN
1
NEM 820 MM (GROSS)
620 MM (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»««x
STATUS 6 STARTUP 0/86
THE LOS ANGELES DEPARTMENT OF MATER AND POWER HAS PLANS FCR FOUR NEM
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820 MM BOILER MILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LBI
AND MILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUB3IN3 SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER ALONG WITH A HOT SIDE ESP IS UiDER
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.
23
-------
EPA UTILITY FGO SURVEY: OCTC3E3 - DECEMBER 1981
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDEMTIFICATIOH
ABSTRACT
LCS AUGELES DEPT OF HTR £ PWR
INTERKC'JNTAIM
NEW 320 M.J IG-CSSI
820 m (ESC)
COAL
.79 7.5 SU33ITUMINCUS
LIME
VENDOR NOT SELECTED
EUIRGY CONSUMPTION; «***x
STATUS 6 STARTUP 0/37
THE LOS ANGELES DEPARTMENT OF MATER AND POWER HAS PLANS FCP FOUR MEW
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4. TO BE LOCATED IN DELTA. UTAH.
EACH 820 hVI BOILER MILL FIRE PULVERIZED COAL (0.7«X S, 10,CCQ ETU/L3)
AND MILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A MET LIME SCSUBBIt.S SYSTEM.
A HORIZONTAL WEIR TYPE SCRUBBER ALONG MITH A HOT SIDE ESP IS UN3E3
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
MILL EXIT A 750 FOOT STACK. UNIT 2 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1967.
LOS ANGELES DEPT OF WTR t PUR
INTERMOUNTAIN
3
NEM 820 KM (GROSS)
820 MM (ESC)
COAL
.79 7.S SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »***X
STATUS 6 STARTUP 0/88
THE LOS ANGELES DEPARTMENT OF MATER AND POMER HAS PLANS FOR FOUR NEW
EOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA. UTAH.
EACH 820 MM BOILER MILL FIRE PULVERIZED COAL (0.797. S, 10,203 BTU/LB)
AND MILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A MET LIME SCRU5EIN3 SYSTEM.
A HORIZONTAL MEIR TYPE SCRUBBER ALONG MITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
MILL EXIT A 750 FOOT STACK. UNIT 3 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1988.
LOS ANGELES OEPT OF HTR & PMR
INTERMOUNTAIN
4
NEM 820 KM (GROSS)
820 MM (ESC)
COAL
.79 XS SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «*«*X
STATUS 6 STARTUP 0/89
THE LOS ANGELES DEPARTMENT OF HATER AND POMER HAS PLANS FOR FOUR NEM
BOILERS, INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA. UTAH.
EACH 820 MM BOILER MILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND HILL SUPPLY 5,400,000 ACFM OF FLUE GAS TO A UET LIME SCRUBBING SYSTEM.
A HORIZONTAL MEIR TYPE SCRUBBER ALONG HITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE UTILITY FOR EMISSION CONTROL. THE CLEANED FLUE GAS
MILL EXIT A 750 FOOT STACK. UNIT 4 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1989.
LOUISVILLE GAS t, ELECTRIC
CANE RUN
4
RETROFIT 188 MM (GROSS)
188 MM (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) FIPED 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 FCLLCMEO BY A DIRECT
COMBUSTION REHEATER AND A 250 FOOT STACK. THE HATER LOOP IS OPEN, AND
THE SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL. THIS RETROFIT SYSTEM
HAS BEEN OPERATIONAL SINCE AUGUST 1976.
LOUISVILLE GAS t ELECTRIC
CANE RUN
5
RETROFIT 200 MM (GROSS)
200 MM (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.5X
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 TMO 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 HATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED. OPERATION OF THIS RETROFIT SYSTEM
BEGAN IN DECEMBER 1977.
LOUISVILLE GAS t ELECTRIC
CANE RUN
6
RETROFIT 299 MM (GROSS)
299 MM (ESC)
COAL
4.80 XS BITUMINOUS
DUAL ALKALI
THYSSEN/CEA
ENERGY CONSUMPTION: l.OX
STATUS 1 STARTUP 4/79
LOUISVILLE GAS AND ELECTRIC'S CANE RUN 6 IS A 299-MM (GnOSS) BITUMINOUS
COAL (4.SOX S, 11,500 BTU/LB) FIRED UNIT LOCATED IN LOUISVILLE.
KENTUCKY. THYSSEN/CEA SUPPLIED A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS UNIT. THE EMISSION CONTROL SYSTEM, DESIGNED TO REMOVE
95X OF THE FLUE GAS S02, CONSISTS OF A COLD SIDE ESP AND TWO TRAY TOMER
MODULES. THE CLEANED GAS PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TMO
DIRECT COMBUSTION REHEATERS BEFORE EXITING A 518 FOOT STACK. THE HATER
LOOP IS OPEN, AND THE SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL.
FOR A ONE YEAR PERIOD FOLLOWING THE FIRST QUARTER OF OPERATION (WHICH BE-
GAN IN APRIL 1979), THE U.S.EPA SUBSIDIZED THE OPERATIONS (FOR $4.5 MAX)
FOR RiO AND REPORT WRITING.
24
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEASES 1931
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
LOUISVILLE GAS & ELECTRIC
MILL CREEK
1
RETROFIT 353 MM (GROSS)
358 MM (ESC)
COAL
3.75 XS BITUMINOUS
Lir.E
CC :SUSTIOH 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 OFEPATrNG
ON THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) PIPED UNIT. CC"2U3TION
ENGINEERING SUPPLIED THE LIME/LIMESTONE FGO SYSTEM WHICH IS SCHEDULED
TO COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1931.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
2
RETROFIT 350 KM (GROSS)
350 MM (ESC)
COAL
3.75 XS .BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4SC
STATUS 1 STARTUP 12/81
MILL CREEK 2 OF LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LCL-ISVILLE, KEN-
TUCKY. A RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY OPERATING CM
THIS PULVERIZED COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT. CCM3USTICN
ENGINEERING SUPPLIED THE LIME/LIMESTONE FGD SYSTEM WHICH IS SCHEDULED TO
COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1932.
LOUISVILLE GAS & ELECTRIC
MILL CREEK
3
NEM 427 MM (GPOSS)
427 MM (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: *»»*X
STATUS I 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 MAS DESIGNED TO REMOVE
85X OF THE S02 FROM THE FLUE GAS. AN ESP IS FOLLOWED BY FCL'S MD3ILE BED
CONTACTORS AND A STEAM TUBE REHEATER. THE MATER LOOP IS OPEN, AND THE
FLYASH AND LIME STABILIZED SLUDGE IS PONDED. THIS UNIT HAS BEEN OPERATION-
AL SINCE AUGUST 1978.
LOUISVILLE GAS t ELECTRIC
MILL CREEK
4
NEM 495 MM (GROSS)
495 MM (ESC)
COAL
3.75 XS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: »»««X
STATUS 2 STARTUP 6/82
MILL CREEK 4 OF LOUISVILLE GAS AND ELECTRIC IS A PULVERIZED BITUMINOUS
COAL (3.75X S, 11,500 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN LOUISVILLE,
KENTUCKY. THE EMISSION CONTROL SYSTEM MILL CONSIST OF AN ESP AND FOUR
MOBILE BED CONTACTORS. THE SYSTEM'S HATER LOOP MILL BE CLOSED, AND
THE SLUCGE HILL BE STABILIZED HITH LIME AND FLYASH. STEAM TUBES WILL
PROVIDE REHEAT OF THE CLEANED GASES. THE SYSTEM 13 SCHEDULED TO START-
UP IN JUNE 1982.
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
RETROFIT 72 MM (GROSS)
72 MM (ESC)
SEAL
2.50 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.8X
STATUS 1 STARTUP 4/73
UNIT 6 AT LOUISVILLE GAS AND ELECTRIC'S PADDY'S RUN STATION IS A DRY BOT-
TOM PULVERIZED COAL (2.5X S, 11,500 BTU/LB) FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. A RETROFIT CARBIDE LIME FGD SYSTEM BY COMBUSTION ENGINEERING TREATS
400,000 ACFM OF FLUE GAS FROM THE BOILER. AN ESP IS FOLLOWED BY TWO MA=3LE
BED ABSORBERS, A DIRECT COMBUSTION REHEATER, AND A 250 FOOT STACK. MIST
ELIMINATION IS PROVIDED BY ONE CHEVPON/MODULE. THE LIME FIXATED SLLCSE IS
TRUCKED TO AN UNLIHEO POND, AND THE MATER LOOP IS CLOSED. THE FGO SYSTEM
BEGAN INITIAL OPERATIONS IN APRIL 1973.
LOUISVILLE GAS & ELECTRIC
TRIMBLE COUNTY
1
NEH 575 MM (GROSS)
575 MM (ESC)
COAL
4.00 XS BITUMINOUS
PROCESS NOT SELECTED
VEKDOH NOT SELECTED
ENERGY CONSUMPTION: *»*»'/.
STATUS 5 STARTUP 7/85
LOUISVILLE GAS AND ELECTRIC HILL BE INSTALLING FGD SYSTEMS CN TWO OF THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATION IN BEDFORD,
KENTUCKY. THE PULVERIZED 4X S (IF NO COAL HASH IS INCLUDED) COAL FIRED
UNITS' FLUE GAS HILL BE CLEANED BY ESP'S AND MET SCRUBBING !90X PEMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 1 IS SCHEDULED
FOR START-UP IN JULY 1985.
25
-------
EPA UTILITY FGO SUPVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ASSTPACT
LCJISVILLE GAS & ELECTRIC
TRIC3LE COUNTY
Z
NEW 575 Mrf (G30SS)
575 MM (ESC)
COAL
4.00 XS BITUMINOUS
FPCCESS HOT SELECTED
VEfOCT NOT SELECTED
ENERGY CONSUMPTION: ***«X
STATUS 5 STARTUP 7/89
LOUISVILLE GAS AND ELECTRIC WILL BE INSTALLING FGO SYSTEMS CM T'nO Or THE
FOUR BOILERS AT THE UTILITY'S PLANNED TRIMBLE COUNTY STATICN II) EsCFC=Di
KENTUCKY. THE PULVERIZED V/. S (IF NO COAL WASH IS INCLUDED) COiL FIRED
UNITS' FLUE GAS MILL BE CLEANED BY ESP'S AND WET SCFUS3IN3 (9CX REMOVAL
EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT Z IS SCHESULED
FOR START-UP IN 1939.
LOWER COLORADO RIVER AUTH
FAYETTE POWER PROJECT
3
MEM 435 MM (GROSS)
435 MM (ESC)
LIGNITE
1.70 XS
LIMESTONE
VEU2CR NOT SELECTED
ENERGY CONSUMPTION: a.ax
STATUS 6 STARTUP 0/88
LOWER COLORADO RIVER AUTHORITY HAS PUNS TO CONSTRUCT A 435 MM 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 WET LIMESTONE SCRUBBING
SYSTEM DESIGNED TO REMOVE 90X S02. OPERATIONS ARE SCHEDULED TO COMMENCE
IN 1988.
MAEQUETTE BOARD OF LIGHT t
SHIRAS
3
MEM 44 MM (GROSS)
44 MM (ESC)
COAL
•***«* XS
LIME/SFRAY DRYING
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «***X
STATUS Z STARTUP 9/62
PUR SHIRAS 3 OF THE MARQUETTE BOARD OF LIGHT AND POWER IS A PULVERIZED COAL
FIRED BOILER UNDER CONSTRUCTION IN MARGUETTE, MICHIGAN. THE UTILITY
HAS AWARDED A CONTRACT TO GE ENVIRONMENTAL SERVICES FOR A LIME/SPPAY
DRYING PROCESS TO CONTROL EMISSIONS. THE SYSTEM WILL UTILIZE A FAERIC
FILTER TO OBTAIN A PARTICLE REMOVAL EFFICIENCY OF 99.67.. THE UNIT IS
SCHEDULED TO COMMENCE OPERATIONS IN SEPTEMBER 1982.
MICHIGAN SO CENTRAL PMR AGENCY
PROJECT
1
NEW 55 MM (GROSS)
55 MM (ESC)
COAL
2.25 XS BITUMINOUS
LIMESTONE
BABCCCK £ MILCOX
ENERGY CONSUMPTION: 1.8X
STATUS 2 STARTUP 6/82
THE PROJECT 1 UNIT OF MICHIGAN SOUTH CENTRAL POMER AGENCY IS UNDER CON-
STRUCTION IN LITCHFIELD, MICHIGAN, AND WILL UTILIZE A MET LIMESTONE FGO
PROCESS. THE PULVERIZED COAL FIRED BOILER MILL FEED ITS FLUE GAS THROUGH
A HOT SIDE ESP FOLLOWED BY A BABCOCK AND WILCOX LIMESTCNE EPP4Y TCMER.
THE CLEANED GAS MILL PASS THROUGH A MIST ELIMINATOR BEFCPE BEING HEATED
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
NEM 890 MM (GROSS)
890 MM (ESC)
COAL
.50 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »«*»x
STATUS 4 STARTUP 0/90
UNIT 1 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.5X S) FIRED
BOILER. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH
COMBUSTION ENGINEERING FOR A WET LIMESTCNE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
6
NEW 690 MM (GROSS)
890 KM (ESC)
COAL
.50 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *»*»X
STATUS 4 STARTUP 0/92
UNIT 2 OF THE ARKANSAS ENERGY LIGNITE CENTER IS A LIGNITE (.5X S) FIREO
BOILER. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT HITH
COMBUSTION ENGINEERING FOR A WET LIMESTCNE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
26
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEASES 1931
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MICOLE SOUTH UTILITIES
UHASSIGNEO
1
NEW 890 KM (GROSS)
890 KM (ESC)
COAL
.50 XS
LIHESTCNE
CCMSUSTION ENGINEERING
ENERGY CONSUMPTION: •****•/.
STATUS 4 STARTUP 0/89
KIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH CC^3L'STIC'l
EN5INEERING FOR A MET LIMESTONE SCRUBBING SYSTEM TO CCNTrOL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED. THE PLANT HILL BE LOCATED
SOMEWHERE IN LOUISIANA. START-UP IS SCHEDULED FOR 19S9.
MIDDLE SOUTH UTILITIES
UNASSIGNED
Z
NEM 890 KM (GROSS)
890 KM (ESC)
COAL
.50 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »«««X
STATUS-* STARTUP 0/93.
MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH CCM3USTION
ENGINEERING FOR A MET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS.
THE PLANT NAME HAS NOT BEEN ASSIGNED. THE PLANT MILL BE LOCATED
SCMEMHERE IN LOUISIANA. START-UP IS SCHEDULED FOR 1993.
MIDDLE SOUTH UTILITIES
HILTON
1
NEM 690 KM (GROSS)
890 KM (ESC)
COAL
.50 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »«*»X
STATUS 4 STARTUP 0/88
HILTON 1 IS A COAL ( .SOX. S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT MITH CCMEL'S-
TION ENGINEERING FOR A MET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CCNTROL. START-UP IS SCHEDULED FOR 1968.
MIDDLE SOUTH UTILITIES
MILTON
2
NEM 690 MM (GROSS)
890 KM (ESC)
COAL
.50 XS
LIMESTONE
COM2USTION ENGINEERING
ENERGY CONSUMPTION: **»»X
STATUS ft STARTUP 0/91
HILTON 2 IS A COAL (.SOX S) FIRED BOILER TO BE LOCATED IN CONVENT, LOUI-
SIANA. KIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT MITH COMBUS-
TION ENGINEERING FOR A MET LIMESTONE SCRUBBING SYSTEM FOR EMISSION
CONTROL. START-UP IS SCHEDULED FOR 1991.
MINNESOTA POMER S LIGHT
CLAY BOSMELL
4
ISM 554 KM (GPOSS)
475 KM (ESC)
CCDAL
i>- .94 XS SUEBITUMINOUS
LIKE/ALKALINE FLYASH
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
STATUS 1 STARTUP 4/80
CLAY BOSMELL 4 OF MINNESOTA POWER AND LIGHT IS A EUBBITUMINCUS COAL (0.94X
S, 6896 BTU/LB) FIPEO UNIT LOCATED IN CCHASSET, MINNESOTA. PEABCQY
PROCESS SYSTEMS HAS SUPPLIED A LIME/ALKALINE FLYASH SYSTEM MHICH
IS DESIGNED TO REMOVE 84.6X OF THE S02 IN THE FLUE GAS. TWO HOT SIDE ESP'S
ARE FOLLOWED BY VENTURI/SPRAY TOMER TRAINS. MIST ELIMINATION IS PSOVIOEO
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.
MIH.VKOTA POWER
MILTON R. YOUNG
2"
NEM 440 MM (GROSS)
185 MM (ESC)
COAL
.70 XS LIGNITE
LIME/ALKALINE FLYASH
THYSSEN/CEA
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) BOILEP 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 THYSSEN/CEA LIME/ALKALINE FYLASH SPRAY TOWERS (75X DESIGN
S02 REMOVAL EFFICIENCY). THE CLEANED GAS PASSES THROUGH A CHEVRON
MIST ELIMINATOR BEFORE IT JOINS A 15X BYPASS REHEAT (HOT UNSCRL'EBED
GAS), AND EXITS A 550 FOOT STACK. THE HATER LOOP IS OPEN, AND THE
SLUDGE IS TRUCKED TO AN OFF-SITE MINEFILL. OPERATIONS BEGAN IN 1977.
27
-------
EPA UTILITY FGC SVVEY: OCTC3E? - DECEMBER 1981
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABS-'ACT
MCN3NGAHELA POWER
PLEASANTS
1
MEM
668 MM (C-POSS)
668 MM (ESC)
BITUMINOUS
COAL
3.00 XS
LIME
3ABCOCK & HILCOX
ENERGY CONSUMPTION: *»»»X
STATUS 1 STARTUP 3/79
MCNONGAHELA POWER PLEASANTS 1 IS A BITUMINOUS COAL (5.70X S. 12.150
BTU/LB) FIRED BOILER IN BELMONT, WEST VIRGINIA. BA3CCCK AND WILCCX SUP-
PLIED A LIME FGO SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS SCC FPCM
THIS UNIT. THE EMISSION CONTPOL SYSTEM INCLUDES AH ESP UFSTPEAM CF FOUR
SF3AY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED GAS BEFORE IT IS DISCHARGED THROUGH A 1200 FC3T PLACITE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM CM THIS
UNIT HAS BEEN OPERATIONAL SINCE MARCH 1979.
MONONGAHELA POWER
PLEASAHTS
2
NEM 666 MM (GPOSS)
663 MM (ESC)
COAL
3.00 XS BITUMINOUS
LIME
BA5COCK & MILCOX
ENERGY CONSUMPTION: «*«»X
STATUS 1 STARTUP 10/80
MONONGAHELA POMER PLEASANTS Z IS A BITUMINOUS COAL (4.5X S, 12150
BTU/LB) FIRED BOILER LOCATED IN BELMONT, WEST VIRGINIA. BA3COCK AND
MILCOX SUPPLIED A LIME FGD SYSTEM DESIGNED TO REMOVE 90X OF THE BOILER
FLUE GAS SOZ. THE EMISSION CONTROL SYSTEM CM THIS UNIT INCLUDES AN ESP
UPSTREAM OF FOUR SPRAY TOUER ABSORBERS. A FLUE GAS BYPASS SYSTEM PPOVIDES
REHEAT OF THE CLEANED GAS BEFCPE IT IS DISCHARGED THROUGH A 1200 FCOT
ACID BRICK STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGO
SYSTEM OPERATION COMMENCED IN OCTOBER 1980.
MONTANA POMER
COLSTRIP
1
NEM 360 MM (GROSS)
360 MM (ESC)
COAL
.77 XS SUB3ITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 9/75
COLSTRIP 1 OF MONTANA POMER IS A 360-MM (GROSS) SU3BITUMINCUS COAL
(0.77X S, 8843 BTU/LB) FIRED UNIT LOCATED IN COLSTRIP, MONTANA. THYSSEN-
CEA SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ASSCPSERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 500
FOOT STACK. THE UMSTABILIZED SLUDGE IS DISPOSED IN AN CN-SITE LINED POND.
THE HATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN SEPTEMBER 1975.
MONTANA POWER
COLSTRIP
2
NEW 360 MM (GROSS)
360 MM (ESC)
COAL
.77 XS SL'BBITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
STATUS 1 STARTUP 5/76
COLSTRIP 2 OF MONTANA POMER IS A 360-MM (GROSS) SU5BITUMINOUS COAL
(0.77X S, 88*3 BTU/LB) PIPED UNIT LOCATED IN COLSTRIP, MONTANA. THYSSEN
CEA SUPPLIED A LIME/ALKALINE FLYASH FGD SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS. THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON HIST ELIMINATORS, A STEAM TUBE REHEATER, AND A 500
FCOT STACK. THE UNSTASILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND.
THE MATER LOOP IS CLOSED. OPERATIONS INITIALLY BEGAN IN MAY 1976.
MONTANA POMER
COLSTRIP
3
NEM 700 MM (G°OSS)
700 MM (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: *»*»X
STATUS 2 STARTUP 10/83
MONTANA POWER'S COLSTRIP 3 IS A LOM SULFUR COAL (0.7X S, 8300 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS EEEN
AWARDED TO THYSSEH/CEA FOR A LIME/ALKALINE FLYASH FGO SYSTEM ON THIS UNIT..
START UP IS SCHEDULED FOR OCTOBER 1983.
MONTANA POWER
COLSTRIP
4
MEM 700 MM (GROSS)
700 MM (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
THYSSEH/CEA
EHEPGY CONSUMPTION: »«*«x
STATUS 2 STARTUP 0/84
MONTANA POWER'S COLSTRIP 4 IS A LOM SULFUR COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN COLSTRIP, MONTANA. A CONTRACT HAS EEEN
AWARDED TO THYSSEN/CEA FOR A LIME/ALKALINE FLYASH FGD SYSTEM ON THIS UNIT.
START UP IS SCHEDULED FOR 1984.
28
-------
EPA UTILITY FGD SURVEY: CCTCSER - DECEMBER 1981
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
MONTANA-DAKOTA UTILITIES
COYOTE
1
NEW 440 KM (GROSS)
440 MM (ESC)
COAL
.87 XS LIGNITE
SCDIL'M CAPSCMATE/SFRAY DRYING
U'HEELABRATOR-FRYE/R. I.
ENEPGY CONSUMPTION: i.ix
STATUS 1 STARTUP 4/81
COYOTE 1 IS A CYCLONE FIRED PULVERIZED LIGNITE (0.87X S. 7C50 BTU/L3)
BOILER OPERATING IN BEULAH, NORTH DAKOTA. THIS UNIT IS JOINTlf C'.Sil3
BY FIVE UTILITIES, WITH MONTANA-DAKOTA UTILITIES BEING THE HAJ2?
OWNER AND CONSTRUCTOR. AN AQUEOUS CAP50NATE DRY FGD SYSTEM Cf'IGNSD TO
REMOVE 70X OF THE S02 WAS SUPPLIED BY WHEELABRATCR-FRYE AN3 "-:<;;eLL
INTERNATIONAL. THE SPRAY ORYER/BAGHOUSE SYSTEM COMMENCED CFERATICN IN
APRIL 1981.
MUSCATINE POWER S WATER
MUSCATINE
9
NEW 166 MW (GROSS)
166 MW (ESC)
COAL
3.21 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.ax
STATUS 2 STARTUP 9/82
MUSCATIHE 9 IS A PULVERIZED BITUMINOUS COAL (3.21X S, 11,200 BTU/L3) FIREO
UNIT UNDER CONSTRUCTION IN MUSCATINE, ICMA. RESEARCH-COTTRELL IS
SUPPLYING A LIMESTONE SCRUBBING SYSTEM FOR EMISSION CONTROL. THE FGO
SYSTEM WILL FEATURE AN ESP, TWO 100X CAPACITY ABSORBER TCWEPS, STEAM COIL
REHEAT A CLOSED MATER LOOP, AND FORCED OXIDATION CF THE SLUDGE EEFCPE
LANDFILL. THE DESIGN S02 REMOVAL WILL BE 94X. START-UP IS SCHEDULED TO
TAKE PLACE IN 1982.
NEBRASKA PUBLIC POWER DISTRICT FOSSIL III 1 IS A PULVERIZED SUBBITUMINOUS COAL 10.35X S, 8000 BTU/LB)
FOSSIL III
1
NEW 650 KM (GROSS)
650 KM (ESC)
COAL
.36 XS SUSBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «««*X
STATUS 6 STARTUP 3/92
FIRED UNIT PLANNED BY THE NEBRASKA PUBLIC POWER DISTRICT TO BE LOCATED
NEAR SARGENT, NEBRASKA. THE UTILITY IS CONSIDERING A DRY SCRUS3IN5
FGO PROCESS TO CONTROL EMISSIONS FROM THE 650 MM BOILER. START-UP FOR
THE UNIT IS TENTATIVELY SCHEDULED FOR MARCH 1992.
NEVADA FCHER
HARRY ALLEN
1
NEW 500 MM (GROSS)
500 MM (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 FIPEO UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR JUNE 1986.
NEVADA POWER
HARRY ALLEN
Z
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 KM (GROSS)
500 KM (ESC)
COAL
*«»»» xs
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *««*X
STATUS 6 STARTUP 6/88
NEVADA POWER'S HARRY ALLEN 3 IS A PLANNED COAL FIPEO UNIT TO 3E LOCATED IN
LAS VEGAS. NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION HITH AN FGO SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR JUNE 1988.
29
-------
EPA UTILITY FGD SURVEY: CCTC3ES - DECSfSER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NEVADA FCWs=
HARRY ALLEN
4
NEW
COAL
SCO MW (GSOSS)
SCO MM (ESC)
NEVADA POWER'S HARRY ALLEN 4 IS A PLANNED COAL FIRED UNIT TO EE LOCATED IN
LAS VEGAS. NEVADA. THE UTILITY IS CONSIDERING A HOT SICE ES? IN CONJUNC-
TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START-
UP IS SCHEDULED FOR JUNE 1989.
FPCCESS NOT SELECTED
VEN3CR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 6/89
NEVADA POWER
REID GARDNER
1
RETROFIT 125 MM (GROSS)
IZS MM (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *»»*Z
STATUS 1 STARTUP 3/74
REID GARDNER 1 IS A 125-MH (GROSS) MET BOTTOM LOU SULFUR COAL (0.5X Si
12,450 BTU/LB) FIRED UNIT OWNED BY NEVADA POWER, LOCATED IN MOAPA, NEVADA.
THE THYSSEN/CEA SODIUM CARBONATE-BASED (TPQNA) SCRUBBING SYSTEM
CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THPOAT VENTURIS FOL-
LOWED 3Y A SEPARATOR IN SERIES WITH A SINGLE STAGE PEFCRATiD PLATE WASH
TCWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTPEAM KULTICLCS'ES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL RtHEATcR
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN MATER LOOP, AN3 THE
SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION PCMD. THE
DESIGN S02 REMOVAL EFFICIENCY IS 90X. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1974.
NEVADA POMER
REID GARDNER
2
RETROFIT 125 MM (GROSS)
125 MU (ESC)
COAL
.SO 7.5 BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *»»*x
STATUS 1 STARTUP 4/74
REID GARDNER 2 IS A 125-MH (GROSS) MET BOTTCM LOU SULFUR COAL (0.5X S,
12,450 BTU/LB) FIRED UNIT OWNED BY NEVADA PCWEP, LOCATED IN M3APA, NEVADA.
THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRCNA) SCRUBBING SYSTEM
CONSISTS OF ONE MODULE CONTAINING TMIH VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES MITH A SINGLE STAG; PEFCRATED PLATE WASH
TOMER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UFSTRE4M MULTICLCNES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL REHEATEP
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN MATER 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 APRIL 1974.
NEVADA POMER
REID GARDNER
3
NEM 125 MU (GPOSS)
125 MU (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *«»«X
STATUS 1 STARTUP 6/76
REID GARDNER 3 IS A 125-MU (GROSS) MET BOTTOM LOW SULFUR COAL (0.5X S.
12,450 BTU/LB) FIRED UNIT OWNED BY NEVADA POMER, LOCATED IN MOAPA, NEVADA.
THE THYSSEN/CEA SODIUM CARBONATE-BASED (TRONA) SCRUBBING SYSTEM
CONSISTS OF ONE MODULE CONTAINING TWIN VARIABLE THROAT VENTURIS FOL-
LOWED BY A SEPARATOR IN SERIES MITH A SINGLE STAGE PEFORATED PLATE WASH
TCWER. PRIMARY PARTICULATE CONTROL IS PROVIDED BY UPSTREAM MULTICLONES.
A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM COIL REHEATER
AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN MATER 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 POMER
REID GARDNER
4
NEM 250 MU (GROSS)
250 MU (ESC)
COAL
.75 XS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: *»*»X
STATUS 4 STARTUP 4/83
REID GARDNER 4 OF NEVADA POMER 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 MITH THYSSEN/CEA TO PROVIDE A SODIUM CARBONATE FGD SYSTEM. A
BAGHOUSE HILL PHECEED THE FGD SYSTEM FC1? PARTICULATE MATTER CCNTPOL
SCHEDULED START-UP OF THIS 250-MM (GROSS) UNIT IS EXPECTED IN AFPIL
1983.
NEW YORK STATE ELEC 4 GAS
SOMERSET
1
NEM 625 MU (GROSS)
625 MU (ESC)
COAL
2.20 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENEPGY CONSUMPTION: **»*•/.
STATUS 4 STARTUP 6/84
THE NEM YORK STATE ELECTRIC S GAS CORP. HAS PLANS TO BUILD A PULVE°IZE3
COAL FIRED BOILER IN SOMERSET, NEM YORK. THE BOILER IS TO GENERATE A
FLUE GAS FLOM OF 2,227,000 ACFM AND BURN A BITUMINOUS COAL WITH AN AVERAGE
SULFUR CONTENT OF 2.2X AND AH AVERAGE HEAT CONTENT OF 12,000 BTU/LB.
A COLD SIDE ESP MITH A DESIGN EFFICIENCY OF 99.77X MILL PROVIDE THE Prl-
MARY PARTICULATE REMOVAL. A LIMESTONE ABSORBER MITH A DESIGN PEI1CVAL
EFFICIENCY OF 90X MILL BE USED FOR S02 REMOVAL. THE SYSTEM HILL OPERATE
IN A CLOSED LOOP MODE. THE SLUDGE IS TO BE DEMATERED AND STABILIZED
BEFORE BEING LANDFILLED. OPERATIONS ARE SCHEDULED FCR 1984.
30
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NIAGARA MOHAWK POWER
CHARLES R. HUNTLEY
66
RETROFIT 100 MM (GPOSS)
100 MM (ESC)
COAL
1.80 ZS
AQUEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: *«**7.
STATUS 2 STARTUP 4/82
CHARLES R. HUNTLEY 66 OF NIAGARA POWER COOP IS A PULVERIZES COAL fl.SX S,
12,500 BTU/LB) FIRED UNIT LOCATED IN BUFFALO, NEW YCPK. A CC'ITPACT MAS
AWARDED TO ROCKWELL INTERNATIONAL FOR THE DESIGN AN3 INSTALLATION OF A °OX
EFFICIENT RETROFIT ACUEOUS CARBONATE FG3 SYSTEM UHICH HILL FPC3UCE ELEMEN-
TAL SULFUR AS AN END PRODUCT. FUNDS ARE BEINS PPOVIDEO BY THE U.S.EPA AND
THE EMPIRE STATE ELECTRIC ENERGY RESEARCH CORP. A SF=AY G°YE? WILL BE
FOLLOWED BY TWO BANKS OF 6 CYCLONES. AN ESP. AND A LINED 200 FCOT CASECN
STEEL STACK. THE MATER LOOP MILL BE OPEN. START-UP OF THE FGD SfSTEM MILL
BE IN
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL
11
RETROFIT 116 MM (GROSS)
115 MM (ESC)
COAL
3.50 XS
MELLMAN 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 MELLMAN
LORD FGO SYSTEM BY DAVY POMERGAS HAS BEEN OPERATING ON THIS UNIT SINCE
JULY 1976. AN ESP IS FOLLOMED BY A VARIABLE THROAT VENTU3I SC8U33ES
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 LIMED STACK.
ELEMENTAL SULFUR AND SODIUM SULFATE IS PRODUCED BY THE PROCESS DEVELOPED
BY ALLIED CHEMICAL. THE SYSTEM OPERATES IN A CLOSED MATER LCCP MQ3E.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
17
NEW 421 MM (GROSS)
421 MM (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: «*»*x
STATUS 2 STARTUP 6/83
SCHAHFER 17 OF NORTHERN INDIANA PUBLIC SERVICE IS A 3.2X SULFUR COAL FIRED
UNIT UNDER CONSTRUCTION IN MHEATFIELD, INDIANA. FMC IS INSTALLING
A DUAL ALKALI FGD SYSTEM FOR S02 EMISSION CONTROL. PARTICULATE
MATTER MILL BE COLLECTED BY AN ESP AND THE SYSTEM HILL INCLUDE A
REHEATER. START-UP OF THIS UNIT IS SCHEDULED FOR JUNE 1983.
NORTHERN INDIANA PUB SERVICE
SCHAHFER
18
NEW 421 MM (GROSS)
421 MM (ESC)
COAL
3.20 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: **»»x
STATUS 3 STARTUP 6/8S
SCHAHFER IB OF NORTHERN INDIANA PUBLIC SEPVICE IS A 3.2X SULFUR COAL FIRED
UNIT PLANNED FOR CONSTRUCTION IN MHEATFIELO, INDIANA. THE UTILITY HAS
AMARDED A CONTRACT TO FMC FOR THE INSTALLATION OF A DUAL ALKALI
FGO SYSTEM AT THIS UNIT. PARTICULATE MATTER MILL BE COLLECTED BY AN ESP
AND THE SYSTEM MILL INCLUDE A REHEATER. START-UP OF THIS UNIT IS
SCHEDULED FOR JUNE 1985.
NORTHERN STATES POWER
METRO COAL
1
.NEW 200 MM (GROSS)
200 MM (ESC)
NORTHERN STATES POWER HAS PLANS TO CONSTRUCT A 190 MM (NET) PULVERIZED COA
(l.OX S, 8700 BTU/LB) FIRED UNIT, METRO COAL 1. THE UNIT IS TO UTILIZE
A LIME SPRAY DRYING SYSTEM ALONG MITH FABRIC FILTERS TO CONTROL EMISSIONS.
OPERATIONS ARE SCHEDULED TO COMMENCE IN 1990.
1.00 XS SUBBITUMIHOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»*»x
STATUS 6 STARTUP 0/90
NORTHERN STATES POMER
RIVERSIDE
6-7
RETROFIT 110 MM (GROSS)
110 MM (ESC)
COAL
1.20 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: *«**X
STATUS 1 STARTUP 11/80
RIVERSIDE 6 AND 7 ARE TWO COAL FIRED BOILERS OWNED BY NORTHERN STATES
POKER 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 MAS SUPPLIED BY NIP.O
ATOMIZER/JOY MANUFACTURING AND CONSIST OF A SPRAY CRYE3 FOLLOWED BY
A BAGHOUSE. THE CLEAN FLUE GAS IS VENTED TO TWO 275 FT CONCRETE STACKS
MITH FIRE BRICK LINERS. SPENT ABSORBENT IS BEING DISPOSED OF IN AN
OFF-SITE LANDFILL. OPERATIONS COMMENCED IN NOVEMBER 1980.
31
-------
EPA UTILITY F6D SLAVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
NORTHERN STATES POUER
SHEPBUPNE
1
NEW 740 MM (C-°OSS)
740 MM (ESC)
COAL
.60 XS SUBBITUMINOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: Z.T/.
STATUS 1 STARTUP 3/76
NORTHERN STATES POWER'S SHERBUSHE 1 IS A BALANCED DRAFT PULVERIZED SL3BI-
TUMINCUS COAL (0.80X S, 8500 BTU/LB) FIRED EOILE9 IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
CCKSUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1976. TWELVE VARIABLE THROAT ROD DECK VENTU3I/MARBLE EED A3SCSBER TRAINS
ARE FOLLOWED BY CNc CHEVRON MIST ELIMINATOR/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COS-TEN LINED STACK. THE SLUDGE IS F03CI2LY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LCOP IS OPEN.
NORTHERN STATES POWER
SHERBURNE
2
MEM 740 MM (GROSS)
740 MM (ESC)
COAL
.80 XS SU33ITUMINCUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
STATUS 1 STARTUP 3/77
NORTHERN STATES POWER'S SHERBURNE Z IS A BALANCED DRAFT PULVERIZED SU33I-
TUMINOUS COAL (0.80X S, 8500 BTU/LB) FIRED BOILER IN BECKER, MINNESOTA. A
SOX EFFICIENT (DESIGN) LIMESTONE/ALKALINE FLYASH FGD SYSTEM SUPPLIED BY
COMBUSTION ENGINEERING HAS BEEN OPERATIONAL ON THIS UNIT SINCE MARCH
1977. TWELVE VARIABLE THROAT ROD DECK VENTURI/MARBLE BED ABSORBER TRAINS
ARE FOLLOWED BY ONE CHEVRON MIST ELIMINATOR/TRAIN, AN IN-LINE HOT WATER
REHEATER, AND A 650 FOOT COR-TEN LINED STACK. THE SLUDGE IS FORCIBLY OXI-
DIZED AND DISPOSED IN A CLAY LINED SETTLING POND. THE WATER LOOP IS OPEN.
NORTHERN STATES POWER
SHERSURNE
3
NEW 660 MM (GROSS)
810 MM (ESC)
COAL
1.00 XS SUBBITUMIHOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **>«x
STATUS 6 STARTUP 0/65
NORTHERN STATES POWER HAS PLANS TO CONSTRUCT A 800 MW (NET) PULVERIZED
COAL (l.OXS, 8700 BTU/LB) FIRED BOILER, SHERBU^HE 3, TO BE LOCATED NEXT TO
THE SHERBURNE 1 AND 2 UNITS IN BECKER, MINNESOTA. THE UTILITY IS CONSID-
ERING THE USE OF A LIME SPRAY DRYING PROCESS ALONG WITH FABRIC FILTERS TO
CONTROL EMISSIONS. THE SYSTEM IS SCHEDULED TO COMMENCE OPERATIONS IN 1985.
PACIFIC GAS
MONTEZUMA
1
NEW
t ELECTRIC
800 MM (GROSS)
800 MM (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENEPGY CONSUMPTION: 3.5*
STATUS 6 STARTUP 6/93
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 BAGHOUSE AND A LIMESTONE FGD SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START-UP IS SCHEDULED FOR 1993.
PACIFIC GAS & ELECTRIC
MCNTEZUMA
2
NEW 800 MM (GROSS)
800 MM (ESC)
COAL
.80 XS SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.5X
STATUS 6 STARTUP 6/94
MONTEZUMA 2 OF PACIFIC GAS AND ELECTRIC IS A COAL (0.8X S, 12,000 BTU/LB)
FIRED BOILER PLANNED FOR COLLINSVILLE, CALIFORNIA. THE EMISSION CONTROL
SYSTEM WILL CONSIST OF A BAGHOUSE AND A LIMESTONE FGO SYSTEM. SLUDGE WILL
BE DISPOSED OF IN A LANDFILL. START-UP IS SCHEDULED FOR 1994.
PACIFIC POWER S LIGHT
JIM BRIOGER
1
RETROFIT 550 MM (GPOSS)
550 MM (ESC)
COAL
.56 XS SU33ITUMINOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»««X
STATUS 6 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 POCK
SPRINGS, WYOMING. THE UTILITY IS CURRENTLY INVESTIGATING A RETROFIT"FSO
SYSTEM FOR S02 CONTROL. A WET, SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLO-SIDE ESP IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE CONTROL. START-UP IS SCHEDULED
FOR 1988.
32
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
SECTION Z
STATUS OF FGD SYSTEMS
UHIT IDENTIFICATION
ABSTRACT
PACIFIC PCHER 4 LIGHT
JIM BRIDGER
2
RETROFIT 550 MM (GROSS)
550 MM (ESC)
COAL
.56 XS SU2BITUMINOUS
SDDIIJM CAPEGNATE
VEHCOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 STARTUP 0/90
PACIFIC POWER AND LIGHT'S JIM ERIDGER 2 IS A DRY EOTTOM PULVERIZED SL3-
BITUMINOUS COAL (0.56XS, 9300 BTU/LB. ) FIPED BOILER LCCATE3 IH SCCK
SPRINGS, UYOMIHG. THE UTILITY IS CURRENTLY INVESTIGATING A RETFCrIT FGQ
SYSTEM FOR S02 CONTROL. A WET, SODIUM CAPEOMATE SYSTEM, UrtlCH TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED. A COLO-SIDE ESP IS CUSPENT-
LY IN OPERATION FOR PPIMARY PARTICULATE CONTROL. START-UP IS SCHEDULED
FOR 1990.
PACIFIC POWER & LIGHT
JIM BRIDGER
2A
RETROFIT 550 MM (GROSS)
100 MM (ESC)
COAL
.56 XS SU33ITUMINOUS
LIME/SODIUM CARBONATE
FLAKT
ENERGY CONSUMPTION: »»**X
STATUS 2 STARTUP 1/82
PACIFIC POWER 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 CURRENTLY CONSTRUCTING A DEMONSTRATION
LIME (ALSO SODIUM CARBONATE I/SPRAY DRYING FGD SYSTEM CAPABLE OF TPEATIN3
ONE SIXTH OF THE TOTAL FLUE GAS FLOW FRCM THE BOILER. A SLIP STREAM OF
APPROXIMATELY 400000 ACFM AT 25O F FRCM DOWNSTREAM OF THE AIR FSEKEATER
MILL BE TREATED. OUTLET GAS FROM THE SPRAY CPYER MILL THEN EE DUCTED BACK
PRIOR TO THE PRESENT COLO SIDE ESP. THE SYSTEM IS SUPPLIED BY FLAKT AND
A/E IS A JOINT VENTURE BETWEEN FLAKT AND PACIFIC POWER ft LIGHT. STARTUP
IS SCHEDULED FOR JANUARY 1982.
PACIFIC POWER ft LIGHT
JIM BRIOGER
3
RETROFIT 550 MU (GROSS)
550 MU (ESC)
COAL
.56 XS SUBBITUMINQUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6 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 CURRENTLY INVESTIGATING 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. START-UP IS SCHEDULED
FOR 1986.
PACIFIC POWER ft LIGHT
JIM BRIDGER
4
NEW 550 MU (GROSS)
550 MU (ESC)
COAL
.56 XS SUB3ITUMINOUS
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
SU3BITUMINOUS COAL (0.56X S, 9300 BTU/LB) FIRED BOILER LOCATED IN
ROCK SPRINGS. WYOMING. A 91X EFFICIENT SCDIUM CARBONATE FGD SYSTEM FOR
THIS UNIT MAS 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 MATER LOOP TQOE. A
SYSTEM CHECK OUT WAS CONDUCTED IN JULY 1979, AND OPERATIONS BEGAN
IN SEPTEMBER 1979.
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
HEW 917 MU (GROSS)
917 MU (ESC)
3.00 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
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) IM SHIPPINGPCST,
PENNSYLVANIA. A GEESI THIOSORBIC LIME FGO SYSTEM WAS DESIGNED TO REMOVE
FLYASH AND S02 (92.IX) FROM 3,350,000 ACFM OF FLUE GAS. THE FGO SYSTEM
CONSISTS OF SIX VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY SIX FIXED
THROAT VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TV.O 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
MATER LOOP IS OPEN. AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF-SITE POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE OECEI3ER 1975.
PENNSYLVANIA POWER
BRUCE MANSFIELD
2
NEW 917 MU (GROSS)
917 MU (ESC)
COAL
3.00 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
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 SHIPPINSP03T,
PENNSYLVANIA. A GEESI THIOSORBIC LIME FGD SYSTEM MAS DESIGNED TO RErOVE
FLYASH AND S02 (92.IX) FPOM 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 CCT3US-
TION REHEATERS (INCLUDED IN ORIGINAL DESIGN BUT LATER REMOVED FPOM
SERVICE) AND A 950 FOOT FLAKEGLASS STACK SHARED BY UNITS 1 AND 2. THE
MATER LOOP IS OPEN, AND THE CALCILOX STABILIZED SLUDGE IS DISPOSED IN
AN OFF-SITE POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
33
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PENNSYLVANIA TOMER
BRUCE MANSFIELD
3
HEW 917 MM (GROSS)
917 KM (ESC)
COAL
3.00 XS
LINE
M.H. KELLOGG
ENEPGY CONSUMPTION: «»»»x
STATUS 1 STARTUP 6/80
BPUCE MANSFIELD 3 OF PENNSYLVANIA POWER IS A SUPERCRITICAL PULVERIZED
COAL (3.OX S, 11,500 BTU/LB) FIRED BOILER LOCATED IH SHIPPIN3POPT,
PENNSYLVANIA. FOUR ESP'S TREAT 3,308,000 ACFM OF FLUE GAS, FOLLOWED
BY FIVE (ONE SPARE) M. M. KELLCGG THIOSORBIC LIME ABSCRBEPS WHICH
REMOVE 92.2X OF THE S02. THE CLEANED GAS PASSES THROUGH
CHEVRON MIST ELIMINATORS AND DIRECT CCr.3USTIQM REHEATERS BEFORE
DISCHARGE THROUGH A 600 FOOT INCONEL 625 STACK FLUE. THE FLYASH STA-
BILIZED SLUDGE IS PIPED TO AN OFF-SITE LANDFILL. OPERATIONS COMMENCED
IN JUNE, 1980.
PHILADELPHIA ELECTRIC
CROKBY
1
RETROFIT 150 HU (GROSS)
150 MM (ESC)
COAL
3.00 XS
MAGNESIUM 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 TMO 3.OX SULFUR COAL FIRED BOILERS AT CROMBY STATION IN PHOEHIX-
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 240 MM (GROSS)
240 MM (ESC)
COAL
2.60 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: *«*»X
STATUS 2 STARTUP 12/82
UNIT 1 OF PHILADELPHIA ELECTRIC'S EDDYSTONE, PENNSYLVANIA STATION IS A
BITUMINOUS COAL (2.6X S, 13,600 BTU/LB) FIRED UNIT WHICH USES ESP'S,
MECHANICAL COLLECTORS, AND THREE PARTICLE SCRUBBERS (TMO ROD DECK SPRAY
TOWERS AND ONE VENTURI) FOR PRIMARY PARTICLE CONTROL. THE UNIT 1 FGD
SYSTEM MILL FOLLCM THE TMO ROD DECK SPRAY TOMERS. UNITED ENGINEEPS
IS SUPPLYING A MAGNESIUM OXIDE FGD SYSTEM FOR S02 EMISSION CONTROL
SIMILAR TO THE MAGNESIUM OXIDE PROTOTYPE SYSTEM THAT MAS PREVIOUSLY
OPERATED AT THIS UNIT. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1982.
PHILADELPHIA ELECTRIC
EDOYSTONE
2
RETROFIT 334 MM (GROSS)
334 MM (ESC)
COAL
2.50 XS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****x
STATUS 2 STARTUP 12/82
EDDYSTONE 2 OF PHILADELPHIA ELECTRIC IS A 2.5X SULFUR COAL FIRED BOILER
LOCATED IN EDDYSTONE, PENNSYLVANIA. THE PLANT'S GENERATING
CAPACITY IS 334 MM. UNITED ENGINEERS WILL SUPPLY A MAGNESIUM OXIOE
FGO SYSTEM FOR EMISSION CONTROL. START-UP IS SET FOR DECEMBER 1982.
PLAINS ELECTRIC G & T
PLAINS ESCALANTE
1
NEM 233 MM (G10SS)
233 MM (ESC)
COAL
.80 XS SUBBITUMINOU3
LIMESTONE
COMSUSTION ENGINEERING
ENERGY CONSUMPTION: «»*»X
STATUS 2 STARTUP 12/83
PLAINS ESCALANTE 1 IS A PULVERIZED SUBBITUMINOUS COAL FIRf UNIT PLANNED
BY PLAINS ELECTPIC G i T COOPERATIVE TO BE LOCATED IN PRExITT, NEW MEXICO.
THE 233 MM UNIT MILL UTILIZE A MET LIMESTONE SCRUBBING PROCESS FOR S02
REMOVAL AND A FABRIC FILTER FOR PRIMARY PARTICLE CONTROL. A CONTRACT
HAS BEEN AMARDED TO COMBUSTION ENGINEERING FOR THE MET LIMESTONE SYSTEM.
THE UNIT INITIAL START-UP IS PROJECTED FOR DECEMBER 1933.
PLATTE RIVER POWER AUTHORITY
RAWHIDE
1
NEM 279 MM (GROSS)
279 MM (ESC)
COAL
.25 XS BITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ****•/.
STATUS 3 STARTUP 12/83
THE PLATTE RIVER POWER AUTHORITY HAS PLANS TO CONSTRUCT RAWHIDE 1, IN
FT. COLLINS, COLORADO. THE 279 HW PULVERIZED COAL (0.25X S, 8702 BTU/LB)
FIRED BOILER MILL BE SUPPLIED BY COMBUSTION ENGINEERING. A CONTRACT HAS
BEEN AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A DRY LIME SCRUBBING
SYSTEM FOR EMISSION CONTROL. SLUDGE MILL BE DISPOSED OF IN A LANDFILL.
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN DECEMBER 1983.
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEKSER 1931
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
PUBLIC SERVICE INDIANA
GIBSON
5
NEM 650 KM (GROSS)
650 MM (ESC)
COAL
3.50 XS
LIMESTONE
n.M. KELLOGG
ENERGY CONSUMPTION: »»«*X
STATUS 2 STARTUP 6/82
GIBSON 5 OF PU3LIC SERVICE OF INDIANA IS A 3.3X SULFUR COAL FIPE3 UNIT
UNDER CONSTRUCTION IN PRINCETON. INDIANA. A CONTRACT WAS AV,'i=DED TO
M. W. KELLOSG FOR A LIMESTONE FGO SfSTEM CONSISTING OF FCU3 KELLC33-
WEIR ABSORBER-REACTOR MC3ULES. SYSTEM START UP IS EXPECTED IN 1S3C. THE
SYSTEM WILL USE KELLOGG'S PROPRIETARY MAGNESIUM-PROMOTED LIMSSTCNE.
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN
1
RETROFIT 361 MU (GROSS)
361 MM (ESC)
COAL
.80 XS SUB3ITUMINOUS
UELLMAN LORD
DAVY KCKEE
ENERGY CONSUMPTION: 4.4X
STATUS 1 STARTUP 4/78
SAN JUAN 1 OF PUBLIC SERVICE OF NEM MEXICO IN MATESFLOW, HEM MEXICO IS A
COAL (0.8X S, 6100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT UELLMAN LORD FGO SYSTEM BY DAVY FGUESGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE APRIL 1973, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUE3EP/SFRAY TOMER ABSOR-
BER TRAINS U'HICH WERE DESIGNED TO REMOVE 85X OF THE FLUE GAS SOS. AM IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END FRC3UCT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE WATER LCCr IS
CLOSED.
PUBLIC SERVICE OF NEW 'MEXICO
SAN JUAN
2
RETROFIT 350 MM (GROSS)
350 MM (ESC)
COAL
.80 XS SU3BITUMINOUS
MELLMAH LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 8/78
SAN JUAN 2 OF PUBLIC SERVICE OF NEM MEXICO IN MATEPFLOM, NEM MEXICO IS A
COAL (0.8X S, 8100 BTU/LB) FIRED BOILER WHICH SUPPLIES 1,319,000 ACFM OF
FLUE GAS TO A RETROFIT MELLMAN LORD FGD SYSTEM BY DAVY FOWEPGAS. THE EMIS-
SION CONTROL SYSTEM, OPERATIONAL SINCE AUGUST 1978, CONSISTS OF A HOT
SIDE ESP FOLLOWED BY FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY TCWER ABSOR-
BER TRAINS WHICH MERE DESIGNED TO REMOVE 85X OF THE FLUE GAS S02. AN IN-
DIRECT HOT AIR REHEATER PRECEDES A BRICK LINED STACK. END PRCOL'CT ELEMEN-
TAL SULFUR IS PRODUCED BY THE ALLIED CHEMICAL PROCESS. THE MATER LOOP IS
CLOSED.
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN
3
NEH 534 MM (GROSS)
534 MM (ESC)
COAL
.80 XS SUBBITUMINOUS
UELLMAN LORD
DAVY MCKEE
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 NEM MEXICO AND IS LOCATED IN MATERFLCM, NEM MEXICO. THE FGD
SYSTEM, SUPPLIED BY DAVY POUERGAS, UTILIZES THE MELLMAN LCRD S02 RECOVERY
RECOVERY PROCESS AND SULFURIC ACID IS PRODUCED AS THE END PRODUCT.
FIVE (ONE SPARE) VENTURI SCRUSBER/SPRAY TOMER ABSORBER (90X DE-
SIGN S02 REMOVAL) TRAINS FOLLCM A HOT SIDE ESP. AN INDIRECT HOT AIR
REHEATER BOOSTS THE GAS TEMPERATURE 50 DEC F. THE SYSTEM OPERATES
IN A CLOSED MATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER 1979.
PUBLIC SERVICE OF NEM MEXICO
SAM JUAN
4
NEH 534 MM (GROSS)
534 MM (ESC)
CO&L
.80 XS SUBBITUMINOUS
MELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
STATUS 2 STARTUP 6/82
SAN JUAN 4 IS A COAL (0.8X S, 8100 BTU/LB) FIRED UNIT OF THE PUBLIC SER-
VICE OF NEM MEXICO UNDER CONSTRUCTION IN UATERFLOM, NEH MEXICO. THE FGD
SYSTEM, BEING SUPPLIED BY DAVY POUERGAS, MILL UTILIZE THE UELLMAN LCRD
S02 RECOVERY PROCESS AND SULFURIC ACID HILL BE FRCOUCED AS THE Eta
PRODUCT. FIVE (ONE SPARE) VENTURI SCRUBBER/SPRAY TOMER AESOPEER (90X DE-
SIGN S02 REMOVAL) TRAINS HILL FOLLOH A HOT SIDE ESP. AN ItJDIPECT HOT AIR
REHEATER HILL BOOST THE GAS TEMPERATURE 50 OEG F. THE SYSTEM HILL OPERATE
IN A CLOSED HATER LOOP MODE. START-UP IS EXPECTED IN JUNE 1932.
PHR AUTHORITY OF STATE OF NY
FOSSIL
HEM 700 MM (GROSS)
700 MM (ESC)
COAL
3.00 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ««»<*X
STATUS 6 STARTUP 4/87
THE POWER AUTHORITY OF NEH YORK PLANS A NEM 3.OX SULFUR COAL FIRED UNIT
WHICH HILL BE LOCATED AT THE ARTHUR KILL FACILITY ON STATEN ISLAIO. THE
UTILITY IS PRESENTLY CONSIDERING FGO SYSTEMS FOR THIS UNIT. PUBLIC SERVICE
COMMISSION HEARINGS ARE CURRENTLY IN PROGRESS. START-UP IS EXPECTED IN
APRIL 1987.
35
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SALT PIVER PROJECT
CCRONAOO
1
MEM
SUBBITUMINOUS
350 MM (GROSS)
280 MM (ESC)
COAL
.50 XS
LIMESTONE
n.U. KELLOSG
ENEPGY CONSUMPTION; 4.3X
STATUS 1 STARTUP 11/79
SALT RIVER PROJECT'S CORONAOO 1 IS A DRY BOTTOM PULVEPIZED S'JSBITL'MINOUS
COAL (0.5X S, 12,000 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS.
ARIZONA. M. 14. KELL033 SUPPLIED THE TWO LIMESTONE HORIZONTAL WEI? SP3AY
TOWERS WHICH REMOVE 82.5X OF THE S02 FROM THE FLUE GAS PASSED THROUGH
THEM. VERTICAL HEIL MIST ELIMINATORS PFECEDE A 500 FOOT STACK. A MINIMUM
OF 20X BYPASS PROVIDES REHEAT. THE WATER LOOP IS OPEN, AND THE
UNSTABILIZED SLUDGE IS DISPOSED OF IN AN UNLINED POND. START-UP WAS
IN NOVEMBER 1979.
SALT RIVER PROJECT
CORONADO
2
NEW
350 MW (GROSS)
280 MW (ESC)
COAL
.50 XS SUSBITUMINOUS
LIMESTONE
M.M. KELLOGG
ENEPGY CONSUMPTION: 4.3X
STATUS 1 STARTUP 7/80
SALT RIVER PROJECT'S C030NAOO 2 IS A DRY BOTTOM PULVERIZED SUSBITUMIHC'JS
COAL (0.5X S, 12,000 BTU/LB) FIRED BOILER LOCATED IN ST. JOHNS, ARIZONA.
M. M. KELLOGG SUPPLIED TWO LIMESTONE HORIZONTAL WEIR SPRAY TCWEPS
WHICH REMOVE 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 OPEN, AND THE
UNSTABILIZED SLUDGE IS DISPOSED OF IN AN UNLINED POND. START-UP WAS IN
JULY I960.
SALT RIVER PROJECT
CORONAOO
3
NEW
400 MW (GROSS)
280 MW (ESC)
COAL
.60 XS SUSBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 3.8X
STATUS 6 STARTUP 0/89
COROHADO 3 IS A DRY BOTTOM PULVERIZED SUBBITUMINOUS COAL 1.607. S, 8300 BTU
/LB) FIRED UNIT PLANNED BY SALT RIVER PROJECT TO BE LOCATED IN ST. JOHN'S.
ARIZONA. THE UTILITY IS PRESENTLY CONSIDERING THE INSTALLATION OF TWO HOR-
IZONTAL SPRAY TOWERS UTILIZING LIMESTONE AS THE ABSORBENT. PLANS FOR AN
EMISSION CONTROL SYSTEM HAVE NOT BEEN FINALIZED. THE SYSTEM HILL HAVE A
20X BYPASS REHEAT, AND THE SLUDGE WILL PROBABLY BE PONDED. SCHEDULED OPER-
ATION DATE 19 1989.
SAN MIGUEL ELECTRIC
SAN MIGUEL
1
NEW 400 MM (GROSS)
400 MM (ESC)
COAL
1.70 XS LIGNITE
LIMESTONE
BABCOCK 4 WILCOX
ENERGY CONSUMPTION: 5.OX
STATUS 1 STARTUP 8/81
SAN MIGUEL 1 OF THE SAN MIGUEL ELECTRIC COOP IS A LIGNITE (1.7X S, 5000
BTU/LB) FIRED RADIANT BOILER LOCATED IN SAN MIGUEL, TEXAS. THE
EMISSION CONTROL SYSTEM ON THIS UNIT CONSISTS OF A COLD SIDE ESP FOL-
LOWED BY FOUR BABCOCK AND WILCOX 86X EFFICIENT LIMESTONE TCA MODULES.
CHEVRON MIST ELIMINATORS PRECEDE AN IN-LINE REHEATEP AND AN ACID
BRICK LINED STACK. THE WATER LOOP IS CLOSED, AND THE DEWATERED SLURRY
IS MIXED WITH FLYASH BY RESEARCH COTTRELL AND DISPOSED OF IN AN OFF-SITE
LANDFILL. OPERATIONS COMMENCED IN AUGUST 1981.
SEMINOLE ELECTRIC
SEMINOLE
1
NEW 620 MM (GROSS)
620 MM (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABCDY PROCESS SYSTEMS
ENERGY CONSUMPTION: »«»*x
STATUS 2 STARTUP 3/83
SEMINOLE 1 OF SEMINOLE ELECTRIC IS A COAL (2.75X S, 11,700'BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IH PALATKA. FLORIDA. THE EMISSION CONTPOL SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE FGD SYSTEM. THE FGO SYSTEM WILL BE
SUPPLIED BY PEABODY PROCESS SYSTEMS. START-UP IS EXPECTED IN MARCH
1983.
SEMINOLE ELECTRIC
SEMINOLE
2
HEM
620 MM (GROSS)
620 MM (ESC)
COAL
2.75 XS SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ««»«X
STATUS 3 STARTUP 1/85
SEMINOLE 2 OF SEMINOLE ELECTRIC IS A COAL (2.75X S, 11,700 BTU/LB) FIRED
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CCNTPCL SYSTEM
MILL CONSIST OF ESP'S AND A LIMESTONE FGD SYSTEM. THE FGD SYSTEM WILL BE
SUPPLIED BY PEABODY SYSTEMS. START-UP IS EXPECTED IN JANUARY 1985.
36
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SIERRA PACIFIC POWER
VALMY
2
NEH 276 MM (GROSS)
276 MM (ESC)
COAL
***«» ;:s
LIME/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: WHWX
STATUS 7 STARTUP 8/8*
SIERRA PACIFIC POWER HAS PLANS TO CONSTRUCT A 276 MM UNIT TO 5E LCCATEO
IN VALMY, NEVADA. THE FOSTER MHEELEH PULVERIZED COAL FIRED EOILER AT THE
VALMY 2 STATION MILL UTILIZE AN FGD SYSTEM OR FIRE LCW SULFUR CC',L TO
CONTROL S02 EMISSIONS. IF FGD IS SELECTED, A CRY LIMi SYSTEM HILL SE
UTILIZED. THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IH AUGUST 1934.
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTOH
1
NEW 235 MM (GROSS)
235 MM (ESC)
COAL
2.80 XS BITUMINOUS
LIMESTONE
BABCQCK » UILCOX
ENERGY CONSUMPTION: 1.7X
STATUS 1 STARTUP 6/61
THE SIKESTON BOARD OF MUNICIPAL UTILITIES' SIKESTCN 1 IS A PULVERIZED COAL
(2.6X S, 11,340 BTU/LB) FIRED BOILER LOCATED IN SIKESTON, MISSOURI.
BABCOCK AND UILCOX SUPPLIED THE EMISSION CONTROL SYSTEM CONSIST-
ING OF TWO ESP'S AND THREE SOX CAPACITY LIMESTONE VENTURI FGD MODULES. THE
CLEANED GAS PASSES THROUGH CHEVRON MIST ELIMINATORS BEFORE EXITING A
454 FOOT FRP LINED FLUE (A SECOND CARBON STEEL LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK). THE HATER LOCP MODE IS OPEN, AMD THE
SLUDGE IS PONDED. THE SYSTEM STARTED OPERATIONS IN JUNE 1981.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
1
NEM 500 MM (GROSS)
500 MM (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: »*»*X
STATUS 3 STARTUP 5/88
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO NEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA. EACH 500 MM
BOILER MILL 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 MET LIMESTONE SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS. UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS IN MAY 19S8.
SOUTH CAROLINA PUBLIC SERVICE
CROSS
2
NEM 500 MM (GROSS)
500 MM (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ***»•/.
STATUS 2 STARTUP 11/83
SOUTH CAROLINA PUBLIC SERVICE HAS PLANS TO CONSTRUCT TWO MEW UNITS,
CROSS 1 AND 2, TO BE LOCATED IN CROSS, SOUTH CAROLINA. E'-CH SCO MM
BOILER WILL FIRE COAL WITH A SULFUR CONTENT RANGING BETWEEN 1.0 AND 2.3X.
CONSTRUCTION OF THE MET LIMESTONE SCRUBBING SYSTEM BEINS SUPPLIED
BY PEABODY PROCESS SYSTEMS FOR 302 CONTROL HAS COMMENCED. UNIT 2 IS
SCHEDULED TO COMMENCE OPERATIONS IN NOVEMBER 1983.
SCUTH CAROLINA PUBLIC SERVICE
MIHYAH
2
HEN 280 MM (GROSS)
140 MM (ESC)
COAL
"1.10 XS BITUMINOUS
LIMESTONE
BABCOCK & HILCOX
ENERGY CONSUMPTION: 1.1X
STATUS 1 STARTUP 7/77
WINYAH 2 OF SOUTH CAROLINA PUBLIC SERVICE IS A PULVEPIZED BITUMINOUS COAL
(1.70X S, 11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN, SOUTH CAROLINA.
A COLD SIDE ESP AND A BABCOCK AND WILCOX VENTURI SCRU2SER/LIKESTCNE TRAY
TOMER ABSORBER TRAIN DESIGNED TO REMOVE 45X OF THE 502 F.=OM THE EOILE°
FLUE GAS MAKE UP THE EMISSION CONTROL SYSTEM ON THIS UNIT. THE SYSTEM
OPERATES IN AN OPEN MATER LOOP, AND THE SLUDGE IS DISPOSED IN AH CM-SITE
UNLINED POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
SOUTH CAROLINA PUBLIC SERVICE WINYAH 3 OF SOUTH CAROLINA PUBLIC SERVICE IS A DRY BOTTOM BOILER WHICH
WINYAH
3
HEM 280 MM (GROSS)
280 MM (ESC)
COAL
1.10 XS
LIMESTONE
BABCOCK t HILCOX
ENERGY CONSUMPTION: 2.IX
STATUS 1 STARTUP 5/80
FIRES 1.7X SULFUR COAL (11.500 BTU/LB) AND IS LOCATED IN GECSGiTCWN,
SOUTH CAROLINA. AN ESP PRECEDES A BABCOCK AND UILCOX LIMESTONE FGD
SYSTEM AND AN INDIRECT STEAM REHEATER. THE SYSTEM OPERATES IN A CLCSE9
MATER LOOP MODE. OPERATIONS COMMENCED IN MAY 1980.
37
-------
EPA UTILITY FC-0 SURVEY: OCTCSER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTH CAPOLIHA PUBLIC SERVICE SOUTH CAROLINA PUBLIC SERVICE'S UINYAH 4 IS A BITL'MIUCUS COAL (1.70X S,
WIN f AH
4
NEW 289 MM (G30SS)
280 MM (ESC)
COAL
1.70 XS BITUMINOUS
LIMESTONE
AMEPTCAN AIR FILTER
ENEEJY CONSUMPTION: z.ix
STATUS 1 STARTUP 7/81
11,500 BTU/LB) PIPED UNIT LOCATED IN GEORGETOWN, SOUTH CAPCLINA.
TWO AMERICAN AIR FILTER LIMESTONE SLUPRY SFPAY TOWERS FOLLOW AN ESP.
THE TEMPERATUPE OF THE CLEANED GAS IS PAISEO BY AN INDIRECT STEAK
PEHEATER. THE SYSTEM OPERATES IN A CLOSED HATER LOOP HC3E. INITIAL
OPERATIONS COMMENCED IN JULY 1931.
SOUTH MISSISSIPPI ELEC PKH
R.D. MORROW, SR.
1
NEW ZOO MM (GROSS)
124 MM (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENV1ECNEERIN3, RILEY STOKER
ENERGY CONSUMPTION: 5.57.
STATUS 1 STARTUP 8/78
R.O. 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 LIMs-
STONE VENTRI-ROD ABSORBER SUPPLIED BY RILEY STOKER/ENVIBCiJEEP.ING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATCR, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED TKPC'JC-H A 403 FOOT
STACK SHARED BY UNITS 1 AND 2 (EACH UNIT HAS ITS OWN ACID ERICK LINED
FLUE). THE MATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLUCGE IS
HAULED BY TRUCK TO AN OFF-SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST 1978.
SOUTH MISSISSIPPI ELEC PMR
R.D. MORROW, SR.
2
NEM 200 MM (GROSS)
1C4 MM (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIRCNEERING, RILEY STOKER
ENERGY CONSUMPTION: 5.57.
STATUS 1 STARTUP 6/79
R.D. MORROM 2 OF SOUTHERN MISSISSIPPI ELECTRIC IS A PULVEPIZEO COAL (1.3X
S. 12.000 BTU/LB) FIRED UNIT IN HATTISSUP.G, MISSISSIPPI. THE EMISSION CON-
TROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD ABSOPBER SUPPLIED BY RILEY STOKEP/ENVIRCNEERING. AFTER
THE CLEANED GAS PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATC?, IT IS
JOINED BY A 38X BYPASS REHEAT BEFORE IT IS DISCHARGED THPOUSH A 408 FCOT
STACK SHARED BY UNITS 1 AND Z (EACH UNIT HAS ITS OWN ACID ERICK LINED
FLUE). THE WATER LOOP IS CLOSED, AND THE FLYASH STABILIZED SLU3GE IS
HAULED BY TRUCK TO AN OFF-SITE LANDFILL. THE SYSTEM HAS SEEN OPERATIONAL
SINCE JUNE 1979.
SOUTHERN ILLINOIS POWER
MARION
4
NEM 173 MM (GROSS)
173 MM (ESC)
COAL/REFUS
3.75 XS BITUMINOUS
LIMESTONE
BAECOCK » MILCOX
ENERGY CONSUMPTION: 2.3X
STATUS 1 STARTUP 5/79
UNIT * 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 3Y EASCCCK AND
HILCOX. TWO SPRAY TOMERS AND A BRICK LINED STACK ARE DOWNSTREAM OF AN ESP
IN THIS SYSTEM. THE HATER LOOP IS OPEN, AND THE FLYASH STABILIZED SLU33E
IS DEHATERED AND LANOFILLEO. THE SYSTEM BECAME OPERATIONAL DURING MAY
1979.
SOUTHERN INDIANA GAS S ELEC
A.B. BROWN
1
MEM 265 MM (GROSS)
265 MM (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FMC
ENERGY CONSUMPTION: .ax
STATUS 1 STARTUP 3/79
SOUTHERN INDIANA GAS AND ELECTPIC'S A.B.BPCUN 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 8SX OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO THREE STAGE DISC CCNTACTOPS. A COLD SIDE ESP
PROVIDES PRIMARY PAHTICULATE CONTROL, AND ONE CHEVRON MIST ELIMINATCS/MOD-
ULE PRECEDES A 498 FOOT ACID BRICK LINED STACK. THE SYSTEM FSOSUCES A
FILTER CAKE HASTE PRODUCT WHICH IS DISPOSED IN AN CM-SITE LANDFILL. THE
HATER LOOP CAN BE EITHER OPEN OR CLOSED. THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1979.
SOUTHERN INDIANA GAS t ELEC
A.B. BROWN
2
265 MM (GROSS)
265 MM (ESC)
COAL
3.35 XS BITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: .8X
STATUS 5 STARTUP 1/85
SOUTHERN INDIANA GAS AND ELECTRIC HAS PLANS TO CONSTRUCT ANOTHER UNIT,
A.B. BROWN Z, TO BE LOCATED IN WEST FRANKLIN, INDIANA. THE 265-MM (G30SS)
UNIT HILL FIRE BITUMINOUS COAL WITH AN AVERAGE SULFUR CONTENT OF 3.35X.
A CCLD SIDE ESP HILL PROVIDE PRIMARY PARTICULATE MATTER CONTROL AND AN
FGO SYSTEM HILL BE USED TO CONTROL S02 EMISSIONS. THE FLUE GAS HILL EXIT
THROUGH A 498-FOOT STACK. THE SYSTEM HILL OPERATE IN A CLOSED HATER LCOP
MODE AND THE SLUDGE HILL BE DISPOSED IN AN CN-SITE LANDFILL. OPERATIONS '-
ARE SCHEDULED TO COMMENCE IN JANUARY 1965.
38
-------
EPA UTILITY FGO SURVEY: OCT03EP - DECEMBER 1<>81
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
SOUTHWESTERN ELECTRIC POWER
DCLET HILLS
1
NEW 720 MM (GROSS)
720 MM (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
AIR CCPPECTION DIVISION, UOP
ENERGY CONSUMPTION: »***X
STATUS 3 STARTUP 3/86
OOLET HILLS 1 OF SOUTHWESTERN ELECTRIC FOWE" IS A PLANNED 720 MM LIC-NITE
(0.7XS, 7100 BTU/LB) FIREO BOILER TO BE LOCATED IN MANSFIELD, LCUiSIASU.
THE EMISSION CONTROL SYSTEM HILL CONSIST OF AN ESP FCP FAFTICULATE CONTROL
AND A MET LIMESTONE FGD SYSTEM FOR S02 CONTROL. THE FLUE GAS MILL EXIT
THROUGH A 525 FOOT STACK. A CONTRACT HAS SEEN AWAFDEO TO UO? FCS THE FGO
SYSTEM. THE UNIT IS SCHEDULED TO START-UP IN 1986.
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
2
HEW 720 KM (GROSS)
720 MM (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «»*»X
STATUS 6 STARTUP 0X88
OOLET HILLS 2 OF SOUTHWESTERN ELECTRIC POWER IS A PLANNED 720 MU LIGNITE
(0.7XS, 7100 BTU/LB) FIREO BOILER TO BE LOCATED IN MANSFIELD, LOUISIANA.
THE EMISSION CONTROL SYSTEM MILL CONSIST OF AN ESP FOR PARTICULAR CONTROL
AND A MET LIMESTONE FGD SYSTEM FOR S02 CONTROL. THE FLUE GAS MILL EXIT
THROUGH A 525 FOOT STACK. THE UNIT IS SCHEDULED TO BEGIN OPERATIONS IN
1988.
SOUTHWESTERN ELECTRIC POWER
HENRY M. PIRKEY
1
NEM 720 MM (GROSS)
720 MM (ESC)
COAL
.80 XS LIGNITE
LIMESTONE
AIR CORRECTION DIVISION. UOP
ENEPGY CONSUMPTION: »*«»x
STATUS 3 STARTUP 12/84
HENRY M. PIRKEY 1 IS A MET BOTTOM LIGNITE (O.SX S, 6300 BTU/LB) FIPED UNIT
PLANNED BY SOUTHWESTERN ELECTRIC POMER 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 HILL BE PPO-
VIDED BY TWO STAGE CHEVRONS, AND THE STACK MILL BE ACID B^ICK LIKED. NO
REHEAT IS PLANNED. THE MATER LOOP HILL BE CLOSED, AND THE SLUDGE MILL BE
POZ-0-TEC STABILIZED. START-UP IS EXPECTED BY DECEMSER 1984.
SOYLAND
SOYLAND
1
NEM
POMER
500 MM (GROSS)
500 MM (ESC)
COAL
3.00 XS UNDECIDED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: »«»*X
STATUS 6 STARTUP 6/87
SOYLAND POMER COOP HAS PLANS FOR A NEH 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 1987.
SPRINGFIELD CITY UTILITIES
SOUTHWEST
1
NEH 194 MM (GROSS)
194 MM (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6X
STATUS 1 STARTUP 4/77
SPRINGFIELD CITY UTILITIES' SOUTHWEST 1 IS A PULVERIZED BITUMINOUS COAL
(3.5X S. 12,500 BTU/LB) FIRED BOILER LOCATED IN SPRINGFIELD, MISSC'JPI. THE
EMISSION CONTPOL SYSTEM FOR THIS UNIT CONSISTS OF A COLO SIDE ESP FOLLCWED
BY TUO UOP LIMESTONE TCA MODULES WHICH HERE DESIGNED TO PEMOVE 60X CF THE
FLUE GAS S02. ONE CHEVRON/MODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
THE DRY FLYASH STABILIZED SLUDGE IS DEUATERED BY A ROTARY DRUM VACUUM FIL-
TER AND TRUCKED TO A LANDFILL. OPERATIONS COMMENCED IN APRIL 1977.
SPRINGFIELD HATER,
OALLMAN
3
NEM
205 KM (GROSS)
185 KM (ESC)
COAL
3.30 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4.9X
STATUS 1 STARTUP 12/80
LIGHT t FHR OALLMAN 3 OF SPRINGFIELD MATER, LIGHT, AND POME? IS A PULVERIZED COAL
(3.3X S, 10,500 BTU/LB) FIRED BOILER LOCATED IN SFRIN3FIELD, ILLINOIS.
RESEARCH COTTRELL SUPPLIED A LIMESTONE FGD SYSTEM DESIGNED TO REMOVE
95X OF THE S02 FROM 650,000 ACFM OF BOILER FLUE GAS. A HOT SIDE ESP
PRECEDES TWO PACKED TOMER ABSORBERS, ONE HORIZONTAL CHEVRON PER MODULE,
AND A 500 FOOT ACID BRICK LINED STACK. NO PEHEAT IS PROVIDED. SLU23E IS
DISPOSED OF IN A LANDFILL. FGD OPERATIONS COMMENCED IN OCTOBER
39
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
ST. JOE ZIMC
G.F. WEATON
1
RETROFIT 60 MM (GROSS)
60 MM (ESC)
COAL
3.00 XS BITUMINOUS
CITFATE
f.C=HISON & KNUDSEN/U.S.B.M.
ENERGY CONSUMPTION: **«»X
STATUS 1 STARTUP 11/79
G.F. WEATON 1, OWNED BY ST. JOE ZINC, IS A COAL (2. OX S, 12,500 BTU/LB)
FIRED BOILER LOCATED IN MCNACA, PENNSYLVANIA. THE BUREAU OF MIMES RE-
TROFITTED A PROTOTYPE CITRATE FGO SYSTEM OH THIS UNIT, WHICH PROVIDES
POWER FOR THE LOCAL UTILITY GRID. ONE VENTUSI SCRUSBER/ABSCSSER TPAIM
FOLLOWS A COLD SIDE ESP. TWO CHEVSON MIST ELIMINATORS APE FOLLOWED BY
A COMBINATION OF INDIRECT HOT AIR AND DIRECT COKSUSTION EEHEATERS, AMD A
102 FOOT FIBERGLASS LINED SCRUBBER STACK. THE SYSTEM S32 PEKOVAL EFFICIEN-
CY WILL BE OVER 90X. THE HATER LOOP IS CLOSED LOOP MODE. THE FGD SYSTEM
COMMENCED OPERATION IN NOVEMBER 1979.
SUNFLOWER ELECTRIC
HOLCOMB
1
NEW 347 MM (GROSS)
347 MM (ESC)
COAL
.47 XS SU3BITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: .9X
STATUS 2 STARTUP 9/83
SUNFLOWER ELECTRIC COOP'S HOLCOMB 1 STATION IS A PLANNED 347 MM UNIT TO BE
LOCATED IN HOLCOMB, KANSAS. THE PULVERIZED COAL (0.47X S, 8300
BTU/LB) FIRED BA8COCK AND HILCOX BOILER WILL UTILIZE A JOY MANUFACTURING/
NIRO ATOMIZER DRY SCRUBBING PROCESS FOR SC2 CONTROL. A FABRIC FILTER
WILL BE UTILIZED FOR PRIMARY PARTICLE CONTROL. THE UNIT IS SCHEDULED
TO COMMENCE OPERATIONS IN THE FALL OF 1983.
TAM°A ELECTRIC
BIG BEND
4
NEM 475 MM (GROSS)
475 MM (ESC)
COAL
2.35 XS
LIME/LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 2.IX
STATUS 3 STARTUP 3/85
UNIT 4 AT TAMPA ELECTRIC1S 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 F0
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 2
STATUS OF FG3 SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TENNESSEE VALLEY AUTHORITY
S-IAUNEE
1C3
RETROFIT 10 MM (GROSS)
10 MM (ESC)
COAL
2.93 XS BITUMINOUS
LIME/LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«»*X
STATUS 1 STARTUP 4/72
SHAWNEE 10 OF TVA IS A 2.9X SULFUR BITUMINOUS COAL FIRED BOILER LOCATED IN
PAOUCAH, KENTUCKY. MODULE 1CB IS A RETROFIT PROTOTYPE LirE/LirESTCNH VEN-
TURI SCRUBBER/SPRAY TOMER ABSORBER SUPPLIED BY GEESI. THE SYSTEM, CFE=A-
TIONAL SINCE APRIL 1972, INCLUDES A CHEVRON MIST ELIMINATOR AN3 A BISECT
COMBUSTION REHEATER, AND OPERATES IN A CLOSED WATER LOOP. THIS TEST PPO-
GRAM MAS FUNDED BY EPA WITH TVA AS THE CONSTRUCTS AND FACILITY OPEPA-
TOH. THE BECHTEL CORP. OF SAN FRANCISCO WAS THE MAJCH CONTSACTOR, TEST DI-
RECTOR, AND REPORT WRITER.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
RETROFIT 575 KM (GROSS)
575 KM (ESC)
COAL
3.70 XS BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »<*»X
STATUS 1 STARTUP 3/81
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
SUPPLIED A LIMESTONE VENTRI ROD SCRUBBER/SPRAY TCWER ABSGPBE3 FGO SYSTEM
ON THIS UNIT. AN ESP PRECEDES THE SCRUBBING TRAIN, AND A COMBINATION OF
A BULK ENTRAINMENT SEPERATOR, TWO CHEVPCN MIST ELIMINATORS AND A FINNED
TUBE REHEATER FOLLOWS THE SYSTEM. THE SCRUBBER SLUDGE IS DISPOSED OF
IN A SLUDGE POND. OPERATIONS COMMENCED IN MARCH 1981.
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
8
RETROFIT 550 KM (GROSS)
550 KM (ESC)
COAL
3.70 XS BITUMINOUS
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 (BOX DESIGN S02 REMOVAL EFFICIENCY) WHICH BE-
GAN OPERATIONS IN HAY 1977. AN ESP PRECEDES FOUR VARIABLE THROAT VENTURI
SCRUBBER/KULTIGRID TOMER ABSORBER TRAINS (ONE OF THE TOWERS IS PACKED).
ONE VERTICAL CHEVPON/TRAIN AND AN INDIRECT HOT AIR REHEATER ARE INCLUDED
IN THE SYSTEM. SLUDGE FROM THE FGD SYSTEM IS PONDED.
TEXAS MUNICIPAL POWER AGENCY
GIESONS CREEK
1
NEM 443 KM (GROSS)
400 MM (ESC)
COAL
1.06 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 1.4X
STATUS 2 STARTUP 10/82
GIBBONS CREEK 1 OF THE TEXAS MUNICIPAL POWER AGENCY IS A DRY BOTTOM PUL-
VERIZED LIGNITE (1.06X S, 4860 BTU/LB) FIRED UNIT PLANNED FOR LOCATION IN
CARLOS, TEXAS. THE EMISSION CONTROL SYSTEM MILL CONSIST OF A COLD SIDE ESP
FOLLOWED BY THREE SOX CAPACITY LIMESTONE SPPAY TOWERS. A CONTRACT HAS BEEN
AMARDED TO COMBUSTION ENGINEERING FOR THE FGD SYSTEM, WHICH INCLUDES A
CHEVRON MIST ELIMINATOR AND A STEAK COIL REHEATER. CLEANED FLUE GAS WILL
BE DISCHARGED THROUGH A 465 FOOT ACID BRICK LINED STACK. THE POZ-0-TEC
STABILIZED SLUDGE MILL BE USED AS STRIP MINE LANDFILL. START-UP
IS EXPECTED IN OCTOBER 1982.
TEXAS POWER I LIGHT
SANDOM
4
NEM 545 KM (GROSS)
382 KM (ESC)
(COAL
1.60 XS LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: JHHHtX
STATUS 1 STARTUP 12/80
SAHDOM 4 IS A PULVERIZED 1.6X SULFUR LIGNITE FIRED BOILER OF TEXAS POWER
AND LIGHT LOCATED IN RCCKDALE, TEXAS. COMBUSTION ENGINEERING HAS SUPPLIED
THREE LIMESTONE SPRAY TOWERS FOR THIS UNIT. A COLO 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 If A CLOSED
MATER LOOP, AND THE SLUDGE IS BEING PONDED. OPERATIONS COMMENCED IN
DECEMBER 1980.
TEXAS POWER t LIGHT
TWIN OAKS
1 .
NEM 750 HVI (GROSS)
750 KM (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: »»**X
STATUS 3 STARTUP 8/85
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
AMARDED TO GEESI FOR A LIMESTONE FGD SYSTEM, ON THIS UNIT. START-UP IS
EXPECTED IN AUGUST 1985.
41
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 2
STATUS OF FGO SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS POWER & LIGHT
TWIN OAKS
2
MEM 750 MM (GROSS)
750 MM (ESC)
COAL
.70 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«**X
STATUS 3 STARTUP 8/87
TWIN OAKS 3 IS A 0.70X SULFUR LIGNITE FIRED BOILER PLANNED BY TEXAS PCUER
AND LIGHT AND ALCOA FOR LOCATION IN BREM3NO, TEXAS. A CONTRACT HAS BE;N
AWARDED TO GEESI FOR A LIMESTONE FGD SYSTEM ON THIS UNIT. START-UP IS
EXPECTED IN AUGUST 1987.
TEXAS UTILITIES
FOREST GROVE
1
NEU 750 MM (GROSS)
750 MM (ESC)
COAL
.60 XS LIGNITE
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
EIIEPGY CONSUMPTION: »**»x
STATUS 5 STARTUP 0/87
TEXAS UTILITIES IS PLANNING A LIGNITE (0.8X S, 7000 BTU/LB) FIRED BOILER,
FOREST GROVE 1, WHICH MILL BE LOCATED IN ATHENS, TEXAS. THE UTILITY IS
PRESENTLY REQUESTING BIDS ON AN FGD SYSTEM FOR THIS UNIT. TUO ESP'S HILL
PROVIDE PRIMARY PARTICULATE CONTROL, AND NO STACK GAS REHEAT IS PUNNED.
START-UP IS EXPECTED IN LATE 1987.
TEXAS UTILITIES
MARTIN LAKE
1
NEU 793 MM (GROSS)
595 MM (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: i.3x
STATUS 1 STARTUP */77
TEXAS UTILITIES' MARTIN LAKE 1 IS A LIGNITE (0.9X S, 7380 BTU/LB) FI°ED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED HITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLO SIDE ESP AND A LIMESTONE FGD SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGO SYSTEM CONSISTS OF SIX PACKED SPRAY
TOMER ABSORBERS WHICH 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 70.57.. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING HASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED MATER LOOP. INITIAL SYSTEM OPERATIONS TOCK
PLACE IN APRIL 1977.
TEXAS UTILITIES
MARTIN LAKE
Z
NEU 793 MM (GROSS)
595 MM (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTHELL
ENERGY CONSUMPTION:
STATUS 1
1.3X
STARTUP 5/78
TEXAS UTILITIES1 MARTIN LAKE 2 IS A LIGNITE (0.«X S, 73SO BTU/LB) FIREO
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED WITH AN EMISSION CONTROL
SYSTEM MHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGD SYSTEM. BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOMER ABSORBERS WHICH TREAT 75X OF THE TOTAL BOILER FLUE GAS. THE REMAIN-
ING FLUE GAS IS BYPASSED FOR REHEAT. THE TOTAL DESIGN SOS REMOVAL EFFICI-
ENCY IS 70.5X. TWO CHEVRONS/MODULE PROVIDE MIST ELIMINATION. THE FLUE GAS
CLEANING HASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED HATER LOOP. INITIAL SYSTEM OPERATIONS TOCK
PLACE IN MAY 1978.
TEXAS UTILITIES
MARTIN LAKE
3
NEU 793 MM (GROSS)
595 MU (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION
STATUS 1
1.3X
STARTUP 2/79
TEXAS UTILITIES' MARTIN LAKE 3 IS A LIGNITE (0.9X S, 7380 BTU/LB) PIPED
BOILER IN TATUM, TEXAS. THIS UNIT IS EQUIPPED HITH AN EMISSION CONTROL
SYSTEM WHICH INCLUDES A COLD SIDE ESP AND A LIMESTONE FGO SYSTEM, BOTH
SUPPLIED BY RESEARCH COTTRELL. THE FGD SYSTEM CONSISTS OF SIX PACKED SPRAY
TOMER ABSORBERS WHICH 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 HASTES ARE FLYASH STABILIZED AND DISPOSED IN AN ON-SITE LANDFILL.
THE SYSTEM OPERATES IN A CLOSED HATER LOOP. INITIAL SYSTEM OPERATIONS TOOK
PLACE IN FEBRUARY 1979.
TEXAS UTILITIES
MARTIN LAKE
<>
HEW 750 MM (GROSS)
750 MM (ESC)
COAL
.90 XS LIGNITE
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: *»«*X
STATUS 3 STARTUP 0/89
MARTIN LAKE 4 OF TEXAS UTILITIES IS A LIGNITE (0.9X S, 73SO BTU/LB) FIRED
BOILER UNDER CONSTPUCTION IN TATUM, TEXAS. A CONTRACT FOR A LIMESTONE FGO
SYSTEM FOR THIS UNIT HAS BEEN AHARDED TO RESEARCH COTTRELL. CONSTRUCTION
HAS NOT YET BEGUN ON THE FGD SYSTEM. FGD START-UP IS EXPECTED IN
1989.
42
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
ABSTRACT
TEXAS UTILITIES
MILL CREEK
1
NEW 750 MVI (GROSS)
750 KM (ESC)
COAL
.(»**» XS LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**x
STATUS 6 STARTUP 0/87
MILL CREEK 1 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO 2E
LOCATED IN HEHDEPSON, TEXAS. THE UTILITY HILL INCLU3E AN FG3 SYSTEM CN
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE P'CCESS TYFE CR
VENDOR. ESP'S MILL PROVIDE PRIMARY PARTICLE CONTROL. START-UP IS
EXPECTED IN 1967.
TEXAS UTILITIES
MILL CREEK
2
HEM 750 rM (GROSS)
750 KM (ESC)
COAL
**»»« XS LIGNITE
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
ENEFGY CONSUMPTION: ****7.
STATUS 6 STARTUP 0/68
MILL CREEK 2 OF TEXAS UTILITIES IS A PLANNED LIGNITE FIRED UNIT TO BE
LOCATED IN HENDERSON, TEXAS. THE UTILITY MILL INCLUDE AN FGO SYSTEM ON
THIS UNIT, BUT NO DECISIONS HAVE BEEN MADE AS TO THE PRCCESS TYFE CR
VENDOR. ESP'S HILL PROVIDE PRIMARY PARTICLE CONTROL. START-UP IS
EXPECTED IN 1988.
TEXAS UTILITIES
MOMTICELLO
3
NEH 800 KU (GROSS)
600 MM (ESC)
COAL
1.50 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: V««*X
STATUS 1 STARTUP 5/78
MOMTICELLO 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 CCMSISTS
OF TWO COLD SIDE ESP'S FOLLOWED BY THREE GEESI LIMESTONE SPPAf TOWERS
{.7V/. DESIGN 502 REMOVAL EFFICIENCY), ONE HORIZONTAL CHEVPCM MIST ELIMINA-
TOR/MODULE, AND AN INDIRECT HOT AIR REHEATER. THE HATER LOO? IS CLOSED.
AND THE FLYASH STABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LANDFILL. THIS
SYSTEM HAS BEEN OPERATIONAL SINCE MAY 1978.
TUCSON ELECTRIC POMER
SPRINGERVILLE
1
NEH 370 MM (GROSS)
370 MM (ESC)
COAL
.61 XS SUBBITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: **»«X
STATUS 3 STARTUP 2/65
TUCSON ELECTRIC POMER HILL BE BUILDING THO HEW UNITS IN SPFIM3EHVILLE,
ARIZONA. SPRIN3ERVILLE 1 AND 2. THE UNITS HILL FIRE PULVEPIZED EL'SBITU-
MINOUS COAL (0.53-0.69X S AND 6500-6900 BTU/L3). A CONTRACT HAS BEEN
AHARDED TO JOY MANUFACTURING/NIRO ATOMIZER FCR A LIME/SPRAY DRYING FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM HILL
BE DESIGNED TO ACCOMOOATE A REHEATER (SHOULD ONE BE REQUIRED) AND UILL
OPERATE IN A CLOSED HATER LOOP. CLEANED FLUE GAS UILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. START-UP IS SCHEDULED FOR FEBRUARY 1985.
TUCSON ELECTRIC POWER
SPRINGERVILLE
2
NEH 370 MM (GROSS)
370 MM (ESC)
COAL
.61 XS SUE9ITUMINOUS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: ***«x
STATUS 3 STARTUP 3/87
TUCSON GAS AND ELECTRIC HILL BE BUILDING THO HEM UNITS IN SPPINSERVILLE,
ARIZONA, SPRINGERVILLE 1 AND 2. THE UNITS UILL FIRE PULVERIZED SU33ITU-
MINOUS COAL (0.53-0.69X S AND 8500-6900 BTU/LB). A CONTRACT HAS BEEN
AHARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A LIME/SFP4Y CRYI','3 FGD
SYSTEM TO CONTROL PARTICULATE MATTER AND S02 EMISSIONS. THE SYSTEM MILL
BE DESIGNED TO ACCCKODATE A REHEATER (SHOULD ONE BE REC'JT'ED) AND UILL
OPERATE IN A CLOSED MATER LOOP. CLEANED FLUE GAS HILL EXIT THE SYSTEM
VIA A 500 FOOT CONCRETE STACK. START-UP IS SCHEDULED FOR MARCH 1987.
UNITED POMER ASSOCIATION
STANTON
1A
NEH 60 MM (GROSS)
SO MM (ESC)
COAL
.77 XS 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 STANTCN, H03TH DAKOTA.
A CONTRACT HAS BEEN AWARDED TO KOMLINE AND SANDERSON fOt A LIME SFPAY
DRYER. A FABRIC FILTER SUPPLIED BY RESEARCH COTTRELL UILL BE DESIGNED
TO REMOVE 99X OF THE PARTICULATE. THE SYSTEM UILL CPEPATE IN AN CPEN
LOOP MODE HITH SLUDGE DISPOSAL TO BE IN A CLAY LINED SETTLII.3 POND.
OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1932.
STATUS 2
STARTUP 6/82
-------
EPA UTILITY FC-0 SURVEY: OCTOBER - DECEMBER 1981
SECTION 2
STATUS Or FGD SYSTEMS
UNIT IDEHTIFICATIOM
ABSTRACT
UTAH POWER
HUNTER
1
MEM
& LIGHT
400 MW (GROSS)
360 rM (ESC)
COAL
.55 XS BITUMINOUS
LIKE
GE ENVIRONMENTAL SERVICES
EN5=3Y CONSUMPTION: ****X
STATUS 1 STARTUP 5/79
HUNTER 1 OF UTAH POWER AND LIGHT IS A COAL (0.55X S, 12.500 STU/LB) FIRED
UNIT IN CASTLEDALEi UTAH. GEESI SUPPLIED A PEEBLE LIME WET SCrL-SBIHS
SYSTEM WHICH BECAME OPERATIONAL IN MAY 1979. THE SC'UEBIUS SYSTEM IS DE-
SIGNED TO OPEPATE IN AN OPEN WATER LOOP WITH AN SOC REMOVAL EFFICIENCY OF
SOX. PRIMARY PAHTICULATE CONTROL IS PROVIDED BY AN UPSTREAM ESP, AfO STACK
GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE IS FLfASH STABILIZED AN3 DIS-
POSED ON-SITE.
UTAH POWER & LIGHT
HUNTER
2
NEW 400 MW (GROSS)
360 MW (ESC)
COAL
.55 XS
LIME
GE ENVIRONMENTAL SERVICES
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, GEESI SUPPLIED
A PEBBLE LIME WET SCRUBBING SYSTEM DESIGNED TO CPEPATE IN AN CPEM WATER
LOOP WITH AN S02 REMOVAL EFFICIENCY OF 80X. AN UPSTPE4M ESP PROVIDES
PRIMARY PARTICLE CONTROL, AND A BYPASS SYSTEM PROVIDES STACK GAS REHEAT.
THE SLUDGE IS FLYASH STABILIZED AND DISPOSED OF CN-SITE. START-UP OF BOTH
THE BOILER AND FGD SYSTEM TOOK PLACE IN JUNE 1980.
UTAH POWER 4 LIGHT
HUNTER
3
NEW 400 MW (GROSS)
400 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION'- »**»X
STATUS £ STARTUP 6/83
HUNTER 3 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (0.55X S, 12500
BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN CASTLEDALE, UTAH. A CONTRACT HAS
BEEN AWARDED TO GEESI FOR A LIMESTONE, NONREGENERABLE FGO UNIT FOR EMIS-
SION CONTROL. INITIAL OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1933.
UTAH PCWER
HUNTER
4
NEW
£ LIGHT
400 MW (GROSS)
400 MW (ESC)
COAL
.55 XS BITUMINOUS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: »»««X
STATUS 2 STARTUP 6/85
HUNTER 4 OF UTAH POWER AND LIGHT IS A PULVERIZED COAL (0.55X S, 12500
BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN CA5TELDALE. UTAH. A CONTRACT HAS
BEEN AWARDED TO GEESI FOR A LIMESTONE, NONREGENERABLE FGD UNIT FOR EMIS-
SION CONTROL. INITIAL OPERATIONS ARE SCHEDULED TO COMMENCE IN JUNE 1935.
UTAH POWER S LIGHT
HUNTINGTON
1
NEW 430 MW (GROSS)
366 MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.6X
STATUS 1 STARTUP 5/78
HUNTINSTON 1 OF UTAH POWER IS A TANGENTIALLY FIRED PULVERIZED COAL (0.55X
S, 12,500 BTU/LB) BOILER IN PRICE, UTAH. A COLD SIDE ESP TREATS 1,742,000
ACFM OF FLUE GAS AND IS FOLLOWED BY A GEESI LIME FGO SYSTEM CONSISTING
OF FOUR SPRAY TOWERS (80X DESIGN EFFICIENCY). ONE FOUR PASS CHEVPON/MODULE
PROVIDES MIST ELIMINATION, AND A COMBINATION OF A STEAM TU3E AND 10-20X
BYPASS HEHEATERS 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 POWER I LIGHT
NAUGHTON
3
RETROFIT 330 MW (GROSS)
330 MM (ESC)
COAL
.55 XS SUBBITUMIHOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 1.5X
STATUS 1 STARTUP 9/81
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 OP FLUE GAS TO AN ESP FOR PARTICULATE MATTER CONTROL. THE
UNIT MAS RETROFITTED WITH A UOP MET SODA ASH FGD SYSTEM FC= S02
CONTROL. THE FGD SYSTEM IS DESIGNED TO REMOVE 70X OF THE S02 BEFORE THE
FLUE GAS EXITS OUT A 475 FOOT STACK. INITIAL START-UP TOOK PLACE IN
SEPTEMBER 1981.
44
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1=31
SECTION 2
STATUS OF FGD SYSTEMS
UHIT IDENTIFICATION
ABSTRACT
WASHINGTON WATER POWER
CRESTCN COAL
1
MEM 570 KM (GROSS)
570 KM (ESC)
COAL
*«*»» xs UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»**x
STATUS 6 STARTUP 0/87
WASHINGTON UATER POMER HAS PLANS FOR A NEM UNIT, CRESTCN COAL 1, TO 3c
LOCATED IN CRESTON, WASHINGTON. THE COAL PIPED BOILER WILL HAVE A G"33
GENERATING CAPACITY OF 570 MM AND MILL UTILIZE A WET LIMESTONE F33 SYSTEM
FOR CONTROL OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO CCrT.ENCE
IN 1987.
WASHINGTON UATER POWER
CRESTON COAL
2
NEM 570 MM (GROSS)
570 MM (ESC)
COAL
***«» XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *»*»X
STATUS 6 STARTUP 0/87
WASHINGTON MATER POMER HAS PLANS FOR A NEM UNIT, CRESTON 2, TO BE LOCATED
IN CRESTCN. WASHINGTON. THE COAL FIRED BOILER MILL HAVE A GROSS GENEPAT-
INS CAPACITY OF 570 MM AND MILL USE A MET LIMESTONE FGD SYSTEM FOP. CCMTROL
OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1987.
WASHINGTON MATER POMER
CRESTON COAL
3
NEW 570 MM (GROSS)
570 MM (ESC)
COAL
****» XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 12.3X
STATUS 6 STARTUP 0/87
MASHINGTON HATER POMER HAS PLANS FOR A NEM UNIT, CPESTON 3, TO BE LOCATED
IN CRESTON, MASHINGTON. THE COAL FIRED BOILER MILL HAVE A GROSS GENERAT-
ING CAPACITY OF 570 MM AND MILL USE A MET LIMESTONE FGD SYSTEM FC3 CONTROL
OF S02 EMISSIONS. FGD OPERATIONS ARE SCHEDULED TO COMMENCE IN 1937.
MASHINGTON MATER POMER
CRESTON COAL
4
NEM 570 MM (GROSS)
570 MM (ESC)
COAL
»»»*» XS UNKNOWN
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: 12.3X
STATUS 6 STARTUP 0/87
MASHINGTON HATER POWER HAS PLANS FC3 A NEM UNIT, CRESTON 4, TO BE LOCATED
IN CRESTON, WASHINGTON. THE COAL FIRED BOILER HILL HAVE A GROSS GENEFAT-
ING CAPACITY OF 570 MM AMD MILL USE A MET LIMESTONE FGD SYSTEM FC3 CONTROL
OF 302 EMISSIONS. FGO OPERATIONS ARE SCHEDULED TO COMMENCE IN 1937.
WEST PENN POWER
MITCHELL
33
RETROFIT 300 MM (GROSS)
300 MM (ESC)
COAL
2.80 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: l.OX
STATUS 2 STARTUP 8/82
UNIT 33 AT ALLEGHENY POWER SYSTEM'S MITCHELL POWER STATION IN CCUPTNEY,
PENNSYLVANIA IS A 2.8X SULFUR COAL FIRED BOILER UNDER CONSTRUCTION. A
CONTRACT MAS AWARDED TO GEESI FOR A LIME SCRUBBING PROCESS. THE SYSTEM
WILL BE DESIGNED WITH AN S02 REMOVAL EFFICIENCY OF 95X. START UP IS
SCHEDULED FOR AUGUST 1982.
MEST TEXAS UTILITIES
CKLAUNION
1 -
NEM 720 MM (GROSS)
504 MM (ESC)
COAL
.34 XS SUBBITUMINOUS
PROCESS NOT SELECTED
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****x
STATUS 3 STARTUP 12/86
WEST TEXAS UTILITIES HAS PLANS TO BUILD TWO PULVERIZED COAL FIRED BOILERS
TO BE LOCATED NEAR OKLAUNION, TEXAS. THE UTILITY HAS SIGNED A CONTRACT
WITH GENERAL ELECTRIC ENVIRONMENTAL SERVICES FOR AN FGD SYSTEM TO CONTROL
S02 EMISSIONS FROM THIS UNIT. INITIAL OPERATIONS ARE SCHEDULED FOR 12/86.
45
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 2
STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION ABSTRACT
WEST TEXAS UTILITIES WEST TEXAS UTILITIES HAS PLANS TO BUILD TWO PULVERIZED COAL FIRED EOILEHS
CKLAUNION TO BE LOCATED NEAR OKLAUNION, TEXAS. THE UTILITY UILL INCLUDE AN ?G3 S.3-
2 TE.1 FOR EMISSION CONTROL FROM THE 7£0 MM UNIT. THE OKLAC'NION 2 PLANT IS
NEW 720 mi (GROSS) SCHEDULED TO COMMENCE OPERATIONS IN 1990.
720 MM (ESC)
COAL
.34 y.5 SUSSITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: «***X
STATUS 6 STARTUP 0/90
46
-------
Section 3, pages 47-851,
appears in Volume IT.
47
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 4
SUMMARY OF FGD SYSTEMS 8Y COMPANY
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
COMPANY NAME
NO. HW
NO. MU
NO.
NO. MU
PLANNED
NO. MM
ALABAMA ELECTRIC
ARIZONA ELECTRIC POWER
ARIZONA PU3LIC SERVICE
ASSOCIATED ELECTRIC
ATLANTIC CITY ELECTRIC
BASIN ELECTRIC POWER
BIG RIVERS ELECTRIC
CAJUN ELECTRIC POWER
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CENTRAL POWER £ LIGHT
CINCINNATI GAS t ELECTRIC
COLORADO UTE ELECTRIC
COLUMBUS 4 SOUTHERN OHIO ELEC
COMMONWEALTH EDISCN
COOPERATIVE POWER ASSOCIATION
OELKARVA POWER t LIGHT
DESERET GEN t TRANS
DUQUESHE LIGHT
EAST KENTUCKY POWER
FLORIDA POWER I LIGHT
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT t PUR
HCOSIER ENERGY
HOUSTON LIGHTING I POWER
INDIANAPOLIS POWER t LIGHT
IOWA ELECTRIC LIGHT t PUR
JACKSONVILLE ELEC AUTHORITY
KANSAS CITY POWER t LIGHT
KANSAS POWER I LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LANSING BOARD OF UATER t LIGHT
LOS ANGELES DEPT OF UTR I PUR
LOUISVILLE GAS t ELECTRIC
LOWER COLORADO RIVER AUTH
MARQUETTE BOARD OF LIGHT S PUR
MICHIGAN SO CENTRAL PUR AGENCY
MICDLE SOUTH UTILITIES
MINNESOTA POWER & LIGHT
HINNKOTA POWER
MONONGAHELA POWER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
MUSCATINE POWER t UATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POUER
HEW YORK STATE ELEC I GAS
NIAGARA MOHAKK POWER
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
PACIFIC GAS t ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA FOUER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC G 4 T
PLATTE RIVER POUER AUTHORITY
PUBLIC SERVICE INDIANA
PUBLIC SERVICE OF NEW MEXICO
2
2
8
1
1
5
4
6
2
1
1
1
2
3
4
1
2
4
2
2
2
2
5
1
2
3
5
1
2
3
4
3
1
1
4
10
1
1
1
6
1
1
2
4
1
1
1
8
I
1
3
5
2
5
3
3
1
1
1
4
358.
196.
2598.
670.
330.
2590.
1364.
3328.
866.
617.
600.
720.
1300.
1267.
1572.
450.
654.
730.
820.
918.
1150.
1600.
3190.
65.
882.
1992.
3012.
720.
1200.
1054.
1575.
1364.
364.
160.
3280.
3539.
435.
44.
55.
5340.
475.
185.
1336.
2120.
440.
166.
650.
2625.
625.
100.
957.
2600.
1600.
2300.
2751.
724.
233.
279.
650.
1779.
2
2
6
a
0
2
2
0
1
1
0
0
1
2
2
1
2
3
0
2
0
0
0
0
1
0
1
0
0
3
4
1
0
0
0
7
0
0
0
0
1
1
2
2
1
0
0
3
0
0
1
3
0
1
3
0
0
0
0
3
358.
196.
1088.
0.
0.
1140.
484.
0.
416.
617.
0.
0.
650.
820.
822.
450.
654.
180.
0.
918.
0.
0.
0.
0.
441.
0.
532.
0.
0.
1054.
1575.
64.
0.
0.
0.
1894.
0.
0.
0.
0.
475.
185.
1336.
720.
440.
0.
0.
375.
0.
0.
115.
1590.
0.
550.
2751.
0.
0.
0.
0.
1245.
0
0
2
1
0
3
1
0
0
0
0
0
0
1
0
0
0
0
1
0
1
0
0
1
1
1
1
0
0
0
0
0
1
0
a
i
0
1
1
0
0
0
0
2
0
1
0
0
0
1
1
0
0
1
0
3
1
0
1
1
0.
0.
1510.
670.
0.
1450.
440.
0.
a.
0.
0.
0.
0.
447.
0.
0.
0.
0.
410.
0.
500.
0.
0.
65.
441.
492.
530.
0.
0.
0.
0.
0.
364.
0.
0.
495.
0.
44.
55.
0.
0.
0.
0.
1400.
0.
166.
0.
0.
0.
100.
421.
0.
0.
100.
0.
724.
233.
0.
650.
534.
0
0
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
a
0
a
a
0
0
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0.
0.
0.
0.
0.
0.
440.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
650.
0.
0.
0.
0.
1500.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
421.
0.
0.
0.
0.
0.
0.
279.
0.
0.
0
0
0
0
1
0
0
6
1
0
1
1
1
0
2
0
0
1
1
0
0
2
5
0
0
0
3
1
2
0
a
2
0
1
4
2
1
0
0
6
0
0
0
0
0
0
1
5
1
0
0
2
2
3
0
0
0
0
0
0
0.
0.
0.
0.
330.
0.
0.
3328.
450.
0.
600.
720.
650.
0.
750.
0.
0.
550.
410.-
0.
0.
1600.
3190.
0.
0.
0.
1950.
720.
1200.
0.
0.
1300.
0.
160.
3280.
1150.
435.
0.
0.
5340.
0.
0.
0.
0.
0.
0.
650.
2C50.
6£S.
0.
0.
1010.
1600.
1650.
0.
0.
0.
0.
0.
0.
NOTE - PLANNED STATUS INCLUDES LETTER OF INTENT SIGNEDt REQUESTING/EVALUATING BIDS,
AND CONSIDERING ONLY FGO SYSTEMS
652
-------
EPA UTILITY FGO SURVEY: OCT03EP - DECEM2E3 1981
SECTION 4
SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
STATUS
OPERATIONAL CONSTRUCTION CCNTPACT
AUAROED
PLANNED
COMPANY NAME
PUR AUTHORITY OF STATE OF NY
SALT RIVER PROJECT
SAN MIGUEL ELECTRIC
SEMINOLE ELECTRIC
SIKESTCN BPD OF MUNICIPAL UTIL
SOUTH CAROLINA PU3LIC SERVICE
SOUTH MISSISSIPPI ELEC PUR
SOUTHERN ILLINOIS POUER
SOUTHERN INDIANA GAS t ELEC
SOUTHWESTERN ELECTRIC POUER
SOY LAND POUER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD MATER. LIGHT i PUR
ST. JOE ZINC
SUNFLOWER ELECTRIC
TAMPA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POUER AGENCY
TEXAS POUER S LIGHT
TEXAS UTILITIES
TUCSON ELECTRIC POUER
UNITED PCUER ASSOCIATION
UTAH POUER i LIGHT
WASHINGTON HATER POUER
UEST PENH POUER
UEST TEXAS UTILITIES
NO.
1
3
1
2
1
5
2
1
2
3
1
1
1
1
1
1
6
1
3
a
2
i
6
4
1
2
MM
700.
640.
400.
1240.
235.
1700.
248.
173.
530.
2160.
500.
194.
165.
60.
347.
475.
2553.
400.
1882.
5585.
740.
50.
2216.
2280.
300.
1224.
NO.
0
2
1
0
1
3
2
1
1
0
0
1
1
1
0
0
4
0
1
4
0
0
4
0
0
0
MM
0.
560.
400.
0.
235.
700.
248.
173.
265.
0.
0.
194.
185.
60.
0.
0.
1145.
0.
382.
2585.
0.
0.
1416.
0.
0.
0.
NO.
0
0
0
1
0
1
0
0
0
0
0
0
0
0
1
0
2
1
0
0
0
1
2
0
1
0
MU
0.
0.
0.
620.
0.
500.
0.
0.
0.
0.
0.
0.
0.
0.
347.
0.
1408.
400.
0.
0.
0.
50.
800.
0.
300.
0.
NO.
0
0
0
1
0
1
0
0
0
2
0
0
0
0
0
1
0
0
2
1
2
0
0
0
0
1
nu
0.
0.
0.
620.
0.
500.
0.
0.
0.
1440.
0.
0.
0.
0.
0.
475.
0.
0.
1500.
750.
740.
0.
0.
0.
0.
504.
NO.
^
1
0
0
0
0
0
0
1
1
1
0
0
0
0
0
0
0
0
3
0
0
0
4
0
1
MU
700.
ZSO.
0.
0.
0.
0.
0.
0.
265.
720.
500.
0.
0.
0.
0.
0.
0.
t>.
0.
2250.
0.
0.
0.
2280.
0.
720.
TOTALS
222 102781.
94 32683.
40 16666.
17 9819.
71 43613.
NOTE - PUNNED STATUS INCLUDES LETTER OF INTENT SIGNED,
AND CONSIDERING ONLY FGD SYSTEMS
REQUESTING/EVALUATING BIDS,
853
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 5
SUMMARY OF FGD SYSTEMS BY SYSTEM SUPPLIER
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTPACT
AWASOED
SYSTEM SUPPLIER/PROCESS
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTOHE
SODIUM CAR30NATE
TOTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK I MILCOX
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
TOTAL -
DAVY MCKEE
UELLMAN LORD
TOTAL -
ENVIRONEERING, RILEY STOKER
LIMESTONE
TOTAL -
FLAKT
LIME/SODIUM CARBONATE
TOTAL -
FMC
DUAL ALKALI
TOTAL -
GE ENVIRONMENTAL SERVICES
DUAL ALKALI
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LIMESTONE
LIME/SPRAY DRYING
PROCESS NOT SELECTED
TOTAL -
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
NO.
2
5
1
2
10
6
1
7
7
8
2
17
6
11
Z
2
21
8
8
3
3
1
1
3
3
1
a
8
3
1
1
1
23
7
7
2
2
MM
822.
2616.
10.
880.
4328.
1658.
280.
1938.
4211.
2521.
1017.
7749.
1160.
5075.
1480.
654.
8369.
2074.
2074.
664.
664.
100.
100.
1107.
1107.
617.
4138.
5000.
579.
10.
44.
504.
10892.
2356.
2356.
882.
882.
NO.
2
3
1
2
8
5
1
6
3
6
0
9
6
6
2
2
16
7
7
3
3
0
0
1
1
1
7
1
3
1
0
0
13
1
1
1
1
MM
822.
1176.
10.
880.
2888.
1163.
280.
1443.
1986.
2102.
0.
4088.
1160.
2532.
1480.
654.
5826.
1540.
1540.
664.
664.
0.
0.
265.
265.
617.
3838.
800.
579.
10.
0.
0.
5844.
110.
110.
441.
441.
NO.
0
0
0
0
0
1
0
1
3
2
2
7
0
3
0
0
3
1
1
0
0
1
1
1
1
0
1
5
0
0
1
0
7
3
3
1
1
MM
0.
0.
0.
0.
0.
495.
0.
495.
1575.
419.
1017.
3011.
0.
1043.
0.
0.
1043.
534.
534.
0.
0.
100.
100.
421.
421.
0.
300.
2700.
0.
0.
44.
0.
3044.
1227.
1227.
441.
441.
NO.
0
2
0
0
2
0
0
0
1
0
0
1
0
2
0
0
2
0
0
0
0
0
0
1
1
0
0
2
0
0
0
1
3
3
3
0
0
irA
0.
1440.
0.
0.
1440.
0.
0.
0.
650.
0.
0.
650.
0.
1500.
0.
0.
1500.
0.
0.
0.
0.
0.
0.
421.
421.
0.
0.
1500.
0.
0.
0.
504.
2004.
1019.
1019.
0.
0.
854
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1=81
SECTION 5
SUMMARY OF FGO SYSTEMS BY SYSTEM SUPPLIER
STATUS
TOTAL OPERATIONAL CONSTRUCTION CCMTPACT
AWARDED
SYSTEM SUPPLIER/PROCESS
MORRISON I KNUDSEN/U.S.B.M.
CITRATE
TOTAL -
M.M. KELLOGG
LIME
LIMESTONE
TOTAL -
PEABOOY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
RESEARCH-COTTRELL
LIMESTONE
LIME/ LIMESTONE
LIME/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY- AUTHORITY
LIMESTONE
TOTAL -
THYSSEN/CEA
DUAL ALKALI
LIME
LIME/ALKALINE FLYASH
SCOIUM CARBONATE
TOTAL -
UNITED ENGINEERS
MAGNESIUM OXIDE
TOTAL -
MHEELABRATCR-FRYE/R . I .
SODIUM CARBONATE/SPRAY DRYING
TOTAL -
NO.
1
1
1
6
7
8
i
9
14
1
1
16
1
1
1
1
1
1
5
3
10
3
3
1
1
MM
60.
60.
917.
2760.
3677.
3418.
475.
3093.
5261.
475.
50.
5786.
100.
100.
550.
550.
299.
500.
2305.
375.
3479.
724.
724.
440.
440.
NO.
1
1
1
2
3
4
1
5
11
0
0
11
0
0
1
1
1
0
3
3
7
0
0
1
1
MM
60.
60.
917.
560.
1477.
1178.
475.
1653.
3315.
0.
0.
3815.
0.
0.
550.
550.
299.
0.
005.
375.
1579.
0.
0.
440.
440.
NO.
0
0
0
3
3
2
0
2
2
0
1
3
1
1
0
0
0
1
2
0
3
3
3
0
0
MM
0.
0.
0.
1760.
1760.
1120.
0.
1120.
696.
0.
50.
746.
100.
100.
0.
0.
0.
500.
1400.
0.
1900.
724.
724.
0.
0.
NO.
0
0
0
1
1
2
0
2
1
1
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
r.M
0.
0.
0.
440.
440.
1123.
0.
1120.
753.
475.
0.
1225.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
TOTAL -
151 59168.
94 32683.
40 16666.
17 9819.
855
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 6
SUMMARY OF FGD SYSTEMS BY PROCESS
STATUS
TOTAL OPERATIONAL CONSTRUCTION CONTRACT
AWARDED
TOTALS
SALEABLE PRODUCT PROCESS
X OF TOTAL MM
182 7750
-------
EPA UTILITY FGO SURVEY: CCTC3ER - DECEMBER 1961
SECTION 7
SUMMARY OF OPERATIONAL FGO SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
CITRATE
G.F. WEATON
DUAL ALKALI
A.B. BROWN
NEUTON
CANE RUN
LIME
CONESVILLE
CONESVILLE
CANE RUN
GREEN
GREEN
GREEN RIVER
MILL CREEK
EAST BEND
PLEASANTS
PLEASANTS
CANE RUN
HAWTHORN
HAUTHORN
MILL CREEK
MILL CREEK
PADDY'S RUN
BRUCE MANSFIELD
BRUCE MANSFIELD
ELRAMA
HUNTER
HUNTER
HUNTINSTON
PHILLIPS
BRUCE MANSFIELD
LIMESTONE
PETERSBURG
POUERTON
SOUTHWEST
UINYAH
LA CYGNE
MARION
SAN MIGUEL
SIKESTON .
UINYAH
WINYAH
JEFFREY
JEFFREY
LAURENCE
LAURENCE
SANDOU
UIDOUS CREEK
DUCK CREEK
R.D. MORROH. SR.
R.D. MCRROM, SR.
KONTICELLO
UNIT NO.
1
1
1
6
5
6
4
1
2
1-3
3
2
1
2
5
3
4
1
2
6
1
2
1-4
1
2
1
1-6
3
3
51
1
4
1
4
1
1
2
3
1
2
4
5
4
7
1
1
2
3
CAPACITY
rw
60.
60.
265.
617.
299.
1181.
411.
411.
188.
242.
242.
64.
427.
650.
668.
668.
200.
90.
90.
353.
350.
72.
917.
917.
510.
360.
360.
366.
408.
917.
9886.
532.
450.
194.
230.
874.
173.
400.
235.
140.
280.
540.
490.
125.
420.
382.
575.
416.
124.
124.
800.
INITIAL
STARTUP
11/79
3/79
9/79
4/79
1/77
6/78
8/76
12/79
11/80
9/75
8/78
3/81
3/79
10/80
12/77
11/72
8/72
12/80
12/81
4/73
12/75
7/77
10/75
5/79
6/80
5/78
7/73
6/80
12/77
4/80
4/77
7/81
2/73
5/79
8/81
6/81
7/77
5/80
8/78
1/80
1/77
4/78
12/80
3/81
7/76
8/78
6/79
5/78
STARTUP
1/80
4/79
12/79
O/ 0
2/77
7/73
8/77
12/79
12/80
6/76
3/79
3/81
3/79
12/80
7/78
O/ 0
O/ 0
4/81
4/82
O/ 0
6/76
10/77
10/75
5/79
6/80
5/78
6/74
6/80
12/77
6/81
9/77
O/ 0
6/73
6/79
O/ 0
9/81
O/ 0
6/80
O/ 0
5/80
O/ 0
O/ 0
1/81
9/81
8/78
8/78
6/79
10/78
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
857
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 7
SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
MEROM
CCSOHADO
CC'CNAOO
CRAIG
CRAIG
TOM3IGBEE
TO"3IG3EE
APACHE
APACHE
CHOLLA
CHOLLA
CHOLLA
OALLMAN
LARAMIE RIVER
LARAMIE RIVER
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
WIDOWS CREEK
LIMESTONE/ALKALINE FLY ASH
SHERBURNE
SHER3URNE
LIME/ALKALINE FLYASH
COAL CREEK
COAL CREEK
FCUR CORNERS
FOUR CORNERS
FOUR CORNERS
CLAY BOSWELL
COLSTRIP
COLSTRIP
MILTON R. YOUNG
LIME/LIMESTONE
SHAU'NEE
SHAUNEE
LIME/SPRAY DRYING
. RIVERSIDE
SODIUM CARBONATE
JIM BRIOGER
NAUGHTCN
REID GARDNER
REID GARDNER
REID GARDNER
UNIT NO.
2
1
2
1
2
2
3
2
3
1
2
4
3
1
2
1
2
3
a
i
2
1
2
1
2
3
4
1
2
2
IDA
10B
6-7
4
3
1
2
3
CAPACITY
MM
441.
280.
280.
410.
410.
179.
179.
98.
98.
119.
264.
126.
185.
570.
570.
595.
595.
595.
550.
14098.
740.
740.
1480.
327.
327.
175.
175.
229.
475.
360.
360.
185.
2613.
10.
10.
20.
110.
110.
550.
330.
125.
125.
125.
INITIAL
STARTUP
12/81
11/79
7/80
10/80
12/79
9/78
6/79
8/78
6/79
10/73
4/73
3/81
12/80
7/80
7/81
4/77
5/73
2/79
5/77
3/76
3/77
7/79
7/80
11/79
11/79
11/79
4/80
9/75
5/76
9/77
4/72
4/72
11/80
9/79
9/81
3/74
4/74
6/76
STARTUP
2/82
12/79
10/81
O/ 0
s/ao
9/73
6/79
1/79
4/79
12/73
6/78
6/81
0/81
7/80
6/31
10/78
O/ 0
O/ 0
1/73
5/76
4/77
8/79
9/80
O/ 0
O/ 0
O/ 0
O/ 0
11/75
10/76
6/78
O/ 0
O/ 0
12/80
2/80
12/31
4/74
O/ 0
7/76
1255.
THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
858
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 7
SUMMARY OF OPERATIONAL FGO SYSTEMS BY PROCESS AND UNIT
PROCESS/
UNIT NAME
UNIT NO.
CAPACITY
KM
INITIAL
STARTUP
CC1MEPCIAL
STARTUP
SODIUM CARBONATE/SPRAY DRYING
COYOTE 1
KELLMAN LORD
DEAN H. MITCHELL 11
DELAWARE CITY 1
DELAWARE CITY 2
DELAWARE CITY 3
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
440.
440.
115.
60.
60.
60.
361.
350.
534.
1540.
4/81
7/76
5/80
5/80
5/80
4/78
8/78
12/79
5/81
6/77
5/80
5/80
5/80
4/73
8/78
O/ 0
TOTAL
32683.
859
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
PROCESS/
UNIT HAME
SECTION 8
SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FGD SYSTEMS
THROHAMAY
UNIT NO STABILIZED UNSTABILIZED
BYPRODUCT
TYPE DISPOSITION
CITRATE
6.F. MEATOM
CUAL ALKALI
A.B. BROUN
NEUTON
CANE RUN
LINE
ELEMENTAL SULFUR
LIMESTONE
PETERSBURG
POWERTON
SOUTHWEST
UINYAH
LA CYGNE
MARION
SAN MIGUEL
SIKESTON
UINYAH
UINYAH
JEFFREY
JEFFREY
LAURENCE
LAUPENCE
SANDOU
WIDOWS CREEK
DUCK CREEK
R.O. MORROW,
R.D. MORHCU,
MCNTICELLO
MEROH
COPONADO
CCPONADO
CRAIG
CRAIG
TC-BIGBEE
TOK3IGBEE
SR.
SR.
3
51
1
4
1
4
1
1
2
3
1
2
4
5
4
7
1
1
2
3
2
1
2
1
2
2
3
LANDFILL
LANDFILL
LANDFILL
CONESVILLE
CONES VI LLE
CANE RUN
GREEN
GREEN
GREEN RIVER
MILL CREEK
EAST BEND
PLEASANTS
PLEASANTS
CANE RUN
HAWTHORN
HAWTHORN
MILL CREEK
MILL CREEK
PADDY'S RUN
BRUCE MANSFIELD
BRUCE MANSFIELD
ELPAHA
HUNTER
HUNTER
KUNTINGTON
PHILLIPS
BRUCE MANSFIELD
5
6
4
1
2
1-3
3
2
1
2
5
3
4
1
2
6
1
2
1-4
1
2
1
1-6
3
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
POND
LANDFILL
POND
POND
LANDFILL
POND
POND
LANDFILL
LANDFILL
POND
POND
FCNO
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
LANDFILL
POND
LANDFILL
LANDFILL
POND
POND
POND
POND
POND
POND
POND
POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
POND
POND
FOND
POND
POND
NONE
NONE
NONE
NONE
NONE
860
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 6
SUMMARY OF END-PRCOUCT DISPOSAL PRACTICES FOR OPERATIONAL FGO SYSTEMS
PROCESS/
UNIT NAME
APACHE
APACHE
CHOLLA
CHOLLA
CHOLLA
OALLKAN
LARAMIE RIVER
LARAMIE RIVER
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
WIDOWS CREEK
UNIT
2
3
1
2
4
3
1
2
1
2
3
8
NO STABILIZED UNSTABILIZED TYPE DISPOSITION
POM)
POND
POND
POND
POND
LANDFILL NONE
LANDFILL
LANDFILL LANDFILL
LANDFILL
LANDFILL
LANDFILL
POND
LIMESTONE/ALKALINE FLYASH
SHERBURNE
SHERBURNE
LIME/ALKALINE FLYASH
COAL CREEK
COAL CREEK
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
CLAY BOSUELL
COLSTRIP
COLSTRIP
MILTON R. YOUNG
LIME/LIMESTONE
SHAHNEE
SHAUNEE
1
2
1
2
1
2
3
4
1
2
2
IDA
10B
POND
POND
POND
POND
POND
POND
POND
LANDFILL
LANDFILL
LANDFILL
LIME/SPRAY DRYING
RIVERSIDE
SODIUM CARBONATE
JIM BRIDGER
NAUGHTON
REID GARDNER
REID GARDNER
REID GARDNER
6-7
LANDFILL
POND
POND
POND
POND
SODIUM CARBONATE/SPRAY DRYING
COYOTE 1 LANDFILL
MELLMAN LORD
DEAN H. MITCHELL 11
DELAWARE CITY 1
DELAWARE CITY 2
DELAWARE CITY 3
SAN JUAN 1
SAN JUAN 2
SAN JUAN 3
POND
POND
POND
ELEMENTAL SULFUR
SULFURIC ACID
SULFURIC ACID
SULFURIC :z:o
ELEMENTAL SULFUR
ELEMENTAL SULFUR
SULFURIC ACID
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
661
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1901
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT MAKE UNIT MO.
ALABAMA ELECTRIC
TOMBIGBEE 2
ALABAMA ELECTRIC
TOM3IGBEE 3
ARIZONA ELECTRIC POWER
APACHE 2
ARIZONA ELECTRIC POWER
APACHE 3
ARIZONA PUBLIC SERVICE
CHOLLA 1
ARIZONA PUBLIC SERVICE
CHOLLA 2
ARIZONA PUBLIC SERVICE
CHOLLA 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BASIN ELECTRIC POWER
LARAMIE RIVER 1
BASIN ELECTRIC POWER
LARAMIE RIVER 2
BIG RIVERS ELECTRIC
GREEN 1
BIG RIVERS ELECTRIC
GREEN 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEWTON 1
CINCINNATI GAS I ELECTRIC
EAST BEND 2
COLORADO UTE ELECTRIC
CRAIG 1
COLORADO UTE ELECTRIC
CRAIG 2
COLUMBUS ft SOUTHERN OHIO ELEC
CCNESVILLE 5
COLUMBUS ft SOUTHERN OHIO ELEC
CONESVILLE 6
COMMONWEALTH EDISON
POWERTOH 51
COOPERATIVE POWER ASSOCIATION
NEW OR 1
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
IAPACITY
MM
179.
179.
98.
98.
119.
264.
126.
175.
175.
229.
570.
570.
242.
242.
416.
617.
650.
410.
410.
411.
411.
450.
327.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIME/ALKALINE FLYASH
GE ENVIRONMENTAL SERVICES
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY STOKER
DUAL ALKALI
GE ENVIRONMENTAL SERVICES
LIME
BABCOCK < WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION. UCP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
START-UP
GATE
9/73
6/79
8/78
6/79
10/73
4/78
3/81
11/79
11/79
11/79
7/SO
7/81
12/79
11/80
7/76
9/79
3/81
10/80
12/79
1/77
6/78
4/80
7/79
COMBUSTION ENGINEERING
862
-------
EPA UTILITY FGO SUSVEY: CCTOSER - OECEf.SER 1981
SECTION 9
SUMMARY OF FGO SYSTEMS IN OPERATION
COMPANY NAME/
UHIT NAME UNIT NO.
COOPERATIVE POWER ASSOCIATION
COAL CREEK Z
DELMARVA POWER S LIGHT
DELAWARE CITY 1
DELMARVA POWER ft LIGHT
DELAWARE CITY 2
DELMARVA POWER ft LIGHT
DELAWARE CITY 3
OUQUESNE LIGHT
ELRAHA 1-4
DUQUESNE LIGHT
PHILLIPS 1-6
HOOSIER ENERGY
MEROM 2
INDIANAPOLIS POWER ft LIGHT
PETERSBURG 3
KANSAS CITY POWER S LIGHT
HAWTHORN 3
KANSAS CITY POWER & LIGHT
HAWTHORN 4
KANSAS CITY POWER ft LIGHT
LA CYGNE 1
KANSAS POWER ft LIGHT
JEFFREY 1
KANSAS POWER t LIGHT
JEFFREY 2
KANSAS POWER ft LIGHT
LAURENCE 4
KANSAS POWER S LIGHT
LAURENCE 3
KENTUCKY UTILITIES
GREEN RIVER 1-3
LOUISVILLE GAS t ELECTRIC
CANE RUN 4
LOUISVILLE GAS t ELECTRIC
CANE RUN 5
LOUISVILLE GAS S ELECTRIC
CANE RUN 6
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 1
LOUISVILLE GAS t ELECTRIC
HILL CREEK 2
LOUISVILLE GAS ft ELECTRIC
HILL CREEK 3
LOUISVILLE GAS t ELECTRIC
NEW OR C
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
:APACITY
MM
327.
60.
60.
60.
510.
408.
441.
532.
90.
90.
874.
540.
490.
125.
420.
64.
188.
200.
299.
358.
350.
427.
72.
PROCESS/
SYSTEM SUPPLIER
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
UELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY MCKEE
UELLMAM LORD
DAVY MCKEE
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK t WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
THYSSEN/CEA
LIME
COMBUSTION ENGINEERING
LIKE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
START-UP
DATE
7/80
s/eo
5/60
5/80
10/75
7/73
12/81
12/77
11/72
8/72
2/73
8/78
1/80
1/77
4/78
9/75
8/76
12/77
4/79
12/80
12/81
8/78
4/73
COMBUSTION ENGINEERING
863
-------
EPA UTILITY FGD SURVEY: OCTC3ER - DECEMBER 1981
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY HAME/
UNIT NAME UNIT NO.
MINNESOTA PQUER I LIGHT
CLAY BOSWELL 4
MINNKOTA POUER
MILTON R. YOUNS Z
MOIiONGAHELA POWER
PLEASANTS 1
MONONGAHELA POUER
PLEASANTS 2
MONTANA POUER
COLSTRIP 1
MONTANA POUER
COLSTRIP 2
MONTANA-DAKOTA UTILITIES
COYOTE 1
NEVADA POWER
REID GARDNER 1
NEVADA POUER
REID GARDNER Z
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POUER
RIVERSIDE 6-7
NORTHERN STATES POUER
SHERBURNE 1
NORTHERN STATES POUER
SHERBURNE 2
PACIFIC POUER & LIGHT
JIM BRIDGER 4
PENNSYLVANIA POUER
BRUCE MANSFIELD 1
PENNSYLVANIA FOUER
BRUCE MANSFIELD 2
PENNSYLVANIA POUER
BRUCE MANSFIELD 3
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 3
SALT RIVER PROJECT
CORONAOO 1
SALT RIVER PROJECT
CORONAOO 2
NEU OR (
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
NEU
NEM
:APACITY
MU
475.
IBS.
663.
668.
360.
360.
440.
125.
125.
125.
115.
110.
740.
740.
550.
917.
917.
917.
361.
350.
534.
280.
280.
PROCESS/
SYSTEM SUPPLIER
LIME/ALKALINE FLYASH
PEABODY PROCESS SYSTEMS
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME
BABCOCK * UILCOX
LIME
BABCOCK t UILCOX
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME/ALKALINE FLYASH
THYSSEN/CEA
SODIUM CARBONATE/SPRAY DRYING
MHEELABRATCR-FRYE/R . I .
SODIUM CARBONATE
THYSSEN/CEA
SODIUM CARBONATE
THYSSEN/CEA
SODIUM CARBONATE
THYSSEN/CEA
UELLMAN 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
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIME
M.U. KELLOGG
UELLMAN LORD
DAVY MCKEE
UELLMAN LORD
DAVY KCKEE
UELLMAN LORD
DAVY MCKEE
LIMESTONE
M.U. KELLOGG
LIMESTONE
M.U. KELLOGG
STAPT-UP
DATE
6/80
0/77
3/79
10/80
9/75
5/76
4/61
3/74
4/74
6/76
7/7&
11/80
3/76
3/77
9/79
12/75
7/77
6/80
4/78
8/78
12/79
11/79
7/80
864
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
SAN MIGUEL ELECTRIC
SAN MIGUEL 1
SIKESTON BPD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 2
SOUTH CAROLINA PUBLIC SERVICE
MINYAH 3
SOUTH CAROLINA PUBLIC SERVICE
HINYAH 4
SOUTH MISSISSIPPI ELEC PUR
R.O. MORROW, SR. 1
SOUTH MISSISSIPPI ELEC PUR
R.D. MORROW. SR. 2
SOUTHERN ILLINOIS POWER
MARION 4
SOUTHERN INDIANA GAS i ELEC
A.B. BROUN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
SPRINGFIELD MATER. LIGHT I PUR
DALLMAN 3
ST. JOE ZINC
G.F. WE ATOM 1
TENNESSEE VALLEY AUTHORITY
SHAKNEE 10A
TENNESSEE VALLEY AUTHORITY
SHAUNEE 10B
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS POUER ft LIGHT
SANDOM 4
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
TEXAS UTILITIES
MONTICELLO 3
UTAH POUER S LIGHT
HUNTER 1
UTAH POWER t LIGHT
HUNTER 2
NEU C«J CAPACITY
RETROFIT MM
NEW
NEM
NEW
NEM
NEM
NEW
NEU
NEU
NEU
NEH
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEU
NEU
NEH
NEU
NEU
NEU
NEU
400.
235.
140.
280.
280.
124.
124.
173.
265.
194.
185.
60.
10.
10.
575.
550.
382.
595.
595.
595.
800.
360.
360.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
BABCOCK & UILCOX
LIMESTONE
BABCOCK & MILCOX
LIMESTONE
BABCOCK t UILCOX
LIMESTONE
BABCOCK 1 UILCOX
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
ENVIRONEERING, RILEY STOKER
LIMESTONE
BABCOCK t UILCOX
DUAL ALKALI
FMC
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIMESTONE
RESEARCH-COTTRELL
CITRATE
MORRISON t KNUDSEN/U.S.B.M.
LIME/LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
STAKT-U?
DATE
8/51
6/81
7/77
5/80
7/81
8/73
6/79
5/79
3/79
4/77
12/80
11/79
4/72
4/72
3/81
5/77
12/80
4/77
5/78
2/79
5/78
5/79
6/80
865
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 9
SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/ NEW OR CAPACITY PROCESS/ START-UP
UNIT NAME UNIT NO. RETROFIT MM SYSTEM SUPPLIER DATE
UTAH POWER t LIGHT NEW 366. LIME 5/78
HUHTINGTON 1 GE ENVIRONMENTAL SERVICES
UTAH POWER t LIGHT RETROFIT 330. SODIUM CARBONATE 9/81
HAUGHTON 3 AIR CORRECTION DIVISION. UOP
TOTAL 3Z683.
866
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
ASSOCIATED ELECTRIC
THOMAS HILL 3
BASIN ELECTRIC POWER
ANTELOPE VALLEY 1
BASIN ELECTRIC POUER
ANTELOPE VALLEY 2
BASIN ELECTRIC POUER
LARAMIE RIVER 3
BIG RIVERS ELECTRIC
D.B. UILSON 1
COLORADO UTE ELECTRIC
CRAIG 3
DESERET GEN ft TRANS
BONANZA 1
EAST KENTUCKY POUER
SPUR LOCK 2
GRAND HAVEN BRD OF LIGHT t PMR
J.B. SIMS 3
HOOSIER ENERGY
MEROM 1
HOUSTON LIGHTING ft POUER
U.A. PARISH 8
INDIANAPOLIS POUER ft LIGHT
PETERSBURG 4
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE GAS ft ELECTRIC
MILL CREEK 4
MARQUETTE BOARD OF LIGHT t PUR
SHIR AS 3
MICHIGAN SO CENTRAL PUR AGENCY
PROJECT 1
MONTANA POWER
COLSTRIP 3
MONTANA POUER
COLSTRIP 4
MUSCATINE POUER ft UATER
MUSCATINE 9
NIAGARA MOHAWK POUER
CHARLES R. HUNTLEY 66
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NEU OR
RETROFIT
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
NEU
RETROFIT
NEW
CAPACITY
755.
755.
670.
440.
440.
570.
440.
447.
410.
500.
65.
441.
492.
530.
364.
495.
44.
55.
700.
700.
166.
100.
421.
PROCESS/
SYSTEM SUPPLIER
LIME
BABCOCK ft UILCOX
LIME
BABCOCK t UILCOX
LIMESTONE
M.M. KELLOGG
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
BABCOCK ft UILCOX
LIMESTONE
M.U. KELLOGG
LIME/SPRAY DRYING
BABCOCK ft UILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIME
THYSSEN/CEA
LIME
BABCOCK ft UILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
BABCOCK ft MILCOX
LIME
AMERICAN AIR FILTER
LIME/SPRAY DRYING
GE ENVIRONMENTAL SERVICES
LIMESTONE
BABCOCK ft MILCOX
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIME/ALKALINE FLYASH
THYSSEN/CEA
LIMESTONE
RESEARCH-COTTRELL
AQUEOUS CARBONATE/SPRAY DRYING
ROCKUELL INTERNATIONAL
DUAL ALKALI
FMC
START-UP
DATE
12/34
12/84
1/32
10/83
10/85
LI/82
7/34
4/33
9/84
1/83
1/63
5/82
11/82
10/84
1/62
6/82
9/82
6/82
10/83
0/34
9/62
4/62
6/83
667
-------
EFA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 10
SUMMARY OF FGD SYSTEMS UNDER CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
PACIFIC FCWEH & LIGHT
JIM BRIDGE!? 2A
PHILADELPHIA ELECTRIC
CROM3Y 1
PHILADELPHIA ELECTRIC
EODYSTONE 1
PHILADELPHIA ELECTRIC
EODYSTONE 2
PLAINS ELECTRIC G S, T
PLAINS ESCALANTE 1
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEM MEXICO
SAN JUAN 4
SEMINOLE ELECTRIC
SEMINOLE 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SUNFLOWER ELECTRIC
HOLCOMB 1
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
UNITED POWER ASSOCIATION
STANTON 1A
UTAH POWER t LIGHT
HUNTER 3
UTAH POWER t LIGHT
HUNTER 4
WEST PENN POWER
MITCHELL 33
NEM OR (
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEM
NEW
NEM
NEM
NEW
NEW
RETROFIT
RETROFIT
NEM
NEM
NEM
NEM
RETROFIT
:APACITY
MW
100.
150.
240.
334.
233.
650.
534.
620.
500.
347.
704.
704.
400.
50.
400.
400.
300.
PROCESS/
SYSTEt SUPPLIER
LIME/SODIUM CARBONATE
FLAKT
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
M.M. KELLOGG
MELLMAN LORD
DAVY MCKEE
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
RESEARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIME
GE ENVIRONMENTAL SERVICES
START-UP
DATS
1/82
5/63
12/82
12/82
12/83
8/82
6/82
3/83
11/83
9/83
0/83
0/83
10/82
6/82
6/83
6/85
8/82
TOTAL
16666.
868
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1=31
SECTION 11
SUMMARY OF CONTRACT AWARDED F6D SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
BIG RIVERS ELECTRIC
0.8. WILSON 2
EAST KENTUCKY POWER
J.K. SMITH 1
HOUSTON LIGHTING I PCWER
LIMESTONE 1
HOUSTON LIGHTING S POWER
LIMESTONE 2
NORTHERN INDIANA PUB SERVICE
SCHAHFER 18
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
SEMINOLE ELECTRIC
SEMIHOLE 2
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEY 1
TAMPA ELECTRIC
BIG BEND 4
TEXAS POWER & LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
TEXAS UTILITIES
MARTIN LAKE 4
TUCSON ELECTRIC POWER
SPRINSERVILLE 1
TUCSON ELECTRIC POWER
SPRINGERVILLE 2
WEST TEXAS UTILITIES
OKLAUNION 1
NEW OR
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
CAPACITY
MM
440.
650.
750.
750.
421.
279.
620.
500.
720.
720.
475.
750.
750.
750.
370.
370.
504.
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
M.W. KELLOGS
LIME
BABCOCK & WILCOX
LIMESTONE
CCM5USTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
DUAL ALKALI
FMC
LIME/SPRAT DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/LIMESTONE
RE5EARCH-COTTRELL
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
GE ENVIRONMENTAL SERVICES
LIMESTONE
RESEARCH-COTTRELL
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
PROCESS NOT SELECTED
GE ENVIRONMENTAL SERVICES
START-UP
DATE
O/ 0
8/37
12/86
12/87
6/85
12/83
1/85
5/88
3/66
12/84
3/85
8/85
8/87
0/89
2/85
3/87
12/86
TOTAL
9819.
869
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
SECTION 12
SUTOARY OF PLANNED FGO SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
NEW OR
RETROFIT
CAPACITY
MW
PROCESS/
SYSTEM SUPPLIER
STA3T-UP
DATE
LETTER OF INTENT SIGNED
IOWA ELECTRIC LIGHT 1 PUR
GUTHRIE CO. 1
KENTUCKY UTILITIES
HANCOCK 1
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 5
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE 6
MIDDLE SOUTH UTILITIES
UNASSIGNED 1
MIDDLE SOUTH UTILITIES
UHASSIGNED 2
MIDDLE SOUTH UTILITIES
MILTON 1
MIDDLE SOUTH UTILITIES
MILTON Z
NEVADA POWER
REID GARDNER 4
NEW YORK STATE ELEC I GAS
SOMERSET 1
TOTAL
REQUESTING/EVALUATING
CAJUN ELECTRIC POWER
OXBOW 1
DESERET GEN ( TRANS
BONANZA Z
GENERAL PUBLIC UTILITIES
COAL 1
GENERAL PUBLIC UTILITIES
SEMARD 7
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RIVER PUR PARK1
JACKSONVILLE ELEC AUTHORITY
ST. JOHNS RIVER PKR PARK2
LOUISVILLE GAS I ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS i ELECTRIC
TRIM3LE COUNTY 2
SOUTHERN INDIANA GAS I ELEC
A.B. BROWN 2
TEXAS UTILITIES
FOREST GROVE 1
TOTAL
NEW
NEW
NEW
NEW
HEW
NEW
NEW
NEW
NEW
NEW
BIDS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
720.
650.
890.
890.
890.
890.
890.
890.
250.
625.
7585.
540.
410.
625.
690.
600.
600.
575.
575.
265.
750.
5630.
870
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK I WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
SODIUM CARBONATE
THYSSEH/CEA
LIMESTONE
PEABOOY PROCESS SYSTEMS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
11/87
4/39
0/90
0/92
0/89
0/93
0/83
0/91
4/83
6/84
0/85
0/88
5/91
5/89
12/85
6/87
7/85
7/89
1/85
0/87
-------
EPA UTILITY FCO SURVEY: 'C'CSEH - DECEM5EB 19S1
SECTICN 12
SUMMARY OF PLANNED FGO SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
CONSIDERING FGO SYSTE
ATLANTIC CITY ELECTRIC
CUMBERLAND 1
CAJUM ELECTRIC POWER
CHICOT 1
CAJUN ELECTRIC POWER
CHICOT 2
CAJUM ELECTRIC POWER
CHICOT 3
CAJUN ELECTRIC POWER
CHICOT 4
CAJUN ELECTRIC POWER
OXBOW 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
CENTRAL MAINE POWER
SEARS ISLAND 1
CENTRAL POWER I LIGHT
COLETO CREEK 2
CINCINNATI GAS I ELECTRIC
EAST BEND 1
COLUMBUS t SOUTHERN OHIO ELEC
POSTON 5
COLUMBUS t SOUTHERN OHIO ELEC
POSTON 6
OELMARVA POWER « LIGHT
VIENNA 9
FLORIDA POWER * LIGHT
MARTIN 3
FLORIDA POWER I LIGHT
MARTIN 4
GENERAL PUBLIC UTILITIES
COAL 2
GENERAL PUBLIC UTILITIES
COAL 3
GENERAL PUBLIC UTILITIES
COAL 4
INDIANAPOLIS POWER 1 LIGHT
PATRIOT 1
INDIANAPOLIS POWER ft LIGHT
PATRIOT 2
INDIANAPOLIS POWER ft LIGHT
PATRIOT 3
KENTUCKY UTILITIES
NEW CR
RETROFIT
MS
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.
562.
562.
562.
562.
540.
450.
600.
720.
650.
375.
375.
550.
aoo.
800.
625.
625.
625.
650.
650.
650.
650.
FPCCESS/
SYSTEM SUPPLIER
PPOCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VEN3CH NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
STAHT-uP
GATE
l/e3
3/36
0/53
0/92
0/94
0/85
1/87
11/89
9/92
0/38
s/ee
0/89
5/90
0/87
0/89
5/93
5/95
5/96
0/87
O/ 0
O/ 0
4/94
HANCOCK
VENDOR NOT SELECTED
871
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
LANSING BOARD OF MATER & LIGHT
ERICKSON 2
LOS ANGELES DEPT OF MTH 8 PWR
INTERMOUHTAIN 1
LOS AN5ELES DEPT OF WTR i PWR
INTERMOUNTAIN Z
LOS ANGELES DEPT OF WTR & PWH
INTERMOUNTAIN 3
LOS ANGELES DEPT OF WTR t PMR
INTERMOUNTAIN 4
LOMER COLORADO RIVER AUTH
FAYETTE POWER PROJECT 3
NEBRASKA PUBLIC POMER DISTRICT
FOSSIL III 1
NEVADA POMER
HARRY ALLEN 1
NEVADA POMER
HARRY ALLEN Z
NEVADA POMER
HARRY ALLEN 3
NEVADA POMER
HARRY ALLEN 4
NORTHERN STATES PCMER
METRO COAL 1
NORTHERN STATES POMER
SHERBURNE 3
PACIFIC GAS A ELECTRIC
MONTEZUMA 1
PACIFIC GAS * ELECTRIC
MOHTEZUMA Z
PACIFIC POMER t LIGHT
JIM BRIDGER 1
PACIFIC POMER t LIGHT
JIM BRIOGER Z
PACIFIC PCMER ft LIGHT
JIM BRIDGER 3
PMR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONAOO 3
SOUTHMESTERN ELECTRIC POMER
DOLET HILLS Z
SOYLAND POMER
SOYLAND 1
TEXAS UTILITIES
MILL CREEK 1
HEW OR (
RETROFIT
NEM
NEW
NEW
NEW
NEM
NEW
NEM
NEM
NEM
NEM
NEM
NEH
NEM
NEH
NEW
RETROFIT
RETROFIT
RETROFIT
NEM
NEM
NEM
NEH
NEM
:APACITY
MU
160.
820.
620.
820.
820.
435.
650.
500.
500.
500.
500.
ZOO.
810.
aoo.
800.
550.
550.
550.
700.
280.
720.
500.
750.
PROCESS/
SYSTEM SUPPLIER
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
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
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
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
START-UP
DATE
1/87
0/86
0/87
0/88
0/89
0/83
3/92
6/86
6/87
6/88
6/89
0/90
0/85
6/93
6/94
0/88
0/90
0/86
4/87
0/89
0/88
6/87
0/87
872
-------
EPA UTILITY FCO SURVEY: OCTOBER - DECEASES 1981
SECTION 12
SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/ NEW OR
UNIT NAHE UNIT HO. RETROFIT
TEXAS UTILITIES NEH
HILL CREEK 2
WASHINGTON UftTER POWER HEW
CRESTON COAL 1
WASHINGTON HATER POWER NEW
CHESTON COAL 2
WASHINGTON MATER POWER HEW
CRESTON COAL 3
WASHINGTON WATER POWER NEW
CRESTON COAL 4
WEST TEXAS UTILITIES NEW
OKLAUNION Z
CAPACITY PROCESS/
KM SYSTEM SUPPLIER
750. PROCESS NOT SELECTED
VENDOR NOT SELECTED
570 . LIMESTONE
VENDOR NOT SELECTED
570. LIMESTONE
VENDOR NOT SELECTED
S70. LIMESTONE
VENDOR NOT SELECTED
570. LIMESTONE
VENDOR NOT SELECTED
720. PROCESS NOT SELECTED
VENDOR NOT SELECTED
STA3T-UP
OWE
o/aa
0/87
0/67
0/87
0/37
0/90
TOTAL
30398.
873
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
SECTION 13
TOTAL FGD UNITS AND CAPACITY (Mill INSTALLED BY YEAR
YEAR
1966
1969
1973
1973
197*
1975
1976
1977
197B
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
UNDEFINED
HEW
MO.
1
0
9
5
3
7
7
11
14
20
20
11
18
16
9
13
8
20
12
11
5
2
4
3
3
1
1
8
ON LINE
MM
140.
0.
674.
1568.
416.
2182.
2699.
4589.
4958.
6360.
6704.
4397.
6005.
6760.
5211.
6806.
4781.
12200.
7117.
6930.
2910.
1515.
2822.
2315.
2012.
625.
625.
2246.
TERMINATED
MO. MM
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 ON LIME
NO. m
I
0
9
13
13
15
18
25
39
57
77
88
106
122
131
144
152
172
184
195
200
202
£06
209
212
213
214
140.
0.
674.
2232.
2308.
3862.
5547.
6087.
13045.
19262.
25966.
30363.
36368.
43128.
48339.
55145.
59926.
72126.
79243.
86173.
89083.
90598.
93420.
95735.
97747.
98372.
98997.
874
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEM2E3
SECTION 14
DESIGN AND PERFORMANCE DATA FOS OPERATIONAL PARTICLE SCRU3BERS
C0.1PANY 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 - MVI
G°OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MW
COMMONWEALTH EDISON
MILL COUNTY
1
ROMEOVILLE
ILLINOIS
E
86. I .200 LB/MM3TU)
774. ( l.BOO LB/MMBTU)
****** (****** L8/MM37U)
1147
167
137
144
167
»» 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 - X
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
•HI* PARTICLE CONTROL
«• MECHANICAL COLLECTOR
NUMBER
TYPE
«« FABRIC FILTER
NUMBER
TYPE
*« ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
«« PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
BABCOCK & MILCOX
CYCLONE
CYCLING
363.36
179.4
107.
******
3.B
770000 ACFM)
355 F)
350 FT)
( 12.4 FT)
( 9570 BTU/LB)
9100-10500
COAL
******
22260.
7.40
3.0-16.0
********
******
1.50
0.3-4.5
«*»««»»*
******
0
NONE
0
NONE
COLD SIDE
WESTERN PREC. DIVISION, JOY
179.4 ( 355 F)
90.0
2
4/72
VEHTURI TOWER
VARIABLE-THROAT/SIDE-MOVABLE BLADES
N/A
BABCOCK t MILCOX
a.O X 26.0 X 16.0
NONE
( 5600 GPM)
(18.0 GAL/1000ACF)
365.4
2.4
LIMESTONE
2.2
( 9.0 IH-H20)
875
-------
EPA UTILITY FGD SLAVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW PATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE PEKOVAL EFFICIENCY - X
ENERGY CCNSJMPTION - X
36.6
181.7
179.4
98.0
4.2
( 120.0 FT/S)
( 385000 ACFM)
( 355 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
2/72 SYSTEM
»« PROBLEMS/SOLUTIONS/COMMENTS
696
IN FEBRUARY 1972 THE BABCOCK & UILCOX MET LIMESTONE FGO SYSTEM AT MILL
COUNTY COMMENCED OPERATION. THE LONGEST PERIOD OF CONTINUOUS OPERATION
HAS 23 DAYS WITH ONE OF THE TWO MODULES. THE S02 REMOVAL EFFICIENCY UAS
ABOUT 85X AND THE PAHTICULATE MATTER REMOVAL EFFICIENCY UAS ABOUT 93X.
THE SYSTEM MAS PLAGUED WITH MANY MECHANICAL PROBLEMS. THE MAIN
PROBLEMS ASSOCIATED MITH THE FGD SYSTEM HEPE PLUGGING OF THE MIS-
ELIMINATORS, CORROSION OF THE REHEATER TUBES AND SLUDGE DISPOSAL. TO
SOLVE THE MIST ELIMINATOR AND REHEATER PROBLEMS, A CONSTANT UNCE3SPPAY AND
INTERMITTENT OVERSPRAY HERE USED TO MASH ALL THE MIST ELIMINATOR COMPART-
MENTS. THE REHEATER UNIT MAS ALSO RETUBED.
DURING THE FIRST TMO MONTHS OF 1975 MODULE A MAS OPERATIONAL WHEN NEEDED
WHILE MODULE B MAS UNDERGOING MODIFICATIONS.
3/72 A
B
SYSTEM
.0
35.0
744
*» PROBLEMS/SOLUTIONS/COMMENTS
IN MARCH 1972 MODULE A UAS DOWN FOR REPAIRS AND MODIFICATION OF THE MIST
ELIMINATOR MASH PIPING ASSEMBLY. MODULE B MAS REMOVED EVERY TWO OR THREE
DAYS TO HAND MASH THE MIST ELIMINATOR.
OTHER PROBLEMS ENCOUNTERED DURING THE MONTH INCLUDED VIBRATION OF THE
REHEATER TUBE BUNDLES, RAPID EROSION OF THE SCRUBBER SPRAY NOZZLES, AND
PLUGGING OF THE VENTURI NOZZLES.
4/72 A
B
SYSTEM
34.0
14.0
720
PROBLEMS/SOLUTIONS/COMMENTS
MODULE A MAS OUT OF SERVICE FOR SIX DAYS IN APRIL BECAUSE OF A NEAR-
RUPTURE OF A VENTURI PIPE EXPANSION JOINT AND HEAVY BUILDUP OF SOLIDS
ON THE MIST ELIMINATOR.
MODULE B UAS OUT OF SERVICE MOST OF THE TIME FOR SIMILAR REPAIR OF THE
VENTURI PIPE EXPANSION JOINT, AND FOR MODIFICATION OF THE REHEATER UNIT
AND MIST ELIMINATOR MASH SYSTEM.
5/72 A
B
SYSTEM
70.0
32.0
744
«* PROBLEMS/SOLUTIONS/COMMENTS
6/72 A
MODULE B UAS OUT OF SERVICE FOR TMO WEEKS IN MAY TO REBPACE THE REHEAT,
INSTALL UNDERSPRAY NOZZLES ON THE MIST ELIMINATOR, AND TO INSTALL HEAVIER
SCREENS IN THE SUMP.
REHEATER PLUGGING DURING THE MONTH CAUSED ADDITIONAL OUTAGES.
8.0
876
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
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
B
SYSTEM
31.0
720
*» PROBLEMS/SOLUTIONS/COMMENTS
7/72 SYSTEM
8/72 A
B
SYSTEM
DURING JUNE BOTH MODULES MERE OUT OF SERVICE PART OF THE MONTH DUE TO
A HIGH DIFFERENTIAL PRESSURE ACROSS THE MIST ELIMINATORS AND PLU3GINS
OF THE MIST ELIMINATORS DUE TO A LEAKING BYPASS VALVE.
THE RUBBER LINER IN MODULE A MAS REPLACED DURING THE MONTH.
744
79.0
21.0
744
*« PROBLEMS/SOLUTIONS/COMMENTS
A TWO DAY OUTAGE DURING AUGUST MAS NECESSARY TO UNPLUG THE VENTURI NOZZLES
AND THE MIST ELIMINATOR OF MODULE A.
MODULE B HAS OUT OF SERVICE 22 DAYS FOR CLEANING OF THE MIST ELIMINATOR
AND REHEATER. INSTALLATION OF OVERHEAD SPRAY NOZZLES AND REPLACEMENT CF
SECTIONS OF THE MIST ELIMINATOR.
THE BOILER MAS SHUTDOWN FOR TWO DAYS TO REPAIR THE TURBINE/GENERATOR.
9/72 A
B
SYSTEM
.0
30.0
720
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER HAS OFF LINE FROM SEPTEMBER 1 TO SEPTEMBER 5 DUE TO A LACK OF
DEMAND.
AN ID FAN PROBLEM CAUSED UNSTABLE OPERATION DURING THE MONTH.
MODULE A HAS OUT OF SERVICE IN SEPTEMBER DUE TO THE NECESSARY MODIFICATION
OFTHE REHEATER AND TO REPAIR THE RECYCLE TANK SCREENS.
10/72 A
B
SYSTEM
.0
.0
744
o* PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER THE BOILER HAS OUT OP SERVICE THE ENTIRE MONTH.
MODULES A AND B HERE OUT OF SERVICE DUE TO THE INSTALLATION OF THE REKEATER
BAFFLE PLATES TO DAMPEN VIBRATIONS AND ALSO THE INSTALLATION OF AN EXPERI-
MENTAL MIST ELIMINATOR HASH SYSTEM.
11/72 A
B
SYSTEM
.0
.0
720
** FROBLEMS/SOLUTIONS/CCMflENTS
THE BOILER REMAINED OUT OF SERVICE DURING THE MONTH OF NOVEMBER.
MODULES A AND B REMAINED OUT OF SERVICE DUE TO UNSTABLE OPERATIONS OF THE
BOILER.
877
-------
EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILZTY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOUFS HOURS HOo'PS FACTOR
12/72 A 22.0
B 30.0
SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B OPERATED INTERMITTENTLY DURING DECEMBER DUE TO TESTING OF
THE ESP AND MISCELLANEOUS INSTRUMENT PROBLEMS.
1/73 A .0
B .0
SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY MODULES A AND B MERE OUT OF SERVICE THE ENTIRE MONTH TO
PERFORM SOME NECESSARY REPAIRS AND MODIFICATIONS TO THE SYSTEM.
2/73 A 22.0
B 24.0
SYSTEM 672
»* FROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY MODULES A AND B REMAINED OUT OF SERVICE DUE TO CRACKS
IN THE INLET DUCTWORK OF THE BOOSTER FAN.
THE IMPROPER INSTALLATION OF THE MIST ELIMINATOR IN MODULE B CAUSED
PLUGGING IN THE REHEATER.
3/73 A 65.0
B 11.0
SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A HAS OUT OF SERVICE FOR FIVE DAYS IN MARCH DUE TO PLUGGING OF THE
MIST ELIMINATOR.
DURING MARCH THE BOILER HAS OUT OF SERVICE FOR APPROXIMATELY FOUR DAYS
DUE TO AN INSPECTION.
MODULE B MAS OUT OF SERVICE PART OF THE MONTH DUE TO REHEATER TUBE LEAKS.
4/73 A 6.0
B 13.0
SYSTEM 720
«« PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL PROBLEMS OCCURRED DUE TO THE DEPOSITS OF CALCIUM SULFATE
SCALE ON THE REHEATER TUBES OF MODULE A.
PERSISTING PROBLEMS WITH THE MIST ELIMINATOR MERE ENCOUNTERED DURING THE
MONTH.
5/73 A .0
B .0
SYSTEM 744
878
-------
EPA UTILITY FGO SURVEY: OCTOBER - OECEMSER 1981
COMMONWEALTH EOI30M: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S03 PART. HOU3S HOUPS HOURS FACTCR
** PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B MERE OUT OF SERVICE FOR THE ENTIRE MONTH OF MAY.
6/73 A 16.0
B .0
SYSTEM 7ZO
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE BOILER-RELATED PROBLEMS MERE RESPONSIBLE FOR MOST OF THE
OUTAGE TIME OF MODULE A. MODULE B UAS TAKEN OUT OF SERVICE TO ALLOV4
CONCENTRATION ON THE PROBLEMS OF MODULE A.
7/73 A 51.0
B .0
SYSTEM 7
*« PROBLEMS/SOLUTIONS/COMMENTS
DURING OCTOBER MODULE A TRIPPED SEVERAL TIMES DUE TO BAD LIMIT SWITCHES
IN THE BYPASS AND THE BLOCK DAMPERS.
THE BOILER MAS TAKEN OUT OF SERVICE TO BALANCE THE BOOSTER 1.0. FAN.
11/73 A 51.0
B .0
SYSTEM 720
** PROBLEMS/SOLUTIONS/COMMENTS
DURING NOVEMBER PROBLEMS OCCURRED WITH THE MIST ELIMINATOR DUE TO POOR GAS
DISTRIBUTION.
679
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 ICONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY DURABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOLPS HOURS FACTC3
MODULE A MAS TAKEN OUT OF SERVICE FOR AN INSPECTION. CLEANING AND MODI-
FICATIONS MERE ALSO DONE DURING NOVEMBER.
12/73 A .0
B .0
SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B MERE OUT OF SERVICE DURING DECEMBER DUE TO MODIFICA-
TIONS AMD MAINTENANCE TO THE ISOLATION VALVES, PUMPS. VENTURI THROATS AND
THE MIST ELIMINATOR.
1/7* A . 0
B .0
SYSTEM 7**
** PROBLEMS/SOLUTIONS/COMMENTS
MODULES A AND B HERE OUT OF SERVICE DUE TO FREEZING IN THE 10-INCH-DIAME-
TERi 4400 FT. LINE BETWEEN THE MODULES AND THE POND.
DAMAGE OCCURRED TO THE SUMP PUMPS AND ALSO SOME OTHER INSTRUMENTS DUE TO
THE FREEZING.
2/74 A .0
B .0
SYSTEM 672
*» PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE FROZEN PIPELINES MERE THAWED. REAMCHCRED AND RETURNED
TO SERVICE. THE INSTRUMENTS DAMAGED BY THE FREEZING WERE REPAIRED.
MODULE A REMAINED OUT OF SERVICE UNTIL THE ARRIVAL OF THE SECOND-STAGE
MIST ELIMINATOR.
3/74 A 21.0
B .0
SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
MODULE A HAS OPERABLE MARCH 20, BUT HAS NOT RETURNED TO SERVICE UNTIL
MARCH 27 DUE TO THE BOILER BEING CUT OF SERVICE.
4/74 A 72.0
B .0
SYSTEM 720
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL MODULE A OPERATED ON LOW-SULFUR COAL FCR 23 CONSECUTIVE DAYS.
TWO SHORT INSPECTION OUTAGES OCCURRED DURING THAT TIME.
THE SUMP SCREEN FROM MODULE B HAS SUBSTITUTED FOR THE DAMAGED SCREEN IN
MODULE A.
5/74 A 93.0
B .0
SYSTEM 744
880
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
COMMONWEALTH EDISON: HILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FC-0 CAP.
S02 PART. HOURS HOUPS HCL'=S FACTOR
*« PROBLEMS/SOLUTIONS/COMttENTS
DURING MAY MODULE A OPERATED MOST OF THE TIME ON HIGH-SULFUR COAL.
THIS TIME A FEW SHORT OUTAGES OCCURRED FOR INSPECTIONS.
DURING
fr/74 A
B
SYSTEM
55.0
.0
720
PHOBLEMS/SOLUTIONS/COMMENTS
DURING JUNE MODULE A OPERATED FOR APPROXIMATELY 300 HOURS.
TWO WEEKS OF' OUTAGE TIME WAS NECESSARY TO MAKE REPAIRS TO THE VENTURI
THROAT DRIVE.
7/74 A
B
SYSTEM
96.0
.0
744
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EOISCT. MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION '/. REMOVAL PER BOILER FG3 CAP.
S02 PART. HOU3S HOUSS HO'JSS FACTC3
*» PHOBLEMS/SOLUTIONS/COMMENTS
MODULE A MAS SHUT DOWN THREE TIMES DURING NOVEMBER. TWICE DUE TO LACK OF
DEMAND AND ONCE FOR AN INSPECTION.
12/7* A 99.0
B .0
SYSTEM 744
WN PROBLEMS/SOLUTIONS/COMMENTS
MODULE A MAS TAKEN OFF LINE PART OF THE MONTH TO REPAIR THE VALVE IN THE
SPENT LIQUOR LINE TO THE POND AND ALSO FOR AN INSPECTION.
1/75 A 99.0
B .0
SYSTEM 744
»* PROBLEMS/SOLUTIONS/COMMENTS
MODIFICATIONS OF MODULE B ARE STILL CONTINUING.
DURING JANUARY MODULE A HAS OUT OF SERVICE TWICE; ONCE FOR AN INSPECTION
AND ONCE DUE TO LACK OF DEMAND.
2/75 A 99.0
B .0
SYSTEM 672
«<> PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY MODULE A WAS OUT OF SERVICE TWO TIMES DUE TO LACK OF DE-
MAND AND ALSO FOR AN INSPECTION. THE INSPECTION SHOWED THAT CONDITION'S
INSIDE THE MODULE MERE THE SAME AS BEFORE.
DURING THE MONTH A SMALL REHEATER LEAK IN A STAINLESS STEEL BUNDLE CAUSED
THE SYSTEM. TO SHUT DOWN.
DURING THE INSPECTION OF MODULE A. THE UNDER WASH NOZZLES HERE CLEANED ANT)
A SMALL SECTION FO THE MIST ELIMINATOR MAS REPLACED.
CHICAGO FLYASH IS TREATING MATERIAL FROM THE SYSTEM WITH PORTLAND
CEMENT AND FLYASH AND DUMPING THE TREATED MATERIAL INTO THE NORTH HALF
OF THE HOLDING BASIN.
3/75 A 94.0 99.2 81.2
B .0 .0 .0
SYSTEM 744 609
«» PROBLEMS/SOLUTIONS/COMMENTS
A VENTURI HOSE LEAK FORCED MODULE A OUT ONCE.
MODULE B MAS 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 720 633
602
-------
EPA UTILITY FGO SURVEY: OCTOBER - OECEH3ER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HO'J=S HOURS HOU7S FAC7C3
** PRGBLEMS/SOLUTIONS/COMMENTS
CHICAGO FLY ASH IS TREATING MATERIAL FROM THE SCRUBBER WITH LIME AKD FLY
ASH AND DUMPING IT INTO THE HOLDING BASIN.
A BOILER OUTAGE FORCED MODULE A OUT OF SERVICE ONCE THIS MONTH (MODULE B
MAS ALREADY OUT OF SERVICE).
COAL BURNED THIS MONTH HAS RECLAIM COAL AND VARIED IN SULFUR CONTENT.
5/75 A 64.5 84.5 84.5
B 37.1 37.1 37.1
SYSTEM 744 744
** PH03LEMS/SOLUTIONS/COMMENTS
MODULE B MAS IN SERVICE ON MAY 20 FOR THE FIRST TIME SINCE APRIL 13, 1973.
RECIRCULATION TANK MIXERS.
MODULE A (WHICH MAS THE ONLY ONE OPERATING I MAS FORCED OUT TWICE IN APRIL
TO AVOID POND OVERBOAROING INTO THE DES PLAINES RIVER. THE SECCND OUTAGE
LASTED UNTIL MAY 5. DURING THE PAST SEVERAL MONTHS OF GENERALLY COHTINUCUS
OPERATION OF MODULE A. IT HAS BECOME APPARENT THAT THE PRESENT LIQUID
CIRCULATING SYSTEM CANNOT BE OPERATED IN A CONTINUOUSLY CLOSED CYCLE. THE
MATER IMBALANCE POSES A HIGH RISK OF OVERBOAROING FPCM THE SLUDGE F3ND
DURING LONG PERIODS OF SUSTAINED OPERATON. THE FOLLOWING REVISIONS HAVE
BEEN MADE TO REDUCE THE HATER IMBALANCE:
1. THE PUMP GLAND MATER FLOWS HAVE BEEN CUT FROM 10 GPM TO 5 GPM.
2. THE SCRUBBER HOUSE SERVICE MATER FILTER BACKWASH HAS BEEN RCUTED
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 21 DUE TO A BROKEN GEAR AND A STUCK
SMEEP ARM. THE THICKENER HAS BEEN BYPASSED AND THE SLUDGE IS GOING TO THE
POND.
DURING MAYi MODULE A HAS OUT FOR 45 MINUTES DUE TO A DAMPER TRIP.
MODULE A HAS OUT ONCE FOR SPRAY NOZ2LE CLEANING.
MODULE B MAS OUT TWICE AFTER START UP, ONCE FOR A VENTURI PUMP TRIP AW
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 TPL'CKS FCR
THE CEMENT TRUCKS WHICH MERE USED IN THE PAST FOR MIXING AND TRANSPORTING
THE MASTE MATERIAL TO THE HOLDING BASIN.
COAL BURNED THIS MONTH VARIED GREATLY IN SULFUR CONTENT, RANGING FKCM LEW
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/COHMENTS
A REHEATER PLUGGAGE INSPECTION FORCED ONE MODULE A OUTAGE.
A LOM LEVEL TRIP CAUSED A 35 MINUTE OUTAGE, AND NO DEMAND ACCOUNTED FOR TWO
883
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: WILL COUNTY 1 (COHT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOIRS HC'JSS HC'JHS FACTOR
MORE MODULE A OUTAGES.
MODULE B HAS OUT FOR 95 HOURS TO CLEAN THE BOOSTER FAN AND OEMISTSS.
HIGH BOOSTER FAN VIBRATIONS CAUSED MODULE B TO SHUT DOWN ON JUNE 30.
DURING THIS MONTH HIGH SULFUR COAL MAS BURNED IN A TWO WEEK TEST. AND LOW
SULFUR COAL MAS BURNED THE REST OF THE MONTH.
7/75 A
B
SYSTEM
.0
79.2
.0
79.4
.0
73.5
744 689
PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO FLY ASH IS TREATING THE SCRUBBER HASTE 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 MAS OUT ONCE (30 MINUTES) TO REPAIR A MINOR STEAM HEADER LEAK.
MODULE B MAS OUT ONCE DUE TO NO DEMAND.
LOU SULFUR COAL MAS BURNED MOST OF THIS MONT, WITH HIGH SULFUR COAL BEING
BURNED DURING THE LAST MEEK OF THE MONTH.
8/75 A
B
SYSTEM
.0
93.5
.0
100.0
.0
76.4
744 565
*» PROBLEMS/SOLUTIONS/COMMENTS
IN JUNE, MODULE A ENCOUNTERED PLUGGAGE IN THE OEMISTER. WHICH REQUIRED ITS
REPLACEMENT. THE WORK MAS 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 NEM 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 MERE DUE TO VIBRATION FATIGUE. THE REHEATER, UHICH
MAS INSTALLED IN MAY, HAS LOST SIX OF ITS TMELVE TUBE BUNDLES SO FAR. THE
LENGTH OF TIME THAT THE TUBES HAVE LASTED MOULD SEEM TO INDICATE THAT TKE5E
IS A DIESIGN RELATED MATERIAL DEFICIENCY. THREE OF THE TUBE BUNDLES MERE
REPLACED MITH MARGINAL BUNDLES LEFT OVER FROM MODULE A.
A SMALL STEAM HEADER LEAK CAUSED ONE MODULE B OUTAGE.
MODULE B MAS OUT FOUR TIMES FOR NO DEMAND AND ONCE FOR A LOW FLOW TRIP.
HIGH SULFUR COAL MAS BURNED ALL MONTH, CAUSING AN INCREASE IN SLUDGE
PRODUCTION UHICH HAS FORCED A MINIMUM SIX DAY A WEEK, TEN HOL'R A DAY
SLUDGE DISPOSAL OPERATION. THE SLUDGE IS BEING TREATED HITH LIME AMD
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.
9/7S A
B
SYSTEM
10/75 A
B
SYSTEM
.0
32.3
.0
100.0
.0
26.6
720
744 194
884
-------
EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1991
COMMONWEALTH EDISON: MILL COUNTY 1 (COOT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOLKS HO'J'S FACTC3
*» PROBLEMS/SOLUTIONS/COMMENTS
MODULE A MAS OFF THE ENTIRE 11 DAYS THE BOILER OPERATED THIS MONTH, WAITING
FOR ITS NEW REHEATER, WHICH HAS NOW BEEN RELEASED FOR MANUFACTURING 3Y
5MED.
MODULE B HAD TWO OUTAGES. ONE FOR NO DEMAND AND ONE MINOR IS MINUTE TRIP.
HIGH SULFUR COAL MAS BURNED THIS MONTH WHEN THE SCRUBBER WAS IN SERVICE.
THE SLUDGE IS BEING TREATED WITH LIME AND FLY ASH AND HAULED TO AN OFF SITE
DISPOSAL AREA.
11/75 A
B
SYSTEM
12/75 A
B
SYSTEM
1/76 A
B
SYSTEM
8/76 A
B
SYSTEM
3/76 A
B
SYSTEM
.0
.0
30.1
a.a
45.2
20.4
.0
.0
18.3
8.5
720
744
744
696
744 309
PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 MAS DOWN FROM OCTOBER 11 THROUGH MARCH 19 FOR ITS BOILER TURBINE
AND SCRUBBER OVERHAUL. THE MAJOR ITEMS TO BE ACCOMPLISHED DURING THE
OUTAGE MERE:
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 AHD 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 MAS PUT INTO THE GAS PATH ON MARCH 22 AND REMAINED AVAILABLE F09
SERVICE THE REST OF THE MONTH.
MODULE B HAD TO REMAIN OUT OF SERVICE UNTIL MARCH 29 WHILE ITS REPAIRED
REHEATER MAS INSTALLED.
4/76 A
8
SYSTEM
23.0
20.0
49.3
19.2
47.3
720 691
885
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERICD MODULI: AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOUPS HOURS FACTOR
** PR03LEMS/SOLUTIOMS/COMMENTS
UNIT 1 RETURNED TO SERVICE APRIL Z AFTER A SHORT TURBINE CONTROL OUTAGE.
BOTH MODULES CAME ON LINE JUST BEFORE THE BOILER.
A FIVE DAY OUTAGE OF MODULE B MAS DUE TO REHEATER TUBE BUNDLE LEAKS.
SEVEPAL MODULE B OUTAGES MERE DUE TO PLUGGED ABSORBER TANK SCREENS CAUSED
BY MILL AND CLASSIFIER FAILURES WHICH ALLOWED ROCK TO GET INTO THE SYSTEM.
MODULE B MAS THOROUGHLY CLEANED.
ONLY ONE ABSORBER PUMP IS BEING USED IN MODULE B, SINCE THE 182 PUMP LINER
FAILED AS A RESULT OF A BROKEN DISCHARGE VALVE. A REPLACEMENT LIt.'EH IS
BEING INSTALLED.
A SCRUBBER TESTING AND EVALUATING PROGRAM UAS 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 B OFF ONCE THIS MONTH.
MODULE B MAS TAKEN OUT OF SERVICE ONCE BECAUSE OF A PLUGGED ABSORBER TANK
SCREEN.
MODULE B MAS OFF ONCE DUE TO A FOULED I.D. FAN.
MODULE B WAS OUT OF THE GAS PATH ONCE DUE TO NO DEMAND.
6/76 A 52.0 44.Z 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 AH INLET 16
INCH BUTTERFLY ISOLATION VALVE BROKE APART AND FELL INTO THE VENTUSI 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 MERE OFF TWICE DUE TO NO DEMAND. DURING THESE OUTAGES, THE
OEMISTERS WERE MASHED AND ABSORBER TRAY SCALE, IP ANY, WAS KNOCKED OFF.
MODULE B MAS 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 1.0. BOOSTER FAN FOULINS. THE ONLY WAY TO
CLEAN THE REHEATERS EFFECTIVELY IS TO REMOVE THEM, WHICH DEMANDS A SUBSTAN-
TIAL OUTAGE.
886
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HCU
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HCU3S HOUSS FtCTCR
B 76.4 56.2 54.8
SYSTEM 744 726
*» FPCBLEMS/SOLUTIONS/COMIENTS
HIGH SULFUR ILLINOIS COAL MAS BURNED IN THE BOILER FROM MARCH THROUGH
OCTOBER.
THE SCRU3BER MASTE MATERIAL MAS 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 MAS OUT OF THE GAS PATH ONCE FOR AN I.D. BOSOOSTER FAN TRIP.
WORK ON RECIRCULATION TANK LEVEL CONTROLS CAUSED A MODULE A OUTAGE.
MODULE B MAS FORCED OFF ONCE TO REPAIR A REHEATER HEADER LEAK.
ONE MODULE B OUTAGE MAS FOR VENTURI NOZZLE CLEANING.
MODULE B WENT OFF FOR A VENTURI LOW FLOM TRIP.
MODULE B REMAINED OUT OF SERVICE WHILE MODULE A MAS BEING TESTED TO AVOID
THICKENER-POND OVERLOADING.
A VACUUM FILTER HAS TIED IN AT THE THICKENER.
11/76 A 20.1 25.6 20.1
B 72.2 69.6 4.7
SYSTEM 720 566
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A OPERATED ON ONE ABSORBER PUMP DURING MODULE B OUTAGE.
MODULE B MAS 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 MAS OFF ONCE DUE TO A CHEMICAL SYSTEM UPSET.
MODULE B HAS OUT OF THE GAS PATH THICE DUE TO NO DEMAND (MODULE A MAS NOT
IN SERVICE AT THE TIME OF THE OUTAGE).
12/76 A 44.9 4S.3 44.9
B 53.4 51.7 48.0
SYSTEM 744 692
*» PROBLEMS/SOLUTIONS/CCMMENTS
DURING THE LAST MEEK OF NOVEMBER, THE 1A2 ABSORBER PUMP MAS TAKEN OUT OF
SERVICE FOR OVERHAUL. THE REPAIRS HERE 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 HAS
BEING REPAIRED.
688
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.J
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CiP.
S02 PART. HOUPS HOURS KOU°S FACTOR
MODULE B PERFORMED SATISFACTIORILY DURING THE FIRST HALF OF THE KCNTH.
EXPERIENCING ONLY ONE NO DEMAND OUTAGE. OH 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.
LOM SULFUR COAL WAS BURNED IN THE BOILER FROM NOVEMBER THROUGH JANUARY.
DUE TO THE LOU VOLUME OF SLUDGE PRODUCED WHILE BURNING LOW SULFUR COAL,
MUCH OF THE SLUDGE HANDLING TIME MAS SPENT DIGGING OUT THE ACCUMULATED
SLUDGE IN THE RECIRCULATION PONDS. THIS MATERIAL, ALONG WITH SCRU2BER
WASTE MATERIAL, WAS TREATED WITH LIME AND FLYASH AND HAULED TO AN OFF
SITE DISPOSAL AREA.
MODULE A MAS FORCED OUT ONCE BY A FAILED SPENT SLURRY VALVE.
PLUGGED OEMISTER UNDERSPRAYS CAUSED ANOTHER MODULE A OUTAGE.
MODULE A WENT OUT ONCE BECAUSE OF NO DEMAND AND ONCE DUE TO A BOILER OUTAGE
(MODULE B MAS 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 MAS PLACED IN THE GAS PATH JANUARY 31.
2/77 A 38.8 42.6 38.8
B 72.0 45.7 41.7
SYSTEM 672 613
«* PROBLEMS/SOLUTIONS/COMMENTS
THERE MAS 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
»» PROBLEMS/SOLUTIONS/COMMENTS
AN ERT S02 ANALYZER MAS INSTALLED ON THE DISCHARGE SIDE OF MODULE B 1.0.
BOOSTER 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 MAS ENCOUNTERED IN MODULE B.
HIGH SULFUR COAL MAS 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 MAS
SPENT ON THE THICKENER AND VACUUM FILTER IPERATION. THE SCRUBBER WASTE
MATERIAL MAS TREATED WITH LIME FLYASH AND HAULED OFF SITE.
DISPOSAL AREA.
889
-------
EPA UTILITY FGD SURVEY: OCTC3ER - DECEMBER 1981
COMMONWEALTH EDISON: WILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPESABILITY RELIABILITY UTILIZATION
X REMOVAL
502 PART.
PER BOILER FGO CAP.
HOU3S HOURS HO'JSS FACTOR
4/77 A
B
SYSTEM
86.1
45.5
67.7
30.2
61.2
27.3
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 CUT TO SERVICE THE ANALYZER
ALMOST EVERY OTHER DAY. THE PROBLEM, ACCOPDING TO ERT TECHNICIANS, IS Or 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 MAS FORCED OUT OF THE 6AS PATH TWICE FOR AN ABSORBER SUCTION
HEADER LEAK REPAIR.
MODULE B HAS OUT OF SERVICE ONCE TO MASH THE I. 0. 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 SCRUS3ER
WASTE MATERIAL MAS TREATED WITH LIME AND FLYASH AND HAULED TO AN CFF SITE
DISPOSAL AREA.
5/77 A
B
SYSTEM
89.4
98.0
2.2
50.9
2.0
47.3
744 691
PROBLEMS/SOLUTIONS/COMMENTS
THE ERT SOS ANALYZER HAS BEEN REMOVED FROM SERVICE DUE TO A POOR FERFCPM-
ANCE RECORD OVER THE LAST THREE MONTHS. ERT IS IN THE PROCESS OF RE-
ENGINEERING THEIR ANALYZER.
THE MGO ADDITION TEST MENT HELL. ALTHOUGH THE MGO INCREASED S02 PEKCVAL
EFFICIENCY ABOUT 10X, IT DID PRACTICALLY NOTHING FOR THE TWO MORE SiRIGUS
PROBLEMS, SINCE THICKENER AND SLUDGE PRODUCTION AND LIMESTONE CONSUMPTION
RATE HERE ABOUT THE SAME.
MODULE A MAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH WHEN THE INLET
VALVE ON 1AZ ABSORBER PUMP FAILED.
MODULE B HAS 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 HESTINGHOUSE.
HIGH SULFUR COAL HAS BURNED FOR ELEVEN DAYS DURING THE MONTH.
6/77 A
B
SYSTEM
31.8
93.2
13.3
93.4
10.5
73.5
720 566
tH* PROBLEMS/SOLUTIONS/COMMENTS
THE 1A1 ABSORBER PUMP IS STILL OUT OF SERVICE WAITING FOR PARTS 1A3
ABSORBER PUMP'S ISOLATION VALVES FORCED MODULE A OFF FOR MOST OF TIE MONTH.
MODULE A HAD ONE NO DEMAND AND ONE BOILER OUTAGE THIS MONTH.
890
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
COMMONWEALTH EDISON: HILL COUNTY 1 (CONT.)
------------------------------------------ PERFORMANCE DATA ------------------------------------------
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HCLPS HC'JSS HC'.?S FACTCR
MODULE B MAS ALSO FORCED OFF TO CLEAN THE 1.0. BOOSTER FAN.
NO HIGH SULFUR COAL MAS BURNED THIS MONTH.
70.3 41.4 31.0
7/77
B
SYSTEM
744 377
PROSLEMS/SOLUTIONS/COMMENTS
HIGH SULFUR COAL HAS BURNED FOR EIGHT DAYS THIS MONTH. LIMESTONE OPERATION
HAS NORMAL FOR HIGH SULFUR OPERATION.
MODULE B MAS FORCED OUT OF THE GAS PATH ONCE TO REMOVE A PLU33EO DIFFUSES.
THE FINAL TEST, FORCED OXIDATION SEEMOD TO BE THE MOST SUCCESSFUL C' ALL.
USING LIQUID OXYGEN, UP TO 12,000 CFM OF GASEOUS 02 HAS FED INTO EACH
VENTURI DOHNCOMER, OXIDATION OF SULFITE TO SULFATE MAS INCREASED FROM
35 TO 90 '/.
MODULE B MAS ALSO FORCED OFF DUE TO A LOM LEVEL IN THE SLURRY STORAGE TANK.
MODULE B HAS ALSO FORCED OFF DUE TO REHEATER TUBE BUNDLE LEAKS.
fl/77
A
B
SYSTEM
99.8
9.7
99.6
12.0
BO.3
9.7
744 604
** PROBLEMS/SOLUTIONS/COMMENTS
MODULE A MAS AVAILABLE THE ENTIRE MONTH WITH JUST THE VENTURI PUMP OPERAT-
ING.
9/77
A 61.0
B 52.3
SYSTEM
77.B
75.4
54.0
52.3
rzo 499
*« PROBLEMS/SOLUTIONS/COMMENTS
MODULE B ENCOUNTERED HIGH VIBERATIOJ4S IN ITS BOOSTER FAN DURING THE FIRST
MEEK OF THE MONTH. AFTER THE FAN MAS BALANCED, THE MODULE OPERATED INTIL
THE UNIT OUTAGE ON SEPTEMBER 21.
10/77
11/77
A
B
SYSTEM
A
B
SYSTEM
.0
.0
.0
8.8
50.1
.0
.0
.0
8.8
744
720 126
M* 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 SCME DIFICULTY IN BALANCES
ITS BOOSTER FAN.
12/77
A
B
SYSTEM
42.5
84.1
42.5
64.1
47.8
94.6
42.5
84.1
744 661
891
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: WILL COUNTY 1 ICONT.J
PERFORMANCE DATA
PERIOD M03ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILE3 FGD CAP.
S02 PART. HOURS HOURS HOUSS FACTOR
*» PROBLEMS/SOLUTIONS/COKMENTS
PLUGSAGE MAS ENCOUNTERED IN THE MODULE B REHEATER. BECAUSE NO SPARE REHEAT
COILS WERE AVAILABLE. THE UTILITY TRIED TAKING SOME COILS FROM M03LJLE A
MODULE B APPEARED TO BE MORE ORE SEVERELY PLUGGED THAN ORIGINALLY THOUGHT.
MODULE A MAS OOHN HALF THE MONTH BECAUSE OF A MAIN STEAM LEAK WHICH COULD
NOT BE ISOLATED.
MODULE 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 MODULE OUT OF SERVICE UNTIL MID DECEMBER.
1/78 A 69.0 89.9 66.3
B 22.0 29.8 22.0
SYSTEM 744 549
** PRCBLEMS/SOLUTIONS/COMMENTS
ON JANUARY 7, THE MODULE B I.D. BOOSTER FAN DISCHARGE DUCT STARTED VIBRAT-
ING MILDLY. THIS FORCED THE BOILER OFF WHILE THE SHOP MADE REPAIRS TO THE
DUCTWORK AND BALANCED THE FAN WITH AN I.R.O. MACHINE.
WHEN THE UTILITY ATTEMPTED TO PUT MODULE B BACK IN THE GAS PATH, A LEAK IN
THE SLUSHY LINE FORCED IT BACK OFF.
A PLUGGED VENTURI PUMP FORCED MODULE B OFF THE REST OF THE MONTH.
DURING THE OUTAGE, THE REHEATER COILS MERE CLEANED WITH A HIGH PRESSURE
(5000 LB) SPRAYER.
MODULE A MAS FORCED OFF WHEN A STEAM REGULATING VALVE BLEU ITS PACKING.
OM 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 UITH THE POND
RETURN PUMPS FREEZING.
2/78 A 40.9 56.5 34.4
B 69.5 92.9 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 HELL 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 MAS ON THE SYSTEM VERY LITTLE.
MODULE B HAD DIFFICULTY FOR SEVERAL DAYS BECAUSE OF A CRACKED SHEAVE CM THE
892
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FSD CAP.
HOURS HOU=S HOL'=S FACTOR
VENTUHI 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 SCRUESER.
4/78
A
B
SYSTEM
99.9
100.0
99.7
99.9
92.0
720 665
«* PROBLEMS/SOLUTIONS/COMMENTS
THE PRESSURE DIFFERENTIAL ACROSS THE VENTURIS HAS BEEN REDUCED BY AP«CXI-
MATELY 40X AT 140 MM BY REMOVING THE VENTURI RESTRICTOR BLOCKS. PASTiCULATE
REMOVAL AND SOLIDS CARRYOVER COULD BE ADVERSELY AFFECTED BY THIS ACTION.
SINCE PARTICULATE REMOVAL AT THE VENTURI IS A FUNCTION OF KATES DROPLET
SIZE. WHICH IN TURN IS A FUNCTION OF PRESSURE DROP. INCREASED SOLIDS CARRY-
OVER COULD POSSIBLY COMPUNO REHEATER PLUGGING PROBLEMS. THE UTILITY IS
KEEPING A CLOSE MATCH FOR PLUGGING, BUT HAS NOT YET FOUND ANYTHING UNUSUAL.
MODULE A MAS FORCED OUT OF THE GAS PATH ONCE THIS MONTH FOR A VENTURI PIPE
LEAK.
5/78
A
B
SYSTEM
9.5
69.a
99.4
100.0
55.2
56.1
744 413
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST PART OF THE MONTH BOTH MODULES WERE FORCED OUT CF THE GAS
PATH DUE TO REHEATER LEAKS. IT REQUIRED A TWO DAY OUTAGE TO PEMOVE 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 PLUG3AGE
MAS DISCOVERED IN MODULE A. MODULE B MAS NOT AS BAD.
HIGH VIBRATION HAS 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 NEM SLL-DGE
TREATMENT SYSTEM SHOULD BE OPERATING BY FALL.
THE SCRUBBER MAS FORCED OUT OF THE GAS PATH CNCE THIS MONTH WHEN THE 1B1
ABSORBER DISCHARGE VALVE FAILED TO OPEN.
THE BOILER MAS FORCED OFF THE LAST FOUR DAYS OF THE MONTH FOR CYCLONE
LEAKS. DURING THIS OUTAGE. THE A AND B MODULE SPENT SLURRY VAL/ES
MERE REPLACED.
7/78 A
B
SYSTEM
97.0
99.2
100.0
100.0
11.6
11.6
744
77
893
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
CCMHOIWEALTH EOISCN: WILL COUNTY I (CCMT.)
PERFORMANCE DATA
PERIOO MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HCU3S FACTOR
«* PROBLEMS/SOLUTIONS/CCMMENTS
THE BOILER WAS PLAGUED ALL MONTH BY CYCLONE CASING LEAKS. BECAUSE OF THE
CYCLONE PROBLEMS AND THE COAL CONSERVATION PROGRAM, THE BOILER HAS ONLY
OPERATED SEVENTY-SEVEN HOURS FCR THE MONTH.
THE BOILER DOWN TIME MAS USED FOR PREVENTATIVE MAINTENAtCE ON THE SCRU3BER.
SIX NEW REHEATEfiS WERE INSTALLED AND A DRAIN VALVE ON THE SPENT SLURRY LINE
UAS REPAIRED.
A VALVE FAILURE ON THE 1A1 ABSORBER PUMP FORCED THE SCRUBBER FROM THE GAS
PATH CMCE DURING THE MOUTH.
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 HASTE MATERIAL MAS TREATED WITH LINE AND FLY ASH AMD 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 UAS RESPONSIBLE FOR FORCING THE UNIT OFF.
MODULE A MAS FORCED OFF ONCE DUE TO HIGH VIBRATION OF THE 1.0. BOOSTER FAN.
THE PROBLEM MAS 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
720 416
«« PROBLEMS/SOLUTIONS/COMMENTS
CHICAGO ADMIXTURES SPENT MOST OF THEIR TIME OPERATING OUT OF THE THICKENER.
THE SCRUBBER MASTE MATERIAL MAS 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 CHE
BOILER OUTAGE AND CAUSED THE FGO SYSTEM TO BE UNAVAILABLE FCP A TOTAL
OF NINETY HOURS. SAMPLES OF THE TUBES HAVE BEEN SUBMITTED TO O.A.O. ?OR
METALLURGICAL EXAMINATION.
A RUPTURED AIR LINE ON A VENTURI PUMP ISOLATION VALVE MOULD NOT ALLOW THE E
VALVE TO GO COMPLETELY CLOSED.
MHEN THE A VENTURI PUMP UAS STARTED, A VENTURI SPRAY HOSE RUPTURED.
IT MAS DISCOVERED THAT THE MODULE A VENTURI TANK LEVEL PRESSURE SHITCH MAS
NOT MORKINS PROPERLY.
THE PUGMILL ORDERED FOR CHICAGO ADMIXTURES HAS ARRIVED OH SITE. Ill OCTOBER,
THEY MILL FINISH THE CONVERSION, WHICH HILL ALLOM THE MATERIAL SERVICE
MIXER TRUCKS TO BE ELIMINATED.
IN OCTOBER, THE THICKENER MILL HAVE TO BE BYPASSED WHILE THE UTILITY DOES
MAINTENANCE ON THE RAKE AND REPLACES SOME LEAKING VALVES.
894
-------
EPA UTILITY FGO SURVEY: OCTOBER - OECEMSER 1981
COMMONWEALTH EDISON: HILL COUNTY 1 ICONT. I
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SOB PART. HCU3S HCL'HS HCU'S FAC7C3
10/78 A 100.0 100.0 35.0
B 100.0 100.0 35.0
SYSTEM 744 CS1
»* PR09LEMS/SOLUTIONS/CCMMENTS
LOW BOILER HOURS MERE DUE TO FOUR OUTAGES CAUSED BY HIGH 8EARIN3 METAL
TEMPERATURES AND EXCESSIVE VIBRATION IN THE 1-B FORCED DRAFT FAN.
THE BOILER DOWN TIHE MAS UTILIZED FOR CLEANING AMD REPAIR OF THE VENTUHI
THROAT, SUMP AND SUMP SCREENS, AND INLET BLOCK DAMPERS OF MODULE A, AS
HELL AS THE VENTURI AND ABSORBER TANKS AND SCREENS AND ALL ABSORBER SPRAY
NOZZLES OF BOTH MODULES.
ON INSPECTION, IT HAS DISCOVERED THAT THE B MCCULE ABSCRBER DEPARTMENTAL
DAMPER HAD SLIPPED SOX CLOSED. THE DAMPERS MERE JACKED OPEN AND MELDED
IN PLACE.
TO CORRECT A HIGH PRESSURE DROP ACROSS THE MODULE B REHEATER, A NEH METHC3
HAS EMPLOYED WHEREBY ONLY THE MIDDLE TUBES HERE 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 GR TWO HEEKS TO TWO DAYS.
11/78 A 96.2 100.0 48.3
B 65.2 100.0 48.3
SYSTEM 720 348
«« PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT HAS 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 744 480
*« PROBLEMS/SOLUTIONS/COHMENTS
REHEATER TUBE LEAKS CAUSED TWO OUTAGES.
THE MODULE B SPENT SLURRY DRAIN HAS REPAIRED.
1/79 A 83.5 100.0 61.3
B 62.2 87.1 53.4
SYSTEM 744 456
*» PHOBLEMS/SOLUTIONS/COKMENTS
THE S02 PLANT HAS FORCED OFF TWICE THIS MONTH DUE TO REHEATER TUBE LEAKS.
TWO TUBES ON MODULE A AND FOUR TUBES ON MODULE B MERE REPLACED.
THE I.D. BOOSTER FAN ON MODULE B MAS FOULED AND HAD TO BE REPLACED.
TWO SPECIAL SECTIONS OF VENTURI PIPING, A SIXTEEN TO EIGHT IS'CH ECCENTRIC
REDUCER AND AN OFFSET TEE HERE PREPARED BY LOCKFCRT FABRICATING AND INSTAL-
LED THIS MONTH. THE ORIGINAL REDUCER AND TEE HAD BEEN PATCHED AND WELCEO SO
MANY TIMES THAT THEY HERE BEYOND REPAIR.
2/79 A 93.0 91.3 54.2
B 93.0 91.3 54.2
SYSTEM 672 399
895
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COMMON-WEALTH EDISCN: MILL COUNTY 1 (CONT. I
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION '/. REMOVAL PEP BOILE3 FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
•« PRC8LEMS/SOLUTIONS/CCMMENTS
THE UNIT MAS FGRCED 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 MILL HAVE TO BE
REPLACED DUE TO EXTENSIVE CORROSION.
THE SYSTEM MAS DOWN ONCE FOR A SPRAY HEADER LEAK.
MODULE B EXPERIENCED A LEAK IN THE VENTURI DOUNCOMER. A FIVE FOOT SECTION
OF THE PIPE MILL HAVE TO BE REPLACED.
4/79 A
SYSTEM 720
5/79 A .0
B .0
SYSTEM 744 0
«« PROBLEMS/SOLUTIOHS/COMHENTS
UNIT 1 HAS OUT OP SERVICE THE ENTIRE MONTH DUE TO A BOILER OVERHAUL.
CHICAGO ADMIXTURES MILL STOCKPILE THE FIXED SLUDGE ON STATION PHOPEPTY.
6/79 SYSTEM 720 0
7/79 SYSTEM 744 0
8/79 SYSTEM 744 0
** PROBLEMS/SOLUTIONS/COMMENTS
UNIT 1 MAS OUT OF SERVICE TO REPLACE THE AIR HEATER TUBES. TUBE SHEET AND
HOPPERS. DURING THIS OUTAGE. THE MORN VENTURI SFPAY NOZZLES AMD OEMISTERS
MERE REPLACED. MELDING LEAKS AND GENERAL CLEANING OF THE S02 INTERNALS
MAS ALSO DONE AT THIS TIME.
THE BOILER AND THE SCRUBBER ARE SCHEDULED TO RETURN TO SERVICE OCTOBER 1,
1979.
720 0
744 0
£5.4
85.4
85.4 720 336 336
*» PROBLErtS/SOLUTICNS/COMMENTS
ON NOVEMBER S, 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.
896
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 FGO SURVEY: OCTOBER - OECErSER 1<=31
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CA=.
502 PART. HOURS HOUPS KOU'S FACTCS
THE UNIT DID NOT FORCE THE BOILER OFF AT ANY TIME DURING NOVEMBER.
12/79 A 77.0 99.5 57.5
B 64.9 100.0 57.8
SYSTEM 77.0 99.5 57.5 744 431 428
«« PROBLEKS/SOLUTIONS/COKKENTS
ON DECEMBER 4, UNIT 1 CAME OFF LINE SO THAT THE AIR HEATER HOPPEPS AMD
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-MCOULE DEVELOPED A SERIOUS STEAM LEAK (£5.000 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 HAS REMOVED FROM THE GAS PATH ON DECEMBER 29, FOR THREE HC'JHS
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 MAS 54 HOURS AND 39 MINUTES.
1/80 A 91.0 87.5 63.0
B 88.6 84.1 60.6
SYSTEM 88.6 84.1 60.6 744 536 451
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST SIX DAYS OF JANUARY, UNIT 1 BOILER MAS 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 DEPATE UNIT 1 TO 50 MM BECAUSE THE RE-
HEATER SECTIONS ON A AND B MODULES MERE PLUGGING. ON JANUARY 17, THE
MODULES MERE TAKEN OUT OF THE GAS PATH TO BEGIN REMOVING AHO CLEANING THE
REHEATER SECTIONS WITH A HIGH PRESSURE (4000 PSD MATER SPPAY. UNIT 1
BOILER MAS LEFT ON TO PROVIDE STABILITY FOR THE 133 KV SYSTEM.
IN THE PAST, ALL 42 BUNDLES CONSISTING OF SEVEN TUBES PER BUT-IDLE,
HAD TO BE TAKEN OUTSIDE TO BE CLEANED ON A CONCRETE SLAB. IN THIS CASE
SINCE TIME MAS THE MOST IMPORTANT FACTOR, A DIFFERENT APPROACH WAS USED.
ONLY THE MIDDLE SIX BUNDLES ON EACH MODULE MERE REMOVED. THIS PROVIDED A
LARGE ENOUGH SPACE SO THAT A LANCE WITH AN EXTENSION ON IT COULD BE USED
TO CLEAN THE BOTTOM OF THE TWO TOP BUNDLES AND THE TOP OF THE TWO BOTTOM
BUNDLES. THERE ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
OF THE REHEATER. USING THIS METHOD, ONLY 12 OR THE 42 BUNDLES MERE
REMOVED. IN THE PAST, THIS JOB HAS TAKEN AS LONG AS TWO WEEKS TO
COMPLETE. USING THE NEM METHOD, ALL THE REHEATER BUNDLES WERE CLEANED IN
20 HOURS.
THE B-MODULE HAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY. BOTH
THESE OUTAGES MERE CAUSED BY THE REHEATER (A COIL LEAK AND A FLANGE LEAK)
TOTALING 18 HOURS AND 24 MINUTES.
2/80 A 79.7 90.5 79.7
B 78.6 69.2 78.6
SYSTEM 74.1 84.2 74.1 696 613 516
»» PRCBLEMS/SOLUTIOM3/COMMENTS
SCRUBBER PROBLEMS IN FEBRUARY HERE CAUSED FROM LEAKS IN THE VENTUPI SPPAY
HEADER. THESE LEAKS DEVELOP WHERE THE RUBBER LINING INSICE THE VENTUrl
PIPING HAS MORN AMAY SO THAT THE BARE METAL IS EXPOSED. THIS EXPOSED METAL
697
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISCN: MILL COUNTY 1 (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL' PER BOILER FGO CAP.
S02 PART. HCU3S HOU3S HCUES FACTOR
IS THEN SUBJECT TO ERROSION/CORHOSION. THE LINING IS TOST LIKELY TO WEAR
AT THE WELD HEAD OF THE SPRAY NOZZLE TO THE MAIN HEADER. ALL THE VENTUHI
SPRAY PIPING IS BEING REPLACED.
TUBE LEAKS IN THE STEAM COIL REHEAT SYSTEM CAUSED SCRUBBER PROBLEMS THIS
MONTH. MODULE A MAS FORCED OUT ONCE AND MODULE B UAS FORCED OUT THREE
TIMES. THESE TUBES MILL BE REPLACED DURING THE NEXT OUTAGE.
3/80 A 83.9 .0
A 83.9 .0
SYSTEM 83.9 .0 744 0 0
»» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER MAS OUT OF SERVICE FOR ALL OF MARCH DUE TO BOILER TUBE LEAKS IN
THE REHEAT SECTION OF THE BOILER.
4/80 A 100.0 71.0 17.3
B 87.7 71.0 17.3
SYSTEM 93.9 71.4 17.3 720 175 125
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST 15 DAYS OF APRIL THE BOILER MAS OUT OF SERVICE DUE TO
TUBE LEAKS IN THE AIR PREHEATER.
WHEN ATTEMPTS MERE 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 MERE MADE TO RETURN THE BOILER TO SERVICE AGAIN, THE AUXIL-
IARY LOW PRESSURE GOVEMOR 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 £4 AMD
MAS AVAILABLE FOR THE REST OF APRIL.
5/80 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
INFORMATION UAS 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 FOPCED THE BOILER OUT OF SERVICE FROM JUNE 6 TO
JUNE 10. THE OUTAGE MAS CAUSED BY PLUGGED REHEATERS ON BOTH MODULES.
THIS MAS 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 MERE 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.
898
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1 (CONT.)
PERFORMANCE DATA
PEPIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CiP.
S02 PART. HOURS HOURS HCt'^3 FACTOR
ON NINE OCCASIONS IN JULY THE SCRUBBER MAS BY-PASSED SO THAT THE BOILER
COULD CARRY MAXIMUM LOAD (163 MM). THE UNIT MAS LIMITED TO 135 MVJ AFTER
A RECENT STACK EMISSION TEST.
6/80 SYSTEM 744
9/80 SYSTEM 720
«« PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION HAS 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
*« PROBLEMS/SOLUnONS/COMMENTS
DURING OCTOBER THERE MAS ONE FORCED OUTAGE DUE TO PROBLEMS MITH THE AB-
SORBER RECIRCULATION PUMP CM MODULE B. DURING THIS OUTAGE THE MALL MASH
HEADERS MERE REPLACED ON BOTH MODULES.
DURING OCTOBER THE BOILER HAS SHUT DOWN TWICE DUE TO A LACK OF DEMAND.
THIS ACCOUNTED FOR APPROXIMATELY 51 HOURS OF DOWN TIME. ADDITIONAL UNIT
OUTAGE TIME MAS DUE TO INTERCEPT VALVE AND AIR HEATER PROBLEMS.
11/80 A 92.4 100.0 63.4 33.0
B 9Z.4 100.0 83.4 33.0
SYSTEM 92.4 100.0 63.4 33.0 720 238 233
»» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT HO 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 FGO SYSTEM HAS LOU DUE TO PLUGGED
VENTURI NOZZLES AND HEADER, WHICH HAD TO BE HIGH-PRESSURE JETTED.
1/81 A 82.4 100.0 60.8 60.8
B 82.4 100.0 80.8 80.8
SYSTEM 82.4 100.0 80.8 60.8 80.00 744 601 601
»» PROBLEMS/SOLUTIONS/COMMENTS
DURING JANUARY THE MIST ELIMINATOR TRAY MAS REPLACED ON MODULE A.
2/81 A 75.4 100.0 66.9 68.9
B 75.4 100.0 68.9 68.9
SYSTEM 75.4 100.0 68.9 66.9 80.00 672 463 463 59.3
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE BOILER MAS OUT OF SERVICE APPROXIMATELY 209 HOURS CUE
TO TUBE LEAKS.
THE SCRUBBING SYSTEM HAS OUT OF SERVICE 164 HOURS DUE TO CLEANING AND A
TWO HOUR INSPECTION.
899
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COmOHMEALTH EOISCN: WILL CCUNTY 1 (CONT.)
PERFORMANCE DATA
PERIOD MCDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOU3S HCU2S HC'JPS FAC7G9
3/31 A 70. 3 100.0 68.2 68.2
B 70.2 100.0 68.2 68.2
SYSTEM 70.2 100.0 68.2 68.2 60.00
744 507 507 63.1
»« PROBLEMS/SOLUTIONS/CCKMENTS
DURING MARCH DOWNTIME OCCURRED DUE TO MISCELLANEOUS CLEANING TO THE BOILER
AND THE SCRUBBER.
4/31 A 32.9 100.0 32.9 32.9
B 32.9 100.0 32.9 32.9
SYSTEM 32.9 100.0 32.9 32.9 7CO 237 237 30.1
** FROBLEMS/SOLUTIONS/COHMENTS
DURING MAY THE SCRUBBING MODULES AND THE SCRUBBER PIPING HERE CLEANED.
THIS ACCOUNTED FOR THE OUTAGE TIME DURING THE MONTH.
5/81 A 59.1 100.0 51.0 48.1
B 59.1 100.0 51.0 48.1
SYSTEM 59.1 100.0 51.0 48.1 80.00 744 353 358 42.7
** PROBLEMS/SOLUTIONS/COHMENTS
DURING MAY THE BOILER MAS DOWN FOR 11 DAYS FGR A SCHEDULED OUTAGE.
IN MAY 41 HOURS OF OUTAGE TIME MAS DUE TO A LACK OF DEMAND.
LEAKS IN THE CYCLONE TUBES CAUSED THE SYSTEM TO SHUT DOWN FCR 53 HOURS.
TOWARD THE END OF MAY, THE SYSTEM WAS SHUTDOWN FOR 30 HOURS TO PREPARE
FOR AN EMISSION TEST.
6/81 A 100.0 100.0 100.0 63.7
B 100.0 100.0 100.0 63.7
SYSTEM 100.0 100.0 100.0 63.7 720 458 458 49.4
»« PROBLEMS/SOLUTIONS/COHMENTS
DURING JUNE NO MAJOR PROBLEMS WERE ENCOUNTERED.
900
-------
EPA UTILITY FGD SURVEY: OCT03E3 - DECEMBER 1931
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCPU2BERS
COMPANY NAME
PL."NT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - N3/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MU
«* WIT DATA - BOILER AND STACK
BOILER SUPPLIER
60ILER 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 CHL03ICE CONTENT - 7.
RANGE CHLORIDE CONTENT - X
**« PARTICLE CONTROL
«* MECHANICAL COLLECTOR
NUMBER
TYPE
*» FABRIC FILTER
NUMBER
TYPE
«• ESP
• NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
*« PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
LIQUID RECIPCULATION RATE - LITER/S
L/G RATIO - LITER/CU.H
PH CONTROL ADDITIVE
DETROIT EDISON
ST. CLAIR
6
BELLE RIVER
MICHIGAN
C
66.
1376.
******
1798
260
«**«*
*****
163
COMBUSTION ENGINEERING
******
PEAK
465.77
132.2
130.
******
*******
( .200
( 3.200
(****** LB/MK3TU)
( 987000 ACFM)
( 270 Fl
( 425 FT)
(»«*** FT)
( 9600 BTU/LB)
9500-9600
COAL
SUBBITUMINOUS
22330.
4.00
3.0-4.0
22.60
22.0-24.0
.35
0.3-0.4
**»»»«
0
NONE
0
NONE
MHEELABRATOR-FRYE
90.0
2
9/75
VENTURI TOMER
VARIABLE-THROAT/AOJUSTABLE DRUM
RADIAL FLOW VENTURI
PEABODY-LURGI
STAINLESS STEEL
AUSTENITIC
ORGANIC
RUBBER
NONE
( 4420 GPM)
(20.0 GAL/1000ACF)
278.5
2.7
LIMESTONE
901
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
DETROIT EDISCN: ST. CLAIR 6 (CONT.)
PRESSURE CROP - KPA 3.5 (14.0 IN-H20)
SUPERFICIAL GAS VELOCITY - M/S 28.3 ( °3.0 FT/S)
INLET GAS FLOW RATE - CU.M/S 116.6 ( £47000 ACFM)
INLET GAS TEMPERATURE - C 133.2 ( 270 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HCVS FACTOR
11/74 SYSTEM 720
12/74 SYSTEM 744
1/75 SYSTEM 744
K* PROBLEMS/SOLUTICNS/COMMENTS
INSTALLATION OF THE FGO SYSTEM HAS ESSENTIALLY COMPLETED BY THE NOVEMBER,
1974 THROUGH JANUARY 1975 PERIOD.
A FAULTY INSTRUMENT PANEL WHICH MAS INCORRECTLY HIRE3 HAS BEEN RETURNED TO
THE MANUFACTURER FOR REPAIR.
TO OATEi THE UTILITY HAS MATER TESTED ALL THE AUXILIARY EQUIPMENT. THE ID
FAN HAS BEEN TESTED AND AIR BALANCE HAS BEEN CHECKED.
2/75 SYSTEM 672
3/75 SYSTEM 744
4/75 SYSTEM 720
«* PRCBLEMS/SOLUTIONS/COraiENTS
A COLD FLUE GAS RUN HAS SUCCESSFULLY CONDUCTED MARCH 22 AND 23. DURING
THIS PERIOD THE RUBBER-LINED PUMPS MERE REPAIRED AND THE LIMESTONE FREARA-
TION SYSTEM MAS CALIBRATED.
5/75 SYSTEM 744
6/75 SYSTEM 720
7/75 SYSTEM 744
«« PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST HOT FLUE GAS RUN MAS CONDUCTED ON JUNE 22, 1975. THE RUN LASTED
FOR A PERIOD OF 22 HOURS. DURING THIS RUN, THE SCRUS9ER MAS PURPOSELY
TRIPPED OFF AT LOADS OF 40 AND 80 PERCENT. THIS MAS PERFORMED TO OBSERVE
IF ANY DETRIMENTAL EFFECTS TO THE STEAM GENERATION OPERATIONS RESULTED.
NONE HERE DETECTED. THE SYSTEM MAS TAKEN CUT OF SERVICE FOLLOMINS THIS
GAS RUN TO CORRECT THE FOLLOWING MAJC3 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 MATER LCM FLOW ALARM TRIPS.
8/75 SYSTEM 744
9/75 SYSTEM 720
*» PROBLEMS/SOLUTIONS/COMMENTS
A SECOND HOT FLUE GAS RUN MAS INITIATED ON AUGUST 6 AND LASTED 27 HOURS.
THE RUN HAS TERMINATED BECAUSE OF A REHEATER THERMOCOUPLE FAILURE. A
SUBSEQUENT INSPECTION OF THE SCRUBBING SYSTEM REVEALED NO APPARENT
ABNORMALITIES OR MALFUNCTIONS.
902
-------
EPA UTILITY FGO SURVEY: OCTOBER - OECEM3ER
DETROIT EDISON: ST. CLAIR 6 (CCNT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILED F6D CAP.
SO2 PART. HCUHS HOURS HOURS FACTO?
A THIRD HOT FLUE GAS PUN OF 41 HOURS DURATION HAS COMPLETED OCT02ES 9. THE
MAIM OBJECTIVE OF THIS RUN WAS TO EVALUATE VARIOUS CCrtPCNEHTS OF THE FRESH
HATER SPRAT SYSTEM AND EFFECTS ON SYSTEM OPERATION. THE TEST fij!l HAS
PREMATURELY TERMINATED BECAUSE OF A BOILED FEED PUMP NALFLCiCTIO.'l. RESJLTIM5
IN A REDUCED BOILER LOAD CAUSING SUBSEQUENT WEEPING OF THE MASH TRAY.
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
** PHOBLEMS/SOLUTION3/COMMENTS
A FOURTH FLUE GAS RUN OF 23 DAYS DURATION UAS TERMINATED DUE TO EXCESSIVE
VIBRATION IH THE 1.0. & BOOSTER FAN. ONE OTHER SCRCEBER-RELATED CUTAuS
OCCURRED WHEN THE PACKING OF ONE OF THE SCRUBSER RECIRCULATICN FU1FS HEEDED
MAINTENANCE. SOZ REMOVAL DURING THIS PERIOD WAS 90 PERCENT AIJD PARTICULAR
OUTLET LOADING MAS 0.1 IB/1000 LBS 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/COtlMENTS
THE 30-DAY VENDOR QUALIFICATION RUN AND FINAL ACCEPTANCE TEST MERE
COMPLETED BY MAY 29. THE QUALIFICATION RUM UAS CONDUCTED OH A "HANDS OFF"
BASIS USING PLANT PERSONNEL EXCLUSIVELY. THE SYSTEM UAS IN SERVICE 100
PEPCENT OF THE TIKE THE BOILER UAS OPERATIONAL. THE FINAL ACCEPTANCE TEST
CONSISTED OF SIX 4-HR. TEST RUNS CONDUCTED IN THE SPACE OF ONE KEEK. THE
S02 REMOVAL EFFICIENCY FOR HIGH SULFUR COAL UAS 90.9 PERCENT. PARTICULATE
REMOVAL ALSO EXCEEDED DESIGN LEVELS. NO MAJOR CHEMICAL OR MECHAMICAL-
RELATED PROBLEMS HERE ENCOUNTERED.
5/76 SYSTEM 744
6/76 SYSTEM 7EO
7/76 SYSTEM 744
6/76 SYSTEM 744
«* PROBLEMS/SOLOTIONS/COMMENTS
THE UTILITY IS NOW PREPARING TO CONDUCT A 2 MONTH MINIMUM IHTEPNAL SCRUBBED
DEMONSTRATION PROGRAM TO ACQUIRE OPERATING DATA AND INFORMATION. FOLLOV4IN3
THE COMPLETION OF THIS PROGRAM THE BOILERS WILL FIRE LCW SULFUR DECKER
COAL (0.3 TO 4.0 PERCENT) TO MEET S02 EMISSION REGULATIONS. THE SCHU36ERS
MILL CONTINUE TO OPERATE IN THE PARTICULATE REMOVAL MODE.
9/76 SYSTEM 720
10/76 SYSTEM 744
»» PROBLEMS/SOLUTIONS/COHMEHTS
THE INTERNAL SOZ SCRUBBING DEMONSTRATION PROGRAM COMMENCED ON OCTOBER 14.
THE SCRUBBERS OPERATED CONTINUOUSLY FOR 10 DAYS.
903
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
DETROIT EDISON: ST. CLAIR 6 (COMT.)
PERFORMANCE DATA
PERIOD MCCULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FCO CAP.
502 PART. HOURS HOURS HOURS FACTOR
OPERATION ON THE DEMONSTRATION PROGRAM MAS INTERRUPTED BY A FORCED SCRUESER
OUTAGE RESULTING FPOM SCALE AND SOLIDS CARRYOVER FROM THE WASH TPAY AND
MIST ELIMINATOR TO THE SCRUBBER 1.0. BOOSTER FAN ASSEMBLY, CAUSING VIBRA-
TION AND BALANCE PROBLEMS. IT MAS DECIDED TO SANDBLAST THE FAN TO REMOVE
SOLIDS BUILDUP ON THE FAN ASSEMBLY.
THE UTILITY PLANS TO MODIFY THE COMPONENT'S MASH SYSTEM FOR GPEATER FLOW
CAPABILITY AFTER COMPLETION OF THE SO2 SCRUBBING PROGRAM. DECO ALSO PLANS
TO CONTINUE PARTICULATE SCRUBBING FOLLOWING THE TERMINATION OF THE S32
PROGRAM BY UNCOUPLING THE SPRAY TOWERS AND MAINTAINING THE PEABCDY-LURG!
VENTURI SCRUBBERS IN THE FLUE GAS STPEAM. SOME LIMESTONE MAY HAVE TO BE
ADDED TO THE PARTICULATE SCRUBBING SOLUTION IM ORDER TO PREVENT LOW PH
SWINGS AND MINIMIZE THE POSSIBILITY OF ACID CORROSION DAMAGE TO THE
INTERNAL COMPONENTS.
11/76 SYSTEM 60.0 720
*» PROBLEMS/SOLUTIOHS/COMMEHTS
FOLLOWING THE COMPLETION OF SAND BUSTING OPERATIONS TO SCRUBBER'S I.D.
BOOSTER FAN FOR REMOVAL OF SOLIDS BUILO UP. OPERATIONS RESUMED ON NOVEMBER
7 AND CONTINUED THROUGHOUT THE MONTH. THE SYSTEM'S AVAILABILITY INDEX fCR
THE MONTH MAS 80 PERCENT. THE MAJORITY OF THE OUTAGE TIME MAS CONSUMED
PROCURING SAND BLASTING SERVICES. THE OPERATION ITSELF REQUIRED ONLY 3
HOURS.
13/76 SYSTEM 51.0 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE SOS DEMONSTRATION PROGRAM CONTINUED THROUGHOUT DECEMBER. THE SYSTEM'S
AVAILABILITY INDEX FOR THE PERIOD MAS 51 PERCEN".
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
3/77 SYSTEM .0 672
** PROBLEMS/SOLUTIONS/COMMENTS
THE S02 DEMONSTRATION PROGRAM HAS OFFICIALLY TERMINATED OH DEC. 31, 1976.
THE SCRUBBER PLANT MAS SHUT DOWN AT THIS POINT AND FLUE GAS MAS BY-PASSED
AROUND THE SYSTEM.
3/77 SYSTEM .0 744
N* PRCBLEMS/SOLUTIONS/COMMENTS
THE BOILER REMAINS IN SERVICE, FIRING LOM 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 SCRL'SBER
OPERATIONS WILL OCCUR IN THE PRIMARY PARTICULATE-REMOVAL MODE. THE
PEABODY-LURGI VENTURI SCRUBBERS AND SPRAY TOWER ABSORBERS MILL PEMAIN III
THE GAS STREAM. SOLUTION WILL BE CIRCULATED THROUGH THE VENTURI'S MASH
TRAYS, AND MIST ELIMINATORS. NO SOLUTION WILL BE CIRCULATED THROUGH THE
SPRAY ZONE OF THE ABSORBER TOWERS. LIMESTONE REAGENT WILL BE ADDED TO THE
SCRUBBING SOLUTION IN ORDER TO PREVENT LOM PH SWINGS AND SUBSEQUENT
904
-------
EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1931
DETROIT EDISON: ST. CLAIR 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PEP BOILE3 FG3 CAP.
SOZ PART. HCUPS HOUSS HCL."?S FACTOR
KATE-IALS DAMAGE TO THE SCRUBBER'S INTERNALS. S02 PECOVAL SHOULD RESIDE
IN THE 35 TO SOX RANGE IN THIS MODE Or OPERATION BECAUSE OF THE SOLUTICN'S
ALKALINITY DUE TO THE FLY ASH AND LIMESTONE. ALSO OECO PLANS TO MAINTAIN
A HIC-HEF 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 SYSTEM
7/77 SYSTEM
8/77 SYSTEM
9/77 SYSTEM
10/77 SYSTEM
.0
.0
.0
.0
.0
.0
7ZO
744
7£0
744
744
7ZO
744
PROBLEMS/SOLUTIONS/COMMENTS
11/77 SYSTEM
1Z/77 SYSTEM
1/78 SYSTEM
3/78 SYSTEM
3/78 SYSTEM
4/78 SYSTEM
5/78 SYSTEM
96.0
85.6
90.0
74.6
THE UNIT HAS PULLED OFF LINE IN DECEMBER 1976 AND DID NOT PESTART UNTIL
OCTOBER 1977. WHILE THE UNIT HAS DOWN THE UTILITY INSTALLED BUILOIN33
AROUND PUMPS THAT MERE EXPOSED TO SEVERE WEATHER CONDITIONS.
7ZO
744
744
67Z
744
7ZO
744
«» PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT EXPERIENCED SPRAY HEADER PROBLEMS IN THE ABSORBER TOMER.
BROKEN NOZZLES MERE DISCOVERED.
SOME
THERE MERE 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 FPC3LEM HAS
A RESULT OF A LOU FAN OIL LEVEL.
THE UTILITY NOW OPERATES 3 RECYCLE TANK AGITATORS. PREVIOUSLY CNLY Z WERE
OPERATED. IT WAS FELT THAT PART OF THE TANK PLUGGING MAS A RESULT OF
INSUFFICIENT AGITATION.
THE SLURRY SPRAY SURGE TANK ENCOUNTERED CONTINUAL OVERFLCM PROBLEMS WHEN
THE ABSORBER SUMP PUMP WAS OPERATING. THIS HAS BELIEVED TO BE A RESULT OF
A BROKEN SECTION IN THE SPRAY NOZZLE LINES. SPRAY WAS BEING DIPECTEO
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.
905
-------
EPA UTILITY FGD SURVEY I OCTOBER - DECEMBER 1931
DETROIT EDISON: ST. CLAIR 6 CCOMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABIUTY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HC'JOS HO'JOS HC'JSS FACTOR
SOME SPRAY HEADER PROBLEMS MERE ENCOUNTERED. THE FP.P PIPING HAS RUFTUSIHG.
IT MAS SUSPECTED THAT THE RUPTURES HEPE A RESULT OF "MATE? H4HHER" I.E.
THE SURGE THAT OCCUSRS IN THE PIPE WITH A SUDDEN FLOW SATE CHAH3E.
THE SPRAY HEADERS HERE PLUGGING. WHEN THE HEADERS ARE DRAINED (E.G.
SYSTEMS SKUTOOMN) SCME SLURRY SETTLES IN THE HEADER LINES ETC. PINSE LIMES
ARE NOW BEING INSTALLED TO FLUSH OUT HEADERS DURING FUTURE SHUTDOWNS.
6/78 SYSTEM 87.9 720
»* PRCBLEMS/SOLUTXOHS/COnMENTS
CNE OF THE BLADES CAME LOOSE FROM AN 1.0. BOOSTER FAN A HO PASSED THROUGH
THE HOUSING. REPAIRS MERE MADE WITHOUT SERIOUS COMPLICATIONS.
7/78 SYSTEM 96.0 V*
»» 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 LIMES WITHOUT SERIOUS
CONSEQUENCES. IT IS NOT CRUCIAL THAT REPAIRS BE MADE IMMEDIATELY.
8/78 SYSTEM 90.* 7V*
9/78 SYSTEM 69.0 720
10/78 SYSTEM .0 7*4
11/78 SYSTEM .0 720
12/78 SYSTEM .0 7*4
1/79 SYSTEM 744
»» PRCBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERICO RECYCLE TANK AGITATORS MERE BREAKING LOOSE AND SIMILAR
PROBLEMS MERE ENCOUNTERED WITH THE SLURRY STORAGE TANK AGITATORS. THE
SCRUBBING SYSTEM MAS REMOVED FROM SERVICE FROM SEPTEMBER TrirOUSH JANUARY.
STEADY BEARINGS UEPE INSTALLED AT THE BOTTOM OF THE RECYCLE TANK SOLVING
THE RECYCLE TANK AGITATOR PPOBLEM. THE SLURRY STORAGE TAfK SYSTEM ALREADY
HAD STEADY BEARINGS. THESE MERE REWORKED TO IMPROVE OPERATIONS.
2/79 SYSTEM 672
3/79 SYSTEM 74$
** 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
906
-------
EPA UTILITY FGO SURVEY' "noEH - C=CE"2E= 1931
DETROIT EDISON: ST. CLAIH 6 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL FE3 BOILER FCO CAP.
S02 PART. HCU3S KCL-PS HC'-'S FACTC3
10/79 SYSTEM 7M
*« PRCBLEMS/SOLUTIONS/COMMEMTS
THE SYSTEft IS CURRENTLY DOWN BUT IS EXPECTED TO BE BACK ON LIME SOCM. THE
SCRUBBING SYSTEM HAS OPERATED ONLY 1 MEEK SINCE MAY 18. 1979 BECAUSE OF
SUMP PROBLEMS.
THE AGITATOR BEARING SYSTEM HAS POORLY DESIGNED. THE BEARING SYSTEM HAS
MOM BEEN COMPLETELY REDESIGNED. THE AGITATORS HAVE NOW OPERATED 2000 HOU=S
ON THE NEH BEARINGS. THE UTILITY WILL PROBABLY DRAIH THE TAW AFTER AECUT
500 MORE HOURS TO INSPECT AND READJUST THE BEARINGS. THE MEW BEARIN3
SYSTEM IS COMPOSED OF STAINLESS STEEL PARTS.
100X OF THE ST. CLAIH FLUE GAS PASSES THHOUSH THE ESP. SOX CF THAT FLUE
GAS ENTERS THE SCRUBBER. THE UNIT IS REQUIRED TO MEET A 55X OPACITY,
HOWEVER, A VARIANCE HAS BEEN GRANTED ALLOWING A 65X OPACITY UNTIL TriE
SCRUBBER IS AGAIN OPERATIONAL. THE UTILITY IS PREPARING TO INSTALL A
MEM ESP WHICH WOULD BE OPERATIONAL IN 2 YEARS. KHEN THE NEW ESP IS IN-
STALLED THE SCRUBBING SYSTEM AND OLD ESP MILL BE SCRAPPED. TriE UNIT MILL
THEN BE REQUIRED TO MEET A 20X OPACITY.
11/79 SYSTEM 90.0 720
12/79 SYSTEM 90.0 74*
»» PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT CAME BACK ON LINE AROUND MID-NOVEMBER.
NEW DENVER PUMPS WITH EJECTORS WERE INSTALLED TO ASSIST THE SUMP FUtlPS
UNTIL THE ESP'S COME ON LINE.
THE ABSORBER PUMPS HAVE BEEN A PROBLEM RESULTING IN A CAPACITY TUSNOCXN
TO 225 MM (FROM 230 MWI.
ONE OF THE COAL MILLS HAS BEEN DOWN CAUSING LIMITED OPERATIONS.
1/60 SYSTEM 7<»
-------
EPA UTILITY FG3 SURVEY: OCTOBER - DECEMBER 1961
DETHOIT EDISCN: ST. CLAIR 6 (COMT.)
PERFORMANCE DATA
PSPIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILES FGD CAP.
SOZ PART. HOLRS KCU3S HOL'=S FACTCS
»* PROaLEMS/SOLUTIONS/CCMHENTS
THE SCRUBBER HAS OUT OF SERVICE THROUGH APRIL WHILE REPAIRS CONTINUED CM
THE SCRUBBER 10 FAN HOUSING. BECAUSE BOILER OPERATED AT LCM LOAD THE
SCRUBBER SERVICES MERE NOT REQUIRED IN APRIL.
5/80 SYSTEM 7
-------
EPA UTILITY FGO SURVEY: CCTC8ER - DECEMBER 1931
DETROIT EDISON: ST. CLAIR 6 (CONT.l
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HCL'PS HCUSS HC'JPS FiCTCS
*» PR03LEHS/SOLUTIONS/COMMENTS
THE SCRUBBER DID NOT OPERATE DURING JANUARY, FEBRUARY OR MARCH. DURING
THIS TIME U'ORK MAS CONTINUING CM THE AGITATORS. THE STATCR 3EARIN3S WERE
MALFUNCTIONING CHRONICALLY. THE BEARINGS HAVE NCH BEEN REMOVED. THE
AGITATOR IS NOW COMPLETELY FREE STANDING AND THE SHAFT HAS EEEM SHORTENED.
GENERAL MAINTENANCE MAS PERFORMED CM THE SCRUBBER DURING THE LAST TV3 WEEKS
OF MARCH. MCRK IS TO CONTINUE THROUGH THE FIRST HALF OF AF3IL. THE
SCRUBBING SYSTEM IS SCHEDULED FOR DECOMMISSIONING OU3IN3 THE FIRST hEEK OF
SEPTEMBER 1981.
2/81 SYSTEM .0 .0 672 0
909
-------
EPA UTILITY FC-D SURVEY: OCTOBER - DECEMBER 1981
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
S02 EMISSION LIMITATION - N3/J
NOX EMISSION LIMITATION - H3/J
tin PLANT GENERATING CAPACITY - MM
C-POSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
MINNESOTA POWER
CLAY BOSMELL
3
COHASSET
MINNESOTA
E
258.
1720.
***<**«
1000
364
347
350
350
& LIGHT
( .600 LB/MM3TU)
( 4.000 LB/KMBTU)
(****** LB/MM3TU)
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYF1
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 - 7.
AVERAGE MOISTU9E CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFU9 CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
*« MECHANICAL COLLECTOR
NUMBER
<•« FABRIC FILTER
NUMBER
TYPE
*« ESP
NUMBER
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
613.47 (1200000 ACFM)
123.3 ( 254 F)
213. ( 700 FT)
CONCRETE
7.9 f £6.0 FT)
COAL
SUBBITUniNOUS
19538.
9.00
4.8-16.0
26.00
24.0-2B.O
.92
0.5-1.5
.01
0.00-0.07
( 8400 BTU/LB)
7500-9900
0
NONE
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
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
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
1
5/73
IMPINGEMENT TOMER
NR
NR
KREBS ENGINEERS
18.0 X 126.0 X 52.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
714.4
1.1
ALKALINE FLYASH
(11240 GPM)
( 8.3 GAL/1000ACF)
1.0
( 4.0 IN-H20)
910
-------
EPA UTILITY FGO SURVEY: OCTC3EH - CECiKEER 1<»31
MINNESOTA POWER » LIGHT: CLAY BOSMELL 3 ICONT. J
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S32 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
2.4
613.5
123.3
.0
98.7
.8
( 8.0 FT/S)
(1300000 ACFM)
( 254 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
S02 PART.
PER BOILER FGD CAF
HOU=S hCURS HCL'^S FAC7C?
5/73 SYSTEM
*» PROBLEMS/SOLUTIONS/COMMENTS
10/79 SYSTEM
11/79 SYSTEM
SINCE STARTUP IN MAY 1973 SCALING AND PLUGGING HAVE OCCURRED IN NOZZLES,
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/CRY 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 SCRL'SSES. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL Bl'PNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY BLCXCOUN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY SELOVJ 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 MASHING OF THE MET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PLACE OF MASHING WAS ATTEMPTED 5UT
WAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT OF WASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION CF A NEW LOW-VELOCITY
STACK.
744
720
12/79 SYSTEM 744
«« PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION MAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
«» PRC3LEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
4/80
5/80-
6/80
SYSTEM
SYSTEM
SYSTEM
»• PROBLEMS/SOLUTIONS/COMMENTS
720
744
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURPED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80
8/80
9/80
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
90.3
78.0
84.0
720 650
744 530
744 625
650 60.2
580 52.3
625 54.8
911
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1<>81
HIHTIESOTA POWER £ LIGHT: CLAY BOSWELL 3 (COOT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION 7. REMOVAL PEP SAILER FG3 CAP.
S02 PART. HCURS hl'JHS KOLSS FACTOR
«» PROBLEMS/SOLUTION5/CCMMENTS
NO OPERATIONAL PROBLEMS MERE REPORTED FOR THE JULY THROUGH SEPTEMBER
PERIOD.
10/80
11/80
12/80
SYSTEM
SYSTEM
SYSTEM
100
100
100
.0
.0
.0
100.0
100.0
100.0
100.0
100
100
.0
.0
85.9
81.5
81.6
744
720
744
639
587
607
639
587
607
62.3
64.6
60.9
*» PROBLEMS/SOLUTIONS/COMMENTS
1/81
2/81
3/81
SYSTEM
SYSTEM
SYSTEM
100
100
100
.0
.0
.0
THE UTILITY
THE FOURTH
100.0
100.0
100.0
REPORTED THAT NO
QUARTER 1980.
100
100
100
.0
.0
.0
SCRUBBER
94.3
97.0
79.0
PROBLEMS MERE ENCOUNTERED
744
672
744
702
651
585
DURING
702
651
585
69.1
73.2
65.1
»» PROSLEMS/SOLUTIONS/COMKENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS MERE ENCOUNTERED
DURING THE FIRST QUARTER 1981.
DURING MARCH THE BOILER MAS OUT OF SERVICE APPROXIMATELY 159 HCURS TO RE-
PAIR STEAK LEAKS AND TO PERFORM MAINTENANCE.
720 447 447 50.9
744 709 709 79.3
7CO 696 696 75.7
** PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED DURING THE
SECOND QUARTER 1981.
4/81 SYSTEM
5/81 SYSTEM
6/81 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
62.1
95.3
96.7
912
-------
EPA UTILITY F60 SURVEY: OCTCSER - DECEMBER 1<=31
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCPU2BERS
CCMPANY HAKE
PUNT MAKE
UMIT NUMBER
CITY
STATE
REGULATCHY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - N6/J
£02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
C.OQSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY WO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KM
»» UHIT DATA - BOIISR AHD 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 - ft
»* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RAN3E ASH CONTENT - X
AVERAGE MOISnjPE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - X
««» PARTICLE CONTROL
** MECHANICAL COLLECTOR
NUMBER
TYPE
«» FABRIC FILTER
NUMBER
TYPE
«» ESP
NUMBER
TYPE
*» PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER JENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
( .600 LB/MM3TU)
( 4.000 LB/KT.STU)
(*****» LB/r.."3TU)
MINNESOTA POVJER S LIGHT
SYL LASKIN
1
AURORA
MINNESOTA
E
£58.
1720.
«*«**«
116
62
57
58
58
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 (
171.1 (
91. (
CONCRETE
3.2
300000 ACFM)
340 F)
300 FT)
COAL
SUBBITUMINOUS
20469.
9.00
4.8-16.0
26.70
24.0-28.0
1.00
0.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
1
6/71
IMPINGEMENT TOUER
NR
NR
KREBS ENGINEERS
34.0 X 18.0 X £3.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
151.2 (
1.1 (
( 10.5 FT)
( 8800 BTU/LS)
7509-9923
2400 GPM)
8.3 GAL/1000ACF)
913
-------
EPA UTILITY FGD SLAVEY: OCT03ER - DECEMBER 1981
MINNESOTA POMES & LIGHT: STL LASKIN 1 (CONT.)
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/5
INLET GAS FLCy RATE - CU.M/S
INLET G4S TErTE°ATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - 7.
ALKALINE FLYASH
.6 (
2.1 (
137. •* (
171.1 (
.0
97.3
1.6
2.5 IN-H20)
7.0 FT/SJ
291160 ACFM)
540 F)
PERIOD MODULE AVAILABILIT
PERFORMANCE D4TA
OPERABILITY RELIABILITY UTILIZATION
X PEMOVAL PES BOILER FG3 CAP.
S02 PART. HOURS HOURS HOURS FACTC9
6/71 SYSTEM
*» FROBLEnS/SOLUTICNS/CCMHENTS
10/79 SYSTEM
SINCE STARTUP IN JUNE 1971 SCALING AND PLUSSIN3 HAVE OCCURPEO IN NOZZLES,
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE UET/DPY ZONE, AND
ON THE FAN AMD THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS CEPCSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SCFU3BER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BUPNED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY BLOWDCWJ OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELCVI 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 MASHING OF THE WET FAN l.'HICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOHEPS IN PLACE OF HASHING HAS ATTEMPTED BUT
HAS UNSUCCESSFUL. THE UTILITY HAS PECUCED THE AtlC'JNT OF HASHING AND HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEU LOW-VELOCITY
STACK.
THE PROBLEMS AT SYL LASKIH ARE NOT AS SEVEPE AS THE PPC3LEMS AT CLAY
BOSHELL DUE TO THE FACT THAT THE RECYCLE LOOP IS NOT CLOSED TO THE SAME
EXTENT. THE MIST CARRYOVER PPC3LEM IS LESS SEVERE CWIN3 TO OPERATION Or
THE UNIT AT PARTIAL LOAD RESULTING IN A LCWER STACK VELOCITY.
720
11/79 SYSTEM
12/79 SYSTEM 744
«« PROBLE.1S/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.
4/30 SYSTEM
5/80 SYSTEM
6/30 SYSTEM
*« PROBLEMS/SOLUTIONS/COMMENTS
720
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCUPRED DURING THE
SECOND QUARTER OF 1980. DOHM TIME FCR MAINTENANCE HAS NOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
914
-------
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
EPA UTILITY FGO SUUVEY: CCTC3E:? - DECSMSEH 1931
MINNESOTA POWER S LIGHT: SYL LASKIN 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER EOIL;3 =GD CAP.
S02 PART. HOURS HC'JPS HC'JPS FACTOR
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/SO 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
»* PROBLEMS/SOLUTIONS/COKMENTS
THE UTILITY REPORTED THAT NO BOILER OR FGD-RELATEO 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
»* FRCBLEMS/SOLUTIONS/COMMENTS
NO SCRUBBER OUTAGES OCCURRED DURING SEPTEMBER. THE LOW UTILIZATION FACTOR
HAS AGAIN THE RESULT OF A LACK OF DEMAND FOR POWER.
744 0 744 .0
730 175 175 10. Z
744 477 477 23.4
*» PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS OCOJRFEO DURING
THE FOURTH QUARTER 1960. LOW UTILIZATION FACTORS WERE CAUSED BY A LACK
OF POWER DEMAND.
1/81 SYSTEM 78.5 100.0 100.0 78.5 744 524 524 £3.3
** PROBLEMS/SOLUTIONS/COMMENTS
CURING JANUARY THE BOILER MAS OUT OF SERVICE APPROXIMATELY 160 HCURS DUE
TO A TURBINE STEAM LEAK. THE BOILER WAS OUT OF SERVICE AM ACDITICNAL 63
HOURS DUE TO A LACK OF POWER DEMAND.
2/81 SYSTEM 5.4 100.0 100.0 5.4 672 36 36 17.4
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE BOILER REMAINED OFF LINE FOR APPROXIMATELY 708 HCURS
TO REPAIR A TURBINE STEAM LEAK.
3/81 SYSTEM 99.1 100.0 100.0 79.0 744 583 533 44.3
** PROBLEMS/SOLUTICNS/COMMENTS
DURING MARCH THE BOILER WAS OUT OF SERVICE SEVEN HOURS TO CLEAN THE ID FANS
AND 77 HOURS DUE TO A LACK OF DEMAND.
4/81 SYSTEM 100.0 100.0 100.0 100.0 720 720 723 46.0
** PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL 10 HOURS OF OUTAGE TIME WAS NECESSARY TO WORK ON THE EXCITER.
5/81 SYSTEM 64.1 100.0 100.0 64.0 744 476 476 31.3
915
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
MINNESOTA POWER & LIGHT: SYL LASKIN 1 (CONT.)
PERFORMANCE DATA
FERIC3 I'.C^'JLE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER SOILED rGD CAP.
S02 PART. HCU'PS KCU=S HO'JPS FACTC3
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY THE UNIT MAS OUT OF SERVICE £09 HOURS FOR AN OVERHAUL.
SYSTEM DOWN TIME WAS NEEDED TO REPAIR A STEAM DRIVEN OIL PUMP.
FOLLOWING A TEST THE SYSTEM MAS TAKEN OFF-LINE FOR SANCBUSTINS 10 FANS.
6/81 SYSTEM 100.0 .0 720 0 0
** FRC3LEMS/SOLUTIONS/COMMENTS
IN JUNE THE UNIT MAS DOWN DUE TO A LACK OF DEMAND. DURINS THIS PERIOD
GENERAL MAINTENANCE MAS PERFORMED.
916
-------
EPA UTILITY FGD SURVEY: OCTCSEiJ - CECEr-3E= 1=31
SECTION 14
DESIGN AND PERFORMANCE DATA PCS OPERATIONAL PARTICLE SCP'JISERS
COMD«NY NAME
PLiNT NAME
L'MIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
F4STICULATE EMISSION LIMITATION - NG/J
EC2 EMISSION LIMITATION - NG/J
HGX EMISSION LIMITATION - NG/J
>!ET PLANT GENERATING CAPACITY - MW
C-SOSS UNIT GENEPATINS CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
*« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
SOI LER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - ft
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.
HAt.'SE 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
«» ESP
NUMBER
TYPE
** PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
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
MINNESOTA POWER
SYL LASKIN
2
AURORA
MINNESOTA
E
258. (
1720. (
*4**«tt (
116
62
57
56
58
& LIGHT
.600 LB/MMSTU)
4.000 '.S/KMSTU)
»<«•>-,•» (.3/riflSTU)
COMBUSTION ENGINEERING
PULVERIZED COAL
INTERMEDIATE
141.57 (
171.1 (
«1. (
CONCRETE
3.2 (
COAL
SUBBITUMINOUS
20469. (
9.00
4.8-16.0
26.70
24.0-28.0
1.00
0.5-1.5
.01
0.00-0.07
0
NONE
0
NONE
0
NONE
1
6/71
330000 ACFM)
340 F)
300 FT)
10.5 FT)
6800 BTU/LB)
7509-9923
IMPINGEMENT TOWER
NR
NR
KREBS ENGINEERS
34.0 X 18.0 X 23
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
151.2 (
1.1 (
.0
2400 GPM)
6.3 GAL/1000ACF)
917
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
MINNESOTA FOH5R t LIGHT: SYL LA5KIN Z (CONT.)
PH CO'fTFOL ADDITIVE
FPESSIPE DPO? - KFA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW BATE - C'J.M/S
INLET j£S -CXPE^ATU^E - C
S3! RLMOV1L ErrlCEI.'CY - '/.
PARTICLE PSKOV,L EFFICIENCY - 7.
EI1EPGY CONSUMPTION - V.
ALKALINE FLYASH
.6 <
2.: (
137.4
171.1
.0
97.8
1.6
< 2.5 IN-K20)
( 7.0 FT/S)
( 291160 ACFM)
( 340 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OFERABILITY RELIABILITY UTILIZATION
X REraVAL
S02 PART.
PER BOILER
HOURS HOURS
FG3 CAP.
HCUSS FACTC3
6/71 SYSTEM
*» FRCBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JUNE 1971 SCALIHG AMD PLUGGING HAVE OCCURRED IH KOZZLES.
NOZZLE TREES, STRAINERS, ON PUNCH PLATE BAFFLES, IN THE WET/DRY Z3NE ANO
ON THE FAN AND THE MIST ELIMINATOR. PLUGGING HAS ALSO RESULTED AS DEPOSITS
HAVE FALLEN INTO THE DRAINS AT THE BOTTOM OF THE SC=U23ER. DUE TO THE
CALCIUM-RICH ASH, CHARACTERISTIC OF THE WESTERN COAL BUSKED, THE SCALING
IS AGGRAVATED. THE UTILITY HAS CONTROLLED SCALE BY SLOWDOWN OF THE
SCRUBBING SYSTEM. THIS HAS MAINTAINED THE PROCESS CHEMISTRY BELOW S4TU3A-
TIOM WITH RESPECT TO CALCIUM SULFITE. A VERY HIGH LEVEL OF MAINTENANCE
HAS BEEN MAINTAINED ALSO TO MINIMIZE SCALE ACCUMULATION AND PLUGGING, THIS
HAS INCLUDED MASHING OF THE MET FAN WHICH HAS RESULTED IN A STACK MIST
PROBLEM. THE USE OF SOOT BLOWERS IN PLACE OF WASHING MAS ATTEMPTED BUT
HAS UNSUCCESSFUL. THE UTILITY HAS REDUCED THE AMOUNT Or HASHIUS AH3 HAS
CONSIDERED THE INSTALLATION OF REHEAT OR CONSTRUCTION OF A NEH LOU-VELOCITY
STACK.
THE FROSLEMS AT SYL LASKIN ARE NOT AS SEVERE AS THE PHC9LEMS AT CLAY
BOSWcLL DUE TO THE FACT THAT THE RECYCLE LOOP IS NOT CLOSED TO THE SAME
EXTENT. THE MIST CARRYOVER PROBLEM IS LESS SEVEPE OWING TO OPERATION
OF THE UNIT AT PARTIAL LOAD RESULTING IN A LOWER STACK VELOCITY.
10/79 SYSTEM
11/79 SYSTEM 720
12/79 SYSTEM 744
»» PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION HAS AVAILABLE FOR THE FOURTH QUARTER 1979.
1/80 SYSTEM 74*
2/80 SYSTEM 696
3/80 SYSTEM 744
*"• FRCBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS DURING THE
1ST QUARTER OF 1980.
*/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
»» PROBLEMS/SOLUTIONS/COMMENTS
720
74*
720
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING THE
SECOND QUARTER OF 1980. DOWN TIME FOR MAINTENANCE WAS HOT REQUIRED SINCE
GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT PAR-
918
-------
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
EPA UTILITY FGO SURVEY: OCTOBER - DECEIVES 1931
MINNESOTA POWER S LIGHT: SYL LASKIN 2 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X PEMOVAL PER BOILER FG3 CiP.
S02 PART. HOURS HG'JRS I-OL~S FACTC"
TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
7/80 SYSTEM 100.0 100.0 100.0 24.5 744 162 132 12.3
** PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER DID NOT OPERATE MOST OF JULY DUE TO A BOILER INSPECTION. NO
PROBLEMS MERE ENCOUNTERED WITH THE FGD UNIT.
e/60 SYSTEM 100.0 100.0 100.0 15.0 744 115 115 5.0
«* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER OPERATED ONLY 115 HOURS DURINS 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 OCCUPIED DURINS SEPTEMBER.
THE LOW UTILIZATION FACTOR RESULTED FROM A LACK OF DEMAND FOR
- POUER.
744 195 195 15.0
720 547 547 37.2
744 527 527 34.9
*« PRCBLEMS/SOLUTIONS/CCMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER-RELATED PROBLEMS WERE ENCOUNTERED
DURING THE FOURTH QUARTER.
1/61 SYSTEM 100.0 100.0 100.0 45.3 744 337 337 23.8
*« PROBLEMS/SOLUTIONS/COMMENTS
DURINS JANUARY THE BOILER MAS OUT OF SERVICE APPROXIMATELY 407 HOURS DUE
TO A LACK OF POWER DEMAND.
2/81 SYSTEM 100.0 100.0 100.0 97.4 672 653 653 28.5
** PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY THE UTILITY REPORTED THAT NO SCRUBBER-RELATED FR03LEMS
OCCURRED.
3/81 SYSTEM 100.0 .0 744 0 0 .0
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING MARCH THE BOILER MAS OUT OF SERVICE TO FIND THE CAUSE OF A TURBINE
VIBRATION.
4/61 SYSTEM 88.2 100.0 100.0 56.4 720 406 406 £6.9
*« FROBLEMS/SOLUTIONS/COMMENTS
DURINS APRIL 229 HOURS OF DOWN TIME MAS DUE TO A LACK OF DEMAND.
THE UNIT MAS DOWN 109 HOURS FOR A BEARING CHECK AND REPAIR DUE TO HIGH
VIBRATION.
5/81 SYSTEM 94.1 100.0 100.0 55.0 744 409 409 28.7
919
-------
EPA UTILITY FGO SURVEY: OCTOBER - OKI" ~°. i981
MINNESOTA POWER S LIGHT: SYL LASKIN Z ICONT.l
PERFORMANCE DATA
PERIOD tlCDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATIOM X REMOVAL FEP BOILER FGO CiP.
S02 PART. HCL'RS HCUPS HCUP.S FACTCR
*« PROBLEMS/SOLUTICN5/CCMMENTS
THE BOILER HAS OFF-LINE APPROXIMATELY 210 HOURS IN MAY DUE TO A LACK OF
DEMAMD.
FOLLOWING A TEST CONDUCTED IN JUNE THE UNIT MAS SHUTCCVIN FC3 SAHD3LASTIMG
THE ID FANS.
6/81 SYSTEM 100.0 .0 720 0 0
** PRCBLEHS/SOLUTICNS/COMnENTS
DURING JUNE THE UNIT WAS OFF-LINE DUE TO A LACK OF DEMAND. CURING THIS
PERIOD GENERAL MAINTENANCE HAS PERFORMED.
920
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCIL'EEEKS
CCflPANY NAME
PLANT NAME
L'MIT NUMBER
CITY
S.ATE
PECULATOR CLASSIFICATION
PAOTICULATE EMISSION LIMITATION - NG/J
£02 EMISSION LIMITATION - NG/J
HOX EMISSIC'l LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - KM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY HO/FGD - KW
EQUIVALENT SCRUBBED CAPACITY - KM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
EOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLCM - CU.tl/S
EOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
•Ht FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - '/.
RANGE MOISTURE CONTENT - V.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
»*» PARTICLE CONTROL
«» KECHANICAL COLLECTOR
NUMBER
TYPE
SUPPLIER
INLET PLUS GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE CROP - KFA
PARTICLE REMOVAL EFFICENCY -X
»« ESP
*» PARTICLE SCRUSBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON HAKE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIPCL'LATIOH RATE - LITER/3
L/G RATIO - LITER/CD.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
INLET GAS FLOW RATE - CU.M/S
MONTANA-DAKOTA UTILITIES
LEWIS & CLA"!K
1
SIDNEY
MONTANA
E
86. (
433. (
******
.:oo
1.003 LB/MM3TU1
(**»*** L3/Mr-.3TU)
50
55
50
52
55
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
153.37
215.6
76.
NONE
4.4
( 325000 ACFM)
( 423 F)
( 250 FT)
( 14.5 FT>
( 6450 BTU/LB)
6200-6700
COAL
LIGNITE
15003.
7.80
7.2-9.3
36.20
34.3-38.2
.61
0.3-1.4
.03
MULTICLONES
WESTERN PREC. DIVISION, JOY
106.2 ( 2=5000 ACFM)
176.7 ( 350 F)
.4 ( 1. IN-H20)
85.7
VENTURI TOMER
VARIABLE-THROAT/BOTTOM-ENTHY LIQUID DISTRIBUTION
FLOODED DISC SCRUBBER
RESEARCH-COTTRELL
10.5 OIA X 27.0
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
212.6
1.7
LIMESTONE
3.2
148.0
( 3374 GPM)
(13.0 GAL/1000ACF)
(13.0 IN-H20)
( 313730 ACFM)
921
-------
EPi UTILITY FG3 SURVEY: OCTOBER - DECEMBER 1981
M3NTANA-OAKOTA UTILITIES: LEWIS £ CLARK 1 (CCNT.)
INLET GAS TEMPEPATU?E - C 215.6 ( 420 F )
ENERGY CQNSUflPTICN - 7. 3.6
PERFORMANCE DATA
FERIC3 M02ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PE1? BOILER FG3 CAP.
S02 PART. HO'J'S HOL'^S KOU~S FACT03
10/79 SYSTEM 720
<•* FRC3LEMS/SCLUTION5/COMMENTS
DURING A SCHEDULED BOILER OUTAGE GENERAL SCRUBBER MAINTENANCE MAS
PERFORMED.
11/79 SYSTEM 720
«* PROSLEMS/SOLUTIONS/COMMENTS
DURING NOVEMBER THE SCRUBBER UAS TEMPORARILY BYPASSED TO ALLOW FOR REPAIPS
NECESSITATED BY A LEAK IN THE FLOODED DISC SCRU33ES.
12/79 SYSTEM 744
** PP03LEMS/SOLUTICNS/COMMENTS
THE UTILITY REPORTED THAT NO SCRUBBER PROBLEMS OCCURRED DURING DECEMBER.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
*» FSCBLEMS/SOLUTIONS/COMMEHTS
DURING THE JANUARY THROUGH MARCH PERIOD THE SCRUBBER UAS 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 SLUPRY AND ULTIMATELY PENDERIN'S 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 EROSICN APEAS 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
»« PROaLEMS/SOLUTIONS/COMHENTS
THE BOILER WAS SHUT DOWN FOR TWO WEEKS IN MAY.
CREWS INSPECTING THE SCRUBBING SYSTEM DISCOVERED THAT THE NIME FCOT SCRUB-
BER LINER SECTION AT THE BOTTOM OF THE CYCLONIC MIST ELIMINATOR WtS SEVE=E-
LY EPRODEO. THE LINER HAS LASTED THREE YEARS. THE UTILITY CONSICEPS THIS
A NORMAL MAINTENANCE PROBLEM. AT ONE TIME LINERS IN THIS SECTION WE=E 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.
922
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1'Sl
rONTANA-OAKOTA UTILITIES: LEWIS S CLARK 1 (COHT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OFEHABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER ?33 CAP.
S02 PART. HOURS HC-'.S HOURS FACTOR
THE UTILITY REPORTED THAT THE SCRUBBER HAS EXPERIENCED PLL'33IH3 AT WET/3?Y
INTERFACES WITHIN THE STRUCTURE. IT APPEARS THAT THIS IS RELATED T3 CCAL
SULFUR CONTENT. WHEN THE SULFUR CONTENT IS RELATIVELY HISH (0.7 TO l.C/: AT
LEWIS AND CLARK) THE PLUGGING DOES NOT OCCUR. LIMESTONE IS AC3ED AS RE-
QUIRED TO PREVENT THE OCCURRANCE OF LOW FH LEVELS. WHEN THE SULrU= CCNTS'IT
FALLS TO THE 0.3X PAUSE THE PH RISES AS A RESULT OF THE ALKALINE CCIISTITU-
EHTS 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/CCMMENTS
DURING JULY TWO WEEKS OF DOWN TIME WAS NECESSARY TO REPLACE THE MIST
ELIMINATOR LINER.
THE PPCBLEM WITH THE FLOODED DISC BUILDUP MENTIONED EARLIER CONTINUED.
THE UTILITY PERFORMS THE NECESSARY REPAIRS IN THREE TO FOUR HGU3S WHEN
THIS OCCURS.
8/80 SYSTEM ~44
9/80 SYSTEM "20
*« PROBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH SMU3SIN3
OPERATIONS DURING THE MONTHS OF AUGUST AND SEPTEMBER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
»« PR03LEMS/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 PP03LEMS WERE FOUND.
1/81 SYSTEM 744
«* FROSLEMS/SOLUTIOHS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR SCRUBBER PROBLEMS OCCURRED DURING
JANUARY.
2/81 SYSTEM 672
** PRC9LEHS/SOLUTICN3/COMMENTS
CM FEBRUARY 10 THE SCRUBBER WAS SHUT DOWN FOR FIVE HOURS DUE TO A PLUGGED
VENTURI.
OH FEBRUARY 23 A LEAK WAS DISCOVERED ON THE t f£R WALL OF THE SCRUBBER,
LOCATED BELOW THE VENTURI. THE LEAK WAS TEMPORARILY REPAIRED F.=CM THE
OUTSIDE WHILE THE SCRUBBER REMAINED ON-LINE. THE UTILITY PLANNED TO REPAIR
THE LEAK DURING THE SCHEDULED OUTAGE IN MARCH.
3/81 SYSTEM 744
923
-------
EPA UTILITY FGD SU=VEV: CC7C3E3 - DECEMBER 1981
MONTANA-DAKOTA UTILITIES: LEWIS t CLARK 1 (CONT.)
PERFORMANCE DATA
PERIOD HC3ULE AVAILABILITY CFERA3ILITY RELIABILITY UTILIZATICN X REMOVAL PER BCILER ?GD CA=.
S02 PART. HO'JSS HOURS HCL'SS FACTOR
«» FHC3LEMS/SOLUTIC^;S/CC^;nE!ITS
THE SCHEDULED OUTAGE PERIOD WAS HELD FROM MARCH 3 TO 15. DURING THIS TIKE
THE VEHTU3I AND SUMP HERE INSPECTED. THE LEAK DISCOVERED EARLIER IN FEB-
RUARY MAS REPAIRED CORRECTLY.
924
-------
EPA UTILITY F63 SURVEY: CCT03ER - DECEMBER 1931
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPEPATICNAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
£02 EMISSION LIMITATION - NG/J
HOX 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/FGO - 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 - V.
RANGE ASH CONTENT - 7.
AVERAGE MOISTUSE CONTENT - X
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
*»* PARTICLE CONTROL
«» PARTICLE SCRUBBER
NUM3ER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC IATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
INLET GAS FLCVt RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
PACIFIC FC'rJEP t LIGHT
DAVE JOHNSTON
4
GLEN90CK
WYOMING
0
90.
215.
*»•«***
( .210 LB/W.3TU)
( .500 LB/rrSTU)
(•«***** LB/MMSTU)
*****
330
3C7
330
330
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
707.85 (1500000 ACFM)
132.2 ( 270 F)
76. ( 250 FT)
******
******* (***** FT)
( 7430 BTU/L3)
5000-9000
COAL
SU3BITUMINOUS
17282.
12.00
******
26.00
******
.50
******
.04
******
3
4/72
VENTUHI TOWER
VARIABLE-THROAT/TOP-ENTHY PLUMB BOS
N/A
GE ENVIRONMENTAL SERVICES
CAPBON STEEL
AISI 1110
ORGANIC
POLYESTER
N/A
409.5 ( 6500 GPM)
1.7 (13.0 GAL/1000ACF)
LIME/ALKALINE FLYASH
2.5 (10.0 IH-HSO)
327.5 ( 694000 ACFM)
135.0 ( 275 F)
40.0
99.7
.9
925
-------
EPA UTILITY FGD SL'=VEY: OCTOBER - DECEMBER 1981
PACIFIC POWER I LIGHT: DAVE JOHNSTON 4 (CCNT.)
PERFORMANCE DATA
PESIC3 KC3ULE AVAILABILITY CPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PE=> BOILER FED CAP.
S02 PART. HOL'=S HOJ?S HCtPS FACTOR
4/72 SYSTEM
••» PRCBLEMS/SOLUTIONS/COMMENTS
5IMCS STARTUP IN APRIL 197Z, THE SCRUBBING UNIT HAS EXPERIENCED MAJOR
SCALING PROBLEMS. HARD GYPSUM SCALE ACCUMULATES IN THE SC^U35E
-------
EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1°31
PACIFIC POWER I LIGHT: DAVE JOHNSTON 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER SOILED FC-D CAP.
SOZ PART. HC'JPS HO'JSS HOL-'S FACTC
*« PROBLEMS/SOLUTIONS/COniENTS
THE UTILITY REPORTED THAT NO MAJOR PROBLEMS HERE ENCOUNTERED WITH THE
SCRUBBING OPERATIONS DURING THE OCTOBER THROUGH DECEMBER FESIC3.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION HAS AVAILABLE FOR THE FIRST QUARTER 1981.
-------
EPA UTILITY FGD SURVEY: OCTC3ER - DECEMBER 1981
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
FEuULATORY CLASSIFICATION
PATriC'JLATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
H3X EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - KVI
G5CS5 UNIT GEHE°ATIHG CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY HO/FGD - MW
EQUIVALENT SCRU33EO CAPACITY - MM
*» UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
E'-ILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
POTOMAC ELECTRIC POWER
OICKERSON
DICKERSON
MARYLAND
******
******
******
******
1348
190
183
*****
190
I****** LB/MMBTU)
(**•*»** L3/MMBTU)
(****** LB/MM3TU)
COMBUSTION ENGINEERING
PULVERIZED COAL
******
******** (****»** ACFM)
******* ( **»* p)
213. 1 700 FT)
CONCRETE
******* (***•** 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 - X
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - '/.
RANGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
M ES»
TYPE
*» PARTICLE SCRUBBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
COAL
******
27214. ( 11700 BTU/LB)
******
14.00
******
*******»
6.0-7.0
2.00
******
********
******
COLD SIDE
0/78
VENTUHI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
AISI 1110
NONE
2
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
96.0
100.0
83.6
80.1
87.4
744 622
720 601
744 650
62C
577
650
928
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEM3ER 1931
POTOMAC ELECTRIC POWER: OICKERSON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PE° BOILER FGD CA?.
S02 PART. HOL-SS HCL'SS riO'JSS FACTC"
»* PROSLEMS/SOLUTZOMS/COMMENTS
DURING THIS PERIOD ONLY ONE SCRUBSER RELATED OUTAGE OCCL'PRED. THE CUTAGE
MAS FCR AN ID FAN INSPECTION WHICH LASTED ONE DAY.
1/80 SYSTEM 100.0 100.0 100.0 744 744 744
2/80 SYSTEM 94.3 95.8 94.3 696 665 656
3/80 SYSTEM 100.0 100.0 100.0 744 744 744
*« FROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 ONLY CHE SCRUBBER OUTAGE CCCUSPED. IN
FEBRUARY OUTAGE TIME MAS NECESSARY TO REPAIR A SLURRY RECYCLE LINE LEAK.
4/80 SYSTEM 720
5/30 SYSTEM 744
6/80 SYSTEM 720
»» PROBLEMS/SOLUTIONS/COMMENTS
OICKERSON 1 SCRUBBER DEPENDABILITY FACTORS MERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD. THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
REPORT. THE UTILITY REPORTED THAT THE FGD SYSTEM OPERATED THE ENTISE
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO,SCHU25ER-RELATED
PROBLEMS MERE REPORTED.
7/80 SYSTEM 744
8/80 SYSTEM 744
9/80 SYSTEM 720
*» PRCBLEMS/SOLUTIONS/COKMENTS
THE UTILITY REPORTED HAVING MINIMAL SCRUBBING SYSTEM PROBLEMS CLAIMS THE
JULY-SEPTEMBER PERIOD.
THE BOILER CAPACITY MAS REDUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
lO/SO SYSTEM 744
IT/80 SYSTEM 720
12/80 SYSTEM 744
«« PR03LEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER MAS OPERATED AT A
60X (110 MM) CAPACITY DUE TO A LINING FAILURE IN THE SCRL3BIIIS SYSTEM
PIPING.
1/81 SYSTEM 97.0 88.1 91.9 82.1 744 694 611
*» PROBLEMS/SOLUTIONS/COKMENTS
DURING JANUARY APPROXIMATELY 53 HOURS OF OUTAGE TIKE MAS CAUSED BY PRC3LEKS
WITH THE RECYCLE LINE REDUCER AND THE BLEED LINE SPOOL.
2/81 SYSTEM .0 .0 672 0 0
929
-------
EPA UTILITY FGD SUPVEY: CCT03ER - DECEMBER 1981
POTCMAC ELECTRIC PCWER: DICKEHSCN 1 (COHT.)
PERFORMANCE DATA
PERIC3 MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILE* FGD CAP.
S02 FART. HG'jaS HOU3S HCU=S FACTOR
3/fil SYSTEH .0 .0 7*4 0 0
** FROSLEMS/SOLUTICMS/'COmENTS
DICKERSCN UNITS 1, 2 AND 3 ME=E SHUT COWN SO THAT THE STACK AND THE COMMON
DUCT LEADING TO THE STACK CCULD BE PELIMED WITH PLASITE. UNIT 1 HAS SHUT
DOWN ON JANUARY 31 AND REMAINED DCMN THROUGHOUT FEBRUARY AND MARCH DUE TO
THESE REPAIRS.
930
-------
EPA UTILITY FGD SURVEY: OCTOBER - OECEM2ER 1931
SECTION 14
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUE3ERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOC EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - N3/J
NrT PLANT GENERATING CAPACITY - MM
G^OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATINS CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KM
x» 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/6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - X
RANGE SULFUB CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
*** PARTICLE CONTROL
*» ESP
TYPE
»» PARTICLE SCRUSBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
POTOMAC ELECTRIC POWER
DICKERSON
DICKEHSON
MARYLAND
******
******
******
*»•***»
1348
190
103
******
190
(**»*** LB/MM3TU)
(****** LB/MKSTU)
(****** LB/MM3TU)
COMBUSTION ENGINEERING
PULVERIZED COAL
******
******** (******* ACFM)
******* (<•«** F )
213. ( 700 FT)
CONCRETE
******* («**»* FT)
( 11700 BTU/LB)
******
COAL
**»**•
27214.
14.00
********
6.0-7.0
2.00
******
******<(*
******
COLO SIDE
0/78
VENTURI TOMER
VARIABLE-THROAT/TOP-ENTRY PLUMB BC3
N/A
CARBON STEEL
AISI 1110
NONE
Z
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FED CAP.
S02 PART. HOURS HOUPS HOU3S FACTOR
10/79 SYSTEM
11/79 SYSTEM
12/79 SYSTEM
100.0
96.4
100.0
97.0
88.9
100.0
744 722
720 664
744 744
722
640
744
931
-------
EPA UTILITY FGO SURVEY: CCTC3ER - DECEMBER 1981
POTOMAC ELECTRIC FOVJER: DICKEPSON 2 (CONT. )
PERFORMANCE DATA
PEHIC3 K03ULE A"AILABILITY OPERABILITY RELIABILITY UTILIZATION X FEMOVAL PER BOILES FC-3 CAP.
S32 PART. HOUPS HOURS HCL^S FACTOR
** PRGBLEMS/SOLUTICNS/COMMEHTS
A CHE DAY OUTAGE OCCURRED. DUE TO A FAN LIMING PROBLEM. NO OTHER
SCSUB3ER UNIT PROBLEMS HERE ENCOUNTERED DURING THE PERIOD.
1/60 SYSTEM 95.* 96.* 95.* 7** 736 710
** PROBLEMS/SOLUTICNS/COMMENTS
IN JANUARY THE SCRUBBER HAS DOWN FOR THREE HOURS TO REPAIR A SLURRY
RECYCLE LINE LEAK.
31 HOURS OF THE OUTAGE TIME IN JANUARY HAS 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 74* 7** 721
«» PROBLEMS/SOLUTIOKS/CCMMEHTS
IN MARCH THE SCRUBBER MAS DOWN FOR A SCRUBBER LINING WARRANTY INSPECTION.
NO REPAIR UCRK MAS NECESSARY.
4/80 SYSTEM 720
5/80 SYSTEM 7**
6/80 SYSTEM 720
*» PROBLEMS/SOLUTIONS/CCMMENTS
DICKEPSON 2 SCRUBBER DEPENDABILITY FACTORS WERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD. THESE FIGURES SHOULD BE AVAILABLE BY THE THIRD QUARTER
REFCST. THE UTILITY REPORTED THAT THE FGO SYSTEM OPERATED THE ENTIRE
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY. NO SCRUBBER-RELATED
PROBLEMS MERE REPORTED.
7/80 SYSTEM 7**
8/80 SYSTEM 7**
9/80 SYSTEM 720
»» PROBLEMS/SOLUTIOHS/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 MAS PEOUCED DURING PART OF THE PERIOD DUE TO A LINING
FAILURE IN THE SCRUBBING SYSTEM PIPING.
10/80 SYSTEM 7**
11/80 SYSTEM 720
12/80 SYSTEM 7**
932
-------
fA. UTILITY FG3 SURVEY: OCTOBER - DECEMBER 1931
POTOMAC ELECTRIC POUEP: OICKERSOH 2 CCONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL FES BOILER FG3 CAP.
SOS PART. HOL'-S KC'J'S KC'J?S FACTC3
•» PR03LEMS/50LUTIONS/COKMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE EOILER MAS OPERATED AT A
60X (110 MM) CAPACITY DUE TO A LINING FAILURE IN THE SC3U3BIN3 SI STEM
PIPING.
1/81 SYSTEM 96.9 92.6 100.0 61.9 744 654 607
2/81 SYSTEM .0 .0 672 0 0
3/81 SYSTEM .0 .0 744 0 0
** PRC3LEMS/SOLUTIONS/CCMMENTS
DICKERSOM UNITS 1. 2 AND 3 HERE SHUT OOV1N SO THAT THE STACK At.'D THE CCM::CN
DUCT LEADING TO THE STACK COULD BE RE LIKED WITH PLASITE. UNIT Z WAS SHUT
DOWN ON JANUARY 31 AND REMAINED DCMN THROUGHOUT FESRUARY AND MARCH DUE TO
THESE REPAIRS.
933
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PAPTICLE SCFU5BERS
COMPANY HAKE
PLANT NAr=
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATICN - NG/J
NOX EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MM
G'OSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGO - MW
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SEPVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.tt/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.
RAUSE ASH CONTENT - 7.
AVERAGE MOISTUPE CONTENT - X
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
PANGE SULFUR CONTENT - 7.
AVEPAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
POTOMAC ELECTRIC POWER
DICKERSON
DICKERSON
MARYLAND
******
***•«**
688.
******
543
190
178
182
95
(*»**»* LB/MM3TU)
( 1.600 LB/KM3TU)
(****** LS/KM3TU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
278.42 ( 590000 ACFM)
126.1 ( £59 F)
213. ( 700 FT)
CONCRETE
******* (***** FT)
COAL
BITUMINOUS
27214.
14.00
******
********
6.0-7.0
2.00
******
********
******
( 11700 BTU/LB)
**» PARTICLE CONTROL
v* MECHANICAL COLLECTOR
HUKSER
TYPE
»* FABRIC FILTER
NUMBER
TYPE
t* PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
INLET GAS FLC'rl RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
ENERGY CONSUMPTION - 7.
0
NONE
0
NONE
1
9/75
VENTURI TOWER
VARIABLE-THROAT/TCP-ENTRY PLUM3 BOB
N/A
GE ENVIRONMENTAL SERVICES
CARBON STEEL
AISI 1110
FIBER-REINFORCED POLYESTER
NONE
2.7 CO.O GAL/1000ACF)
2.7 (11.0 IN-H20)
139.2 ( 295000 ACFM)
126.1 ( 259 F)
99.0
2.1
934
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEK2EH 19S1
POTOMAC ELECTRIC FCWER: OICKERSCN 3 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PE<3 BOILER FGD CAP.
S02 PAPT. HOL'PS HCU=S HO'.PS FAC"R
9/73 SYSTEM 720
10/73 SYSTEM 744
11/73 SYSTEM 720
12/73 SYSTEM 7**
1/74 SYSTEM 7**
** PRCBLEMS/SOLUTIONS/COMMENTS
PROBLEMS DURING THIS PERIOD RANGED FROM CCRRCSICN LEAKS IN EXPANSION JOINTS
TO PROBLEMS IN MATERIAL HANDLING EQUIPMENT, FEEDIN3 AND SLAKING CF r.SQ,
PLL'GSiriS IN THE MGO MIX TAW AND SUCTION LINES TO THE MGO MAKE-UP PUKFS.
2/7* SYSTEM 672
3/74 SYSTEM 744
4/74 SYSTEM 720
4/74 SYSTEM 720
*» PHOBLEMS/SOLUTIONS/COMMENTS
MAINTENANCE AND MODIFICATIONS MERE PERFORMED ON THE SYSTEM. THE MAJOR
SYSTEM REVISION MADE DURING THIS PERIOD MAS THE ADDITION CF A FRE-HIX TANK
IN THE MSO SYSTEM.
5/74 SYSTEM 744
6/74 SYSTEM 720
7/74 SYSTEM 744
«» PROBLEMS/SOLUTIONS/COMMENTS
LIMITED OPERATION OCCURRED BECAUSE THE UTILITY DID NOT HAVE ACCESS TO THE
EPA CALCINING FACILITY AT THE ESSEX CHEMICAL COMPANY SULFURIC ACID PLANT.
BY THE END OF JUNE 1974. ALL THE MGO AT DICKERSCN HAD BEEN USED AND A SILO
PLUS THREE CARS MERE FULL OF MGS03.
8/74 SYSTEM 744 87
9/74 SYSTEM 720
10/74 SYSTEM 744
2,
11/74 SYSTEM 720
12/74 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THIS PERIOD THE SYSTEM GENERALLY OPERATED AT 75 PERCENT CF THE
DESIGN GAS FLOW.
1/75 SYSTEM 744
935
-------
EPA UTILITY FGO SURVEY: CCT03ER - DECEMBER 1981
POTOMAC ELECTRIC POWER: OICKERSCN 3 (CONT. )
PERFORMANCE DATA
PEPIC3 MC2ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HQ-3S FACTCR
** PROBLEMS/SOLLTICNS/COMMENTS
PPCBLEMS DEVELOPED IN THE BUCKET ELEVATOR TRANSPORTING THE MGSC3 FROM THE
CRYER TO THE STORAGE SILO.
2/75 SYSTEM 672
3/75 SYSTEM 7*4
4/75 SYSTEM 720
5/75 SYSTEM 744
6/75 SYSTEM 7CO
7/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMEHTS
UNIT NO. 3 WAS TAKEN OUT OF SERVICE FOR AN 8 TO 12 KEEK TUPBINE OVERHAUL.
THE SCRUBSER MAS INSPECTED, MAINTENANCE AND MODIFICATIONS WERE MADE.
8/75 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMKENTS
THE FGD SYSTEM CONSISTS OF A SINGLE, TWO-STAGE SCRUSSER/ABSC33ER, WHICH
INCORPORATES AN ADJUSTABLE-THROAT VENTURI SCRUBBER FOS.-JARTICULATE PE*!CVAL
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 MCCE.
UNTIL MID-1975 THE MAGNESIUM SULF1TE GENERATED WAS TRANSFERRED TO AN EPA
FINANCED FACILITY AT THE ESSEX CHEMICAL CCMPANY SULFURIC ACID MANUFACTURING
PLANT IN RUMFORD, RHODE ISLAND WHERE MAGNESIUM OXIDE WAS REGENERATED AMD
SC2 FROM THE REGENERATION PROCESS WAS CONVERTED TO SULFURIC ACID. THE
RUMFCRO FACILITY HAS SINCE BEEN CLOSED DOW).
CONSTRUCTION MAS 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, FC3
APPROXIMATELY 87 HOURS.
FGD UNIT OUTAGES WERE CAUSED PRIMARILY BY PIPE AMD PUMP CORROSION AND
MAJOR TURBINE OVERHAUL OF THE BOILER. PARTICULATE AND S02 REMQVA.
EFFICIENCY GUARANTEES WERE CORROBORATED CURING OPERATIONAL PHASES.
THE FGD SYSTEM MAS RESTARTED IN AUGUST. STEAM WAS LOST TO THE KGO MIX
TANK, RESULTING IN A VERY MOIST PRODUCT FROM THE CENTRIFUGE. CAKIN3 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 PRECIPITATCR. 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
936
-------
EPA UTILITY FGD SURVEY: C"C3ER - DECSr2i" 1"31
PCTCMAC ELECTRIC POWER: OICKERSCN 3 (CONT.)
PERFORMANCE DATA
PE3ICD K30ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REnC-AL FE3 EOIL:= FGO CAP.
S02 PAi«T. KCL'-S HC'J=S HC'-'S FAC7C3
2/76 SYSTEM 6«6
3/76 SYSTEM 744
4/76 SYSTEM 710
5/76 SYSTEM 744
6/76 SYSTEM 720
7/76 SYSTEM 744
fl/76 SYSTEM 744
9/76 SYSTEM 7£0
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
*» PROBLEMS/SOLUTIONS/COKHENTS
THERE HAVE BEEN MANY MAINTENANCE PROBLEMS AND PROBLEMS WITH LINER FAILURES.
SINCE SHIFTING FROM S02 TO PARTICULATE SCRUs3I!.'S ONLY, PLUESIK3 PRCSLE'IS
HAVE NOT OCCURRED. LCU PH HAS CAUSED CCFKOSICN WHICH WAS AG:-3.V/ATE3 BY
PARTICULATE ERROSION. THE UTILITY MILL FRC2ABLY FELINE WITH A FLAKc GLASS
TYPE LINER. NO CHEMICALS (E.G. LIME I ARE ACDEO TO THE CIRCULATIN5 LI31C3
FOR PH BALANCE.
OUTAGE TIME MAS CAUSED BY LEAK REPAIRS IN SLURRY PIPING.
3/78 SYSTEM 21.0 22.0 21.0 744 717 156
937
-------
EPA UTILITY FED SLAVEY: CCTOSER - DECEMBER 1961
FQTCMAC ELECTRIC FO'^E?: DICKEFSON 3 tCONT.)
PERFORMANCE DATA
FE"?IC3 MC^.ljLEl A/AIU3ILITY OFERABILITY RELIABILITY UTILIZATION X REMOVAL PER 20ILER FGO :A?.
502 PART. HCUSS HOURS HOU.
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
POTOMAC ELECTRIC POWER: OICKERSON 3 (CONT.)
PERFORMANCE DATA - -
FERICO MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HO'JSS KCU?S HC'JSS FAC7C3
UNIT REMAINS IN COMPLIANCE.
THERE HAVE BEEN HO 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 7*4
8/79 SYSTEM 744
9/79 SYSTEM 7£0
10/79 SYSTEM 98.6 95.* 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
*» FROBLEMS/SOLUTION5/COMMENTS
IN NOVEMBER, 8 HOURS OUTAGE TIME MAS REQUIRED TO REPAIR A LEAK IN A
RECYCLE LINE.
12/79 SYSTEM 96.1 93.5 74* 72* 696
»* PROBLEMS/SOLUTICNS/COMMENTS
AN OUTAGE FOR GENERAL INSPECTION TOOK PLACE DURING DECEMBER.
1/80 SYSTEM 78.7 88.2 78.7 7** 66* 506
** PROBLEMS/SOLUTIOHS/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 7** 7** 744
»* PROBLEMS/SOLUTIONS/COMMENTS
DURING FEBRUARY AND MARCH THE SCRUBBER OPERATED WITH NO MAJOR Pr~3LEMS.
4/80 SYSTEM 720
5/80 SYSTEM 744
6/80 SYSTEM 720
*« PROBLEMS/SOLUTIONS/COKMENTS
THE UNIT 3 SCRUBBER EXPERIENCED SOME DOWN TIME DURING THE APRIL-JUNE PERIOD
AS A RESULT OF THE CONTINUING DETERIORATION OF THE SCRU3SER 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
939
-------
EFA UTILITY FGD SURVEY: OCTC3EH - DECEMBER 1981
FOTCMAC ELECTRIC POWER: DICKEKSCN 3 (CONT.)
PERFORMANCE DATA
PERIOD MC3ULE AVAILABILITY OFERA8ILITY RELIABILITY UTILIZATION 7. REMOVAL PER EOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
«* FHC3LEMS/SOLUTICHS/COHMENTS
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 BOI1 ER CAPACITY MAS REDUCED TO 1/2 LOAD DURING PART OF THE PERIOD DUE
TO THE -ECESSABY PATCHIH3 OF THE SCKU23ER LINING. THE UTILITY IS PRESENTLY
STUDYING THE POSSIBILITY OF REPLACING THE FLAKEGLASS LINER WITH A P.UESiR
LINER.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
** PROBLEMS/SOLUTIOMS/COKMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD THE BOILER WAS OPERATED AT A
60X (110 MM) CAPACITY DUE TO A LINING FAILURE IN THE SCRUBBING SYSTEM -
PIPING.
UNIT 3 MILL BE SHUTDOWN ON FEBRUARY 2, 1981 TO REPLACE THE FLAKEGLASS
LINING.
1/81 SYSTEM 96.8 96.9 97.5 94.2 744 723 701
2/81 SYSTEM .0 .0 672 0 0
3/81 SYSTEM .0 .0 744 0 0
*» FROBLEnS/SCLUTIONS/COMMENTS
DICKERSCN UNITS 1. Z AND 3 WERE SHUT DOWN SO THAT THE STACK AND THE CCKKGN
DUCT LEADING TO THE STACK CCULO BE RELINED KITH PLASITE. UNIT 3 HAS SHUT
DOWN ON JANUARY 30 AND REMAINED DOWN THROUGHOUT FEBRUARY AND MARCH DUE TO
THESE REPAIRS.
940
-------
EPA UTILITY FGD SURVEY: OCTCSER - DECEMBER 1931
SECTION 14
DESIGN AND PERFOPMANCE DATA FOR OPERATIONAL PARTICLE SC3U2BEPS
COMP4NY NAHE
FLAHT NAME
UNIT NUMBER
CITY
STATE
RE3ULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - HG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
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
** 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.
** 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 - X
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
j*** PARTICLE CONTROL
*» MECHANICAL COLLECTOR
NUMBER
«* FABRIC FILTER
NUMBER
TYPE
i« ESP
NUMBER
*» PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
( .100 L3/T.M3TU)
I****** LB/r.M3TU)
(»***** LB/Mr,3TU)
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
B
43.
******
******
*****
112
109
*****
112
******
PULVERIZED COAL
******
245.39
148.9
******
******
*******
( 520000 ACFM)
( 300 F)
f***« FT)
(**«*« FT)
COAL
SU33ITUMINOUS
23725.
9.30
******
13.70
.95
0.6-1.0
.01
******
COAL
BITUMINOUS
23493.
12.50
11.20
******
.65
******
.01
( 10200 BTU/LB)
******
( 10100 BTU/LB)
******
0
NONE
1
9/73
PACKED TOMER
941
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
FU3LIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
SPECIFIC TYPE
T'ADE NAME/CCmON NAME
£UPDLIER
r.ELL GHfJEHIC MATEPIAL
SrtELL SrEC:c:C MATERIAL
LINE? GEkl=-5IC MATEPIAL
LIHcR SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NL'IiEER OF CONTACTING ZONES
L/G FATIO - LITER/CU.M
FH CONTROL ADDITIVE
PRESSURE CPO? - KPA
SUPERFICIAL GAS VELOCITY - M/S
IliLET GAS FLOU RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 PEMOVAL EFFICENCY - 7.
PARTICLE REMOVAL EFFICIENCY - X
MOBILE BED PACKING
TUFBULEHT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL
3
7.5 (56.0 GAL/1000ACF)
ALKALINE FLYASH
3.0 (13.0 IN-H20)
3.* ( 11.0 FT/S)
245.4 ( 520000 ACFM)
151.7 ( 305 F)
30.0
93.0
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OFERAS1LITY RELIABILITY UTILIZATION
7, REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HCUPS HOURS FACTOR
9/77 SYSTEM
»* PROBLEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN SEPTEMBER 1977 SCALING AND PLUGGING AT THE UET/ORY ZONE,
CN THE FIRST STAGE 6PIDS, AND IN THE REHEATERS HAVE BEEN THE MOST P°OMINENT
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 HEAR AND PERI03IC 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 III THE
RECIRCULATING PUMPS.
10/79 SYSTEM 744
11/79 SYSTEM 720
12/79 SYSTEM 744
*« PR03LEMS/SOLUTIONS/COMMENTS
DURING THE FOURTH QUARTER REHEATER FAILURES OCCURRED.
LEAKAGE IN THE INLINE STEAM TUBES HAS BEEN ENCOUNTERED. CORROSION
IS KNOWN TO OCCUR AFTER LEAKS ARE EXPERIENCED.
THE PRIMARY PROBLEM WITH THE SYSTEM IS THE INABILITY TO ISOLATE MODULES.
IF A PROBLEM OCCURS NO MODULE MAINTENANCE CAM BE PERFORMED UNLESS THE
UNIT LOAD IS CUT BACK OR THE UNIT IS SHUT DOWN.
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTEM
744
696
744
*« PROBLEMS/SOLUTIONS/COMMENTS
THE MOCULE ISOLATION PROBLEMS CONTINUED THROUGH THE FIRST QUARTER OF 1930.
USE OF THE CARBON STEEL DAMPERS HAS BEEN ABANDONED. THE PFOG3AM FOR RE-
PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY. THE UNIT IS SHUTDOWN
WHEN MAJOR SCRUBBER PROBLEMS OCCUR.
942
-------
EPA UTILITY F6D SUBVEY: ;7C3EH - DECREES •-'531
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER EOILER FG3 CAP.
S02 PART. HCL'HS HOU=S hOL'f-S FACTOR
REHEATER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS. THE SIX STEAM COI'.S
ON THIS IN-LINE REHEAT SYSTEM, TWO OF WHICH ARE 516S3 AND FCL1? OF WHICH
AFE CARBON STEEL, ARE EXPERIENCING CCHROSICN PROBLEMS. A S3LUTICN 70 THE
PROBLEM HAS NOT YET BEEN DETERMINED.
IN FEBRUARY THE UTILITY REPLACED THE SCRUBBER BALLS AND GRIDS. THE CLD
BALLS WERE REPLACED WITH THE NEW HOLLOW HAPD PLASTIC-WALLED BALLS WITH
NOTCHED SEAMS. THE GRIDS UEPE ORIGINALLY 316L SS, CERAMIC, POLYrFCPYLiNE,
AND RUBBER LINED CARBOH STEEL, BUT HAVE BEEN REPLACED WITH 317L SS GRIDS.
THE SCRU3BERS OPERATED CONTINUOUSLY THROUGHOUT THE QUARTER EXCEPT FOR THE
BALL AND GRID REPLACEMENT DOWNTIME.
4/80 SYSTEM 100.0 100.0 720 720 7CO
5/80 SYSTEM 100.0 100.0 744 744 744
6/60 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 MILL EE ENTIRELY REPLACED WITH NEW 316L SS
BUNDLES DURING THE NEXT SCHEDULED OUTAGE IN NOVEMBER AND DECEMBER. OURINS
THE SECOND QUARTER MORE TUBES WERE BLANKED OFF AFTER STcAM LEAKS OCCUPIED.
TO DATE ROUGHLY SOX OF THE TUBES ARE SEALED OFF AMD ARE OUT OF SERVICE
BECAUSE OF LEAKS THAT OCCURRED OVER THE PAST MONTHS.
7/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
9/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
«» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND SCRUBBERS OPERATED ACCEPTABLY DURING THE JULY-SEPTEMBER PER-
IOD. NO PLANS HAVE BEEN MADE TO REPAIR THE ISOLATION OAf.PEPS. THE FAULTY
REHEATER TUBES MILL BE REPLACED DURING THE SCHEDULED CUTAGE 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 1981.
NO MAJOR SCRUSSER RELATED PROBLEMS HERE ENCOUNTERED, EXCEPT THE REPLACE-
MENT OF THE DISCHARGE VALVE ON THE RECIRCULATION PUMP.
1/81 SYSTEM 744
2/81 SYSTEM 672
943
-------
E°A UTILITY FGD SUPVEY: CCTC9ER - DECEMBER 1981
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4 (CCNT.)
PERFORMANCE DATA
PEHICD MODULE AVAILABILITY OPERA3ILITY RELIABILITY UTILIZATION 7. REMOVAL FE= EOILE5 FC-D CAP.
S02 PART. HCL'SS HOL'SS HC'uSS FAC7C3
3/fll SYSTEM 744
«* PROBLEHS/50LUTIONS/COMMENTS
DURING THE SCHEDULED FOL"? WEEK OUTAGE STARTING JANUAPY 30 AND ENDING FEc=U-
ARY 24, TWO NEW A-SIDE REHEATER BUNDLES MERE INSTALLED. THE UNIT WAS THEN
RESTARTED.
THE UNIT HOWEVER HAD TO BE SHUT DOWN ON FEBRUARY £4 ONLY AFTEP OPERATING 3
HOURS DUE TO OPERATOR ERROR. THE SCOSTER FAN MAS RESTARTED UIThC'JT ITS OIL
BEARING CCOLINS SYSTEM. CONSEQUENTLY, THE FAN BEARINGS WERE DAMAGE WO THE
BOOSTER FAN HAD TO BE SHUT DO^'N. THE UTILITY HAS SINCE REPAIRED THH FAN
SHAFT BUT STILL AWAITS FCR THE REPAIRED FAN BEARINGS BEFORE T.HE UNIT CAN 3E
RESTARTED.
944
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 14
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCSU53ERS
COMPANY NAME
PLANT NAME
UNIT NUK3ER
CITY
STATE
PEGULATCRY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SQ2 EMISSION LIMITATION - HG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GKCSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY KO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MU
PUBLIC SERVICE
CHEROKEE
1
DENVER
COLORADO
B
43.
******
*«»»»»
710
115
100
105
102
OF COLORADO
( .100 LB/MMSTU)
( ***»ii* LB/MM3TU )
(»»««*« LB/MM3TU)
** 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 - ft
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 - X
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
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
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
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOU RATE - CU.M/S
BABCOCK ft UILCCX
PULVERIZED COAL
******
245.39
146.1
******
******
*******
COAL
BITUMINOUS
23493.
12.50
9.4-12.5
11.30
******
.65
******
.01
******
( 520000 ACFM)
( 295 F)
(**** FT)
(***** FT)
C 10100 BTU/LB)
******
0
NONE
1
6/73
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION. UOP
CARBON STEEL
AISI 1110
CPGANIC
RU3BER
STAINLESS STEEL
3
7.5 (56.0 GAL/1000ACF)
ALKALINE FLYASH
3.2 (13.0 IN-H20)
3.4 (
164.4
11.0 FT/S)
I 346400 ACFM)
945
-------
cPA UTILITY FC-D SURVEY: CCT03ER - DECEMBER 1901
PUBLIC SERVICE OF COLCRACQ: CHEPCKEE 1 (CONT.)
INLET GAS TEnFEDAT'J^E - C 146.1 t 295 f)
sea REro/AL EFFICE»;:Y - x I6.o
PARTICLE REMOVAL EFFICIENCY - X 97.0
E.'iiKGY CONSUMPTION - V. 4.3
PERFORMANCE DATA
PERIOD M03ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X PEK3VAL PER BOILER FGO CAP.
S02 PART. HOURS HOPS HOL'RS FACTOR
6/73 SYSTEM
»» PROBLEMS/SOLUTICHS/COMMENTS
SINCE STARTUP IN JUNE 1973 SCALING AND PLUGGING AT THE MET/DRY ZONE,
ON THE FIRST STAGE GRIDS. AI.'O IN THE REHEATERS HAVE BEEN THE MOST PROMINENT
FR03LEM AREAS CHARACTERIZED BY THIS SYSTEM. VARIOUS CHEMICAL AC3ITIVES
HAVE BEEN TESTED FOR CONTROL OF SCALING. INCLUDING PH03FHATEO ESTEPS. BUT
WITHOUT SIGNIFICANT IMPROVEMENT. SLOWDOWN IS MAINTAINED AT A HICH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FOR TESTING FUSFOSES NO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCLT.ULATICN.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF TH5
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
FLY ASH.
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 HILL BE REPAIRED TEMPORARILY WITH A SPRAY OS
FIBERGLASS-LIKE MATERIAL.
1/80 SYSTEM 100.0 100.0 744 744 744
2/80 SYSTEM 100.0 100.0 696 696 696
3/80 SYSTEM 100.0 100.0 744 744 744
t* FRC3LEMS/SOLUTICNS/COMMENTS
THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE FIRST QUARTER OF 1980.
THE ISOLATION DAMPERS HAVE NOT CAUSED ANY PROBLEMS BECAUSE MODULE
ISOLATION HAS NOT REQUIRED DURING THE PERIOD.
THE FANS ARE STILL EXPERIENCING EROSION PROBLEMS.
IN MARCH A BOILER/SCRUBBER OVERHAUL BEGAN. DURING THIS TIME THE CARBON
STEEL ISOLATION DAMPERS WILL BE REPLACED WITH 316 SS. THE HEM FANS
WILL BE INSTALLED IN THE OLD HOUSINGS. THE NSM HIGH STRENGTH CiRBCN STEEL
FANS MILL BE EQUIPPED WITH REPLACABLE CHROMIUM ALLOY WEAR PLATE BLADE
TIPS.
4/80 SYSTEM 720
5/80 SYSTEM 744
946
-------
EPA UTILITY FGO SURVEY: OCTOBER - CECEK3EH 1531
PUBLIC SERVICE OF COLCRADQ: CHEROKEE 1 (COHT.)
PERFCRHAHCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL Pet BOILES FG3 CAP.
S02 PART. HOUPS HO'JSS hQ'JFS F4.C7CT
6/80 SYSTEM 7£0
*» PRC3LEMS/SOLUTICNS/COMMENTS
THE IB ID FAN MAS SEVERELY ERRODED. THE FAN MAS RE2UILT DURING THE OUTAGE.
THE OLD CARBON STEEL ISOLATION DAMPERS HERE REPLACED WITH 316 S3 DAKFESS
DURING THE CONTINUING MAY-JULY OUTAGE.
7/80 SYSTEM 744
9/80 SYSTEM 744
9/80 SYSTEM 7ZO
«* PROBLEMS/SOLUTIONS/COMMENTS
SHAFT BEARING FAILURES ON THE RECIRCULATION PUMP CAUSED SCRUBBER SYSTEM
PROBLEMS THROUGHOUT THE JULY-SEPTEMBER PERIOD.
10X80 SYSTEM 744
11/80 SYSTEM 7EO
12/80 SYSTEM 744
*» PHOBLEMS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED NO MAJOR PROBLEMS WERE ENCOUNTERED DURING THE OCTCSER
THROUGH DECEMBER PERIOD. HOWEVER, SHAFT BEARING REPAIRS WERE MADE TO THE
RECIRCULATION PUMPS.
1/81 SYSTEM 744
o* PHOBLEHS/SOLUTIONS/COMMENTS
DURING THE MONTH OF JANUARY THE UNIT HAS SHUT DOWN FCR THE ENTIRE MCMTH FC3
A GENERAL SCRUBBER OVERHAUL. THE OVERHAUL INCLUDED THE REPLACEMENT OF THE
SCRUBBER BALLS AND REPAIR WORK TO THE SCRUBBER BALL PARTITIONS.
2/81 SYSTEM 672
** PHOBLEMS/SOLUTIONS/COMMENTS
UTILITY REPORTED THAT NO SCRUBBER RELATED PROBLEMS OCCURRED DURING THE
MONTH OF FEBRUARY.
3/61 SYSTEM 744
»* FROBLEMS/SOLUTIONS/COMMENTS
DURING PART OF MARCH THE UNIT HAS FORCED TO SHUT DOWN DUE TO A FROZEN
GUILLOTINE INLET DAMPER.
947
-------
EPA UTILIT' FGD SURVEY: CCTCBER - DECEMBER 1981
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCEU3BE=S
CCMPANY NAME
PUNT HAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PART:CULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GP3SS UNIT GENERATING CAPACITY - KM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY MO/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
RANSE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - Y.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - X
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
NUM3ER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
HUrSER OF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PH CONTROL ADDITIVE
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - M/S
S02 REMOVAL EFFICEHCY - 7.
I .100 LB/MMBTU)
(*»**** LB/MM3TJ)
(«»«**» LB/MM3TU)
PUBLIC SERVICE OF COLORADO
CHEROKEE
4
DENVER
COLORADO
B
43.
******
******
710
375
350
375
356
COMBUSTION ENGINEERING
PULVERIZED COAL
******
717.29 (1520000 ACFM)
135.0 ( C75 F)
****** (**** FT)
******
******* (***** FT)
COAL
BITUMINOUS
23493.
12.50
9.4-12.5
11.30
******
.65
******
.01
******
( 10100 BTU/LB)
******
0
NONE
4
7/74
PACKED TOMER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL
3
7.5 (56.0 GAL/1000ACF)
ALKALINE FLYASH
3.2 (13.0 IN-H20)
3.4 ( 11.0 FT/S)
16.0
948
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEASES 1931
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 (COMT.)
PARTICLE REMOVAL EFFICIENCY - 7. 97.0
ENERGY CONSUMPTION - X 6.7
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 FART. HCUSS HOURS HC'JPS FAC7CH
7/74 SYSTEM
** PR08LEMS/SOLUTIONS/COMMENTS
SINCE STARTUP IN JULY 1974 SCALING AND PLUGGING AT THE HET/CPY ZCNE.
Otl THE FIRST STAGE GRIDS, AI.'D 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 FKCSPHATEO ESTERS, BUT
WITHOUT SIGNIFICANT IMPROVEMENT. BLCWDCUN IS MAINTAINED AT A HIGH LEVEL
TO CHECK THE BUILDUP OF SALTS BUT, OTHER THAN FCR TESTING ?U=POSES KO
CHEMICAL CONTROL METHOD HAS BEEN USED TO CONTROL SCALE ACCUr.JLATICN.
OTHER OPERATING EXPERIENCES INCLUDE WEAR AND PERIODIC REPLACEMENT OF THE
MOBILE BALLS, EROSION OF LINING AND COPROSIVE FAILURE OF REriEATERS. 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
FLY ASH.
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 MILL BE REPAIRED TEMPORARILY WITH A SPRAY ON
FIBERGLASS LIKE MATERIAL.
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
»» 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 ERCSICH/
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 SYS'EM 744
6/80 SYSTEM 720
949
-------
EPA UTILITY FGD SURVEY: CCTC3ER - DECEMBER 1981
PUBLIC SERVICE OF COLORADO: CHEROKEE 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS KCL'PS HCL'S FACTCS
** FROBLEMS/SOLUTICNS/CCMMENTS
THE NEVI FANS DESCRIBED DUPING THE LAST REPORT PERIOD UE°E INSTALLED IN CUE
OF THE FOUR MODULES. NEW FANS MILL BE INSTALLED IN THE OTHER THREE MODULES
DURING A SCHEDULED LATE SEPTEMBER OUTAGE UNLESS THE UTILITY HAS AN OPPOR-
TUNITY TO MAKE THE REPLACEMENTS SOONER.
7/80 SYSTEM 744
«<* PROBLEMS/SOLUTIONS/COMMENTS
THE SCRUBBER RETURNED TO SERVICE IN MID JULY AFTER A TWO MEEK OUTAGE.
DURING THIS TIME. THE FIBERGLASS INSIDE THE OUCTVJC°K WAS REPLACED, AH3 A
VERTICAL GRID MAS INSTALLED ON THE SECOND LEVEL OF THE M03ILE BED TOWER TO
IMPROVE SYSTEM PERFORMANCE.
8/80 SYSTEM 744
9/80 SYSTEM 720
»» PROBLEMS/SOLUTICNS/CCMMENTS
THE BOILER AND FGD SYSTEM WENT DOWN ON SEPTEMBER 15, 1980 FCR A SCHEDULED
OVERHAUL. DURING THIS TIME, FANS MERE INSTALLED ON MODULES A, C, AND D.
THE UTILITY IS CURRENTLY EVALUATING THE VERTICAL GRID OH THE SECOND LAYER.
IF THE GRID IMPROVES SYSTEM PERFORMANCE, THEY MILL INSTALL ANOTHER ONE
ON THE THIRD LEVEL.
10/80 SYSTEM 744
11/80 SYSTEM 7CO
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 MERE INSTALLED ON THE SCRUBBER BED. THIS
MAS INTENDED TO SOLVE THE PROBLEM OF KEEPING THE SCRUBBER BALLS FRCM MOVING
HORIZONTALLY, RESULTING IN PILES OF SCP.U3BER BALLS IN LOCALIZED AREAS, BUT
CCRPOSION AND SYSTEM PERFORMANCE DID NOT IMPROVE.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
*» PH08LEMS/SOLUTIONS/COMMENTS
THROUGHOUT THE JANUARY-MARCH PERIOD THE UTILITY INTERMITTENTLY SHUT DOWN
THE SCRUBBER MODULES (ONE MCDULE AT A TIME) TO REPLACE SCRUBBER BALLS AND
REPAIR SCRUBBER BALL PARTITIONS.
THE UTILITY REPORTED EXPERIENCING CORROSION PROBLEMS WITH THE FOUR SCRUBBER
BOOSTER FANS.
950
-------
EPA UTILITY FG3 SURVEY: CCTC3E3 - DECEPSER 1=31
SECTION 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCSU33EPS
COMPANY NAME
PUNT NAME
UNIT NUKSEH
CITY
STATE
PEGULATOHY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOC EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GTCSS UNIT GENERATING CAPACITY - KM
NET UNIT GENERATING CAPACITY M/FGO - MM
NET UNIT GENERATING CAPACITY MO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
SOILER 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 - fl
*« FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANSE 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 - X
»»» PARTICLE CONTROL
»» MECHANICAL COLLECTOR
NUMBER
INLET FLUE GAS CAPACITY - CU.M/S
»» FABRIC FILTER
NUMBER
TYPE
«» ESP
NUMBER
TYPE
INLET FLUE GAS CAPACITY - CU.M/S
»» PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
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
PH CONTROL ADDITIVE
.100 L2/rrsTu)
« LS/MMBTU)
I****** LB/MH3TU)
PUBLIC SERVICE OF COLCRASO
VAU10NT
5
VALMONT
COLORADO
E
43.
*»»**»
******
274
166
157
163
166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
436.98 ( 926000 ACFM)
126.7 ( 260 F)
*K»*ft* (»*»* FT)
»»K*tt*
«*«*«** (»«*«* FT)
COAL
SUBBITUMINOUS
25131.
6.00
5.4-7.0
15.00
12.7-13.3
.70
0.6-0.7
«*****«*
***»*»
218.5
0
NONE
COLD SIDE
218.5
( 10800 BTU/LB)
»•«*«**
( 463000 ACFM)
( 463000 ACFM)
2
11/71
PACKED TOMER
MOBILE BED PACKINS
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION, UOP
CARBCN STEEL
AISI 1110
ORGANIC
RU33EP
STAINLESS STEEL
3
7.8 (53.3 GAL/1000ACF)
LIMESTONE/ALKALINE FLYASH
951
-------
EPA UTILITY FGO SURVEY: OCTC3ER - DECEMBER 1981
PUBLIC SERVICE OF COLCPADO: VALMONT 5 (COHT.)
FPESSU=E 0=OP - KPA
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLCU RATE - CU.M/S
INLET GAS 7Er?ERATUPE - C
S02 FEKCVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
ENERGY CCNSUMPTICN - X
3.7
3.4
109.2
132.8
45.0
06.0
3.6
(15.0 IH-U2C)
( 11.0 rT/S)
( 231500 ACFtt)
( C71 F)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY CPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER 30ILER FGD CAP.
S02 PART. KCURS HOURS KO'JPS FACTOR
11/71 SYSTEM
** PROBLEMS/SOLUTIONS/COMMENTS
720
THE FIRST PARTICLE MATTER SCPUBBEH COMMENCED OPERATION IN NOVEMBER 1971.
THE SCPUBBEH MAS ORIGINALLY INSTALLED FCR PARTICLE MATTES REMOVAL SINCE THE
PLANT BURNS LOU SULFUR COAL! HOWEVER, 45X OF THE SO2 IS REMOVED-AS WELL
BECAUSE OF THE ALKALINITY OF THE FLYASH.
DURING THE FIRST YEAR OF OPERATION PRC3LEMS 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 MAS THE MOST PREDOMINANT
CONTINUING MAJOR CAUSE OF DOWNTIME IN THE SCRUBBER. SCALE ACCUMULATION
MAS NOTED ON THE UET-ORY INTERFACE IMMEDIATELY DCMISTREAM OF THE PRESATU-
RATION 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 "PINS
PONG" BALLS TENDED TO KEEP THE SCALE OFF OF THESE SECTIONS. SCALE ALSO
COLLECTED ON THE WALLS OF THE VESSEL AND INTERMITTENTLY SLCUC-HED OFF AND
FELL INTO THE SUMP IN LAPGE PIECES CAUSING BLOCKAGE OF THE RECIRCULATIOM
PUMP SUCTION SCREENS. SCALING OF THE HIST ELIMINATOR ABATED SCMEMHAT WITH
THE INTRODUCTION OF A CLEAR RINSE MATER WASH. SCALE FORMATION IN THE RE-
HEAT SECTION SOMETIMES REQUIRED SUPPLEMENTAL CLEANING OF THE REUEATER IN
ADDITION TO THE CLEANING OBTAINED BY THE USE OF THE SCOT3LOWERS WHICH UEHE
INSTALLED AS A PART OF THE HEHEATER EQUIPMENT. UNDER NORMAL OPERATION,
THE SOOTBLOWERS LOCATED IN THIS REHEAT 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 PEPIOD
OF TIME, THE CALCIUM SULFATE-FLYASH SCALING CONTINUED TO BE A SIGNIFICANT
OPERATING PROBLEM AT THE VALMONT INSTALLATION. Ill ADDITION TO THESE
SCALING RELIABILITY PROBLEMS, A WATER QUALITY CONCERN ALSO SURFACED THAT
MAS A DIRECT RESULT OF THE PARTICLE SCRUBBER OPERATION. THE RELATIVELY
HIGH CAO CONCENTRATION IN THE VALMONT FLYASH RESULTED IN FAIRLY HIGH £02
REMOVAL RATES (45-50 PERCENT) WITHIN THE UNITS. SINCE NO PH CONTROL CAPA-
BILITY FOR EITHER THE RECIRCULATING SLURRY OR THE SYSTEM BLOHOCWN SLURRY
WAS DESIGNED INTO THE SYSTEM, AN iCID CONDITION WAJ CPEATED IN THE SLURRY
AND THE SLOWDOWN STREAM. PH LEVELS OF THE BLCWOOHN 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 STPEAM. THE CALCIUM SULFATE
SCALING PROBLEM WAS THOUGHT TO BE THE PESULT OF A SUPER-SATURATED CALCIUM
SULFATE CONDITION IN THE RECIRCULATING SLURRY. BECAUSE OF THIS IT WAS FELT
THAT CONTINUOUS PH CONTROL OF THE RECIRCULATING SLUSHY, CONVERSION Or 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 FCR
THE ALKALI REAGENT. IN THE FIRST TEST, SIHCE LIMESTONE UTILIZATION WAS A
MAJOR CONCEFM, A SPECIAL EFFORT WAS MADE TO REDUCE THE POTENTIAL FOR THE
SHORT CIRCUITING OF THE ADDED LIMESTONE AND TO PPOVIOE 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 FPCM 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
952
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
PUBLIC SERVICE OF COLOR ADO: VAU10NT 5 (COMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FCD CAP.
SOZ PAPT. HOURS HG'JKS HC'JSS FACTCR
FOR RECYCLE WATER.
2. PHESATUHATION OF THE INCOMING FLUE GAS WITH HECIFCULATIHG SLURRY.
3. INTERMITTENT HIST ELIMINATOR MASH.
4. PROPER SELECTION OF MATERIALS OF CONSTRUCTION TO PROTECT AGAINST
ATTACK CAUSED BY HIGH CHLORIDE CONCENTRATIONS.
THE SCRUBBERS R i D FACILITY MAS NOT EQUIPPED WITH A MECHANICAL THICKENER
FOR CONTROL OF THE SUSPENDED SOLIDS CONCENTRATION OF THE RECIPCULATIN3
SLURRY (ALL PURGED MATERIAL WAS SENT TO THE SLUDGE POND). WITH A SCO PPM
502 CONCENTRATION IN THE FLUE GAS, IT IS EXPECTED THAT THE RECIPCULATIN3
SLURRY SOLIDS COULD BE REALLY CONTROLLED IN THE 5 TO 7 PEPCENT RANGE. DUE
TO THE MIXED FUEL FIRED AT THE UNIT DURING THE TEST FERIC3, HCUEVEP, THE
S02 CONCENTRATIONS EMITTED FROM THE BOILER AND HENCE PRESENT IN THE FLUE
GAS STPEAM VARIED SIGNIFICANTLY AND FINALLY FELL TO SUCH LCVI LEVELS (OFTEN
100-COO PPM) THAT SUSPENDED SOLIDS CONCENTRATIONS IN THE SLURRY CCULD NOT
BE MAINTAINED. IT IS ALMOST CERTAIN THAT A THICKENER, HITH THE SU3SE-
QUENT RETURN OF SOLIDS TO THE SCRU2BEH LIQUOR, COULD HAVE BEEN USED TO
GOOD ADVANTAGE DURING THIS TIME PERIOD. GENERALLY SPEAKING, THE SEVEPE
SCALING CONDITIONS PLAGUING THE TEST MODULE MERE INTENSIFIED DUSIN3 THESE
PERIODS OF LOM INLET S02 CONDITION.
11/74 SYSTEM 720
12/7$ SYSTEM 744
1/75 SYSTEM 744
2/75 SYSTEM 672
3/75 SYSTEM 744
«» PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SCRUBBING SYSTEM HAS OPERATED FOR A TOTAL OF FOUR AND ONE-HALF
MONTHS, FROM MID-OCTOBER 1974 TO MARCH 1975. THE OVERALL RELIABILITY OF
THE SYSTEM MAS APPROXIMATELY 75X.
4/75 SYSTEM 720
5/75 SYSTEM 744
6/75 SYSTEM 720
7/75 SYSTEM 744
8/75 SYSTEM 744
9/75 SYSTEM 720
10/75 SYSTEM 744
11/75 SYSTEM 720
12/75 SYSTEM 744
1/76 SYSTEM 744
2/76 SYSTEM 696
3/76 SYSTEM 744
4/76 SYSTEM 720
5/76 SYSTEM
6/76 SYSTEM 720
953
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
PUBLIC SERVICE OF COLORADO: VALMGNT 5 (CONT.)
PERFORMANCE DATA
PEPIC3 KC3ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PE3 BOILER FGD CAP.
S0£ PART. HOURS HO'JPS HCIPS FACTOR
7/76 SYSTEM 744
8/76 SYSTEM 74*
9/76 SYSTEM 720
10/76 SYSTEM 744
11/76 SYSTEM 730
12/76 SYSTEM 74*
1/77 SYSTEM 744
2/77 SYSTEM 672
3/77 SYSTEM 74*
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
«» PR03LEMS/SOLUTIONS/COMMENTS
THERE HAVE BEEN RECURRING PROBLEMS ASSOCIATED WITH BALL MIGRATION IN THE
BALL COMPARTMENT AS WELL AS HECIRCULATICN FUKP KOTOS BEARING FAILUPE, 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 AMD OUTLET OF THE SCRUBBER.
MORE RECENTLY THERE WAS A PINCH BELT FAILL'PE.
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
** PRCBLEMS/SOLUTIONS/COMMENTS
NO SIGNIFICANT PROBLEMS WERE ENCOUNTERED.
6/78 SYSTEM 720
7/78 SYSTEM 744
954
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
PUBLIC SERVICE OF COLORADO: VALKONT 5 (CONT.)
PERFORMANCE DATA -
PERIOD KCOULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HCUKS HO'JSS HCLPS FACTOR
8/78 SYSTEM 744
** FROBLEMS/SOLUTION5/CCMMENTS
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 MAS 64.42X.
AVERAGE SCRUBBER AVAILABILITY FOR 1978 MAS 66.85;.
AVERAGE SCRUBBER AVAILABILITY FROM JANUARY 1, 1979 THROUGH HAY, 1979 MAS
APPROXIMATELY 80X.
BALL MIGRATION, ALTHOUGH NOT SERIOUS, IS A CHRONIC PROBLEM FOR VALMCNT 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/COKMENTS
DURING THE ANNUAL SHUTDOWN IN SEPTEMBER THE OLD SCRUBBER BALLS MERE
REPLACED WITH A NEM BRAND. DUE TO BALL MOTION THE RU33ER LINER ERCDED.
IN THE MIST ELIMINATOR SECTION EROSION AND CORROSION OCCURRED.
955
-------
EPA UTILITY FGD SUPVEY: OCTOBER - DEC: 1EH 1981
FU3LIC SERVICE OF COLORADO: VALM3MT 5 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/79 SYSTEM 100.0 744
11/79 SYSTEM 92.3 720
12/79 SYSTEM 98.1 744
*» FRCBLEMS/SOLUTIOHS/CCKMENTS
ONE OF THE MAJOR SCRUBBING SYSTEM PROBLEMS IS THE SCRUBBER WALL HEAR WHICH
HAS TO BE PATCHED DURING THE SPRING AND FALL.
HEHEATER 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: 66.6X
1979: 80.5X
1/80 A 98.5
B oa. 5
SYSTEM 98.5 744
2/80 A 84.4
B 94.9
SYSTEM 89.7 696
3/80 A 90.8
B 87.7
SYSTEM 89.0 744 615
** PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980, NO MAJOR PROBLEMS WERE ENCOUNTERED WITH
THE SCRUBBER.
4/80 A 88.1
B 68.1
SYSTEM 88.1 720 716
»« PROBLEMS/SOLUTIOHS/COttMENTS
THE SCRUBBER MAS SHUT DOWN ON APRIL 14 FOR A WEEK TO HAKE REPAIRS TO A HOLE
IN THE SCRUBBER RUBBER LINING, RECYCLE PUMP LININGS AND A STEAM REGULATOR
ON ONE OF THE REHEATERS.
5/80 A 96.8
B 100.0
SYSTEM 98.4 744 744
»» PROBLEMS/SOLUTIONS/COHMENTS
NO PROBLEMS WERE REPORTED FOR MAY.
6/80 A 8.0
B 8.0
SYSTEM 8.0 720 720
*» PRCBLEMS/SOLUTIONS/COMMENTS
DURING JUNE THE SCRUBBER HAS FORCED OUT OF SERVICE WHEN AN INBOARD FAN
PEDISTLE BEARING FAILED. THE BEARING SECTION WAS REBUILT.
956
-------
EPA UTILITY f-3 SURVEY: CCTCBEH - OECEf.3EH 1981
PUBLIC SERVICE OF COLORADO: VAU10NT 5 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION 7. REMOVAL PER EOILE? FG3 CAP.
SOZ PART. HCU3S HBUSS HCU3S FACTC5
WHILE FAN REPAIRS MERE IN FPC3HESS EXTENSIVE MAINTENANCE HAS FE=FCPttEO CM
THE SCRUBBER. MAINTENANCE WORK INCLUDED COMPLETE BiLL REPLACEMENT. ADDI-
TIONAL REPAIR WORK OH THE SCKUB3ER LINER. REPAIR OF HOLES IN THE T^ES
SHELL AND OF A RUPTURED MIST ELIMINATOR HASH LINE ANO THE REHEATEH WAS
CLEANED.
DAMPER JAMMING AT VALMOHT HAS OCCURRED PERIODICALLY. SOMETIMES 0*r.?E7S DO
HOT READILY CLOSE. THE OPERATOR KUST MOVE THE DAMPER UP AND OCXH UNTIL THE
GUILLOTINE SEATS. BECAUSE OF CONTINUOUS FLY ASH ACOJ!"'LATICH IT APPEARS
THAT THE OAMPEHS MUST BE EXERCISED FREQUENTLY TO PREVENT JAMMING.
7/80 5A 48.3 46.6
SB 46.3 46.6
SYSTEM 48.3 46.6 744 719 347
•w PROBLEMS/SOLUTIONS/COMHENTS
THE SCRUBBER SYSTEM MAS SHUT DOWN BECAUSE OF 5CRU3BER BOOSTER FAN
BEARING FAILURE.
8/80 5A 87.5 84.8
SB 95.6 92.6
SYSTEM 91.5 87.7 744 721 660
x* PRC3LEMS/SOLUTIONS/COMMENTS
THE RECIRCULATION PUMP MOTOR BEARING FAILED CAUSING SOME MINOR OUTAGE
TIKE IN AUGUST.
9/80 SYSTEM .0 720 0 0
»» PROBLEMS/SOLUTIONS/COMT1ENTS
THE BOILER AND SCRUBBER MERE SHUT DOWN DURING SEPTEMBER FCR SCHEDULED
MAINTENANCE.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
*« PRC3LEMS/SOLUTIONS/CGMHENTS
THE SCRUBBER REMAINED OUT OF SERVICE THROUGHOUT THE OCTOBER-DECEIVER 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.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/61 SYSTEM 744
*» P30BLEMS/SOLUT1CNS/CCMMENTS
SCRUBBER CAME BACK ON-LIKE AT THE END OF JANUARY AND OPERATED THPCUSHOUT
THE MONTHS OF FEBRUARY AND MARCH WITHOUT ANY MAJOR SCRUBBER RELATED PROB-
LEMS.
957
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTNtf 14
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCPU3SERS
COMPANY NAME
PLANT IIAM3
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NCX EMISSION LIMITATION - NG/J
NET HUNT GENERATING CAPACITY - MW
GFOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
*v 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 - 7.
AVERAGE MOISTURE CONTENT - Y.
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
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY - 7.
»* PARTICLE SCRUBBER
KUK3EH
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUKSER OF CONTACTING ZONES
LIQUID RECIRCULATICN RATE - LITER/S
L/G RATIO - LITER/CU.M
FH CONTPOL ADDITIVE
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
SOUTHWESTERN PUBLIC SERVICE
HARHIN3TON
AMARILLO
TEXAS
B
43.
516.
******
360
360
320
*****
360
( .100 LB/KKBTU)
( 1.ZOO LB/MMSTU)
(****»» LB/HK3TU)
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
778.63 (1650000 ACFM)
176.7 ( 350 Fl
76. ( 250 FT)
CONCRETE
8.2 ( 27.0 FT)
COAL
SUBBITUMINOUS
19538.
5.00
4.5-6.0
27.10
25.0-30.0
.42
0.4-0.5
********
( 8400 BTU/LB)
8000-8900
COLD SIDE
RESEARCH-COTTRELL
778.6 (1650000 ACFM)
168.3 ( 335 F)
.1 I 1. IN-H20)
95.0
PACKED TOMER
STATIC BED PACKING
MARBLE-BED SCRUBBER
COMBUSTION ENGINEERING
24.0 X 25.0
CARBON STEEL
AISI 1110
ORGANIC
GLASS MARBLES
1
444.1
3.1
LIMESTONE
2.4
141.6
60.0
50.0
I 7050 GFM)
123.0 GAL/1000ACF)
8.0 FT/S)
300000 ACFM)
140 F)
958
-------
EPA UTILITY FGD SURVEY: OCTCSEa - DECEM2ER 1=81
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER EOILE3 FGD CAP.
S02 PART. HO'JRS HOUPS HCL'.-S FACTOR
10/79 SYSTEM 744
11/79 SYSTEM 7=0
12/79 SYSTEM 744
»» FROBLEMS/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 UAS ENCOUNTERED WHEN THE CHEMISTRY CONTROL UAS
TEMPORARILY LOST.
THE CONE SHAPED EXPANDED METAL (316L SS) SCREENS COVERING THE BED CRAIM
PIPES HAVE ERODED AWAY FROM BALL MOVEMENT. THE MAF8LE 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 SYSTEM 744
»» PROBLEMS/SOLUTIONS/COMMENTS
DURING THE FIRST QUARTER OF 1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
CAUSING PLUGGING IN SCRUBBERS 4 AND 5. THE UTILITY PLANS TO REPLACE
ALL FRP PIPING WITH STEEL. THE RUPTURE ON NO. 5 ALSO DAMAGED THE 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 CCPRCDED TO
THE POINT THAT HOLES HAVE FORMED. SCALE AND MOISTURE V.ERE FOUND ON THE
PLATE WHERE THE CORROSION FORMED. THE PLATE WAS REMOVED AND A NEW CARBON
STEEL PLATE WAS WELDED IN. NO OTHER REHEATER DUCTS HAVE EXPERIENCED ANY
SCALE OR MOISTURE ACCUMULATION.
4/80 SYSTEM 720
** PRCBLEMS/SOLUTIONS/COMMENTS
A PUMP LINER FAILURE OCCURRED IN APRIL. THE IMPELLER SHAFT LINER WAS RE-
PAIRED AND REPLACED.
5/80 SYSTEM 744
** F303LEMS/SOLUTIONS/COMMEHTS
THE BOILER WAS SHUT DOWN A FEW DAYS IN LATE APRIL AND 12 TO 14 DAYS IN
EARLY MAY FOR AIR FREHEATER REPAIRS.
DURING APPIL AND MAY THE SCRUBBING SYSTEM EXF 4IENCED 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.
959
-------
E?A UTILITY FGD SUKVEY: OCTOBER - DECEMBER 1981
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA
PEHIC3 KC2ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER 20ILE3 FG3 CAP.
S02 PAST. HOURS HOPS HCUPS FACTOR
6/60 SYSTEM 92.1 720 696 79.3
«* PRC3LEMS/SOLUTIONS/COKMENTS
DURING JUNE THE SCRUBBER EXHIBITED AN AVAILABILITY OF 92.IX. THERE MAS
GREATER SCRUBBER CAPACITY AVAILABLE THAN REQUIRED BY THE BOILER. NO
PROBLEMS WERE REPORTED FOR JUNE.
DAMPER PROBLEMS REPORTED PREVIOUSLY HAVE BEEN ELIMINATED. THE OLD CPERATCR
MECHANISMS MERE 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 MILL P3C3ABLY NOT CLEAR FLSTHEH
THROUGH DISSOLUTION DURING NORMAL SCRUBBER OPERATIONS AS HAD 3EEV HOPED.
ALTHOUGH THE MODULE MUST OPERATE AT LCHEH THAN OESIGN GAS FLCH SCRU2QEH
OPERATIONS ARE NOT HAMPERED OVERALL BECAUSE THE SYSTEM HAS SOME DESIGN
SPARE CAPACITY..
THE REHEATER PROBLEM REPORTED PREVIOUSLY HAS OCCURRED ON THFEE PEHEATEPS
NOW. THE FAILURE OF THE REHEATER DUCT BOTTOM PANELS MAY BE A PESULT OF AN
UNDERSIZED DEFLECTION SHIELD BENEATH THE TUBE BANKS. IT IS ALSO POSSI3LE
THAT THE DUCTING HAS IMPROPERLY UELCED.
7/80 SYSTEM 74*
8/80 SYSTEM 744
9/flO SYSTEM 720
»* PRCBLEMS/SOUJTICNS/COMMENTS
THE UTILITY REPORTED THAT NO MAJOR SCRUBBING SYSTEM PROBLEMS OCCURRED
DURING THE THIRD QUARTER 1980.
THE PROBLEM REPORTED EARLIER WITH THE MIST ELIMINATOR HASH PIPING IS
PRESENTLY BEING SOLVED BY REPLACING THE PIPING WITH CARBON STEEL.
10/80 SYSTEM 744
11/80 SYSTEM 720
12/80 SYSTEM 744
*« PROBLEMS/SOLUTIONS/COMMENTS
DURING THE OCTOBER THROUGH DECEMBER PERIOD REPLACEMENT OF THE MIST ELIMI-
NATOR HASH PIPING WITH CARBON STEEL CONTINUED; AS THE OLD PIPIN3 UEARS CUT
AND MAINTENANCE TIME PERMITS.
DURING LATE DECEMBER. THE SLURRY SPRAY PUMP HOUSING CRACKED DURING A BACK
FLUSH. THIS MAS THE SECOND TIME IN THO YEARS THAT THIS PROBLEM HAD
OCCURRED.
1/31 SYSTEM 744
»» PRCBLEKS/SOLUTIONS/COMMENTS
THE UTILITY REPORTED THAT AT THE BEGINNING OF THE YEAR THE SCSUEBE? SYSTEM
BEGAN TO SEE VOLUMES OF FLUE GAS GREATER THAN THAT PRODUCED BY THE BOILER.
IT MAS LATER DISCOVERED THAT THE EXPANSION JOINTS LOCATED AT THE ESP HAD
CRACKED AND MERE ALLOWING AMBIENT AIR TO ENTER THE SYSTEM. THE UTILITY
REPORTED THEY HAD ORIGINALLY ORDERED VITROU EXPANSION JOINTS BUT INSTEAD
RECEIVED CHLOROBUTYL JOINTS WHICH SUBSEQUENTLY FAILED. DUE TO THE ZN-
960
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
SOUTHWESTERN PUBLIC SERVICE: HARRINGTON 1 (CONT.)
PERFORMANCE DATA
FERICD MCDULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PEP BOILE3 FGD CAP.
302 PART. HCUP.S HCL'SS HC'JRS FAC7C3
CREASED GAS LOAD THE UTILITY HAS HAD TO PUN MCRE MCDULES THAN NORMALLY
NECESSARY FOR A GIVEN BOILER LOAD. THE UTILITY PLANS TO REPLACE THE
EXPANSION JOINTS DURING THE NEXT SCHEDULED OUTAGE IN MAY.
3/81 SYSTEM 67C
3/81 SYSTEM 744
»« PROBLEMS/SOLUTIONS/COMMENTS
MODULE 3 MAS SHUT DOWN FOR 24 HOURS TO REPLACE A RU3BER PUMP LINER WHICH
HAD BEEN WORN AWAY BY THE PUMP IMPELLERS.
EXCEPT FOR THE PUMP LINER AND EXPANSION JOINT FAILURES THE SCRU2SER SfSTEM
OPERATED WELL THROUGHOUT THE JANUARY-MARCH PERIOD.
961
-------
EPA UTILITY FG3 SURVEY: OCTC3ER - OECEM3ER 1981
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUM3ER
CIT
COUNTHY
ECGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NCX EMISSION LIMITATICN - NG/J
NET PLANT GENERATING CAPACITY - MM
G=OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BCILER 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 - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUP CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLCPIDE CONTENT - X
**» PARTICLE CONTROL
*» MECHANICAL COLLECTOR
TYPE
SUPPLIER
»* FABRIC FILTER
NUMBER
TYPE
«» ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE CROP - KPA
*« PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LII1EH SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
CHUGOKU ELECTRIC
SHIMONOSEKI
1
SHIMONOSEKI
JAPAN
******
******
219.
******
575
175
****»
*****
175
MITSUBISHI
PULVERIZED COAL
BASE
£66.27
130.0
200.
CONCRETE
3.0
(****»« LB/M13TU)
( .510 L3/MK3TU)
(«***»* LB/MM3PJJ
( 564255 ACFM)
( £66 F)
( 656 FT)
( 9.7 FT)
( 10766 BTU/LB)
******
COAL
******
25046.
24.60
******
2.30
******
.59
******
.04
0.01-0.11
MULTICLONES
MITSUBISHI
0
NONE
COLO SIDE
MITSUBISHI HEAVY INDUSTRIES
246.1 ( 521589 ACFM)
140.0 ( 284 F)
.6 ( 3. IN-H20)
SPRAY TOMER
NR
H3
MITSUBISHI
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
NONE
1
962
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEASE? 1S81
CHUGCXU ELECTRIC: SHIMONOSEKI i ICONT.)
LIQUID RECIRCULATICN RATE - LITER/S
L/G PATIO - LITE=/CU.M
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW «ATE - CJ.M/S
**» FGD SYSTEM
*» GENERAL DATA
SALEABLE FR03UCT/THRCWAUAY PRODUCT
S02 PEMOVAL MODE
FPCCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
CONTRACT AWARDED
ft* DESIGN AND OPERATING PARAMETERS
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
NUMBER
NTJMSER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TPAOE NAME/COMMON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATICN 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 - 7.
PARTICLE REMOVAL EFFICENCY - 7.
*» MIST ELIMINATOP
PRE-MIST .LIM1NATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUM3ER OF STAGES
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
WASH HATE - L/S
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
544.3
3.0
13.1
203.7
( 6S40 G?M)
(22.5 GAL/lOOOACr)
( 63.0 FT/S)
( 431725 ACFM)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTCNE
NONE
MITSUBISHI HEAVY INDUSTRIES
MITSUBISHI
FULL SCALE
RETROFIT
85.00
1
7/79
5/79
5/77
NR
NR
1
0
COMBINATION
NR
N/A
MITSUBISHI
CARBON STEEL
AISI 1110
H/A
ORGANIC
NR
NR
2722.
1.0
3.0
203.73
50.0
69.0
90.0
(43200 GPM)
( 3.9 IN-H20)
( 9.3 FT/S)
( 431725 ACFM)
( 122 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
2
.1
NR
NR
FRESH
200.0
( .6 IN-H20)
( 3170 GAL/MIN)
WASTE HEAT RECOVERY
NR
NR
157.8
203.73
105.0
NR
NR
( 264 F)
( 431725 ACFM)
I 221 F)
963
-------
EPA UTILITY FGO SUSVEf: CCTC3ER - DECEMBER 1981
chusoKu ELECTRIC: SHIHCNOSEKI i ICONT.)
*» FANS
SUPPLIER
FLUE GAS FLOW PATE - CU.M/S
FLUE GAS TEMPERATURE - C
** DAKPEPS
FUNCTION
GENERIC TYPE
S°EC:FIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LIMES GENEPIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
»» SOLIDS CONCENTHATINS/DEHATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SOLIDS CCNCENTRATING/DEMATERIHG
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
**» SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
QUALITY - X
*»» SLUDGE
*» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
*« WATER BALANCE
WATER LOOP TYPE
EVAPORATION MATER LOSS - LITER/S
POND SEEPAGE/RUNOFF HATER LOSS - LITERS/S
MAKEUP WATER ADDITION - LITERS/S
MITSUBISHI HEAVY INDUSTRIES
£94.04 ( 623103 ACrM)
140.0 ( 284 F)
NR
NR
US
NR
NR
NR
NR
MET BALL MILL
NR
NR
CENTRIFUGE
5
0
ZS7. SOLIDS
90X SOLIDS
THICKENER
1
0
33.0 DIA X 10.0
57. SOLIDS
25X SOLIDS
GYPSUM
6.98
99.0
NR
NR
NR
NR
NR
MR
C 7.70 TPHI
OPEN
54
3.0
6.8
( 47 GPM)
C 108 GPM)
964
-------
EPA UTILITY F6D SURVEY: OCTOSER - DECETOsR 1931
CHU3CKU ELECTRIC: SHIKONOSEKI i CCOHT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA6IHTY RELIABILITY UTILIZATION X REMOVAL PE=? EOILE5 FCO CAP.
502 PART. HOUSS HOVJSS HCUS5 FACTCR
7/79
6/79
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
372
744
7CO
372
744
7:0
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
FROBLEMS/SOLUTIONS/COMMENTS
COMMERCIAL OPERATIONS BEGAN IN THE KIDDLE OF JULY 1979. THE FGD LIMIT HAS
OPERATED CONTINUOUSLY THROUGH THE THIRD QUARTER WITH NO PROBLEMS.
744 744 744
720 720 7CO
744 744 696
»« PROBLEMS/SOLUTIONS/COMMENTS
THE FGD UNIT OPERATED CONTINUOUSLY THROUGH THE FOURTH QUARTER EXCEPT FCR A
2 DAY SHUTDOWN TO INSPECT THE GAS-GAS HEATER DURING DECEMBER. THE 3CILEH
WAS OPERATED FIRING A LOU SULFUR OIL DURING THE TUO DAYS.
1/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
2/80 SYSTEM 100.0 100.0 100.0 53.4 696 372 372
** FHOSLEMS/SOLUTION5/COKMENTS
DURING JANUARY AND THE FIRST HALF OF FEBRUARY THE FGD UNIT OPERATED WITH
NO FROSLEHS. THE BOILER MAS TAKEN OFF-LINE ON FEBRUARY 8 F03 SCHEDULED
MAINTENANCE.
3/80 SYSTEM 100. a .0 744 0 0
*» PRCBLEMS/SOLUTIONS/CDKMENTS
THE BOILER REMAINED DOHN THROUGH MARCH FOR ANNUAL MAINTENANCE.
4/80 SYSTEM 100.0 100.0 100.0 182.4 720 593 593
»* PRCBLEMS/SOLUTIONS/COKMENTS
DURING THE ANNUAL MAINTENANCE THE SCR (SELECTIVE CATALYTIC REDUCTICM OF
MOX) UNIT MAS CONNECTED BETWEEN THE BOILER AND AIR FRtHEATER. AFTE3 THE
STARTUP OH APRIL 6, COAL ONLY HAS BEEN USED IBEFCRE FEBRUARY, COAL ANO
OIL HERE USED 50:50). EXCEPT FOR A 2 HOUR SHUTDOWN FOR A TURBINE TEST CM
APRIL 7. THE FGO SYSTEM HAS OPERATED CONTINUOUSLY WITH HO PROBLEMS.
5/80 SYSTEM 100.0 100.0 100.0 90.3 744 672 672
*« PROBLEMS/SQLUTIONS/COHMENTS
THE FGD SYSTEM OPERATED CCNTINOUSLY WITH NO PROBLEMS. A THPEE DAY
SHUTDOWN FCR INSPECTION OF THE SCR UNIT FROM MAY 16 TO MAY 19 MAS THE
ONLY DOWN TIME EXPERIENCED DURING HAY.
6/30 SYSTEM 100.0 100.0 100.0 100.0 7ZO 7£0 7ZO 99.4
965
-------
EPA UTILITY FGD SURVEY: OCTCEER - DECEMBER 1981
CHUGOKU ELECTRIC: sxir:cr:os£Ki i ICCHT.I
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
*» PROBLEMS/SOLUTIONS/COMHENTS
THE FGO SYSTEM OPERATED CQNTINOUSLY 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 83.7 88.7 88.7 88.7 744 744 660 99.5
*« PRGBLEMS/SOLUTICNS/COMMENTS
CURING AUGUST THE FGO SYSTEM HAS SHUT DOWN FOR 64 HOURS DUE TO SOME PLUS-
GINS IN THE REHEATER. DURING THIS TIME THE REHEATER MAS MATER HASHED AND
THE SOOT BLOWER SYSTEM HAS IMPROVED.
9/60 SYSTEM 89.0 69.0 89.0 89.0 720 720 641 97.3
»« PHOBLEMS/SOLUTICNS/COMttENTS
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 83.5
*» PR03LEMS/SOLUTIONS/COMKENTS
DURING OCTOBER THE BOILER MAS TAKEN OFF LINE FOR THREE DAYS FOR AM
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
** PR03LEMS/SOLUTIONS/COMMENTS
NO PROBLEMS WERE ENCOUNTERED DURING THE MONTHS OF NOVEMBER AHO DECEMBER.
1/81 SYSTEM "44
2/81 SYSTEM 672
3/81 SYSTEM 744
«» PROBLEM5/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME! HOWEVER THE
DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1961 REPORT.
966
-------
EPA UTILITY FGO SUPVEY: OCTCSEH - DECEMEE= 1«31
SECTION 15
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT HUK3ER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - HS/J
SC2 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY M/FGD - KM
NET UNIT GENERATING CAPACITY HO/FGO - MM
EQUIVALENT SCRU3BED CAPACITY - MM
*« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SEPVICE 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 - '/.
RANGE CHLORIDE CONTENT - 7.
*** PARTICLE CONTROL
*» MECHANICAL COLLECTOR
NUMBER
TYPE
»* ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
** PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
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
ELECTRIC POWER DEVELOPMENT
ISC30
1
YOKOHAMA
JAPAN
20.
58.
*******
238
265
238
*****
265
IHI
PULVERIZED COAL
BASE
405.36
170.0
122.
CAPBON STEEL
3.7
.046 L3/MMBTU)
.135 LS/MM3TU)
650000 ACFM)
333 F)
400 FT)
( 12.0 FT)
( 11160 BTU/L3)
11160-11520
COAL
******
25958.
16.00
15.0-17.0
7.00
6.0-8.0
.60
0.2-0.6
****»**«
*******
0
NONE
COLD SIDE
TOYO ENGINEERING
353.2 ( 743362 ACFM)
150.0 ( 302 F)
98.0
1
0
VENTURI TOWER
N3
NS
IHI-CHEMICO
43.6 DIA X 101.4
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
HONE
1
£194.1 (34827 G?M)
9.4 (70.0 GAL/10COACF)
967
-------
EPA UTILITY FGD SL'WEY: CCTC3ER - DECEMBER 1961
ELECTRIC PCHER DEVELOPMENT: ISOGO 1 (CONT.)
F35SSIPE DROP - KPA
SUPEPFICIAL GAS VELOCITY - M/S
INLET GAS FLOW KATE - CU.M/S
INLET GAS TEMPERATURE - C
*** FGO SYSTEM
<* GENERAL DATA
SALEABLE FRODUCT/THROMAMAY PRODUCT
S02 REM3VAL MCCE
F3CCESS T^PE
SYSTEM SLVPLIEH
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UMIT DESIGN S02 REMOVAL EFFICIENCY - 7.
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
*» CUENCHER/FRESATURATOH
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*» ABSORBER
NUMBER
NUJ13ER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LIMER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCUUTION 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 - 7.
«» MIST ELIMINATOR
PPE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DPOP - KPA
SUPEHFICAL GAS VELOCITY - H/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH FREQUENCY
** REHEA-ER
GENERIC TYPE
SPECIFIC TYPE
TPADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
1.5
3.3
424.6
170.0
( 5.9 IN-H20)
( 10.0 FT/S)
( 69936* ACFM)
( 333 F)
SALEABLE PRODUCT
MET SCRUBBING
LIMESTCNE
IHI-CHEMICO
FULL SCALE
RETROFIT
7. 97.00
95.00
1
3/76
12/75
NR
NR
1
0
VENTURX TOMER
NR
NR
IHI/CHEMICO
43.5 DIA X 76.8
CARBON STEEL
NR
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NR
NONE
1
2194.
9.4
1.5
3.0
566.28
55.0
96.7
(34827 GPM)
( 70.0 GAL/1000 ACPI
( 5.9 IN-H20)
( 10.0 FT/S)
(1200000 ACFM)
( 131 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
4
4
.5 (
3.0 (
ORGANIC
NR
INTERMITTENT
2.0 IN-H20)
9.8 FT/S)
DIRECT COMBUSTION
NR
OIL
83.9
120.0
NR
( 151 F)
( 248 F)
968
-------
EPA UTILITY F6D SURVEY: OCTCSER - DECEM2ER 1°S1
ELECTRIC POWER DEVELOPMENT: ISOGO 1 (COHT.)
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» 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
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
OXIDATION TOMER FEED
RECYCLE
SLURRY
THICKENER OVERFLOW
FILTRATE
** PUMPS
SERVICE
SLURRY MAKEUP
ABSORBER RECIRCULATICN
OXIDATION TCUER SUPPLY TRANSFER
FILTRATE
** SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
NUMBER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*« SOLIDS CCNCENTRATING/OEUATERING
DEVICE
NUMBER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHAPACTERISTICS
OUTLET STREAM CHARACTERISTICS
»** SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
DISPOSITION
NR
Z
0
BOOSTER
36Z.14
170.0
( 767400 ACFM)
( 336 F)
1
0
OXIDATION BLOWER
.86 (
10.0 (
NR
NR
NR
NR
NR
NR
NR
MET BALL KILL
NR
NR
NUMBER
1830 ACFM)
50 F)
Z
«**»
1
1
1
NUMBER
3
8
2
Z
CENTRIFUGE
4
1
18.SX SOLIDS
90X SOLIDS
THICKENER
1
0
20.0 OIA X 10.0
6.SX SOLIDS
18.6X SOLIDS
GYPSUM
4.53
MARKETED
( 5.00 TPH)
969
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ELECTRIC POHER DEVELOPMENT: ISOSO 1 ICONT.)
*•*« SLUDGE
** TPEATMEMT
r.ETHO? FC3CEO OXIDATION
CEVICE OXIDATION TANK
PROPRIETARY PROCESS N/A
»* DISPOSAL
MATURE NR
TYPE NR
SITE TREATMENT KR
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS PH
PROCESS CONTROL MANNER AUTOMATIC
PROCESS CHEMISTRY MODE FEEDBACK
*» WATER BALANCE
HATER LOOP TYPE OPEN
POND SEEFAGE/FUNOFF HATER LOSS - LITERS/S 40
MAKEUP WATER ADDITION - LITERS/S 22.3 ( 354 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER EOZLER FGD CAP.
S02 PART. HOURS HOURS HOIRS FACTOR
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 7£0
12/78 SYSTEM 744
1/79 SYSTEM 744
2/79 SYSTEM 672
3/79 SYSTEM 744
*« PR09LEMS/SOLUTIONS/COMMENTS
100X AVAILABILITY FOR THE FGD SYSTEM HAS REPORTED DURING THE PERIOD APRIL
1978 THROUGH MARCH 1979. THE SYSTEM S02 REMOVAL EFFICIENCY WAS PEPCRTEDLY
AVERAGING 95X.
4/79 SYSTEM 720
5/79 SYSTEM 744
6/79 SYSTEM 720
7/79 SYSTEM 744
8/79 SYSTEM 744
970
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEASES i«81
ELECTRIC POWER DEVELOPMENT: ISOSO 1 (CONT.J
PERFORMANCE DATA
PERIOD MOBULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL FE3 BOILED FG3 CAP.
SOI PART. HOU3S HOLSS HOURS FAC7C3
9/79 SYSTEH 7CO
10/79 SYSTEH 744
11/79 SYSTEH 720
12/79 SYSTEH 744
1/80 SYSTEM 744
2/80 SYSTEM 696
3/80 SYSTEM 744
** PHOSLEMS/SOLUTIONS/COMMENTS
NO INFORMATION MAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 FERIC3.
4/60 SYSTEM 100.0 100.0 100.0 100.0 720 7CO 720
*« PROBLEMS/SOLUTIONS/COMMENTS
THE FGO SYSTEM OPERATED ALONG WITH THE BOILER FOR THE ENTIRE MONTH OF
APRIL.
5/80 SYSTEM 100.0 100.0 109.0 52.B 744 393 593
6/80 SYSTEH 1QO.O 100.0 109.0 10.0 7CO 7£ 72
»* PROBLEMS/SOLUTIOHS/COMMENTS
THE BOILER MAS SHUT DOWN FROM MAY 17 TO JUNE 27 FOR ANNUAL MAINTEN-
ANCE. THE FGD SYSTEM MAS OPERATED DURING ALL OF THE EDILER OPiRATICN
IN MAY AND JUNE.
7/80
6/80
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. a
95.30
95.70
96. ZO
744
744
720
744
744
710
744
744
716
90.9
91.9
90.4
** PROBLEMS/SOLUTIOHS/COMMENTS
DURING SEPTEMBER THE BOILER HAS OUT OF SERVICE FOR APPROXIMATELY TWO HOURS
TO CHANGE THE TAP ON THE MAIN TRANSFORMER.
10/80
11/80
12/60
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100
100
100
.0
.0
.0
100.0
100.0
100.0
91.4
100.0
100.0
96.00
95.50
95.00
744
720
744
680
7EO
744
680
720
744
S4.5
91.7
93.2
*» PROBLEMS/SOLUTIONS/COMKENTS
DURING JULY THROUGH DECEMBER THE FGD SYSTEH EXPERIENCED NO OPERATIONAL
PROBLEMS.
1/81 SYSTEM 744
2/81 SYSTEH 672
3/81 SYSTEM 744
971
-------
EPA UTILITY FGO SURVEY: CC7CBER - DECEMBER 1981
ELECTRIC POWER DEVELOPMENT: ISCGO 1 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION Y. REMOVAL PE=J BOILER FGO CAP.
SOZ PART. HCU'S HOUSS HC'J'S FACTOR
«» PROBLEHS/SOLUTICNS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOWEVER THE
DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
972
-------
EPA UTILITY FGD SURVEY: OCTCSER - DECEMBER 1931
SECTION IS
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY MAKE
PLANT HArS
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
rARTICULATE EMISSION LIMITATION - NG/J
£02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY MO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - KU
*» UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
E'JILER 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
PAHGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
**» PARTICLE CONTROL
*« MECHANICAL COLLECTOR
NUMBER
TYPE
ELECTRIC POWER DEVELOPMENT
ISCGO
YOKOHAMA
JAPAN
******
20.
58.
******
23d
265
233
246
265
( .046 LS/MMBTU)
( .135 LB/Mr,3TU)
(»***** L3/MM3TU)
IHI
PULVERIZED COAL
BASE
405.36 (
170.0 (
140. (
CARBON STEEL
3.7 (
859000 ACFM)
333 r)
460 FT)
12.0 FT)
COAL
******
25958.
16.00
15.0-17.0
7.00
6.0-8.0
.60
0.2-0.6
******»»
******
0
NONE
( 11160 BTU/LB)
11160-11520
*« ESP
NUM3ER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
*» PARTICLE SCRUBBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIHCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAS VELOCITY - ft/3
356.6
150.0
98.0
( 755654 ACFM)
( 302 F)
1
0
VENTURI TOMER
NR
NR
IHI-CHEMICO
43.6 OIA X 101.4
CARBON STEEL
AISI 1110
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
1
2194.1 (34827 GPM)
9.4 (70.0 GAL/1000ACF)
1.5 (5.9 IN-H20)
3.0 ( 10.0 FT/S)
973
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
ELECTRIC POWER DEVELOPMENT: ISOGO 2 (CONT.)
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
*»* FGO SYSTEM
»* GENERAL DATA
SALEABLE PPQOUCT/THROUAUAY PRODUCT
502 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
HEW/RETSOFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
<*« DESIGN AND OPERATING PARAMETERS
*» QUENCHER/PPESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
NUKSER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
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
NUMBER OF CONTACTING ZONES
LIQUID RECALCULATION RATE - LITER/S
L/G PATIO - 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
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUM3EP OF STAGES
NUMBER OF PASSES PER STAGE
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH FREQUENCY
*» REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. M/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
424.6
170.0
( 899364 ACFM)
( 333 F)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
IHI-CHEMICO
FULL SCALE
RETROFIT
X 97.00
95.00
3.0
1
5/76
3/76
NR
NR
1
0
VENTURI TOMER
NR
NR
IHI/CHEMICO
43.5 DIA X 76.8
CARBON STEEL
NR
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NR
NONE
1
2194.
9.4
1.5
3.0
566.28
55.0
96.7
(34327 GPM)
( 7C.O GAL/1000 ACF)
( 5.« IN-H20)
( 10.0 FT/S)
(1200000 ACFM)
( 131 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
4
4
.5
3.0
ORGANIC
NR
INTERMITTENT
DIRECT COMBUSTION
NR
OIL
83.9
132.50
120.0
NR
( 2.0 IN-H20)
( 9.8 FT/S)
( 151 F)
( 280733 ACFM)
( 248 F)
974
-------
ELECTRIC POWER DEVELOPMENT: ISOSO 2 (CONT.)
COMSTRUCTICM MATERIAL SPECIFIC TYPE
** FANS
NUMBER
NUMBER OF SPARES
FUNCTION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
** FANS
NUMBER
N'-MSER OF SPARES
APPLICATION
FLUE GAS FLOW PATE - CU.M/S
FLUE GAS TEMPERATURE - C
*» DAMPERS
FUNCTIQ>4
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
OXIDATION TOWER FEED
SLURRY
THICKENER OVERFLOW
FILTRATE
«* PUMPS
SERVICE
SLURRY MAKEUP
ABSORBER RECIRCULATION
OXIDATION TOWER SUPPLY TRANSFER
FILTRATE
«* SOLIDS CONCESTRATING/OEVIATERING
DEVICE
NUMBER
NU.-3ER OF SPARES
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
** SOLIDS CONCENTRATING/OEHATERING
DEVICE
NU."SER
NUMBER OF SPARES
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
**» SALEABLE BYPRODUCTS
NATURE
FULL LOAO QUANTITY - M T/H
DISPOSITION
««* SLUDGE
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
NR
2
0
BCDSTER
252.14
170.0
( 767430 ACFM)
( 333 F)
1
0
OXIDATION BLOWER
.66 ( 1830 ACFM)
10.0 ( 50 F)
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NUMBER
NUMBER
2
8
2
2
CENTRIFUGE
4
0
18.5X SOLIDS
90X SOLIDS
THICKENER
1
0
20.0 DIA X 10.0
8.SX SOLIDS
18.6X SOLIDS
GYPSUM
4.53
MARKETED
( 5.00 TPH)
975
-------
EPA UTILITY FGO SURVEY: OCTCSER - DECEMBER 1981
ELECTRIC POWER DEVELOPMENT: ISQGO 2 (CONT.)
<•» TREATMENT
METHOD FORCED OXIDATION
DEVICE OXIDATION TANK
FBOFRIETARY PROCESS N/A
M* DISPOSAL
NATURE NR
TY"»E MS
SITE TREATMENT N3
** P70CESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS PH
PROCESS CONTROL MANNER AUTOMATIC
PROCESS CHEMISTRY MODE FEEDBACK
*» MATER BALANCE
WATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF MATER LOSS - LITERS/S 40
MAKEUP MATER ADDITION - LITERS/S 22.3 ( 354 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION V. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/78 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
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
1002 AVAILABILITY FOR THE FGD SYSTEM WAS REPORTED DURING THE PSRIC3 AF'IL
1978 THROUGH MARCH 1979. THE FGO SYSTEM LOGGED A TOTAL OF 1,689 HOURS OF
OPERATION.
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
976
-------
EPA UTI- rcO SURVEY: CCTC3=3 - DECEKE=P 1931
ELECTRIC POWER DEVELOPMENT: ISOGO 2 (CCNT.)
PERFORMANCE DATA
PERIOD r.C3ULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION X PEMOVAL PER SOILED FG3 Ci=.
S02 PART. KCL"S HC'JRS hC'J^S FACTCa
21/79 SYSTEM 720
1C/79 SYSTEM 74*
1/80 SYSTEM 744
2/60 SYSTEM 696
3/60 SYSTEM 744
** PHOBLEMS/SOLUTIONS/COrfflENTS
NO INFORMATION UAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH I960 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 31.3 720 225 2:5
<•* PROBLEMS/SOLUTIOHS/COMMENTS
OH MARCH 30 THE BOILER MAS SHUTDOWN FOR ANNUAL MAINTENANCE. THE W4IT
REMAINED DOWN THROUGH APRIL 20. WHEN OPERATIONS COMMENCED THE FGO SYSTEM
OPERATED WITH THE BOILER FOR THE REST OF THE MONTH.
5/80 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
6/80 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
** PROBLEMS/SOLUTIONS/COKMENTS
BURINS MAY AND JUNE THE FED SYSTEM OPERATED WITH NO REPCRTED PHC3LEMS.
7/80 SYSTEM 100.0 100.0 100.0 S3.2 94.90 744 656 656 82.0
»* PHC3LEMS/SOLUTIONS/COKMENT3
CUBING JULY THE BOILER WAS OFF LINE APPROXIMATELY 88 HOURS FCR MAINTEN-
ANCE.
6/80 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 95.70 720 713 713 92.1
*« FROBLEMS/SOLUTIONS/COMKENTS
APPROXIMATELY TWO HOURS OF BOILER OUTAGE TIME UAS NECESSARY TO CHAU3E
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/COMMEMTS
DURING JULY THROUGH DECEMBER THE FG3 SYSTEM OPERATED WITH NO PROBLEMS.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
977
-------
E=A UTIL:TY FGD SURVEY: OCTOBER - DECEMBER 1981
ELECTRIC FCWER DEVELOPMENT: ISCGO 2 (CONT.)
PERFORMANCE DATA
PERICD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HCLIrS HOUPS HO'JPS riCTO=
*» FRCBLEMS/SOLUTIONS/COMMEHTS
THE FIPST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HOUEVET THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
978
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSICN LIMITATION - NG/J
S02 EMISSION LIMITATION - MG/J
HOX EMISSICN LIMITATION - NG/J
NET PLANT GcNEPATINS CAPACITY - MU
G=OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY U'O/FGD - MM
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
*« 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
*» ESP
NUMBER
TYPE
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
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATICN RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
ELECTRIC POUER DEVELOPMENT
TAKASAGO
1
TAKASAGO
JAPAN
( .086 LB/M^3TU)
( .350 LB/MH5TU)
(****** LB/MM5TU)
( 774000 ACFM)
( 310 F)
( 590 FT)
( 11.9 FT)
( 11160 BTU/LB)
11160-11520
37.
150.
**«*«*
230
250
230
238
250
MITSUBISHI
*•«*»•**
BASE
3o5.25
154.4
ISO.
CARBON STEEL
3.6
COAL
*«***»
25958.
22.00
******
7.00
******
1.80
******
********
******
0
NONE
COLO SIDE
MITSUBISHI HEAVY INDUSTRIES
344.3 ( 729507 ACFM)
154.4 ( 310 F)
99.5
1
0
VENTURI TOWER
NR
NR
MITSUI-CHEMICO
37.7 DIA X 62.3
CARBON STEEL
AISI 1110
COSRISION RESISTANT
NONE
1
1228.8 (19505 GPM)
6.5 (48.6 GAL/1000ACF)
1.5 ( 5.9 IN-H20)
979
-------
EPA UTILITY FGO SURVEY: CCT03ER - DECEMBER 1981
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPEFATUPE - C
SOS REMOVAL EFFICE.'JCY - X
PARTICLE REMOVAL EFFICIENCY - X
»«* FGO SYSTEM
260.5
154.4
56.0
50.0
552000 ACFM)
510 F)
** GENERAL DATA
SALEABLE FRCOUCT/THROWAUAY PRODUCT
S02 REMOVAL MCDE
FPOCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
HEM/RETROFIT
UNIT DESIGN SOS REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
INITIAL START-UP
*« DESIGN AND OPERATING PARAMETERS
*« QUENCHER/PRESATURATCR
CONSTRUCTION MATERIAL GFNERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** ABSORBER
NUMBER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TPADE 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
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
** ABF-3RBEH
Nli,~.2ER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TPADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING OE-/:C£ TYPE
NUMSER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLO'J - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
»* ABSORBER
NUM5ER
GENERIC TYPE
SPECIFIC TYPE
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
MITSUI-CHEMICO
FULL SCALE
RETROFIT
93.00
3.2
1
2X75
NR
NR
1
0
VENTURI TOMER
NR
NR
MITSUI/CHEMICO
45.9 OIA X 78.7
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
2566.
6.5
1.5
55.0
85.0
(40727 GPM1
( 48.6 GAL/1000 ACF)
( 5.9 IN-H20)
( 131 F)
VENTURI TOMER
NR
NR
MITSUI/CHEMICO
26.2 OIA X 62.3
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
610.
69.37
154.4
63.0
SPRAY TOWER
NR
( 9689 GFtt)
( 147000 ACFM)
( 310 F)
980
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEH5ES 1?31
ELECTRIC POWER DEVELOPMENT: TAKASASO 1 ICONT.)
TPADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SFFCIFIC MATERIAL
LINER MATERIAL TPADE NAME/COMMON TYPE
GAS CCNTACTIK3 DEVICE TYPE
NUMBER OF CONTACTINS ZONES
LIQUID RECIRCULATION RATE - LITER/S
INLET GAS FLOW - CU. tl/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
FRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUtiEER OF STAGES
NUMSER OF PASSES PER STAGE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH MATER SOURCE
»* REHEATER
NUMSER
GENERIC TYPE
SPECIFIC TYPE
TRADE HAME/CCMMOH TYPE
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* FANS
FUNCTION
*« FANS
APPLICATION
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»« REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
** TANKS
SERVICE
CENTRIFUGE OVERFLOW
ABSOPBENT MAKEUP
CENTRIFUGE FEED
PRIMARY LICL'OR
ABSORBER FEED
** PUMPS
SERVICE
MITSUI/CHEMICO
19.7 DIA X 65.0
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
9936.
18.26
154.4
(»*»»» GPM)
( 38666 ACFM)
( 310 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
4
4
NR
NR
BLENDED
DIRECT COMBUSTION
NR
OIL
120.0 ( 248 F)
NR
NR
BOOSTER
OXIDATION BLOWER
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
NUMBER
CIRCULATION
PH ADJUSTER CIRCULATION
REACTOR CIRCULATION
NUMBER
5
3
3
981
-------
EPA UTILITY F6D SURVEY: CCTC3ER - DECEMBER 1981
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
** SOLIDS CONCEHTRATIHG/DEHATERIN3
DEVICE CENTRIFUGE
HUK3ER 7
OUTLET STREAM CHARACTERISTICS 90X SOLIDS
«* SOLIDS CmiCENTRATING/DEHATERING
DEVICE THICKENER
CUTLET STREAK CHARACTERISTICS 20X SOLIDS
*•»« SALEABLE BYPRODUCTS
NATURE GYPSUM
FULL LOAD QUANTITY - M T/H 8.62 ( 9.50 TFH>
**» SLUDGE
«» TREATMENT
METHOD FORCED OXIDATION
DEVICE OXIDATION TANK
PROPRIETARY PROCESS N/A
«* DISPOSAL
NATURE NR
TYPE NR
SITE TREATMENT NR
»* PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS FLUE GAS VOLUME & S02 CONCENTRATION
»» MATEP BALANCE
WATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF MATER LOSS - LITERS/S 40
MAKEUP MATER ADDITION - LITERS/S 13.1 ( 208 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
SOS PART. HOIPS HOURS HOUPS FACTCR
2/75 SYSTEM 96.9 68.8 672 616 597
** PROBLEMS/SOLUTIONS/COMMENTS
THE FGO SYSTEM MAS DOWN ONCE DUE TO A PIPING FLANGE LEAK.
3/75 SYSTEM 100.0 48.4 744 360 360
4/75 SYSTEM 100.0 44.1 720 318 318
** PR03LEMS/SOLUTICNS/COMMENTS
THE BOILER MAS 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 97.8 744 743 723
8/75 SYSTEM 98.0 98.0 744 744 729
9/75 SYSTEM 95.7 91.7 720 690 660
982
-------
EPA UTILITY FGO SURVEY: OCTC3E= - OECEM2E1? 1931
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PE3IOD MODULE AVAILABILITY OPERA3ILITY RELIABILITY UTILIZATION X REMOVAL PER BCILZR FGD CAP.
S02 PART. KSL'SS HCURS HOtJ=S FACTOR
*» 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/SOLUTICNS/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 MAS ENCOUNTERED IN NOVEMBER.
12/75 SYSTEM 95.9 92.2 74* 715 636
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 92.3 744 687 637
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 7CO
10/76 SYSTEM 91.7 91.7 744 744 682
** PROBLEMS/SOLUTIONS/COHMENTS
THE SYSTEM MAS TAKEN OFF-LINE FOR CLEANING OF THE FIRST STAGE SCRUBBER.
11/76 SYSTEM 99.3 99.3 720 720 715
»» PROBLEMS/SOLUTIONS/COMMENTS
REPAIR OF A DUCT FORCED ONE SYSTEM OUTAGE DURING THE MONTH.
12/76 SYSTEM 98.9 98.9 744 744 736
*« PR03LEMS/SOLUTIONS/COMMENTS
A DECEMBER OUTAGE MAS DUE TO THE REPAIR OF A SPRAY PIPE.
1/77 SYSTEM 99.3 99.3 744 744 739
983
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ELECT? 1C POWER DEVELOPMENT: TAKASAGO 1 (COMT.J
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER e :D CAP.
SOS PART. HOURS HOURS HC'.iS FACTOR
** PRC3LcMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS TAKEN OFF-LINE ONCE FOR CLEANIN6 OF THE FIRST STAGE
SCRUBBER.
2/77 SYSTEM 100.0 100.0 672 672 672
3/77 SYSTEM .0 744 0 0
»* PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM MAS OFF OURIN6 MARCH FOR ANNUAL BOILER MAINTENANCE.
4/77 SYSTEM 100.0 71.3 7CO 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/COMflENTS
THE FIRST STAGE ABSORBER MAS 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.Z 94.2 744 744 701
*« PR03LEMS/SOLUTIONS/COKMENTS
THE SYSTEM MAS OFF LINE PART OF THIS MONTH FOR CLEANIMS OF THE SCRU23ERS
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
»» PHOBLEMS/SOLUTIONS/COMHENTS
THE FIRST REACTOR HAS CLEANED THIS MONTH.
4/73 SYSTEM 720
5/78 SYSTEM 744
6/78 SYSTEM 720
7/78 SYSTEM 744
8/78 SYSTEM 744
9/78 SYSTEM 7CO
10/78 SYSTEM 744
984
-------
EPA UTILITY FGO SURVEY: OCTCBEB - DECEMBER 1931
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (COHT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OrERABILITY RELIABILITY UTILIZATION 7. REMOVAL FER BOILER FG3 CAP.
S02 PART. HOURS HOUPS hC./'S FACTOR
11/78 SYSTEM 720
12/78 SYSTEM 744
1/79 SYSTEM 7**
3/79 SYSTEM 672
3/79 SYSTEM 74*
«» PHOBLEMS/SOLUTIONS/COHMENTS
DURING APRIL 1978 THPOUSH MARCH 1979 HO FCRCED OUTAGES CCCU7KED. THE FGD
SYSTEM AVAILABILITY HAS 99.9X. AND LOG3ED A TOTAL OF 7823.4 HOURS Or
OPERATION WITH 6.1 HOURS OF SCHEDULED OUTAGE TIKE.
4/79 SYSTEM 720
6/79 SYSTEM 710
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/SOLUTICNS/COMtlENTS
NO INFORMATION MAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH 1980 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 31.1 720 224 £24
*» PROBLEMS/SOLUTIONS/COMHENTS
THE BOILER HAS SHUTDOWN ON MARCH £9 F03 ANNUAL MAINTENANCE. THE UNIT
REMAINED OFF LINE THROUGH APRIL 21. WHEN OPERATIONS CO^EilCED 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
*» PHOBLEHS/SOLUTIONS/CCKMENTS
THE FGO SYSTEM EXPERIENCED NO PROBLEMS OLHING THE KAY-JUNE PERIOD.
7/80 SYSTEM 100.0 100.0 100.0 100.0 93.00 744 744 744 83.4
8/80 SYSTEM 100.0 100.0 100.0 100.0 92.30 744 744 744 33.6
9/80 SYSTEM 100.0 100.0 100.0 100.0 95.00 720 720 720 83.3
985
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
ELECTRIC POWER DEVELOPMENT: TAKASAGO 1 (CONT.)
PERFORMANCE DATA
PERIOO MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FC-3 CAP.
SOZ PART. HOURS HCU3S HO'J=S FACTOR
M* FROBLEHS/SOLUTIONS/CCrtMENTS
NO PROBLEMS MERE 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/COMMENTS
THE FGO SYSTEM MAS SHUT DOWN FOR APPROXIMATELY FOUR HOURS IN CCTCSER FOR
AH 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 7£0 85.0
12/80 SYSTEM 100.0 100.0 1CO.O 100.0 92.70 744 744 744 89.9
*» PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS MERE ENCOUNTERED DURING NOVEMBER AND DECEMBER.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME! HOUEVER THE
DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
986
-------
EPA UTILITY FGO SURVEY: OCTC3HH - OECEttScP 1981
SECTION 15
DESIGN AMD PERFORMANCE DATA FOR OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
«» UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
EOILER SERVICE LOAD
DESIGN 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
FUEL GPAOE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - V.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUP CONTENT - X
AVERAGE CHLCRIOE CONTENT - X
RANGE CHLORIDE CONTENT - X
*»» PARTICLE CONTROL
«» MECHANICAL COLLECTOR
NUMBER
TYPE
«» ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
** PARTICLE SCRUBBER
NUM2ER
NUMBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TPADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZCNES
LIQUID RECIRCULATICN RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
ELECTRIC POWER DEVELOPMENT
TAKASAGO
TAKASAGO
JAPAN
******
37.
150.
******
230
250
230
238
250
( .056 LB/MM3TU)
( .350 LB/ri3TU)
(»•**»** L3/MM3TU)
774300 ACFM)
310 F)
( 590 FT)
( 11.9 FT)
( 11160 BTU/LB)
11160-11520
MITSUBISHI
******
BASE
365.25
154.4
180.
CARBON STEEL
3.6
COAL
******
25953.
22.00
7.00
******
i.ao
******
********
******
o
NONE
COLD SIDE
MITSUBISHI HEAVY INDUSTRIES
344.3 ( 729507 ACFM)
154.4 ( 310 FI
99.5
1
0
VENTURI TOMER
NR
NR
MITSUI-CHEMICO
37.7 OIA X 62.3
CARBON STEEL
AISI 1110
CORRISION RESISTANT
NONE
1
1542.2 (24480 GPM)
6.5 (48.6 GAL/1000ACF)
1.5 ( 5.9 IN-H20)
987
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ELECTRIC PCHER DEVELOPMENT: TAKASAGO 2 (CONT.)
IMLET GAS FLOW PATE - CU.tt/S
INLET GAS T£MFE=ATUPE - C
SOS PEMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
»<•» FGD SYSTEM
*» GENERAL DATA
SALEABLE PRODUCT/THROMAUAY PRODUCT
SCC PEMCVAL MCOE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
HEU/RETRCFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
INITIAL START-UP
ft* DESIGN AND OPERATING PARAMETERS
*« QUEHCHER/P'ESATURATOH
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» ABSORBER
NUMBER
NUTBER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRACE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESS'JPE DROP - KPA
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
*» ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENEPIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENEPIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE MAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIPCULATION RATE - LITER/S
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
** ABSORBER
NUMBER
GENERIC TYPE
£60.5
154.4
56.0
50.0
( 553000 ACFM)
( 310 F)
SALEABLE PRODUCT
WET SCRUBBING
LIMESTONE
MITSUI-CHEMICO
FULL SCALE
RETROFIT
93.00
3.2
1
3/76
MR
NR
1
0
VENTURI TOMER
NR
NR
MITSUI/CHEMICO
45.9 DIA X 78.7
CARBON STEEL
NR
N/A
NR
NR
NR
NCNE
1
2066.
6.5
1.5
280.24
55.0
85.0
(32801 GPM)
( 48.6 GAL/1000 ACF)
( 5.9 IN-H20)
( 593855 ACFM)
( 131 F)
VENTURI TCUER
NR
NR
MITSUI/CHEMICO
26.2 DIA X 82.3
CARBON STEEL
NR
N/A
NR
NR
NR
NONE
1
743.
69.37
154.4
63.0
SPRAY TOWER
(11799 GPM)
( 147000 ACFM)
( 310 F)
988
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEfSER 1981
ELECTRIC POWER DEVELOPMENT: TAKASAGO 2 (CONT.)
SPECIFIC TYPE
TPADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRACE NAME/COMMON TYPE
LINE1? GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TPADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUriEEH OF CONTACTING ZONES
LIQUID RECIPCULATION 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/CCMMON TYPE
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
UASH MATER SOURCE
** REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
FUNCTION
NR
NR
MITSUI/CHE^ICO
CAFBON STEEL
NR
N/A
NR
NR
NR
NONE
1
19639.
36.51
154.4
(»»»<* GPMI
( 77372 ACFM)
I 310 F)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
4
4
NR
NR
SLEWED
DIRECT COMBUSTION
NR
OIL
120.0 ( 248 F)
NR
NR
BOOSTER
»* FANS
APPLICATION
«« DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENEPIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
*» TANKS
SERVICE
CENTRIFUGE OVERFLOW
ABSORBENT MAKEUP
CENTRIFUGE FEED
PRIMARY LICUOR
ABSORBER FEED
«* PUMPS
SERVICE
OXIDATION BLCMER
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
NUMBER
CIRCULATION
PH ADJUSTER CIRCULATION
REACTCR CIRCULATION
NUMBER
5
Z
1
989
-------
EPA UTILITY FGO SURV=' •TC.-ER - DECEMBER 1981
ELECTRIC POWER OEVELCFI.iNT: TAKASAGO 2 (CONT.)
** SOLIDS CCNCENTRATING/OEWATERING
DEVICE CENTRIFUGE
NUM3EP 7
CUTLET STREAM CHARACTERISTICS 90X SOLIDS
«*» SOLIDS CCNCEHTRATING/DEHATERIMS
DEVICE THICKENER
CUTLET STREAM CHARACTERISTICS 20X SOLIDS
**« SALEABLE BYPRODUCTS
NATURE GYPSUM
FULL LOAD QUANTITY - M T/H 8.62 ( 9.50 TPH)
**tt SLUDGE
** TREATMENT
METHOD FORCED OXIDATION
DEVICE OXIDATION TAHK
PROPRIETARY PROCESS N/A
»* DISPOSAL
MATURE NR
TYPE NR
SITE TREATMENT NH
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS FLUE GAS VOLUME & S02 CONCENTRATION
»« WATER BALANCE
MATER LOOP TYPE OPEN
POND SEEPAGE/RUNOFF MATER LOSS - LITERS/S 40
MAKEUP MATER ADDITION - LITERS/S 13.1 ( 208 GFM)
PEPFOPMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HCURS HOURS KOU.7S FACTOR
3/76
4/76
5/76
6/76
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100
100
100
100
.0
.0
.0
.0
100
100
29
67
.0
.0
.0
.8
744
720
744
720
744
720
216
632
720
7CO
216
632
*» PR03LEMS/SOLUTIONS/COMMENTS
THE SYSTEM HAS 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
9/76 SYSTEM 100.0 100.0 720 720 720
10/76 SYSTEM 94.2 94.2 744 744 701
»» PROBLEMS/SOLUTIOHS/CCMMENTS
OUTAGE TIME DURING OCTOBER MAS NECESSARY FCR DUCT CLEANING.
11/76 SYSTEM 100.0 100.0 720 720 720
12/76 SYSTEM 99.3 99.3 744 744 739
990
-------
EPA UTILITY F6D SURVEY: CCTC3ER - DECEASE"? 1981
ELECTRIC PCUER DEVELOPMENT: TAKASAGO 2 (CONT.)
PERFOPKAHCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
£02 PART. HOURS HOURS HC'JOS FACTCR
** PR03LEMS/SOLUTICNS/COKMENTS
THE SYSTEM MAS DOMN 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
** PRCBLEMS/SOLUTIONS/COMMENTS
OUTAGE TIME IN FEBRUARY I MARCH MAS NEEDED FOR CLEANING CF A PH CONTROLLER.
4/77 SYSTEM 100.0 100.0 720 720 720
5/77 SYSTEM 100.0 51.6 744 384 234
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/SOLUTICNS/COMMENTS
CLEANING OF THE PH CONTROLLER CAUSED ONE OUTAGE DURING NOVEMBER.
A REACTOR MAS 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
8/78 SYSTEM 744
9/78 SYSTEM 720
10/78 SYSTEM 744
11/78 SYSTEM 720
12/73 SYSTEM 744
1/79 SYSTEM 744
991
-------
EPA UTILITY FGO SL'PVEY: OCTOBER - DECEMBER 1981
ELECTRIC PCWER DEVELOPMENT: TAKASAGO 2 (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY CPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HOU3S HCL'RS hCUHS FACTOR
2/79 SYSTEM 672
3/79 SYSTEM 744
»* FR03LEMS/SOLUTIOMS/COMMENTS
DURING THE PERIOD FPOM APRIL 1978 THROUGH MARCH 1979 THE FG3 SYSTEM
OPERATED WITH 99.OX AVAILABILITY. THERE WERE NO FORCED OUTAGES DURING THIS
TIME. A TOTAL OF 8147.4 HOURS OF FGD SYSTEM OPERATION WEPE LC3GED 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
I/SO SYSTEM 744
2/30 SYSTEM 696
3/30 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
NO INFORMATION HAS AVAILABLE FOR THE APRIL 1979 THROUGH MARCH I960 PERICD.
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
»« PRCBLEMS/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
«* PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER MAS SHUTDOWN FROM JUNE 3 TO JUNE 24 FOR ANNUAL MAINTENANCE.
THE FGD SYSTEM OPERATED ALONG WITH THE BOILER THE REMAINDER OF THE TIMS.
7/80
8/80
9/80
10/60
11/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100
100
100
100
100
.0
.0
.0
.0
.0
100.0
100.0
100.0
100.0
100.0
92.80
92.80
93.10
92.60
744
744
720
744
720
744
744
720
744
720
744
744
720
744
7CO
83.0
83.3
83.4
65.1
84.8
992
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEXSsR 1931
ELECTRIC POHE9 DEVELOPMENT: TAKASAG3 2 (COHT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OFERABILITY RELIABILITY UTILIZATION 7. REMOVAL PcP EOILER FG3 CAP.
S02 PART. HCU'S HOL'SS HCL3S FACTO?
12/30 SYSTEM 100.0 100.0 100.0 67.3 92.60 744 649 649 78.4
*» PSOBLEMS/SOLUTIC.NS/COKMENTS
DURING JULY THROUGH DECEMBER NO FGD-RELATED PROBLEMS MERE EXPERIENCED.
IN DECEMBER THE BOILER WAS OUT OF SERVICE APPROXIMATELY FOUR DAYS FOR
GENERAL MAINTENANCE.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIP*; HOWEVER THE
DATA MILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
993
-------
EPA UTILITY FC-0 S'.'-VEY: OCTOBER - DECEMBER 1981
SECTION 15
DESIGN AND PEPFC3MANCE DATA FOR OPERATIONAL FOREIGN FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
COUNTRY
FEGULATCRY CLASSIFICATION
PANICULATE EMISSION LI 'ITATICN - NG/J
S02 EMISSION LIMITATION - N3/J
UOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATIN3 CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY UO/FGO •• MM
EQUIVALENT SCRUBBED CAPACITY - KM
«* 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
«t* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
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
NUMBER
TYPE
*» ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPEPATURE - C
PARTICLE REMOVAL EFFICENCY - X
»« PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
LINER GENERIC 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
( .130 LB/MM3TU)
( .630 LB/MM3TU)
(»**«** LB/MM3TUJ
ELECTRIC POWER DEVELOPMENT
TAKEHARA
1
MIHARA
JAPAN
******
56.
271.
******
231
250
231
239
250
BABCOCK-HITACHI
PULVERIZED COAL
BASE
577.13
140.0
201.
CARBON STEEL
3.6
(1223000 ACFM)
( 284 F)
( e60 FT)
( 11.9 FT)
( 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 TOWER
NR
NR
HITACHI
ORGANIC
NONE
1
533.7
2.5
2.3
168.0
140.0
( 8471 GPM)
(18.7 GAL/1000ACF)
( ".I IN-H20)
( 356000 ACFM)
( 284 F)
994
-------
EPA UTILITY FGD SURVEY: CCTC£EH - DEC=K3ER 1«31
ELECTPIC POWER DEVELOPMENT: TAKEHARA 1 (COMT.>
*»» FGO STSTEtl
** GENEPAL DATA
SALEABLE PPCDUCT/THROUAWAY PRODUCT
302 REMOVAL MCDE
FFCCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT OESIC-N S02 REMOVAL EFFICIENCY - X
EHEfiGY CONSUMPTION - X
CURRENT STATUS
COMMERCIAL START-UP
INITIAL START-UP
«» DESIGN AKO OPERATING PARAMETERS
** CUENCKER/FRESATURA70R
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE MAME/CCKMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC HATERIAL
LINER SPECIFIC MATERIAL
LTMER MATERIAL TRADE NAKE/COMHON TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
INLET GAS FLOU - CU. M/S
INLET GAS TEMPERATURE - C
** MIST ELIMINATOR
FRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBE9 PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/TOW.ON TYPE
CONFIGURATION
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH MATER SOURCE
WASH FREQUENCY
WASH RATE - L/S
** R EM EATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
ZNLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» FANS
NUMBER
FUNCTION
APPLICATION
SERVICE
SALEABLE FB03UCT
MET SCRU33IMG
L:MESTCNE
NC>:=
BAE.SCK-HITACHI
FULL SCALE
RETROFIT
X 91.70
94.20
3.2
1
2/79
2/77
Kt?
NR
TRAY TOMER
MR
NR
BABCOCK-KITACHI
CARBON STEEL
NR
H/A
ORGANIC
POLYESTER
NR
5
721.
7.0
3.0
164.76
52.2
(11446 GFM)
( 52.4 GAL/1000 ACF)
(15.2 IN-H20)
( 340142 ACFM)
( 126 F)
PRIMARY COLLECTOR
Z
IMPINGEMENT
TUBE BANK
VERTICAL PARALLEL TUBE BANK
HORIZONTAL
.1
NR
NR
FRESH
CONTINUOUS
( .4 IN-H20)
1.3
( ZO GAL/MIN)
DIRECT COMBUSTION
NR
OIL
120.0 I 24S F)
KR
NR
2
BOOSTER
INDUCED DRAFT
WET
995
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ELECTRIC FCHER DEVELOPMENT: TAKEHARA 1 ICONT.)
** DAMPEPS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
*« REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
»« TA»«S
SERVICE
PRESCRUBBEH RECYCLE
SCRUBBER RECYCLE
FILTER LIQUID
SLURRY
OXIDATION TOMER FEED
PUMPS
SERVICE
COOLER RECYCLE
ABSORBER RECYCLE
«* SOLIDS CCNCENTRATING/OEMATERING
DEVICE
NUMBER
NUMBER OF SPARES
CAPACITY
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
*« SOLIDS CONCENTRATING/OEWATERING
DEVICE
NUMBER
CONFIGURATION
DIMENSIONS - FT
FEED STREAM CHARACTERISTICS
OUTLET STREAM CHARACTERISTICS
«»» SALEABLE BYPRODUCTS
NATURE
FULL LOAD QUANTITY - M T/H
QUALITY - 7.
DISPOSITION
**« SLUDGE
** TREATMENT
METHOD
DEVICE
PROPRIETARY PPOCESS
«» DISPOSAL
NATURE
TYPE
SITE TREATMENT
*« PPOCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
NUMBER
««**
2
NUMBER
2
4
CENTRIFUGE
9
1
4 GPM
ZOX SOLIDS
88X SOLIDS
THICKENER
1
HORIZONTAL
45.0 OIA X 10.0
12X SOLIDS
20X SOLIDS
GYPSUM
9.89
95.0
MARKETED
( 10.90 TPH)
FORCED OXIDATION
OXIDATION TANK
N/A
NR
NR
NR
PH. GAS FLOW
PH 5.0-6.0
996
-------
EPA UTILITY FGO SURVEY: CCTC3ER - DECEMBER 1«S1
ELECTRIC POWER DEVELOPMENT: TAKEHARA 1 (CONT.)
PPOCESS CONTROL MANNER AUTOMATIC
** UATER BALANCE
WATEP LCOP TYPE OPEN
POilD SEEPAGE/RUNOFF MATER LOSS - LITERS/S 60
MAKEUP MATER ADDITION - LITERS/S 14.9 ( 237 GFtl)
PERFORMANCE DATA
FERICD MODULE AVAILABILITY OPEHABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FCD CA?.
S32 PART. HOL-'SS HC'J?S KCL"S FACTCH
4/78 SYSTEM 720
5/78 SYSTEM 74*
6/78 SYSTEM 720
7/78 SYSTEM 744
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
*» PH03LEMS/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
997
-------
EPA UTILITY FG3 SURVEY: CCTC3ER - DECEMBER 1931
EL:CT3XC FCXER DEVELOPMENT: TAKEHARA 1 (CONT.)
PERFORMANCE DATA
PERIOD MC3ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HOL.SS HOUPS HC'J=S FACTOR
M* FSC3LEMS/SOLUTICNS/COKMENTS
NO INFORMATION WAS AVAILABLE F0!7 THE APRIL 1979 THROUGH MARCH 1989 PERIOD.
4/80 SYSTEM 100.0 100.0 100.0 100.0 723 720 7CO
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
*» PH03LEMS/SOLUTIONS/COKKENTS
THE FGD SYSTEM MAS OUT OF SERVICE FOR APPROXIMATELY 3 DAYS IN JUNE TO
REMOVE THE SCALE ACCUMULATION IN THE F6D CUTLET 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
55.3
95.3
** PROBLEMS/SOLUTIONS/COMMENTS
NO PROBLEMS HERE 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 £06 £06 22.4
»» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER MAS OUT OF SERVICE FROM DECEMBER 1 THROU3H DECEMBER 25 FOR
SCHEDULED MAINTENANCE.
1/81 SYSTEM 744
2/81 SYSTEM 672
3/81 SYSTEM 744
** PHOSLEMS/SOLUTIOMS/COMMENTS
THE FIRST QUARTER 1981 DATA IS NOT AVAILABLE AT THIS TIME; HCWEVER THE
DATA WILL BE AVAILABLE IN THE SECOND QUARTER 1981 REPORT.
998
-------
EPA UTILITY FGD SURVEY: OCTOBER - OECEM3ES 19£1
SECTION 15
DESIGN AND PERFORMANCE DATA FOR OPERATIONAL FOPEIGN FGD SYSTEMS
C3MPANY NAME
PLANT HAKE
UNIT NUM3ER
CITY
C3UNTRY
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOI EMISSION LIMITATION - NG/J
HOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGD - MW
MET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.tl/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - fl
*» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
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
«» ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS CAPACITY - CU.M/S
INLET FLUE GAS TEMPERATURE - C
PRESSURE DROP - KPA
PARTICLE REMOVAL EFFICENCY - X
»« PARTICLE SCRUBBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
GAS CONTACTING DEVICE TYPE
INLET GAS FLOM RATE - CU.M/S
INLET GAS TEMPERATURE - C
»«« FGD SYSTEM
*« GENERAL DATA
SALEABLE FROOUCT/THROMAWAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
HOKKAIDO ELECTRIC PCWER
TOMATOATSUMA THERMAL POM
1
TOMAKOMAI
JAPAN
******
****««
******
******
350
350
175
175
350
BABCOCK-HITACHI
PULVERIZED COAL
BASE
503.21
121.1
170.
CARBON STEEL
4.5
(***»** LB/MP3TU)
(*»**** LB/FM3TU)
(*****» LB/r.KSTU)
(1076939 ACFM)
( 250 F)
( 553 FT)
( 14.6 FT)
COAL
BITUMINOUS
******
20.50
***»»«
7.00
*»**»»
.30
********
******
4
HOT SIDE
HITACHI
628.6
363.9
.2
99.8
(108000 BTU/LB)
******
(1756252 ACFM)
( 687 F)
( 1. IN-HZO)
VENTURI TOMER
NR
NR
BABCOCK-HITACHI
NONE
198.7 (
47.2 (
421036 ACFM)
117 F)
SALEABLE PRODUCT
MET SCRUBBING
LIMESTONE
BABCOCK-HITACHI
FULL SCALE
RETROFIT
999
-------
EPA UTILITY FG3 SURVEY: CCTC3ER - DECEMBER 1981
HOKKAIDO ELECTRIC POWER: TOMATOATSUMA THERMAL POM 1 (CONT.)
UNIT OESI3J1 S02 REMOVAL EFFICIENCY - 7.
ENERGY CCJiUMPTICN - X
CU7.-ENT STATUS
CCMMEPCIAL START-UP
INITIAL START-UP
»» DESIGN AND OPERATING PARAMETERS
<** qUENCHES/P=ESATURATCR
CCMSTPUCTICN MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE HAME/COMKON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRiCE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
INLET GAS FLOM - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
*« MIST ELIMINATOR
PRE-MIST ELIMINATOR/HIST ELIMINATOR
NUMBEf. PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» REHEATEH
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOU RATE - CU. M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*« FANS
HUM3ER
DESIGN
SUPPLIER
FUNCTION
FLUE GAS FLOU RATE - CU.M/S
FLUE GAS TEMPERATURE - C
»« DAMPERS
FUNCTION
GENEOIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
90.00
.0
1
10/60
7/30
NR
MR
1
NR
NR
NR
BABCOCK-HITACHI
NR
NR
MR
NR
NR
NR
198.69
47.2
90.0
421036 ACFM)
117 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
NR
VERTICAL
NR
NR
WASTE HEAT RECOVERY
GAS-GAS
WHEEL TYPE
14.3
65.6
199.17
NR
NR
( 118 F)
( 422057 ACFM)
CENTRIFUGAL
HITACHI.LOT.
BOOSTER
254.47
137.2
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
m
NR
1
( 530247 ACFM)
( 279 F)
1000
-------
EPA UTILITY FGD SURVEY: OCTC3ER - DECEM2ER 1981
HOKKAIDO ELECTRIC POWER: TCMATOATSUMA THERMAL POM 1 (COHT.)
PRODUCT QUALITY - X SOLIDS 92.0
** SOLIDS CONCENTRATING/DEMATERING
DEVICE THICKENER
NUM3ER 2
«» SCLIOS CONCENTRATING/DEUATERING
DEVICE CENTRIFUGE
IIUM3ER 3
NUMBER OF SPARES 1
««« SALEABLE BYPRODUCTS
NATURE GYPSUM
QUALITY - •/. 45.0
DISPOSITION MARKETED
*»« SLUDGE
»>* TREATMENT
METHOD Nft
DEVICE NR
PROPRIETARY PROCESS NR
** DISPOSAL
NATURE NR
TYPE NR
SITE TREATMENT NR
*» MATER BALANCE
MATER LOOP TYPE CLOSED
MAKEUP MATER ADDITION - LITERS/S 4.0 ( 63 GPM)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HC'JRS 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
12/80 SYSTEM 100.0 100.0 100.0 100.0 94.10 744 744 744 94.7
«» PROBLEMS/SOLUTIONS/COMMENTS
DURING DECEMBER SCALE FORMATION MAS OBSERVED IN THE PIPING AND IN A PUMP OF
THE HASTE MATER TREATMENT FACILITY. A WATER MASH LINE MAS INSTALLED PCS
THE PIPING AND A PUMP MAS ADDED TO ELIMINATE SCALE. THE FGD SYSTEM
OPERATION MAS NOT AFFECTED DURING THIS TIME.
1001
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT HAKE
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
H3X EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MW
GROSS UNIT GENERATING CAPACITY - MM
MET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY KO/F60 - MM
EQUIVALENT SCRUBBED CAPACITY - MM
»» UNIT DATA - EOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
EOILE9 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
RANSE HEAT CONTENT - BTU/LB
AVERAGE ASH CCNTENT - 7.
RANGE ASH CCNTENT - 7.
AVERAGE MOISUPE CONTENT - X
RANSE MOISTURE CONTENT - X
AVERAGE SULFUR CCNTENT - X
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
RANSE CHLORIDE CONTENT - 7.
•«» PARTICLE CONTROL
»« MECHANICAL COLLECTOR
NUMBER
TYPE
»• ESP
»* PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
»«» FGD SYSTEM
«• GENERAL DATA
SALEABLE PROOUCT/THROHAHAY PRODUCT
SOS REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
ENEPGY CONSUMPTION - 7.
CURRENT STATUS
TERMINATION
INITIAL START-UP
ARIZONA PUBLIC SERVICE
FOUR CORNERS
5A
FARMINGTON
NEW MEXICO
D
21.
258.
»»**»»
2089
755
.050 LB/MMBTU)
.600 LB/MMBTU)
LB/MMBTU)
I
(
(»**»»*
**«*»
755
»*»»»»
PULVERIZED COAL
BASE
«*«••»»»
»•»****
»**»«»
**»»*»
•««*«*«
(«*«»*»* ACFM)
(»**» F)
(«»»» FT)
(«»*«« FT)
COAL
SUBBITUMINOUS
22562. ( 9700 BTU/LB)
*«*»*»
24.00
•*»»•»»
11.00
*»»*«*
.61
**«»»*«*
•*»»•»
0
NONE
NONE
N/A
N/A
N/A
THROUAUAY PRODUCT
WET SCRUBBING
LIME
SOUTHERN CALIFORNIA EDISON
BECHTEL
EXPERIMENTAL
RETROFIT
.0
a
12/76
2/76
1002
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1961
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A CCONT.)
»* DESIGN AND OPERATING PARAMETERS
»* OUENCHER/PPESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«* ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/CCHMCN TYPE
DIMENSIONS - FT
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
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
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» FANS
NUMSER
FUNCTION
APPLICATION
CONSTRUCTION MATERIAL GENERIC TYPE
«« DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«» DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«« REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
»» PUMPS
SERVICE
SLURRY RECIRCULATION
NR
NR
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
HORIZONTAL SPRAY CHAMBER
60.0 X 28.0 X 17.0
CARBON STEEL
AISI 1110
N/A
ORGANIC
NATURAL RUBBER, GLASS FLAKE-FILLED POLYESTER
BLACK NATURAL RUBBER. NR
NONE
5
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
STAINLESS STEEL, CARBON STEEL
NR
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
KR
NR
1
BOOSTER
FORCED DRAFT
MANGANESE, VANADRUM STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
SLAKER
OETENTSN
N/A
1
NUMSER
12
1003
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A (CONT.)
Reproduced from
best available co
»* SOLIDS CONCENTRATING/DEUATEHING
DEVICE
NUMBER
DIMENSIONS - FT
SHELL GENERIC MATERIAL TYPE
OUTLET STREAM CHARACTERISTICS
•«» SLUDGE
«» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«* DISPOSAL
NATURE
TYPE
SITE TREATMENT
THICKENER
1
60.0 DIA
CARBON STEEL
302 SOLIDS
NR
NR
NR
NR
NR
NR
... PERFORMANCE DATA—-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PEA BOILER FGO CAP.
302 PART. HOURS HOURS HOURS FACTOR
2/76 SYSTEM
692
*« PROBLEMS/SOLUTIONS/COMMENTS
3/76 SYSTEM
4/76 SYSTEM
UNIT NO. 5 HAS FIRST PLACED IN COMMERCIAL OPERATION IN JULY 1970. THE FGD
SYSTEM WHICH HAS RETROFITTED ON UNIT NO. 5 UAS A UEIR HORIZONTAL CROSSFLOW
SPRAY ABSORBER WHICH UAS FORMERLY INSTALLED AND OPERATED IN A TEST PROGRAM
AT THE MOHAVE GENERATING STATION OF THE SOUTHERN CALIFORNIA EDISON CCMPAHY.
THE HORIZONTAL MODULE UAS A FOUR-STAGE SCRUBBINS CHAMBER. EACH STAGE
CONTAINED A ROU OF 36 EXTERNALLY, MOUNTED NOZZLES. THE SLUPRY MAS CYCLED
THROUGH THE SCRUBBER IX A COUNTERCURRENT MANNER AT A RATE OF 36,000 GPM/
STAGE. THE FRESH LIME SLURRY UAS SPRAYED ACROSS THE FLUE GAS AT THE FOURTH
STAGE. WHICH UAS THE DISCHARGE END OF THE SCRUBBING CHAMBER. THE SCRUS3IN3
SOLUTION UAS 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 6ASES THEN PASSED THROUSH A MIST ELIMI-
NATOR AND HERE 'REHEATED BEFORE BEING DISCHAR5ED TO THE STACK. THE SPENT
SLURRY UAS DISCHARGED FROM THE SCRUBBING SYSTEM TO A THICKENER AND THE
UNDERFLOW UAS PUMPED TO AN ON-SITE SETTLING POND. UATER UAS RETURNED TO
THE PROCESS FOR FURTHER USE.
INSTALLATION OF THE MODULE AT THE FOUR CORNERS GENERATING STATION UAS
COMPLETED AND THE SYSTEM UAS PLACED IN SERVICE ON FEBPUARY 17, 1976, FOR
INITIAL OPERATION.
744
720
«* PROBLEMS/SOLUTIONS/COMMENTS
5/76 SYSTEM
6/76 SYSTEM
7/76 SYSTEM
8/76 SYSTEM
9/76 SYSTEM
THE FGD SYSTEM UAS TAKEN OFF LINE IN MID-APRIL FOR A SCHEDULED BOILER
OVERHAUL. THE SYSTEM UAS SCHEDULED TO COME BACK ON LINE IN JULY 1976.
744
720
744
744
720
1004
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ARIZONA PUBLIC SERVICE: FOUR CORNERS 5A (COHT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOUPS HOLRS HCU'S FACTOR
«» PROBLEMS/SOLUTICNS/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
1Z/76 SYSTEM 744
»» PR09LEMS/SOLUTIONS/CCMMENTS
THE PROTOTYPE WAS IN SERVICE THROUGHOUT THE MONTH OF NOVEMBER. ON
DECEMBER 6 THE TEST PROGRAM MAS CONCLUDED AND THE UNIT MAS DISMANTLED.
1005
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
=LANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOZ EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MU
GROSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY U/FGO - MW
NET UNIT GENERATING CAPACITY HO/FGO - MK
EQUIVALENT SCRUBBED CAPACITY - MW
»« WIT 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/6
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTUPE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CONTENT - X
RANGE SULFUP CONTENT - X
AVERAGE CHLORIDE CCNTENT - X
RANGE CHLORIDE CONTENT - 7.
•wi PARTICLE CONTROL
«* MECHANICAL COLLECTOR
NUMBER
TYPE
«• FABRIC FILTER
NUMBER
TYPE
•• ESP
«» PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
»"« FGO SYSTEM
BOSTON EDISON
MYSTIC
6
EVERETT
MASSACHUSETTS
»*»*••
*«»0tt*
*•««»*
**»•»
150
•*•*«
«**«*
150
COMBUSTION ENGINEERING
OIL FIRED
«««*«»
273.70
148.9
99.
(«*«*«• LB/MM3TU)
(*»»««» LB/MM3TU)
(*«««»« LB/M.-.BTU)
( 580000 ACFMI
( 300 F)
( 325 FT)
»»»«•»*
OIL
NO. 6
•*•*«»
.07
»*•»••
1.00
••*••»
z.oo
*«««»«
•«*••*«*
(*»»«» FT)
(»**•** BTU/LB)
»«**»*
0
NONE
0
NONE
NONE
N/A
N/A
N/A
*• GENERAL DATA
SALEABLE PRODUCT/THROHAHAY PRODUCT
SOZ REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X
UNIT DESIGN SOZ REMOVAL EFFICIENCY - X
SALEABLE PRODUCT
MET SCRUBBING
MAGNESIUM OXIDE
GE ENVIRONMENTAL SERVICES
DEMONSTRATION
RETROFIT
55.00
90.00
WARNING MUNNORMALIZED NUMBERCSI BEING EDITED FOR OUTPUT**
ENERGY CONSUMPTION - X .0
1006
-------
EPA UTILITY FGD SURVEY: OCTOBER - OECEK3ER 1981
BOSTON EOISON: MYSTIC 6 (CONT.)
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
•» DESIGN AND OPERATING PARAMETERS
«» QUENCHER/PRE5ATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» ABSOPBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON 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
GAS CONTACTING DEVICE TYPE
WK3ER CF CONTACTING ZCNES
LIQUID RECIRCULATIOH RATE - LITER/S
L/G RATIO - L/CU.M
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
«* MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NU.-.3ER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
NUMBER OF PASSES PER STAGE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH MATER SOURCE
«» REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» FANS
NUMBER
APPLICATION
»» DAMPEPS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«« DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
v* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
8
7/74
4/7Z
4/7Z
NR
MR
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
CARBON STEEL
NS
N/A
ORGANIC
EPOXY
NR
N/A
1
945. (15000 GPM)
4.4 ( 33.0 GAL/1000 ACF)
200.56 ( 425000 ACFM)
148.9 ( 300 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
6
NR
NR
FRESH
0
NONE
N/A
N/A
NONE
N/A
INDUCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
SLAKER
NR
NR
1007
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1961
BOSTON EDISON: MYSTIC 6 (CONT.)
«« SOLIDS CONCENTRATING/OEHATERING
DEVICE CENTRIFUGE
tAIKSER 1
SHELL GENERIC MATERIAL TYPE CARBON STEEL
FEED STREAM CHARACTERISTICS 102 SOLIDS
**• SLUDGE
»• TREATMENT
METHOD MR
DEVICE NR
PROPRIETARY PROCESS NR
** DISPOSAL
MATURE N/A
TYPE NONE
SITE TREATMENT NR
»» PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PAPAMETERS PH, FLUE GAS INLET TEMP., SCRUBBER OUTLET TEMP.
CONTROL LEVELS PH 6.8
MONITOR LOCATION PH - BLEED LINE FROM ABSORBER TO CENTRIFUGE
PROCESS CONTROL MANNER MANUAL
PROCESS CHEMISTRY MODE FEEDBACK
«• WATER BALANCE
HATER LCOP TYPE CLOSED
-. . PERFORMANCE DATA
PERIOD MCCULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/72 SYSTEM
«• PROBLEMS/SOLUTIONS/COMMENTS
•THIS EXPERIMENTAL MAGNESIUM OXIDE SCRUBBING UNIT UAS RETROFITTED ON A 155
MU, OIL FIRED BOILER. THE SULFUR DIOXIDE AND PARTICLE MATTER REMOVAL
OCCURRED IN THE VENTURI SCRU33EH MODULE. THE S02 UAS CAPTURED AND CON-
VERTED TO MAGNESIUM SULFITE IN THE VENTURI. THE PRODUCT SLL'PRY UAS THEN
FILTERED AND DRIED. THE DRY MATERIAL CALCINED AT HIGH TEMPERATURES TO
DRIVE OFF THE SO2 AND REGENERATE MAGNESIUM OXIDE. THE 502 STREAM UAS
PROCESSED IN A SULFURIC ACID PLANT TO PRODUCE SULFURIC ACID. THE UTILI-
TY AND THE EPA PROVIDED THE MAJOR PORTION OF THE FUNDING FOt THIS
REGENERABLE DEMONSTRATION PROJECT.
5/73 SYSTEM
«• PR03LEMS/SOLUTIONS/COMMENTS
FROM INITIAL STARTUP IN APRIL 1972 UNTIL HAY 1973 THE SCRUBBER OPERATED
INTERMITTENTLY BECAUSE OF MECHANICAL DIFFICULTIES. THE MAJ03 PROBLEM
ENTAILING DESIGN AND OPERATION OF THE MAGNESIUM SULFITE CRYSTAL DRYER,
APPARENTLY UAS 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
DURING JUNE AND JULY THE LONGEST PERIOD OF CONTINUOUS OPERATION OCCURRED.
THE SYSTEM OPERATED 7.5 DAYS.
8/73 SYSTEM .0 744 0
1008
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
BOSTCN EDISON: MYSTIC 6 ICONT. )
PERFORMANCE DATA
PEPIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HCUSS HOURS FACTOR
•» PROBLEMS/SOLUTIONS/CORMENTS
DURING AUGUST THE BOILER HAS TAKEN OFF-LINE FOR AN ANNUAL OVERHAUL.
9/73 SYSTEM 36.1 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 LIGUCR RECIR-
CULATION PUMPS AND CENTRIFUGE DECREASED THE AVAILABILITY OF THE FGD SYSTZM.
11/73 SYSTEM £5.6 22.5 720 629 162
12/73 SYSTEM 13.1 11.6 744 656 66
1/74 SYSTEM 27.4 20.4 744 555 152
2/74 SYSTEM 25.5 20.5 672 541 133
*« 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
»* PR08LEMS/SOLUTIONS/COHMENTS
SINCE FEBRUARY 1974 THE AVAILABILITY OF THE BOILER HAS INCREASED.
4/74 SYSTEM 80.5 65.4 720 585 471
«» PRCBLEMS/SOLUTIONS/COKMENTS
DURING APRIL> TWO 7-DAY CONTINUOUS OPERATION PERIODS OCCURRED.
5/74 SYSTEM 57.4 37.6 744 468 280
»» PROBLEMS/SOLUTIONS/COMMENTS
DURING MAY, A TWO WEEK OUTAGE OF THE ACID PLANT MAS THE CAUSE OF A LOU
FGD SYSTEM OPERABILITY FIGURE.
6/74 SYSTEM 51.5 40.0 720 559 288
«« PROBLEMS/SOLUTIONS/COMMENTS
DURING JUNE 1974 THE DEMONSTRATION PROGRAM MAS COMPLETED AND THE FGD
SYSTEM WAS SHUTDOWN. EPA FUNDING OF THE CALCINING PORTION OF THIS OPERA-
TION EXPIRED. THERE WERE NO DEFINITE PLANS FOR RESTARTING THIS UNIT.
MAJOR PROBLEM AREAS ENCOUNTERED DURING THE OPERATION OF THIS PROTOTYPE
UNIT INCLUDED TRIHYORATE 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.
1009
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1961
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
MET PLAN' GENERATING CAPACITY - MM
G=OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENEPATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«» UNIT DATA - EOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SEPVICE 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 - X
RAN3E ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RAN3E SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
»«« PARTICLE CONTROL
«» MECHANICAL COLLECTOR
tiUKSER
TYPE
« FABRIC FILTER
NUMBER
TYPE
»» ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
«* PARTICLE SCRUBBER
NUMEEH
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
COMMONWEALTH EOISCN
MILL COUNTY
1A
ROUE OVULE
ILLINOIS
E
86.
774.
*«
-------
EPA UTILITY F6D SURVEY: OCTC9ER - DECEMBER 1931
CCMMONHEALTH EDISON: MILL COUNTY 1A (CONT.l
LIQUID RECIRCULATION RATE - LITER/S
L/6 RATIO - LITER/CU.M
PRESSURE DROP - KPA
SUPERFICIAL GAJ VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICIENCY - 7.
*** FGD SYSTEM
«* GENERAL DATA
SALEABLE FRODUCT/THROWAMAY PRODUCT
SO: REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIR.1
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
ENERGY CONSUMPTION - 7.
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
»» DESIGN AND OPERATING PARAMETERS
»• QUENCHER/PRESATURATCR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» ABSORBER
NUM2ER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TPAOE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
LIQUID RECIRCULATION RATE - LITER/S
L/G RATIO - L/CU.M
GAS-SIDE PRESSUPE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - 7.
*• MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TPADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUMBER OF PASSES PER STAGE
FREEBOARD DISTANCE - M
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
UASH HATER SOURCE
365.4
2.4
2.2
36.6
181.7
179. it
98.0
( 5800 GPM)
(18.0 GAL/1000ACF)
( 9.0 IN-H20)
( 120.0 FT/SI
( 385000 ACFM)
( 355 F)
THROMAUAY PRODUCT
WET SCRUBBING
LIMESTONE
BABCOCK t WILCOX
BECHTEL
FULL SCALE
RETROFIT
7. 98.00
76.00
.0
8
7/77
2/73
2/72
NR
NR
TRAY TOMER
SIEVE TRAY
N/A
BABCOCK I HILCOX
16.0 X 24.0 X 60.0
CARBON STEEL
HIGH STRENGTH LOU ALLOY
COR-TEN
ORGANIC
NATURAL RUBBER
BLACK NATURAL RUBBER
PERFORATED TRAYS
2
693.
4.7
2.5
3.0
181.68
179.4
76.0
(11000 GPM)
( 35.0 GAL/1000 ACF)
(10.0 IH-H20)
( 10.0 FT/S)
( 3S5000 ACFM)
( 355 F)
PRIMARY COLLECTOR
2
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
2
3
3.05
3.8
45
.2
ORGANIC
FIBER-REINFORCED POLYESTER
BLENDED
(10.0 FT)
( 1.50 IN)
( 1.0 IN-H20)
1011
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
COMMONWEALTH EDISON: MILL COUNTY 1A (CONT.)
MASH FREQUENCY
HASH RATE - L/S
»» REKEATER
NUN3EH
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOW RATE - CU. H/S
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» FANS
NUMBER
FUNCTION
APPLICATION
FLUE GAS TEMPERATURE - C
*» DAMPERS
FUNCTION
GENEPIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* OUCTW01K
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
** REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
FULL LOAD DRY FEED CAPACITY - M.TONS/HR
PRODUCT QUALITY - X SOLIDS
«« TANKS
SERVICE
SCRUBBER RECYCLE
*» PUMPS
SERVICE
VENTURI RECIPCULATION
ABSORBER RECIRCULATION
»« SOLIDS CONCENTRATING/DEUATERING
DEVICE
NUMBER
CONFIGURATION
DIMENSIONS - FT
*» SOLIDS CONCENTRATING/DEUATERING
DEVICE
NUMBER
CAPACITY
•»« SLUDGE
UNOERSPRAY-CONTINUOUS; OVERSF3AY-INTESMITTEHT
71.0 ( 1125 GAL/MIN)
2
IN-LINE
STEAM
NR
28.9 (
179.32 (
53.3 (
STAINLESS STEEL
AUSTENITIC
52 F)
38000C ACFM)
2
BOOSTER
INDUCED DRAFT
62.2 (
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
COMPAHTMENTED
NR
2
10.9 (
27.5
NUMBER
2
NUMBER
160 F)
12 TPH)
THICKENER
1
CIRCULAR. SLOPED BOTTOM
65.0 DIA X 15.0
VACUUM FILTER
1
90TON/DAY
1012
-------
COMMONWEALTH EDISON: MILL COUNTY 1A (CONT.)
EPA UTIL"Y FGO SURVEY: OCTCSER - DECEASES 1981
»» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«* DISPOSAL
NATURE
TYPE
LOCATION
SITE TREATMENT
»« DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
»« PROCESS CONTROL AMD INSTPUMENTATION
CHEMICAL PARAMETERS
PROCESS CONTROL MANNER
*» MATER BALANCE
WATER LOOP TYPE
FIXATION
PUS MILL
CHICAGO ADMIXTURES
INTERIM
POND
OH-SITE
CLAY LINING
FINAL
LANDFILL
OFF-SITE
TRUCK
PRESSURE, LIMESTONE FEED, PH
AUTOMATIC
CLOSED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
•/. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTCR
0/72 SYSTEM
*» PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR MILL COUNTY LOCATED IN
SECTION 14 OF THIS REPORT.
1013
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAf.E
UVIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - MM
G"OSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - MM
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUE3EO CAPACITY - MM
N» 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/S
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RAMSE ASH CONTENT - 7.
AVERAGE MOISTUPE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUS CONTENT - 7.
PANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
«»« PARTICLE CONTROL
«» ESP
NUMBER
*» PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
«*« FGO SYSTEM
*« GENERAL DATA
SALEABLE PRCDUCT/THROUAUAY PRODUCT
S02 REMOVAL MCOE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
DAIRYUND POMER
ALMA
5
ALMA
WISCONSIN:
«•«•*»
**•«•*
*«*«»*
«*»*«»
210
60
»•*«•
•»*«»
80
»*»*«»
•»*«**
*••*•»
»«»*«•»*
(»»«««» LB/MK8TU)
(»«*«*• LB/TK3TU)
(««**«* LB/MMBTU)
*»*»M»
•««*•»
***»»*»
COAL
•»•*••
(»»tHHHH. ACFM)
(»h«« F)
(MHt« FT)
(»*««« FT)
(*«*»«» BTU/LB)
10500-11000
•**••««<»
12.0-20.0
«**«»**»
3.0-3.5
•*«****•
•»*«»*
*»•«••«•
NONE
N/A
N/A
N/A
THROHAUAY PRODUCT
MET SCRUBBING
LIME
FOSTER WHEELER
EXPERIMENTAL
RETROFIT
32. SO
WARNING «*UNNORMALIZEO NUMBER!S) BEING EDITED FOR OUTPUT**
ENERGY CONSUMPTION - 7.
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
•» DESIGN AND OPERATING PARAMETERS
.0
8
8/74
6/71
1014
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
DAIRYUND POWER: ALMA 5 (CONT. )
«* (JUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENEPIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NH
ft* ABSORBER
GENERIC TYPE KR
SPECIFIC TYPE NH
TRADE NAME/COMMON TYPE MR
SHELL GENERIC MATERIAL NR
SHELL SPECIFIC MATERIAL NR
SHELL MATERIAL TRADE NAME/COMMON TYPE NR
LINER GENERIC MATERIAL NR
LINER SPECIFIC MATERIAL NR
LINER MATERIAL TRADE NAME/COMMON TYPE NR
«» MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR NR
GENEPIC TYPE NR
SPECIFIC TYPE NR
TRADE NAME/COMMON TYPE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
«» REHEATER
GENERIC TYPE NR
SPECIFIC TYPE NR
TRADE NAME/COMTO.M TYPE NP
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
«« DAMPERS
FUNCTION NR
GENERIC TYPE NR
SPECIFIC TYPE NR
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
LINER GENERIC MATERIAL TYPE NR
LINER SPECIFIC MATERIAL TYPE NR
*» DUCTWORK
SHELL GENERIC MATERIAL TYPE NR
SHELL SPECIFIC MATERIAL TYPE NR
LINER GENERIC MATERIAL TYPE NP
LINER SPECIFIC MATERIAL TYPE NR
»» REAGENT PREPARATION EQUIPMENT
FUNCTION SLAKER
DEVICE NR
DEVICE TYPE NR
«* SOLIDS CONCENTRATING/DEMATERINS
DEVICE NA
««* SLUDGE
«* TREATMENT
METHOD NA
DEVICE NA
PROPRIETARY PROCESS NA
*« DISPOSAL
NATURE NR
TYPE NH
1015
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
DAIRYLAND POWER: AU1A 5 (CONT.)
PERF09MAHCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HOURS HOUPS HOU=?S FACTOR
6/71 SYSTEM
« PROBLEMS/SOLUTIONS/COMMENTS
THIS EXPERIMENTAL MET LIME FURNACE SYSTEM COMMENCED OPERATIONS IN JUNE
1971 AND WAS OPERATIONAL FOR PERIODS UP TO 30 DAYS. IN AU5UST 1974 THE
UNIT MAS TESTED FOR TWO DAYS USING WESTERN LOU-SULFUR COAL. THE TEST
SHOWED ABOUT SOX S02 REMOVAL EFFICIENCY, BUT ESP PERFORMANCE WAS ADVERSELY
AFFECTED. THE FGO PROJECT HAS BEEN SHUT DOWM INDEFINITELY SINCE AUGUST
1974, AND THERE ARE NO PLANS FOR FUTURE OPERATION.
1016
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FCR DISCONTINUED DOMESTIC FG3 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOS EMISSION LIMITATION - NG/J
N3X EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGO - MM
NET UNIT GENERATING CAPACITY UO/FGD - HW
EQUIVALENT SCRUBBED CAPACITY - MM
** UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.H/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
RAI.'SE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RAH3E MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORI3E CONTENT - X
RANGE CHLORIDE CONTENT - X
•*» PARTICLE CONTROL
«* MECHANICAL COLLECTOR
NUMBER
TYPE
»» FABRIC FILTER
NUMBER
TYPE
*• ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
*« PARTICLE SCRUE9ER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
LIQUID HECIHCULATION RATE - LITER/S
L/G RATIO - LITER/CU.M
PRESSURE DROP - KPA
DETROIT EDISON
ST. CLAIR
6A
BELLE RIVER
MICHIGAN
C
86.
1376.
»***»«
1798
325
154
163
163
COMBUSTION ENGINEERING
( .200 LB/MKBTU)
( 3.200 LB/rr&TU)
(««**•» LB/MKBTU)
PEAK
465.77
132.2
130.
*•«»»»
««»»»** (•*«*« PT)
( 987000 ACFM)
( 270 F)
( 425 FT)
( 9600 BTU/LB)
9500-9600
COAL
SUSBITUMINOUS
22330.
4.00
3.0-4.0
22.60
22.0-24.0
.35
0.3-0.4
«•»«•«**
««»«*•
0
NONE
0
NONE
MHEELABRATOR-FRYE
90.0
2
9/75
VFNTURI TOWER
VARIABLE-THROAT/ADJUSTABLE DRUM
RADUL FLOW VENTURI
PEAEODY-LURG:
STAINLESS STEEL
AUSTENITIC
ORGANIC
RUBBER
NONE
276.5 ( 4420 GPM)
2.7 (20.0 GAL/1000ACF)
3.5 (14.0 IN-H20)
1017
-------
EFA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
DETROIT EDISON: ST. CLAIR 6A (CONT.)
SUPERFICIAL GAS VELOCITY - H/S
IMLET GAS FlOU RATE - CU.M/S
INLET GAS TEMPERATURE - C
»•» FGD SYSTEM
28.3
116.6
132.2
( 93.0 FT/SJ
( 247000 ACFK)
( 270 F)
•» GENEPAL DATA
SALEABLE PRODUCT/THROUAUAY PRODUCT
502 REMOVAL MQ3E
P3CCES5 TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
THROUAMAY PRODUCT
WET SCRUBBING
LIMESTONE
PEABODY PROCESS SYSTEMS
BECHTEL
DEMONSTRATION
RETROFIT
X 99.70
90.00
WARNING *«UNNORMALIZED NUMSER(S) BEIN5 EDITED FOR OUTPUTS-
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
«* DESIGN AND OPERATING PARAMETERS
»• GUENCHER/PRESATIRATGR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*» ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON 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 CONTACTINS DEVICE TYPE
L/G RATIO - L/CU.M
GAS-SIDE PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. H/S
INLET GAS TEMPERATUPE - C
S02 REMOVAL EFFICIENCY - X
*» MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
NUMBER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
FREEBOARD DISTANCE - M
DISTANCE BETWEEN VANES - CM
VANE ANGLES - DEGREES
PRESSURE DROP - KPA
SUPERFICAL GAS VELOCITY - H/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TPAOE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS FLOU RATE - CU. M/S
.0
8
12/76
9/75
6/75
NR
NR
SPRAY TOWER
OPEN COUNTERCURRENT SPRAY
N/A
PEABODY PROCESS SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 316L
NONE
N/A
N/A
NONE
10.7 (80.0 GAL/1000 ACF)
2.3 (io.o IN-H:OI
2.9 ( 9.5 FT/S)
101.46 ( 215000 ACFM)
47.a ( 118 F)
90.0
PRIMARY COLLECTOR
2
CENTRIFUGAL
RADIAL VANE
RADIAL BAFFLE
HORIZONTAL
1.37 ( 4.5 FT)
20.3 ( 8.00 IN)
45
.0 ( .2 IN-HZO)
3.0 ( 10.0 FT/S)
STAINLESS STEEL
AUSTENITIC
DIRECT COMBUSTION
EXTERNAL COMBUSTION CHAMBER
OIL
.0
27.8 ( 50 F)
187.20 ( 396700 ACFM)
1018
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
DETROIT EDISON: ST. CUIR 6A (CONT.)
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*• FANS
NUMBER
SUPPLIER
FUNCTION
APPLICATION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
»* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«« DUCTUORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
•* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
PRODUCT QUALITY - 7. SOLIDS
»« PUMPS
SERVICE
50.0
NR
NR
( 122 F)
VENTURI RECIRCULATION
SPRAY TOMER RECIRCULATION
»» SOLIDS CONCENTRATING/DEWATERING
DEVICE
NUMBER
**» SLUDGE
»« TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«» 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
•• MATER BALANCE
WATER LOOP TYPE
PEABODY ENGINEERING
BOOSTER
INDUCED DRAFT
WET
TYPE 316L STAINLESS STEEL
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NONE
N/A
N/A
1
35.0
NUMBER
3
6
NONE
0
BLEED
N/A
N/A
FINAL
POND
PIPE LINE
NONE
1
PH. SOLIDS
PH 5.8-6.0. SOLIDS 15X
RECYCLE TANK
AUTOMATIC
FEEDBACK
OPEN
1019
-------
EPA UTILITY fGD SURVEY: OCTOBER - DECEMBER 1981
DETROIT EDISON: ST. CLAIR 6A (CONT.)
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
SOZ PART. HOURS HOUPS HCU'S FACTOR
0/75 SYSTEM
»* PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR ST. CLAIR 6 LOCATED IN
SECTION 14 OF THIS REPORT.
1020
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
C:TY
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/FGO - MW
NET UNIT GENERATING CAPACITY UO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.H/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 - X
RANGE MOISTUPE CONTENT - X
AVERAGE SULFU3 CONTENT - X
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - X
«»« PARTICLE CONTROL
•» ESP
NUMBER
** PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
••* FGO SYSTEM
** GENERAL DATA
SALEABLE PROOUCT/THROUAUAY PRODUCT
S02 REMOVAL MCOE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEK/RETROFIT
GULF POWER
SCHOLZ
1
SNEADS
FLORIDA
E
*««»**
«*«»*«
»«**««
60
20
•»**»
(««»«»« LB/MMSTU)
(«»««*« LB/MM3TU1
(»*»*«» LB/MM3TU)
20
BABCOCK t UILCOX
PULVERIZED COAL
BASE
50.02
*******
******
**»»«*
•*«•«»»
COAL
«*«««*
30905.
«*»•**»«
«**»«»
**««***»
******
3.25
3.0-3.5
«*«*****
»»*»**
( 106000 ACFM)
(»*»« F)
(»«»* FT)
(»»»*« FT)
( 12900 BTU/LB)
••*»*«
NR
NR
NR
THROHAUAY PRODUCT
WET SCRUBBING
DUAL ALKALI/LIMESTONE
THYSSEN/CEA
A.O. LITTLE
DEMONSTRATION
RETROFIT
WARNING "UNNORMALIZEO NUMBER(S) BEINS EDITED FOR OUTPUT**
ENERGY CONSUMPTION - X .0
CURRENT STATUS 8
INITIAL START-UP 8/80
»* DESIGN AND OPERATING PARAMETERS
*» QUENCHER/PRESATUBATOS
CONSTRUCTION MATERIAL GENERIC TYPE NR
CONSTRUCTION MATERIAL SPECIFIC TYPE NR
1021
-------
EPA UTILITY F63 SURVEY: OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ 1 (CCNT.)
«» ABSO'BER
GENERIC TYPE TRAY TOWER
SPECIFIC TYPE NR
TRADE NAME/COMMON TYPE NR
SHELL GENERIC MATERIAL NR
SHELL SPECIFIC MATERIAL NR
SHELL MATERIAL TRADE NAME/COMMON TYPE NR
LINER GENERIC MATERIAL NR
LINER SPECIFIC MATERIAL NR
LINER MATERIAL TRADE NAME/COMMON TYPE NR
»» MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** REHEATER
GENERIC TYPE
SPECIFIC TYPE
TiJAOE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
DESIGN
FUNCTION
APPLICATION
SERVICE
«» DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENEPIC MATERIAL T1PE
LINER SPECIFIC MATERIAL TYPE
*n DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENEPIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
*» SOLIDS CONCENTRATING/OEWATERING
DEVICE
NUMBER
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
•• SOLIDS CONCENTRATING/DEUATERING
DEVICE
NUM5ER
SHELL SPECIFIC MATERIAL TYPE
FEED STREAM CHARACTERISTICS
*«« SLUDGE
NR
NR
NR
NR
NR
NR
INDIRECT HOT AIR
NR
NR
22.2 ( 40 F)
NR
NR
CENTRIFUGAL
BOOSTER
INDUCED DRAFT
WET
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
THICKENER
1
CARBON STEEL
FLAKE REINFORCED LINING
VACUUM FILTER
1
FIBERGLASS
20X SOLIDS
1022
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
GULF POWER: SCHOLZ 1 (CONT.)
«» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
** DISPOSAL
NATURE
TYPE
SITE TREATMENT
*« WATER BALANCE
WATER LOOP TYPE
OEUATERED
N/A
N/A
FINAL
POND
CLAY LINING.
CLOSED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOUPS HOURS HOURS FACTOR
8/80 SYSTEM
744
«* PROBLEMS/SOLUTIONS/COMMENTS
INITIAL OPERATION OF THIS DEMONSTRATION LIMESTONE DUAL ALKALI SYSTEM BEGAN
ON AUGUST 20. OPERATIONS DURING THE REST OF THE MONTH WERE INTERMITTENT
AS MECHANICAL PROBLEMS MERE RECTIFIED.
9/60 SYSTEM
10/80 SYSTEM
11/80 SYSTEM
»» PROSLEMS/SOLUTIOHS/COMMENTS
720
744
720
THE FGD SYSTEM CONTINUED TO OPERATE THROUGH NOVEMBER IN A DEBUGGING MODE
OF OPERATION.
12/60 SYSTEM
75.9
744
565
•* PRC3LEMS/SOLUTIOHS/COMMENTS
DURING DECEMBER THE DEMONSTRATION FGD SYSTEM OPERATED CONTINUOUSLY FOR
TWO EIGHT DAY PERIODS. DURING THIS TIME THE SYSTEM S02 REMOVAL EFFICIENCY
WAS FOUND TO BE GREATER THAN 90X.
THE FGD SYSTEM MAS FORCED TO REMAIN OFF LINE FOR 6-6 DAYS IN DECEMBER
DUE TO AN UNAVAILABILITY OF RAM MATERIALS.
1/81 SYSTEM
»« PRCBLEMS/SOLUTIONS/COMMENTS
43.4
744
323
AT THE END OF JANUARY THE SYSTEM HAS SHUT DOWN TO MAKE COPRECTICNS TO THE
THICKENER. REPAIRS HERE CONDUCTED ON THE OVERFLOW WEIR AND RETURN LINES
TO THE THICKENER CENTERUELL.
2/81 SYSTEM
86.2
86.2
66.2
672 672
579
«» PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM HAS STARTED UP ON FEBRUARY 2 AT NOONTIME. AFTER CORRECTIONS HERE
COMPLETED ON THE THICKENER. FAN MAINTENANCE REQUIRED A BRIEF 10 MINUTE
SHUT DOWN LATER ON THAT DAY. AFTER TWO DAYS OF OPERATION, THE SYSTEM HAS
SHUT DOWN ON FEBRUARY 4 FOR 11 HOURS. THIS HAS A PREVENTIVE MEASUPE TO
ALLOW SOLIDS IN THE THICKENER TO SETTLE (THICKENER OVERFLOW UAS CLOUDY).
THE SYSTEM HAS RESTARTED ON FEBRUARY 5 AND OPERATED FCR 3 DAYS BEFC3E IT
MAS SHUT DOWN DUE TO THE INABILITY TO TRUCK AWAY SOLID HASTE MATERIAL.
HEAVY RAINS HASHED OUT THE ROADS TO THE PONDS AND THE TRUCKS COULD NO LONG-
1023
-------
EPA UTILITT FGD SURVEY: OCTOBER - DECEMBER 1981
GULF POKER: SCKOLZ 1 CCQNT.)
PERFORMANCE DATA
PERIOD HCOULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REHOVAL PER BOILER FG3 CAP.
SOZ PART. HOURS HOURS HOWS FACTOR
ER HAUL THE HASTE MATERIAL DISCHARGED BY THE VACUUM FILTER. IMPROVEMENT IN
WEATHER COOITIOM5 AND THE SFPEADIKG OF SOME PCCKS ON THE PCNO BANKS MADE
IT POSSIBLE TO RESUME WASTE DISPOSAL; THE SYSTEM UAS RESTARTED OH FESRUA3Y
10 AFTER 39 HOURS OF INTERRUPTION. IT OPEPtTED UNTIL THE ENO OF THE MOUTH
WITH ONE OUTAGE ON FEBRUARY 27 DUE TO A FAILURE IN THE SCRUS5E? PUMPS.
THE AVERAGE SOZ REMOVAL EFFICIENCY FOR THE flOHTH UAS 95.7 PERCENT.
3/81 SYSTEM 58. Z 46.5 744 346
»* PROBLEMS/SOLUTIONS/COMMENTS
TWO SEPERATE OUTAGES OCCURRING ON MARCH Z AND MARCH 3 TOTALING 7.8 HOURS
WERE DUE TO PROBLEMS WITH THE SCRUBBER PUMPS. THE MOTOR IN ONE PUMP UAS
INOPERATIVE AND THE IMPELLER IN THE OTHER PUMP HAD TO BE REPLACED.
A THIRD OUTAGE LASTING 190 HOURS WAS REQUIRED TO REPAIR THE VACUUM FILTER.
THE PERFORMANCE OF THE VACUUM FILTER HAD BEEN DETERIORATING STEADILY.
LEAKS HAD BEEN DETECTED IN THE INTERNAL PIPINS OF THE FILTER DRUM AND BY
THE TIKE THE FILTER WAS REMOVED, ONLY HALF OF THE PANELS WERE ABLE TO PULL
CAKE. THE SYSTEM UAS RESTARTED ON MARCH 13 AFTER THE FILTER HAD SEEM FIXED
AND REINSTALLED. ALTHOUGH ALL 12 PANELS HERE PULLING CAKE. THE QUALITY OF
THE SOLID CAKE PRODUCED BY THE FILTER DID NOT IMPROVE SIGNIFICANTLY
(PERCENT SOLIDS CONCENTRATION UAS ABOUT 40 PERCENT 1. THE VACUUM REMAINED
LOU, 5 TO 10 INCHES OF H6, VERSUS THE DESIGNED VACUUM OF 5 TO 10 INCHES HG.
THE SOLIDS LEFT IN THE THICKENER DETERIORATED AS FAR AS SETTLING CHARAC-
TERISTICS ARE CONCERNED. WHILE THE FILTER UAS BEING REPAIRED. THESE SOLIDS
SLOWLY RESU5PENDED DURING THE 8 DAY OUTAGE. WHEN THE SYSTEM WAS RESTARTED
ON MARCH 13. THE RESUSPENSIOM OF SOLIDS UAS AUGMENTED BY THE CIP.CULATICM
OF LIQUOR THROUGHOUT THE SYSTEM. THIS PROBLEM CAUSED 3 OUTAGES TOTALING
94 HOURS. A FLOCCULANT WAS USED TO HELP IN THE SETTLING OF THESE SOLIDS.
OH MARCH 23, THE RAKE LOCKED IN PLACE. ROTATION OF THE RAKE WAS STOPPED
TO PREVENT RESUSPENSION OF SOLIDS WHILE GOOD SETTLING SOLIDS BEING GENER-
ATED IN THE REACTORS WERE BEIKS USED TO FOPM A BLANKET TO COVER THE PCC3
SETTLING SOLIDS. AM AIR-LIGU09 SPARGER UAS USED TO FREE THE RAKE. THE
OUTAGE LASTED 23 HOURS. THE SYSTEM RESTARTED AND OPERATED UNTIL NOON,
MARCH 28. TESTING OF THE SYSTEM CONCLUDED AT THAT TIME. THE AVERAGE S02
REMOVAL EFFICIENCY DURING THE OPERATING TIME IN THE MONTH OF MARCH UAS
96.8 PERCENT.
THE DECISION CONCERNING THE FUTURE OF THE FGD SYSTEM IS LEFT UP TO THE
SOUTHERN COMPANY WHICH CONSISTS OF FOUR POWER COMPANIES I GULF, ALABAMA.
GEORGIA. AND MISSISSIPPI).
1024
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
PEGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SOC EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENEF4TING CAPACITY - MM
GROSS UNIT GENe3ATIN3 CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - KM
NET UNIT GENERATING CAPACITY UO/FGD - MU
EQUIVALENT SCRUBBED CAPACITY - MU
*« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BCILEP FLUE GAS FLOU - CU.M/S
EOILER 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 - X
RANGE ASH CONTENT - V.
AVEPAGE MOISTURE CONTENT - X
PASSE MOISTURE CONTENT - X
AVEPAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RAN3E CHLCRIOE CONTENT - X
»«» PARTICLE CONTROL
«« ESP
NUMBER
TYPE
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
•« PARTICLE SCRUBBER
NUMBER
INITIAL STAPT-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TPAOE NAME/COMMON NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
*«* FGD SYSTEM
«* GENERAL DATA
SALEABLE PRODUCT/THROUAUAY PRODUCT
S02 REMOVAL RODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
GULF POWER
SCHOLZ
1A
SNEAOS
FLORIDA
C
**«»««
516.
****»•
60
43
40
•«»*•
48
BABCOCK t HILCOX
PULVERIZED COAL
BASE
(«»»««* LB/MM3TU)
( 1.200 LB/MM3TU)
(»*«»*« LB/MM3TU)
»*«*«««*
146.1
**»«M»
NR
«*•«»««
COAL
**»•»•
«««**»
•«*»**»»
«»»*»«
«**•**»«
«*«»«•
5.00
(«***•»« ACFM)
( 295 F)
(**«» FT)
(«»»«* FT)
(»««••• BTU/LB)
******
»«»«»***
******
COLO SIDE
BUELL DIVISION,
99.5
ENVIROTECH
1
8/75
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
THYSSEN/CEA
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BOHDED CEMENT
NONE
THROUAUAY PRODUCT
MET SCRUBBING
DUAL ALKALI
THYSSEN/CEA
FPOTOTYPE
RETROFIT
1025
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
GULF POWER; SCHOLZ IA ICONT.>
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X 99.70
UNIT DESIGN S02 REMOVAL EFFICIENCY - X 95.00
HARMING «*UNNORMALIZED NUHBER(S) BEING EDITED FOR OUTPUT**
.0
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
»• DESIGN AND OPERATING PARAMETERS
** CUEMCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»tt ABSQPBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON 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
«« MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COnrCN TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«« REHEATER
KUKSER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
*• DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CC.'STPUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
•« DUCTUQRK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«» SOLIDS COHCENTRATING/OEUATERINS
DEVICE
NUMBER
CONFIGURATION
SHELL SPECIFIC MATERIAL TYPE
8
7/76
Z/7S
KR
NR
VENTURI TOMER
NR
NR
THYSSEN/CEA
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
KR
HOME
NR
I1R
KR
NR
NR
NR
1
NR
NR
NR
5.0
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
VACUUM FILTER
1
ROTARY DRUM
PLASTIC t FIBERGLASS
1026
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ 1A CCONT.)
*»» SLUDGE
»• TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»» DISPOSAL
MATURE
TYPE
LOCATION
SITE TREATMENT
•• WATER BALANCE
WATER LOOP TYPE
DEUATERED
N/A
N/A
FINAL
POND
ON-SITE
CLAY LINING
CLOSED
PEPFOHMAHCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
7. REMOVAL
S02 PART.
PER B'JILES FGD CAP.
HOURS HOURS HOUPS FACTOP
2/75 SYSTEM
98.9
67.6
672 459
454
»* PROBLEMS/SOLUTIONS/COMMENTS
3/75 SYSTEM
4/75 SYSTEM
5/75 SYSTEM
6/75 SYSTEM
7/75 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 SOX OF THE FLUE GAS FROM THE BOILER. THE BOILER MAS RETROFITTED
WITH A SECTIONALIZED, HIGH EFFICIENCY ESP INSTALLED UPSTREAM OF THE FGO
SYSTEM AND CAPABLE OF 99.T/. PARTICLE MATTER REMOVAL.
THE PROTOTYPE SYSTEM INCORPORATED A HIGH DEGREE OF FLEXIBILITY FCR GENERA-
TION OF DESIGN AND OPERATINS INFORMATION FOR A HIDE VARIETY OF APPLICA-
TIONS. ALTHOUGH THE BASIC MODE OF SYSTEM OPERATION MAS DUAL ALKALI V.ITH
LIME REGENERATION. THE SYSTEM UAS 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 UAS COMPLETED AND PUT IN
OPERATION IN EARLY FEBRUARY 1975.
95.7
55.6
62.7
100.0
32.4
65.2
46.7
50.4
100.0
29.7
744 507
720 604
744 593
720 720
744 683
485
33*
375
7ZO
C£l
«* PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM MAS OPERATED FROM FEBRUARY 8. 1975 UNTIL JULY 18 WHEN IT UAS
TAKEN OUT OF SERVICE FOR TUO MONTHS FOR MODIFICATIONS, REPAIRS AND REPLACE-
MENT OF PARTS. THE SYSTEM UAS UNAVAILABLE FCR A 491 HOUR PERIOD DUE TO
SOME NECESSARY ADJUSTMENTS AND MODIFICATIONS FCR A FORMAL EPA TEST PRO-
GRAM IN MID-MAY.
8/75 SYSTEM
9/75 SYSTEM
.0
44.0
.0
35.3
744 744
7CO 577
0
254
1027
-------
EPA UTILITY FGD SUPVEY: OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ u tcoirr.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
»» PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM WAS SHUT DOWN FROM MID-JULY TO MID-SEPTEMBER FOR A MECHANICAL
OVEPHAUL INVOLVING REPLACEMENT OF VALVE PARTS THAT HAD FAILED. THE SYSTEM
MAS PUT BACK IN OPERATION ON SEPTEMBER 16.
10/75 SYSTEM 100.0 75.1 744 559 559
*« PROBLEMS/SOLUTIONS/COMMENTS
FROM MID-SEPTEMBER UNTIL MID-OCTOBER THE AIR PREHEATER MAS REPAIRED AND
BOILER OPERATION MAS ADJUSTED TO REDUCE OXYGEN LEVELS IN THE FLUE GAS TO
THE 5-6X RANGE. THE SYSTEM OPERATED APPROXIMATELY 600 HOURS DURING THIS
PERIOD.
11/75 SYSTEM 90.3 77.6 720 620 560
12/75 SYSTEM 100.0 96.4 744 732 732
1/76 SYSTEM 744
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM RAH CONTINUOUSLY FOR THE REMAINDER OF THE TEST PERIOD THROUGH
JANUARY 2, 1976. S02 LEVELS DURING THIS PERIOD RANGED FROM 600 TO 1700
PPM. THE SYSTEM OPERATED IN THE CONCENTRATED MCCE 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 97*.
2/76 SYSTEM 696
»* PROBLEMS/SOLUTIONS/COMMENTS
THE FGO SYSTEM AND BOILER WERE SHUT DOWN FOP A SCHEDULED OVEPHAUL. THE
SYSTEM MAS SCHEDULED TO RESTART IN MID-MARCH AND WAS TO CONTINUE UNTIL
JUNE. DURIN5 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 59.6 744 742 445
*• PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM MAS RETURNED TO SERVICE ON MARCH 12. 1976. THE SYSTEM OPERATED
A TOTAL OF 445 HOURS.
5/76 SYSTEM 68.6 67.5 744 735 651
«* PROBLEMS/SOLUTIONS/COMMENTS
DURING APRIL AND MAY SOME MINOR MECHANICAL PROBLEMS WITH THE AGITATOR
SHAFT HERE ENCOUNTERED.
SOME PROBLEMS WERE EXPERIENCED WITH THE CONTROL VALVES DURING APRIL AN3 HAY
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 69.0 720 656 641
1028
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEASES 1981
GULF POWER: SCHOLZ 1A (COMT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
«» PHOBLEMS/SOLUTIONS/COMMENTS
DURING THE LAST PHASE OF OPERATION. THE SYSTEM UAS TREATING FLUE GAS OF
VARYING PARTICULATE MATTER LOADS. THE UPSTREAM ESP MAS SELECTIVELY DE-EN-
ERGIZED. BOTH PARTIALLY AND TOTALLY. WITH NO MAJOR UPSETS IN THE FPCCESS
CHEMISTRY RESULTING. BOILER LOAD VARIATION RANGED FROM 30 TO 100/C.
7X76 SYSTEM 100.0 7.3 744 54 54
«« PROBLEMS/SOLUTIONS/COMHENTS
ON JULY 3, 1976 THE PROTOTYPE TEST PROGRAM MAS CONCLUDED.
10Z9
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FG9 SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PANICULATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - NG/J
N3X EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - KM
NET UNIT GENERATING CAPACITY MO/FGO - MW
EQUIVALENT SCRUBBED CAPACITY - MH
»* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW
BOILER FLUE GAS TEMPERATURE
STACK HEIGHT - M
STACK SHELL
STACK TCP DIAMETER - M
cu.n/s
c
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - 7.
AVERAGE MOISTUPE CONTENT - I
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT
RANGE CHLORIDE CONTENT -
- 7.
7.
«** PARTICLE CONTROL
«« ESP
NUMBER
TYPE
SUPPLIER
PARTICLE REMOVAL EFFICENCY - 7.
•» PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMCN NAME
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
»•» FGD SYSTEM
** GENERAL DATA
SALEABLE PRODUCT/THROHAUAY PRODUCT
502 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
(*«»*** LB/MMBTU)
( 1.200 LB/MK3TU)
(«»*«»« LB/MM3TU)
GULF POWER
SCHOLZ
1B,2B
SNEADS
FLORIDA
C
#*«»»»
516.
»*««»*
80
48
40
»»*•«
48
BABCOCK I UILCOX
PULVERIZED COAL
BASE
«*«»***» (*»•*«** ACFM)
146.1 ( 295 F)
23. ( 76 FT)
FIBER-REINFORCED POLYESTER
**»»*»» (»«»»* FT)
COAL
»«**Ht»
*•**»•
(«»«»«« BTU/LB)
»**•**
*«*•»»
««*»•*
5.00
**««**
•»»«**«*
•****•
COLO SIDE
BUELL DIVISION.
99.5
ENVIROTECH
1
2/75
VENTURI TOUER
VARIABLE-THROAT/aOP-ENTRY PLUMS BOS
N/A
CHIYODA INTERNATIONAL
CARBON STEEL
AISI 1110
INORGANIC
HYDRAULICALLY-BONOEO CEMENT
NONE
THROUAWAY PRODUCT
NET SCRUBBING
THOROUGHBRED 101
CHIYODA INTERNATIONAL
PHOTOTYPE
RETROFIT
1030
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
GULF POWER: SCHOLZ 13,28 (CONT.)
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN SOS REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
** DESIGN AND OPERATINS PARAMETERS
»* OUENCHEP/PRESATURATCR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»• ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TPAOE 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
TPADE HAME/COMHSN TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» REHEATER
GENERIC TYPE
SPECIFIC TYPE
TPAOE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
CCNSTPUCTICN MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» DAMPEPS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«« OUCTU3PK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«* REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICi
DEVICE TYPE
«« SOLIDS CONCEKTRATING/OEHATEHING
DEVICE
NUMBER
CONFIGURATION
««« SLUDGE
7. 99.70
90.00
«*»•»»*
a
3/77
2/75
NR
NR
PACKED TOMER
NR
NR
CHIYODA INTERNATIONAL
STAINLESS STEEL
AUSTENITIC
TYPE 316L
NONE
N/A
N/A
PRIMARY COLLECTOR
2
IMPINGEMENT
BAFFLE
CLOSED VANE
NR
NR
NR
NR
NR
5.0
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
MIX TANK
M/A
AGITATED TANK
CENTRIFUGE
1
CONTINUOUS SCREU-OECANTER/SOLID SOUL
1031
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEIVER 19B1
GULF POWER: SCHOLZ 1B.2B (CCNT. I
DEWATERED
DEVICE N/A
FPOPRIETARY PROCESS N/A
•» DISPOSAL
NATURE FINAL
TYPE POI«)
SITE TREATMENT CLAY LINING
»» WATER BALANCE
MATER LOOP TYPE OPEN
., PERFORMANCE DATA—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FC-3 CAP.
SOZ PART. HCU3S HOURS HOURS FACTOR
2/75 SYSTEM 672 672
«» PROBLEHS/SOLUTIONS/CCKMENTS
THE F6D SYSTEM AT SCHOLZ IB AND 2B WAS DESIGNED FOR TESTING AND PROCESS
DEMONSTRATION OF THE THROUGHBREO 101 PROCESS ON A COAL-FIRED APPLICATION.
THE PROCESS IS USED IN JAPAN EXCLUSIVELY ON OIL-FIRED AND GAS-FIRED ECIL-
ERS. AND TAIL GAS 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 57. MERE SCHEDULED FCP BU=NIK5.
THE PARTICLE MATTER 1.0ACS FROM THE ESP RANGSO FROM 0.02 TO 0.1 GR/SCF.
FLUE GAS FROM THE ESP WAS QUENCHED WITH COOLINS WATER TO REMOVE ADDITIONAL
FLY ASH AMD TO COOL THE GAS BEFORE IT ENTERED THE ABSCPBER. THE SOC HAS
ABSORBED IN WATER AfJD CATALYTICALLY OXIDIZED WITH AIR TO FORM SULFURIC
ACID. THE DILUTE ACID WAS RECIRCULATED THROUGH THE ABSOR3ER. A PORTION
OF THE AGIO WAS NEUTRALIZED WITH LZHESTONE TO PRODUCE GYPSUM AS A BY-
PRODUCT.
THE INITIAL SHAKEDOWN A HO DEBUGGING OPERATIONS AT THIS PILOT PUNT SIZE
DEMONSTRATION UNIT COMMENCED ON FEBRUARY 11, 1975. PROBLEMS ENCOUNTERED
INCLUDED CRACKS IN THE FRP LINIKS AT THE OXIDIZING TOWER.
3/75 SYSTEM 744
•« PROBLEMS/SOLUTICNS/COMflENTS
AFTER INITIAL OPERATION FOR BREAK-IN TESTS IN MARCH, THE SYSTEM MAS
SHUTDOWN FOR INTERNAL INSPECTION.
4/75 SYSTEM 27.6 27.8 7ZO 720 £00
5/75 SYSTEM 13.4 13.4 744 744 100
6/75 SYSTEM 100.0 95.1 720 685 665
7/75 SYSTEM 83.9 83.9 744 744 624
«» PROSLEHS/SOLUTIONS/COrinENTS
RELIABILTY TESTS HERE PERFORMED IN JULY ALTHOUGH EMISSION TESTS HAD NOT
BEEN RUN AT THIS TIME.
UP TO THIS POINT, SOUS PUMP AND INSTRUMENTATION FAILURES HAD OCCURRED.
DURING JULY ONE CENTRIFUGE BECAME UNBALANCED, REQUIRING THE SPARE TO BE
PLACED IH SERVICE.
6/75 SYSTEM 74*
9/7S SYSTEM 46.6 46.8 720 720 337
1032
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ 13,28 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOUPS HOURS HOUFS FACTOR
«» 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 SOZ REMOVAL EFFICIENCY DURING THE MONTH OF
SEPTEMBER.
10/75 SYSTEM 100.0 100.0 744 744 744
«« PRC3LEMS/SOLUTIONS/COMMENTS
THE DISCHARGE OF WASTE MATER FROM THIS SYSTEM WAS A CONTIUOUS PROBLEM
AREA.
11/75 SYSTEM 100.0 100.0 720 720 720
«» PROBLEMS/SOLUTIONS/COMMENTS
A MINOR 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 JAWARY 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.
SOZ REMOVAL EFFICIENCY UP TO THIS PERIOD HAS BEEN AS HIGH AS 95X.
3/76 SYSTEM 99.6 99.6 744 744 741
4/76 SYSTEM 14.0 14.0 720 720 101
«« PROBLEMS/SOLUTIONS/COMMEHTS
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 SYSTEM .0 744 0
6/76 SYSTEM .0 723 0
7/76 SYSTEM .0 744 0
1033
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ 18.2B (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PE9 BOILER FGD CAP.
S02 PART. HOURS HOL'RS HOURS FACTOR
*• PROBLEMS/SOLUTIONS/COHMENTS
THE SYSTEM REMAINED OUT OF SERVICE DURING MAY, JUNE AND JULY TO REPAIR THE
FIRE DAMAGED AREAS.
8/76 SYSTEM 66.1 66.1 744 744 492
•* PROBLtHS/SOLUTICNS/COKMENTS
THE SYSTEM CAME BACK ON LINE IN AUGUST; BUT, HAS BROUGHT DOWN OUPIH3 THE
MONTH TO COMPLETE ADDITIONAL REPAIRS WHICH UEMT UNDETECTED DURING THE
PREVIOUS OUTAGE. THESE ADDITIONAL REPAIRS ACCOUNTED FCR APPROXIMATELY 242
HOURS OF OUTAGE TIME.
THE MATERS SAVINGS PROGRAM MAS TESTED DURING AUGUST. THE TEST PROGRAM
CALLED FOR A REDUCTION IN HASTEIUTER SLOWDOWN AND FRESH MATER MAKEUP
REQUIREMENTS BY RECYCLING THE MOTHER LIQUOR BLEED BACK TO THE PROCESS FOR
ADDITIONAL SERVICE.
9/76 SYSTEM 99.3 68.9 99.3 68.9 720 720 496
** PROBLEMS/SOLUTIONS/COMMENTS
THE SYSTEM MAS FORCED OUT OF SERVICE APPROXIMATELY FIVE HOURS OURINS
SEPTEMBER.
10/76 SYSTEM 70.6 48.0 62.0 48.0 744 744 357
«• PROSLEMS/SOLUTICNS/COMMENTS
DURINS OCTOBER SYSTEM DOWN TIME AMOUNTED TO APPROXIMATELY 387 HOURS. OF
THIS TOTAL 218 HOURS MERE REPORTED TO REPAIR ANTICIPATED DAMAGES INCURRED
IN THE PRESCRUBBER RESULTING FPOM OPERATIONS IN THE WATER SAVINGS PPOSRArt.
SPECIFICALLY, THE LINING HAD SUFFERED FROM EXTENSIVE COPROSICN D-AMAGE
BECAUSE OF HIGH ACID CONCENTRATIONS WHICH DEVELOPED IN THE SCRUBBER
SOLUTION.
DURING OCTOBER SYSTEM DOWN TIME AMOUNTED TO APPROXIMATELY 387 HOURS. OF
11/76 SYSTEM 99.6 99.6 99.6 99.6 720 723 717
12/76 SYSTEM 99.6 99.6 99.6 99.6 744 744 741
«* 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 MATER HEADER.
744 744 744
672 672 672
744 744 514
»• PR03LEMS/SOLUTIONS/COMMENTS
THE CT-101 TESTING AND DEMONSTRATION PROGRAM MAS CONCLUDED ON MARCH 22.
DURING JANUARY, FEBRUARY AND MARCH THE TOTAL SCRUBBER OUTAGE TIME MAS
0.33 HOUR. THE SYSTEM HAD OPERATED ON A VIRTUALLY CONTINUOUS BASIS SINCE
OCTOBER 17, 1976.
1/77 SYSTEM
2/77 SYSTEM
3/77 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
1034
-------
EPA UTILITY FED SURVEY: OCTOBER - DECEMBER 1931
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
SOS EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGO - MM
NET UNIT GENERATING CAPACITY WO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILEP TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOM
BOILER FLUE GAS TEMPERATURE
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
CU.M/S
C
«» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT
RANSE MOISTUPE CONTENT - X
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT
RANGE CHLORIDE CONTENT -
- X
- X
X
»»» PARTICLE CONTROL
«» ESP
NUMBER
TYPE
SUPPLIER
INLET FLUE GAS TEMPERATURE - C
PARTICLE REMOVAL EFFICENCY - X
*» PARTICLE SCPUB3ER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
«•« FGD SYSTEM
»• GENERAL DATA
SALEABLE PRODUCT/THROMAMAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
UNIT DESIGN SOS REMOVAL EFFICIENCY - X
GULF POMER
SCHOLZ
1.2
SMEADS
FLORIDA
C
««>»»«*
«*«**•
*«•**»
80
23
23
(»»*»•« LB/MKBTU)
(*«»»*» LB/MKBTU)
(**«««* LB/Mr.3TU)
23
BABCOCK S MILCOX
PULVERIZED COAL
BASE
****»««» (**»*«*
COAL
BITUMINOUS
£9075.
11.00
«»*«»«
5.00
*«»*»»
2.50
2.5-5.0
*»»•*»*»
**««»*
COLD SIDE
BUELL DIVISION. ENVIROTECH
151.7 ( 305 F)
99.5
NONE
N/A
N/A
N/A
THPCUAUAY PRODUCT
KET SCRUBBING
LIMESTONE/THOROUGHBRED 121
NONE
CHIYODA INTERNATIONAL
CHIYODA CHEMICAL ENG'R 1 CONSTION
FPOTOTYPE
RETROFIT
X 99.50
90.00
WARNING "UNNOHMALIZED NUMBER!S) BEING EDITED FOR OUTPUT**
ENERGY CONSUMPTION - X .0
CURRENT STATUS 6
1035
-------
EPA UTILITY FGO SURVEY: OCT03ER - DECEMBER 1981
GULF POWER: SCHOLZ l.C (CONT.>
TERMINATION
INITIAL START-UP
»• DESIGN AND OPERATING PARAMETERS
** QUENCHER/P5ESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» ABSORBER
N'JfSEH
GSNEPIC TYPE
SPECIFIC TYPE
TPAOE NAKE/COnnON TYPE
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LIMER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
GAS CONTACTING DEVICE TYPE
NUMBER OF CONTACTING ZONES
INLET GAS FLOW - CU. M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICIENCY - X
«* MIST ELIMINATOR
PRE-KIST ELIMINATOR/MIST ELIMINATOR
NUnSER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONFIGURATION
NUMBER OF STAGES
NUrSEP OF PASSES PER STAGE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»« REHEATER
GENERIC TYPE
SPECIFIC TYPE
TPADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» FANS
NUMBER
APPLICATION
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
«» DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»* OUCTUCRK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
6/79
6/78
NR
NR
MECHANICALLY-AIDED TOMER
GAS SPARGER
JET BUBBLER REACTOR
CHIYODA INTERNATIONAL
24.0 DIA
STAINLESS STEEL
AUSTENITIC
NR
ORGANIC
FIBER-REINFORCED POLYESTER
HR
N/A
1
37.73 ( 80000 ACFM)
148.9 ( 300 F)
95.0
PRIMARY COLLECTOR
1
IMPINGEMENT
BAFFLE
CLOSED VANE
VERTICAL
2
.Z
I 1.0 IN-HZO)
NR
NR
NONE
N/A
N/A
NONE
N/A
FORCED DRAFT
25.01
148.9
NR
NR
NR
N<>
NS
NR
NR
NR
NR
NR
NR
53000 ACFM)
300 F)
1036
-------
GULF POWER: SCHOLZ 1,2 (CONT.)
EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1981
«» PEAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«« SOLIDS CONCENTRATING/OEWATEHING
DEVICE
«*« SALEABLE BYPRODUCTS
NATURE
DISPOSITION
««* SLUDGE
«» TREATMENT
METHCO
DEVICE
PROPRIETARY PROCESS
»« DISPOSAL
NATURE
TYPE
SITE TREATMENT
«* PROCESS CONTROL AND INSTRUMENTATION
PROCESS CONTROL MANNER
«• WATER BALANCE
HATER LOOP TYPE
UET BALL MILL
COMPARTMENTEO
NR
NONE
GYPSUM
STACKED IN PONO
FORCED OXIDATION
JET BUBBLER
N/A
FINAL
POND
CLAY LINING
MANUAL
CLOSED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
SOS PART. HOURS HOUPS HOURS FACTOR
6/78 SYSTEM 744
«« PRC3LEMS/SOLUTIONS/COMMENTS
OPERATION BEGAN ON AUGUST 30. 1978.
NO INITIAL OPERATIONAL PROBLEMS MERE REPORTED.
9/78 SYSTEM 720
10/78 SYSTEM 100.0 720
«» PRCBLEMS/SOLUTIONS/COMMENTS
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
«e PR03LEMS/SOLUTIONS/COMMENTS
THERE HERE NO UNPLANNED SHUTDOWNS DURING DECEMBER AND JANUARY.
THE SYSTEM HAS BEING OPERATED IN WHAT MAS CALLED PHASE II OF THE TESTING.
THE SYSTEM HAS DELIBERATELY BEING UPSET FROM EQUILIBRIUM (FH, OXIDIZING AI
INPUT, ETC.) TO SEE HOM IT RESPONDED.
1037
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
G'JLF POWER: SCHOLZ 1.2 (CCNT. J
PERFORMANCE DATA
PERIOD M33ULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HCbSS HOURS HOURS FACTOR
1/79 SYSTEM 100.0 744 0
3/79 SYSTEM 98.3 98.4 672 672 661
3/79 SYSTEM 100.0 100.0 100.0 100.0 744 744 744
4/79 SYSTEM 100.0 100.0 100.0 100.0 720 720 720
*» PR03LEHS/SOLUTIONS/COMMENTS
ONE PUMP FAILURE CAUSING A 5 MINUTE OUTAGE HAS REPORTED BY THE UTILITY.
HIGH PARTICULATE LOADING TESTS WERE DONE IN APRIL. THE ESP MAS TOTALLY
SHUT DOWN. THE S02 REMOVAL WAS NOT AFFECTED BUT THE GYPSUM PRODUCT WAS
TEMPORARILY AFFECTED. HIGH CHLORIDE TESTS UERE ALSO PERFORMED BY ADDING
CALCIUM CHLORIDE TO THE SYSTEM. A RESULTANT CONCENTRATION OF 6000 PPM
CHLC3IDE UAS FOUND IN THE UNDERFLOW. NO SIGNIFICANT SCALING UAS ENCOUNT-
ERED.
5/79 SYSTEM 744
6/79 SYSTEM 720
*» PROBLEMS/SOLUTIONS/COMMENTS
THE FGD SYSTEM OPERATED THROUGH THE 24TH OF MAY WHEN THE SYSTEM UAS RE-
MOVED FROM SERVICE BECAUSE THE EPRI STUDIES HERE COMPLETED.
JUNE:
AFTER SHUTDOWN THE UNIT UAS MODIFIED TO SIMULATE A SMALLER JET BUE3LER
REACTOR UITH THE SAME AMOUNT OF FLUE GAS. THIS UAS DONE BY PLUGGING SOME
OF THE SPAPGERS AND RISER TUBES. THE UNIT UAS OPERATED LIKE THIS F»C;1
JUNE 8 UNTIL JUNE 29 UITH RESULTS THAT INDICATED SLIGHTLY REDUCED PEHOVAL
EFFICIENCIES. DURING THE 21 DAYS OF OPERATION THE UNIT UAS DOWN ONLY
ONCE FCR NINE HOURS FOR ROUTINE INSPECTION.
OURIKS THE EPRI STUDY A TOTAL OF 4448 HOURS OF OPERATION UERE LOGGED UITH
A TOTAL OF 123.3 HOURS OF SHUTDOWN. THE AVERAGE AVAILABILITY FOR SIX
MONTHS UAS 99.53X.
ALL STUDIES UERE COMPLETED AND THE SYSTEM HAS BEEN TERMINATED.
1038
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
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 - NQ/J
N3X EMISSION LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MM
GPOSS UNIT GENERATING CAPACITY - MU
NET UNIT GENERATING CAPACITY M/FGD - MW
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 FLOM - CU.I1/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
RANSE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANSE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - V.
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANSE CHLORIDE CONTENT - X
««« PARTICLE CONTROL
»« MECHANICAL COLLECTOR
NUMBER
TYPE
«» ESP
NUMBER
v« PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
*«» FGD SYSTEM
«» GENERAL DATA
SALEABLE PRODUCT/THROWAHAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEM/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
GULF POMEB
SCHOLZ
£A
SNEADS
FLORIDA
C
•**»»*
«**»*•
(»•»»»»
(»*«*»* LB/MM3TU)
(*»<*«• L8/MMBTU)
60
48
40
»***«
48
BABCOCK t UILCOX
PULVERIZED COAL
BASE
««»»*»*«
146.1
««»»*»
«»***«
»»*»»•»
COAL
BITUMINOUS
(»««»»«« ACFM)
( 295 F)
(««»» FT)
(»«»»« FT)
(«»»»«« BTU/LB)
•**»«*
«•»»«*•*
*»*««»
«»**««*»
******
3.50
«««*««
»*«•**»»
0
NONE
NONE
N/A
N/A
N/A
SALEABLE PRODUCT
DRY AO^RPTICN
ACTIVATED CARBON
FOSTER UHEELER/BEPGBAU
DEMONSTRATION
RETROFIT
X 99.70
74.50
MAPNING «»UNNORMALIZEO NUKBER(S) BEING EDITED FOR OUTPUT"*
ENERGY CONSUMPTION -
CUPRENT STATUS
TERMINATION
COMMERCIAL START-UP
8
5/76
2/76
1039
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 19S1
JULF POWER: SCHOLZ 2A (CONT.)
INITIAL START-UP
CONTRACT AWARDED
«» DESIGN AND OPERATING PARAMETERS
8X75
1/73
** QUENCHER/PRESATURATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATEPIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
»» MIST ELIMINATOR
FRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
•» REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAttE/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«« DAMPEPS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«« DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
•» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
»» SOLIDS CONCENTRATINS/DEUATEHIN3
DEVICE
««» SLUDGE
»« TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
NR
NR
PACKED TOKER
NR
KR
FOSTER UHEELER/BERG8AU
NR
NR
NR
NR
NR
NR
MR
NR
NR
NR
NR
NR
0
NONE
N/A
N/A
NONE
N/A
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
N/A
N/A
N/A
NONE
N/A
N/A
N/A
1040
-------
EPA UTILITY F60 SURVEY: OCTOBER - DECEMBER 1961
GULF PC-ER: SCHOLZ ZA ICOHT.)
«» DISPOSAL
NATUPE
TYPE
SITE TREATMENT
FINAL
POND
CLAY LINING
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
5/7S SYSTEM
«« PROBLEMS/SOLUTIONS/COMMENTS
744
THE DEMONSTRATION SYSTEM AT SCHOLZ £A CONSISTED OF A 20-MW ADSORBER SECTION
AMD A 47.5 MW REGENERATION AND REDUCTION SECTION. THE ZO MM ADSC'EER
MAS DESIGNED TO HANDLE SOX OF THE MAXIMUM FLUE GAS FLOW. THE PURPOSE OF
THE ADSORPTION SECTION OF THE DRY REMOVAL SrSTEM WAS TO REMOVE SULFUR
DIOXIDE; NITROGEN OXIDES. AND PARTICLE MATTER FROM THE FLUE GAS WITH
ACTIVATED CHAR, CONVERTING THE CAPTURED POLLUTANTS TO SULFURIC ACID. THE
REGENERATION SECTION PROVIDED CONTINUOUS ON-SITE REGENERATION OF THE CHAR,
WHICH MAS LOADED WITH SULFUR DIOXIDE IN THE FORM OF SULFL'PIC ACID. THE
REGENERATED CHAR AND A LOU VOLUME. SULFUR DIOXIDE-RICH OFF-GAS STREAM WAS
FED TO A RESOX REACTOR, WHICH REDUCED THE SULFUR DIOXIDE STREAM
TO GASEOUS ELEMENTAL SULFUR THAT HAS COLLECTED AND STORED IN AN INSULATED
TANK.
6/75 SYSTEM
7/75 SYSTEM
*» PROBLEMS/SOLUTIONS/COMMENTS
720
744
COMPLETION OF CONSTRUCTION WAS FOLLOWED BY A THREE MONTH COMMISSIONING
PERICD DURING WHICH VARIOUS PIECES OF EQUIPMENT WERE OPERATED INDIVIDUALLY
AND THEN IN COMBINATIONS TO SIMULATE SUBSYSTEM OPERATION.
6/75 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 UAS INCOMPLETE AT THIS TIME.
9/75 SYSTEM
10/75 SYSTEM
»« PROBLEMS/SOLUTIONS/COMMENTS
720
744
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.
11/75 SYSTEM
12/75 SYSTEM
1/76 SYSTEM
«» PROBLEMS/SOLUTIONS/COMMENTS
720
744
744
2/76 SYSTEH
A PROGRAM OF MODIFICATIONS ON THE SYSTEM BEGAN IN LATE AUGUST 1975 AN3
CONTINUED THROUGH JANUARY 1976, WITH THE EXCEPTION OF FIVE DAYS OF RESOX
OPERATION IN OCTOBER.
696
1041
-------
EPA UTILITY FG3 SURVEY: OCTOBER - DECEMBER 1981
GULF POWER: SCHOLZ 2A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA3ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTCR
»» PP08LEMS/SOLUTIONS/COMMENTS
MODIFICATIONS HERE COMPLETED AND PRE-STARTUP TESTIN5 UAS CONDUCTED IN LATE
JA'JUARY AND EARLY FEBRUARY. A THREE DAY CONTINUOUS RUN UAS SUCCESSFULLY
COMPLETED.
DUPIN5 FEBRUARY THE MATERIALS HANDLING LOOPS AND THE RESOX LOOPS WERE
OPERATED AT FULL OPERATING TEMPERATURES AND PRESSURES. REINTH03UCTION OF
FLUE GAS INTO THE SYSTEM COMMENCED. AND A FOUR MONTH FORMAL TEST PPOGRAM
CONDUCTED BY SOUTHERN SERVICES AND FOSTER WHEELER BEGAN.
3/76 SYSTEM 744
4/76 SYSTEM 720
«» FR08LEMS/SOLUTIONS/COMMENTS
THREE OPERATIONAL PERIODS HERE LOGGED BY THE PROTOTYPE SYSTEM DURING MAPCH
AND APRIL. THE RESOX SECTION OPERATED INTERMITTENTLY BECAUSE OF PLU3GIN3
PROBLEMS IN THE SULFUR CONDENSER. ALSO, THE FRONT END OF THE SYSTEM UAS
TAKEN CUT OF SERVICE AT ONE POINT DUE TO FREQUENT HIGH TEMPERATURE
EXCURSIONS. THIS PROBLEM UAS CORRECTED BY MODIFYING SYSTEM OPERATING
PROCEDURES. WORK BEGAN ON THE SOLUTION OF THE SULFUR CCN3EN5ER PR03LEM.
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 UAS 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 UAS HADE TO PREMATURELY TERMINATE THE SYSTEM
DEMONSTRATION PROGRAM RATHER THAN SHUT DOWN, DEBUS AND RESTART THE SYSTEM
AGAIN. THE SYSTEM SUPPLIER UAS PURSUING ADDITIONAL FUNDING FCR THE
CONTINUATION OF THE PROTOTYPE DEMONSTRATION PROGRAM.
1042
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT HAME
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
GPOSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGD - HU
NET UNIT GENERATING CAPACITY KO/FGO - KM
EQUIVALENT SCRUBBED CAPACITY - KM
«* UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOU - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - H
«* FUEL DATA
FUEL TYPE
FUEL GRADE
AVEPAGE HEAT CONTEND - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUP CONTENT - X
RANGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
««» PARTICLE CONTROL
«* MECHANICAL COLLECTOR
NUMBER
•« FABRIC FILTER
NUMBER
TYPE
«• ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
«« PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
»« FGD SYSTEM
*« GENERAL DATA
SALEABLE PRCDUCT/THROWAHAY PRODUCT
SOS REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEW/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
ILLINOIS POWER COMPANY
UOOD RIVER
EAST ALTON
ILLINOIS
D
«»*»•*
774.
*»**«*
651
110
103
(»««»»» LB/MMSTU)
( 1.800 LB/MM3TU)
(«*»*«» LB/MMBTU)
110
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
fc»««»*«* (**»«*** ACFM)
154.4 ( 310 F)
76. ( 250 FT)
*««**»
»»»«»»» (•*»»» FT)
COAL
******
25121.
10.00
*«»»**
4.30
**«*««
3.10
«*»««»
««»*•***
«*»*»*
( 10800 BTU/LB)
0
NONE
RESEARCH-COTTRELL
99.6
NONE
N/A
N/A
N/A
SALEABLE PRODUCT
WET SCRUBBING
CATALYTIC OXIDATION
MONSANTO ENVIRO CHEM SYSTEMS
DEMONSTRATION
RETROFIT
X 99.90
1043
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)
UNIT DESIGN SOI REMOVAL EFFICIENCY - X
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UF
CONTRACT AWARDED
»« OESISN AND OPERATING PARAMETERS
«* QUENCHER/PSESATURAT08
CONSTRUCTION MATEPIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
85.00
.0
6
0/74
10/72
9/72
6/70
NR
NR
«» ABSORBER
NUT'S ER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/CCMMON TTPE
DIMENSIONS - FT
SHELL GENERIC MATEPIAL
SHELL SPECIFIC MATEPIAL
SHELL MATERIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
NUM3ER OF CONTACTING ZONES
DISTANCE BETWEEN GAS CONTACTING ZONES
GAS-SIDE PRESSURE DROP - KPA
INLET GAS TEMPERATURE - C
SOS REMOVAL EFFICIENCY - X
•« ABSOPBER
MUKSER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATEPIAL TRADE NAME/COMMON TYPE
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATERIAL TRADE NAME/COMMON TYPE
INLET GAS TEMPERATURE - C
«» MIST ELIMINATOR
FRE-MIST ELIMINATOR/MIST ELIMINATOR
NUKSER PER SYSTEM
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PRESSURE DROP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
MASH FREQUENCY
»* REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
PERCENT GAS BYPASSED - AVG
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUC.ION MATERIAL SPECIFIC TYPE
** FANS
NUMBER
APPLICATION
PACKED TOMER
NR
NR
30.0 DIA X 65.0
CARBON STEEL
AISI 1110
N/A
NR
NR
NR
8
CM 30.5
1.0
454.4
85.0
( 12.0IN)
( 4.0 IN-H20)
( 830 F)
PACKED TOMER
NR
NR
CAPBON STEEL
AISI 1110
N/A
INORGANIC
PREFIREO BRICK/SHAPES
ACID-RESISTANT BRICK [LOU H20 ABSORPTION!
121.1 ( 250 F)
PRIMARY COLLECTOR
1
IMPINGEMENT
MESH
KNITTED HIRE MESH PAD
4.5 (18.0 IN-H20)
HIGH ALLOY
NR
INTERMITTENT
1
IN-LINE
NR
NR
14.5
247.8 ( 446 F)
176.7 ( 350 F)
NR
NR
INDUCED DRAFT
1044
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)
»* FANS
CONSTRUCTION MATERIAL GENERIC TYPE
»» CAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» OUCTWCHK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«» TAWS
SERVICE
PRODUCT ACID
«« PUMPS
SERVICE
ACID RECIRCULATION
PRODUCT ACID
*• SOLIDS COHCENTRATING/DEUATERIN5
DEVICE
NUMBER
»»« SLUDGE
»» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»« DISPOSAL
NATURE
TYPE
SITE TREATMENT
»» PROCESS CONTROL AN9 INSTRUMENTATION
CHEMICAL PARAMETERS
STAINLESS STEEL
KB
NR
NR
NR
NR
HR
NR
STAINLESS STEEL
NR
NONE
N/A
N/A
N/A
N/A
NUMBER
2
NUMBER
ita
o
N/A
N/A
N/A
N/A
NONE
NR
TEMPERATURE, ASH LOADINGS. ACID CONCENTRATION
^ PERFORMANCE DATA
PERIOD tlODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTCR
9/72 SYSTEM
** PHCBlEHS/SOLUTIONS/CCrCIENTS
33.9
7CO
£44
THE EMISSION CONTROL EQUIPMENT AT THE HOOD RIVER SITE INCLUDED MECHANICAL
COLLECTOPS, A HIGH EFFICIENCY ESPi AND A MONSANTO CATALYTIC OXIDATIOM
(CATOX) FGD SYSTEM FOR THE CONTROL OF PARTICLE MATTER AND SULFUR DICXIDE.
FOLLOWING PASSAGE THROUGH THE PARTICLE MATTER REMOVAL SYSTEM, THE FLUE GAS
1045
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
ILLINOIS POWER COMPANY: WOOD RIVER 4 (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PE9 BOILER FGO CAP.
S02 PART. HOUPS HOUPS HOUPS FACTOR
ENTERED THE SCRUBBINS SYSTEM AliO WAS HEATED TO A TEMPERATURE OF 650F AND
THEM PASSED THROUGH A VANADIUM PENTOXIOE FIXED-BED CATALYTIC CCNVEPTER,
WHERE THE SULFUR DIOXIDE HAS OXIDIZED TO SULFUR TPIOXI3E. THE GAS THEN
FLOWED THROUGH AN ACID ABSORPTION TOWER > k'HEPE THE SULFUR TRIOXIDE IN THE
GAS WAS CONVERTED TO SULFURIC ACID. AN ACID HIST ELIMIHVT09 EHSJSE3
REMOVAL OF ENTRAINED ACID MIST FROM THE GAS STREAM. THE CLEANED GAS WAS
DISCHARGED TO THE STACK AND THE PRODUCT ACID HAS COOLED AND STORED IN
TANKS.
10/72 SYSTEM 23.9 744 17S
•• PROBLEnS/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 HAS 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 REGENERA8LE SYSTEM INCLUDED: FROZEN DAMPERS CN REHEAT
BURNEPS, CRACKS IN THE TEFLON LINER ON THE ACID PUMP'S DISCHARGE HEADER
CRACKS IN THE REHEAT DUCTIN5, FALL OF REFRACTORY BRICKS FROM THE REHEATER
BURNER DOME, AND NEED FOR REINFCPCEMEHT OF THE STRUCTURE SUPPORTING THE
HIGH TEMPERATURE FLUEGAS DUCT TO THE CATALYTIC CONVERTER.
1046
-------
EPA UTILITY FGO SURVEY: OCTOBER - OECErBER 1931
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUM3ER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - KS/J
SOZ EMISSION LIMITATION - HG/J
KOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - HU
GPOSS UNIT GENERATING CAPACITY - MU
MET UNIT GENERATING CAPACITY U/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGO - MU
EQUIVALENT SCRUBBED CAPACITY - M!4
KEY WEST UTILITY BOARD
STOCK ISLAND
1
KEY WEST
FLORIDA
473.
******
42
42
37
«*•**
37
(»»*•«» LB/MMSTU)
( 1.100 LB/r-.3TU)
(««««»* LB/fuM.3TU)
UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SEPVICE LOAD
DESIGN BOILER FLUE GAS FLOW
BOILER FLUE GAS TEMPERATURE
STACK HEIGHT - M
STACK SHELL
STACK TOP DIAMETER - M
cu.n/s
c
ERIE CITY
OIL FIRED
BASE
*««**»*
34.
GUNITE
«**»*«»
(»•»»««* ACFM)
(«««« F)
( 110 FT)
(«««»« FT)
»« FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - 7.
RANSE ASH CONTENT - 7.
AVERAGE MOISTU°E CONTENT - 7.
RANSE MOISTUPE CONTENT - 7.
AVERAGE SULFUR CONTENT - 7.
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RANGE CHLORIDE CONTENT - 7.
«»« PARTICLE CONTROL
•« MECHANICAL COLLECTOR
NUM5ER
PRESSURE DROP - KPA
•« FABRIC FILTER
NUMBER
TYPE
«« ESP
NUMBER
TYPE
«« PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
••« FGD SYSTEM
»• GENERAL DATA
SALEABLE PRODUCT/THROUAMAY PRODUCT
SC2 REMOVAL MOOE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
HEM/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
OIL
NO. 6
*«»<•*«
.04
«•**«*
«»»*««««
(«»»»•• BTU/LB)
«»**»*
2.01
2.0-3.0
«•«»»*•»
«*»*»«
( 3. IN-HZO)
0
NONE
0
NONE
NONE
N/A
N/A
N/A
THPOKAMAY PRODUCT
WET ECRUSBIN3
LIMESTONE
ZURN AIR SYSTEM
DEMONSTRATION
NEW
7. 90.00
1047
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)
UNIT DESIGN 32 REMOVAL EFFICIENCY - X 85.00
HARMING ««UNNORMAL:ZEO NirsER(S) BEING EDITED FOR OUTPUT**
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
INITIAL START-UP
»» DESIGN AND OPERATING PARAMETERS
»* OUENCHER/FHESATUPATO'?
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
•• ABSOPBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRAOE NAME/COMMON 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
GtS CONTACTING DEVICE TYPE
LIQUID RECIRCULATICN RATE - LITER/S
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
TPAOE NAME/CCMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«« REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENEPIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* FANS
NUMBER
APPLICATION
»* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
*» DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
*»»**«*
a
1/75
10/73
NR
NR
VENTURI TOMER
NR
NR
ZURN AIR SYSTEMS
STAINLESS STEEL
AUSTENITIC
TYPE 304L
NONE
N/A
N/A
SCRUBBING TUBE
25. (
1.5 (
58.04 C
62.3 C
400 GPM)
6.0 IN-H20)
123000 ACFM)
145 F>
PRIMARY COLLECTOR
IMPII.'SEMENT
CURVED DEFLECTOR PLATE
GULL WING
ORGANIC
FIBER-REINFORCED POLYESTER
0
NONE
N/A
N/A
NOME
N/A
INDUCED DRAFT
NR
NR
NR
NR
NR
NR
NR
NR
NR
MET BALL MILL
NR
NR
1046
-------
EPA UTIL" Y FGD SURVEY: OCTOBER - DECEMBER 1981
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.)
«« SOLIDS CONCEKTRATING/DEUATERING
DEVICE NA
»»» SLUDGE
»* TREATMENT
METHOD BLEED
DEVICE N/A
PROPRIETARY PROCESS N/A
»« DISPOSAL
NATURE FINAL
TYPE POND
SITE TREATMENT NONE
** PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS TEMPERATURE. PARTICLE LOADING. PH
•« MATER BALANCE
MATER LOOP TYPE OPEN
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGO CAP.
502 PART. HOURS HCURS HOURS FiCTCR
6/73 SYSTEM 3.6 744
»» PROBLEMS/SOLUTIONS/COKMENTS
THE EMISSION CONTROL SYSTEM AT THE STOCK ISLAND PLANT CONSISTED OF A
MULTIPLE TUBE MECHANICAL COLLECTOR INSTALLED UPSTREAM OF TMO SULFUR DIOXIDE
MET SCRUEBERS. THIS DEMONSTRATION FACILITY EMPLOYED LIMESTONE IN A SEAHATER
SOLUTION FOR THE REMOVAL OF SOZ. THE LIMESTONE ABSORBENT MAS OBTAINED
FROM CORAL DREDGED FROM THE OCEAN. THE CORAL CONSISTED PRIMARILY OF
CAC03 MITH LITTLE OR NO MGC03. THE CORAL MAS GROUND TO A FINE PCKOER IN A
HAMHERMILL CRUSHER TO 90X MINUS 325 MESH AND SLURRIEO IN SEAH4TEP.
THE SCRUBBING SYSTEM MAS SCHEDULED TO START UP IN JULY 1972, BUT DID NOT
OPERATE UNTIL AUGUST 1973. DURING THE INTERIM, THE PRIMARY CPUSHIH3
SYSTEM BECAME FROZEN BECAUSE OF SALT AIR CORROSION TAKING PLACE FROM
DISUSE.
9/73 SYSTEM .0 720
10/73 SYSTEM 4.6 744
11/73 SYSTEM 5.6 720
12/73 SYSTEM 9.7 744
•« PROBLEMS/SOLUTIONS/COMMENTS
FROM STARTUP IN AUGUST 1973 UNTIL DECEMBER 10. 1973 THE LONGEST SCFU3BER
RUN MAS FIVE DAYS; ASIDE FROM THAT, THE SCRUBBER MAS UP AND OCXN C.'IE
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 UITH 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
1049
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
KEY WEST UTILITY BOARD: STOCK ISLAND 1 (CONT.>
PERFORMANCE DATA
PERIOD KCOULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
S02 PART. HO'JPS HOURS HOURS FACTOR
»» PROBLEMS/SO LUTIONS/COMMEMTS
ON JANUARY 2 THE 1A SCRUBBER EXPERIENCED PLUGGING CAUSING THE SYSTEM TO
SHUTOOMN.
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 HIGH PRESSURE ALARM AND THE SENSING DEVICE TRIPPED DUE TO SLUC3E
BUILDUP. THIS KEPT THE SYSTEM OUT CF SERVICE FOR APPROXIMATELY FOUR DAYS.
ON JANUARY 22 THE SYSTEM MAS TAKEN OUT OF SERVICE FOR ABOUT THREE HOIPS
DUE TO A RUPTURED LINE ON ONE OF THE PUMPS AND A DECREASE IN THE PRESSURE
CROP. CORRODED LOOSE NUTS AND BOLTS HERE FOUND IN THE LINE.
ON JANUARY £8 THE SYSTEM MAS SHUTDOWN FOR MODIFICATIONS WHICH INCLUDED;
REPLACEMENT OF THE CYCLONE BY A BAGHOUSE AND REPLACEMENT OF THE VI33ATCPY
FEEDER BY A SCREW FEEDER.
2/74 SYSTEM .0 672
3/74 SYSTEM .0 74*
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 7CO
10/74 SYSTEM 37.5 744
11/74 SYSTEM 43.1 720
12/74 SYSTEM 16.1 744
1/75 SYSTEM .0 744
»• PROBLEMS/SOLUTIONS/COMMENTS
AFTER STARTUP IN AUGUST 1973, ENSUING OPERATION PROCEEDED ON AN INTERMIT-
TENT BASIS. THE MAJOP 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 SCRUSBER MODULES
• POOR LIMESTONE UTILIZATION I APPROXIMATELY 20X)
•INDUCED DRAFT FAN REPAIRS
•REPLACEMENT OF INTERNAL STAINLESS STEEL PARTS WITH HONEL COMPONENTS
•BOILER FOUNDATION AND BOILER TUBE PROBLEMS
•LIMESTONE SUPPLY SHORTAGES
AS OF MARCH 1977 IT HAD NOT BEEN DECIDED WHETHER THERE WOULD BE FUTURE
FGO OPERATIONS AT THE STOCK ISLAND PLANT. DURING OPERATION THE SCRUBBING
SYSTEM LOGGED 1579 HOURS FOR A TOTAL OPERABILITY OF 8X.
1050
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1=81
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PUNT NAME
UNIT NUMBER
CITY
STATE
PEC-ULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
502 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENEPATINS CAPACITY - MM
GROSS UNIT GENEPATINS CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - MM
NET UNIT GENERATING CAPACITY KO/FGD - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN EOILER FLUE GAS FLOM - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK S»ELL
STACK TOP DIAMETER - M
PHILADELPHIA ELECTRIC
EODYSTONE
1A
ECOYSTOME
PENNSYLVANIA
D
«•»«»» (*»•***
»»•»»« (««»»»» LB/KM3TU)
«»«»•* (*»*»*« LB/MM3TU)
1395
120
120
120
COMBUSTION ENGINEERING
***»*»
BASE
437.45
157.2
76.
CONCPETE
5.6
927000 ACFM)
315 F)
249 FT)
( 18.5 FT)
»» FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/6
RAN3S HEAT CONTENT - BTU/Lfi
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - 7.
RANGE MOISTURE CONTENT - 7.
AVERAGE SULFUR CO'ITENT - 7.
RANGE SULFUR CONTENT - 7.
AVEPAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - 7.
«»* PARTICLE CONTROL
»* MECHANICAL COLLECTOR
HUrSER
COAL
BITUMINOUS
31634.
9.40
*»***»
5.90
«»«*«*
2.60
( 13600 BTU/LB)
««»**«
«**«*««*
«« ESP
NUHBER
»» PARTICLE SCRUBBER
NUMBER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CONTACTING DEVICE TYPE
NUT.3ER 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
NUMBER
INITIAL START-UP DATE
2
9/75
VENTURI TOMER
VARIABLE-THROAT/VERTICALLY-AOJUSTABLE ROD DECKS
ROD SCRUBBER
ENVIRONEERING
14.0 X 25.0 X 53.0
STAINLESS STEEL
AUSTENITIC
NONE
N/A
NONE
1
.6 (
.0 (
145.8 (
157.2 (
1
9/75
4.8 GAL/1000ACF)
.1 IN-H20)
309000 ACFM)
315 F)
1051
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
PHILSCELPHIA ELECTRIC: EODYSTONE 1A (CONT.)
GENERIC TYF
SPECIFIC TY?i
TRADE NAME/COMMON NAME
SUPPLIER
DIMENSIONS - FT
SniLL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
LINER GENERIC MATERIAL
LINER SPECIFIC MATERIAL
GAS CC! -ACTING DEVICE TYPE
NUMBER JF CONTACTING ZONES
L/G RATIO - LITER/CU.M
PRESSURE DPOP - KPA
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
••* FGD SYSTEM
»» GENERAL DATA
SALEABLE PRODUCT/THROUAUAY PRODUCT
SO: 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.
ENERGY CONSUMPTION - 7.
CU3PEHT STATUS
TERMINATION
COMMERCIAL START-UP
INITIAL START-UP
** DESIGN AND OPERATING PARAMETERS
»* GUENCHER/PRESATUPATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
PHILADELPHIA ELECTRIC: EDDYSTONE 1A ICONT.)
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL £-=CIFIC TYPE
WASH WATER SOL'PCE
WASH FREQUENCY
*« REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE HAtlE/COrmON TYPE
TEMPERATURE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
•* FANS
NUMBER
SUPPLIER
FUNCTION
APPLICATION
SERVICE
FLUE GAS FLOW RATE - CU.M/S
FLUE GAS TEMPERATURE - C
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»« DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»« DUCTUSSK
LOCATION
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
•« REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«« PUMPS
SERVICE
ABSORBER RECIRCULATION
** SOLIDS CONCENTHATING/DEWATERING
DEVICE
NUMBER
DIMENSIONS - FT
OUTLET STREAM CHARACTERISTICS
»« SOLIDS CONCENTRATING/DEUATERING
DEVICE
NUMBER
*«* SLUDGE
ORGANIC
FIBER-REINFORCED POLYESTER
FRESH
INTERMITTENT
DIRECT COMBUSTION
IN-LINE BURNER
OIL
57.2 ( 103 F)
51.7 ( 125 F)
NR
NR
BUFFALO FORGE
BALANCED DRAFT
INDUCED DRAFT
DRY
107.2
268000 ACFM)
225 F)
NR
NR
NR
NR
NR
NR
NR
SCRUBBER INLET
STAINLESS STEEL
AUSTENITIC
NONE
N/A
SCRUBBER OUTLET
STAINLESS STEEL
AUSTENITIC
NCNE
N/A
SLAKER
NR
Hit
NUMBER
2
THICKENER
1
40.0 DIA
25X SOLIDS
CENTRIFUGE
1
1053
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
PHILADELPHIA ELECTRIC: EDDYSTOHE 1A (CONT.)
«» TREATMENT
METHC3 DEUATERED
DEVICE N/A
PROPRIETARY PROCESS N/A
*» DISPOSAL
NATURE N/A
TYPE NONE
SITE TREATMENT N/A
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
PHILADELPHIA ELECTRIC: EDDYSTONE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PEP BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
MSO REGENERATION FACILITY FIRST PROCESSED MAGNESIUM SULFITE FROM THE EDDY-
STONE SCRUBBER OH OCTOBER 26, 1975. THE C-SIOE PARTICULATE SCPU2SEP OPEPA-
TED A TOTAL OF 2831 HOURS THROUGH JANUARY 31, 1976. FCR AN OPEPABILITY OF
70X. THE B-SIDE TPAIN HAS OPERATED A TOTAL OF 1933 HOURS THPC'JC-H
JANUARY 31, 1976 FCR AN OPERABILITY OF 55X. THE A-SIDE TRAIN OPERA-
TED A TOTAL OF 626 HCUPS THROUGH JANUARY 31, 1976, FOR AN OPERABILITY OF
24X. THE C-SIDE S02 ABSOPBER HAS IN SERVICE A TOTAL OF 556 HOURS
THROUGH DECEMBER 31. 1975. KITH AN OPERABILITY OF 33X SINCE START
UP. PROBLEMS ENCOUNTERED IN THE OPERATION OF THE THPEE SCRUS5INS TRAINS
INCLUDED UNDER-DESIGNED RECIRCULATIOH PUMPS, MALFUNCTION OF THE FLUE GAS
BY-PASS DAMPER DRIVE UNITS AMD 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 MAS TEMPORARILY HALTED
BECAUSE THE ACID PLANT REGENERATION FACILITY AT THE OLIN CHEMICAL SULFURIC
ACID PLANT IN PAULSBORO, NEW JERSEY PERMANENTLY CEASED OPERATIONS. THE
UTILITY WAS INVESTIGATING ALTERNATIVE REGENERATION SITES. A MINIMUM
PEPIOD OF SIX MONTHS WAS REQUIRED FCR 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 MERE CONTINUING TO OPERATE AND THESE UNITS
UEREARE CONTINUING TO EXPERIENCE PROBLEMS WITH THE FANS, REHEAT BURNERS,
DAMPERS AND EXPANSION JOINTS.
1/76 SYSTEM 744
2/76 SYSTEM 696
3/76 SYSTEM 744
4/76 SYSTEM 720
5/76 SYSTEM 744
6/76 SYSTEM 720
«• PROBLEMS/SOLUTIONS/COMMENTS
RESUMPTION OF SO2 SCRUBBING OPERATIONS WAS SCHEDULED FOR DECEMBER
1976. THE RELOCATION OF THE REGENERATION FACILITY WAS IN PROGRESS. THE
PARTICULATE SCRUBBERS WERE OPERATIONAL. THE C-SIOE BOOSTER FAN DEVELOPED
A MATERIALS FAILURE BETWEEN THE HUB AND SHAFT (IDENTICAL TO THE
B-SIDE UNIT MENTIONED EARLIER).
7/76 SYSTEM 744
8/76 SYSTEM 744
9/76 SYSTEM 720
1055
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
PHILADELPHIA ELECTRIC: EDOYSTONE 1A (CONT. )
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGO CAP.
SOZ PART. HOURS HOURS HOURS FACTOR
«» PROBLEMS/SOLUTIONS/COMMENTS
ALL THREE BOOSTER FANS DOWNSTREAM OF THE REHEATEPS DEVELOPED MATERIALS
FAILURE BETWEEN THE HU3 AND SHAFT (AS IDENTIFIED EARLIER FOR THE B-SICE
UNIT I. THESE UNITS MERE RETURNED TO THE MANUFACTURER FOR MODIFICATIONS
AND REPAIRS. ONE OF THE PARTICULATE SCRUBBERS UAS IN THE FLUE GAS
STREAM. TO DATE, THE THREE MET PARTICULATE SCRUBBERS HAD ACHIEVED
LITTLE SIMULTANEOUS SERVICE TIME.
10/76 SYSTEM 744
11/76 SYSTEM 720
1Z/76 SYSTEM 744
*» PROBLEMS/SOLUTIONS/COMMENTS
MGO SCRUBBING OPERATIONS HERE SCHEDULED TO RESTART IN MAY 1977. RE-
GENERATION FACILITY RELOCATION MAS BEING COMPLETED, AND MODIFICATIONS TO
THE ID BOOSTER FANS BEING EFFECTED CONSISTED OF CONVERSION FROM A
SLIP FIT TO A SHRINK FIT. THESE MODIFICATIONS MERE EXPECTED TO ELIMINATE
RECURRING VIBRATION PROBLEMS.
1/77 SYSTEM 744
2/77 SYSTEM 672
3/77 SYSTEM 744
fc» PRCBLEMS/SOLUTIONS/COMMENTS
THE MGO SCRUBBING SYSTEM AT EODYSTONE 1A HAS STILL SCHEDULED FOR
RESTART IN MAY 1977. THE START-UP OF THE HEM MAGNESIUM SULFITE REGENER-
ATION FACILITY AT THE ESSEX CHEMICAL PLANT AT NEWARK. N.J. MAS ALSO SCHED-
ULED FOR MAY 1977. THE THREE PARALLEL VENTL'RI SCRUS3ERS CONTROLLING PAR-
TICULATE EMISSIONS ON EODYSTONE 1 UENT BACK INTO SERVICE IN MARCH 1977.
4/77 SYSTEM 720
5/77 SYSTEM 744 206
•« PROBLEMS/SOLUTIONS/COMMENTS
RESUMPTION OF MAGNESIUM OXIDE SCRUBBINC OPERATIONS OCCURRED DUPING THE
REPORT PERIOD. THE UTILITY REPORTED THAT SOZ SCRUBBING OPERATIONS MEPE
NOT CONTINUOUS THROUGHOUT THE PERIOD. THE ABSORBER MAS IN SERVICE APPROXI-
MATELY 206 HOURS DURING MAY. REGENERATION OPERATIONS AT THE ESSEX FACILITY
MERE NOT CONDUCTED DURING THE PERIOD. PECO PLANNED TO INITIATE S02 RE-
COVERY AND MAGOX REGENERATION OPERATIONS DURING THE MONTH OF JUNE. THE S32
MODULE CONTAINED TMO ABSORBER SECTIONS IN SERIES (EACH SECTION CONSISTING
OF AN ADJUSTABLE ROD DECK MITH UHDERSPHAYS). ONLY ONE OF THE ABSORBER
SECTIONS MAS BEING USED FOR S02 REMOVAL. SOZ REMOVAL EFFICIENCY HAS NOT
MEASURED. MAGNESIUM OXIDE LOSSES IN THE SYSTEM (ABSORPTION AND
REGENERATION) HERE ESTIMATED AT 10X.
6/77 SYSTEM 720
7/77 SYSTEM 744
1036
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEASES 1931
PHILADELPHIA ELECTRIC: EOOYSTCNE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FCC CAP.
502 PART. HOURS HO'J=S HO'JPS FACTOR
•« PROBLEtlS/SOLUTIONS/COmENTS
FAILURE OF MINOR ANCILLIAHY EQUIPMENT CAUSED SOME SCRUSBER SHUTDOWNS.
LATER. THE BOILER ITSELF WAS SHUT DOWN. OVER THIS FEHIC3 THE EOTiRY VALVE
C!< THE MAG SULFITE DRIER OISCHAPGE PLUGGED REPEATEDLY. ALSO THE BELTS ON
THE AGITATOR OF THE MAG-OX PRESLAKER FAILED.
8/77 SYSTEM 744
9/77 SYSTEM 720
** PRCBLEHS/SOLUTlONS/CCmENTS
THE ROTARY VALVE PROBLEM APPEARED TO BE SOLVED. CUMULATIVE OPERABILITY
SIHCE MAY MAS ESTIMATED TO BE ROUGHLY 33X. PECO REPORTED 131 HCURS OF
CONTINUOUS OPERATION FOR THE SCRU5BER AND THICKENER CENTRIFUGE DRYING
LOOP. DURING THE AUGUST-SEPTEM5ER REPORT PERIOD CONTINUAL FRC3LEMS 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
*« PROBLEHS/SOLUTIONS/CCMHENTS
CUMULATIVE OPERABILITY FOR MAY THROUGH NOVEMBER 1977 WAS 39X. DURING THE
OCTOBER-NOVEMBER PERIOD THE FGO SYSTEM ACHIEVED A 213 HOUR CONTINUOUS
RUN. THIS WAS THE LCNGEST CONTINUOUS RUN SINCE KAY 1977.
GLAND PACKING PROBLEMS PERSISTED AND MECHANICAL SEALS WERE BEIMS
CONSIDERED AS POSSIBLE ALTERNATIVES. EVEN WITH HEAT TRACING THE SEAL
HATER FROZE-UP CAUSING HOTAMETERS TO BURST. HIGH SOLIDS ACCUMULATION IN
THE THICKENER MAS STILL A PROBLEM AREA.
12/77 SYSTEM 41.0 744
1/7B SYSTEM 744 0
«« PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT MAS 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 MEEK IN MAPCH.
THE CUMULATIVE OPERABILITY FACTOR FOR THE FOURTH QUARTER OF 1973 HAS 41X.
DURING THIS PERIOD SOME OF THE HEAT TRACING FAILED AND OTHER PHCSLEKS
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 MERE STILL BEINS CONSIDERED.
THE UTILITY MAS 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
MERE CRACKED. SO UNIT MAINTENANCE TOOK LONGER THAN EXPECTED. SOME
MINOR FGO SYSTEM MODIFICATIONS WERE INCORPORATED IN THE COURSE OF
1057
-------
EPA UTILITY F6D SUS.EY: OCTOBER - DECEMBER 1981
PHILADELPHIA ELECTRIC: EODYSTOME 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERASILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HOURS HOU^S HOURS FACTOR
THE SHUTDOWN PERIOD. START UP HAS EXPECTED IN MID-APRIL 1976.
4/73 SYSTEM .0 720 0
5/78 SYSTEM .0 744 C
«* PROBLEMS/SOLUTIONS/COMMENTS
THE UNIT CAME BACK ON LINE JUNE 1 AFTER AN EXTENSIVE SYSTEM MODIFICATION
OUTAGE WHICH BEGAN DECEMBER 22. THE UNIT UAS EXPECTE3 BACK OH LIME IN MID-
APRIL. BUT THERE UAS A PPOBLEM KITH A SUPER PRESSURE STEAM TUHSIKE.
6/78 SYSTEM 49.0 720
7/78 SYSTEM 51.0 744
*» PROBLEMS/SOLUTICNS/COKriENTS
DURING JUNE THE FGD SYSTEM ACHIEVED A 49Z OPERABILITY. OPERABILITY FOR
JULY UAS SIX. PROBLEMS OCCURRED IN LATE JUNE UITH THE H3S03 SLU=RY
CIRCULATION PUMP WHEN THE UTILITY DISCOVERED THE RUBBER LINER UAS TORN
AUAY. THERE HERE SOME PROBLEMS UITH THE MGO SECTION UHERE THE MSO
MIXES UITH THE SYSTEM LIQUOR. FIRE BRICK UAS REMOVED FROM THE FLUID BED
REACTOR CHAMBER TO REPLACE THE ACID BARRIER PLATES UHICH UERE FAILING.
THE FIRE BRICK UAS THEN REPLACED. THE SLOW PIECE BY PIECE PROCEDURE UAS
TIME CONSUMING AI
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEM3EH 19S1
PHILADELPHIA ELECTRIC: EDOYSTONE 1A (CONT.)
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPEPABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FG3 CAP.
S02 PART. HOIRS HOURS KCUSS FACTOR
5/79 SYSTEM 7*4
6/79 SYSTEM 710
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 0
2/80 SYSTEM 696 0
3/80 SYSTEM 744 0
*» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER AND TURBINE MERE DOWN DURING THE FIRST QUARTER 1980 FOR TUPBINE
MAINTENANCE.
OPERATION OF THIS PROTOTYPE MAGNESIUM OXIDE SYSTEM. WHICH TREATED ONE
THIRD OF THE FLUE GAS FROM THE EDDYSTONE 1 BOILER. WAS TERMINATED.
THE S02 REMOVAL EQUIPMENT WILL BE REPLACED WITH A SIMILAR MAG-OX SYSTEM
DESIGNED TO TREAT 100X OF THE BOILER FLUE GAS. THE EXPECTED START
DATE OF THIS SYSTEM IS DECEMBER 1982. CURRENT REGULATIONS 00 NOT
REQUIRE CONTROL OF S02 EMISSIONS UNTIL THE NEW SCHUSSER IS AVAILABLE
FOR OPERATION.
1059
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGO SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTIC'JLATE EMISSION LIMITATION - N6/J
£02 EMISSION LIMITATION - NG/J
NCX EMISSION LIMITATION - NS/J
NET PLANT GENERATING CAPACITY - HH
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY U/FGO - KU
NET UNIT GENERATING CAPACITY UO/FGO - MW
EQUIVALENT SCRUE3EO 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 - H
STACK SHELL
STACK TOP DIAMETER - M
»« FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVEPAGE ASH CONTENT - X
RANGE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTUPE CONTENT - X
AVERAGE SULFUR CONTENT - X
RAN'GE SULFUR CONTENT - X
AVERAGE CHLG9IDE CONTENT - X
RANGE CHLORIDE CONTENT - X
»»» PARTICLE CONTROL
«» MECHANICAL COLLECTOR
NUMBER
TYPE
»* FABRIC FILTER
NUM3ER
TYPE
»• ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
«» PARTICLE SCRU2SER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
»»» FGD SYSTEM
«* GENERAL DATA
SALEABLE PRODUCT/THROWAWAY PRODUCT
SOS REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
(»««««* LB/~M3TU)
( 1.600 LB/MM3TU)
(«*«»** IB/KKBTU)
POTOMAC ELECTRIC POWER
DICKERSON
3A
DICKERSON
MARYLAND
E
««»*•*
668.
»»»»»*
548
190
178
182
95
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
278.42 ( 590000 ACFM)
126.1 I 259 F)
122. ( 400 FT)
CONCRETE
*«*««•*« («**•* FT)
I 11700 BTU/LB)
•«*•««
COAL
BITUMINOUS
27214.
14.00
••»*«*
**»««»*»
6.0-7.0
2.00
««*»**
«*«*«*«»
*«*«•*
0
NONE
0
HONE
RESEARCH-COTTRELL
97.5
VEMTURI TCWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
NONE
SALEABLE PRODUCT
WET SCRUSBIt.'S
MAGNESIUM OXIDE
NCME
GE ENVIRONMENTAL SERVICES
GE ENVIRONMENTAL SERVICES
1060
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
POTOMAC ELECTRIC POWER: OICKERSON 3A (COKT.)
DEVELOPMENT LEVEL
NEH/RETPCFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN S02 REMOVAL EFFICIENCY - 7.
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
CCriERCIAL STA3T-UP
INITIAL START-UP
CONTRACT AWARDED
»« DESIGN AND OPERATING PARAMETERS
«» GUENCHER/PRESATURATOH
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
•• ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON 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
L/G RATIO - L/CU.n
GAS-SIDE PRESSURE DROP - KPA
SOI 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
PRESSUPE DROP - KPA
SUPE9FICAL GAS VELOCITY - M/S
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«•> REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»" FANS
NUMBER
FUNCTION
SERVICE
CONSTRUCTION MATERIAL GENERIC TYPE
** DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
DEMONSTRATION
RETROFIT
X 99.30
90.00
.0
a
8/75
7/74
9/73
7/71
NR
NR
VENTURI TOWER
VARIABLE-THROAT/TOP-ENTRY PLUMB BOB
N/A
GE ENVIRONMENTAL SERVICES
CARBON STEEL
AISI 1110
N/A
ORGANIC
GLASS FLAKE-FILLED POLYESTER
NONE
5.3
2.2
90.0
( 40.0 GAL/1000 ACFI
( 9.0 IN-H20)
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
3
2
5.1
45
.2
3.0
ORGANIC
C 2.00 IN)
( 1.0 IN-H20)
( 10.0 FT/S)
FIBER-REINFORCED POLYESTER
0
NONE
N/A
N/A
NONE
N/A
1
UNIT
MET
HIGH ALLOY
NR
NR
NR
NR
HP
NR
NR
1061
-------
EPA UTILITY F6D SURVEY' "CTXER - DECEMBER 1981
POTOMAC ELECTRIC POWER: ..ICKERSON 3A (CONT.)
»« DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«* PEAGENT PREPARATION EQUIPMENT
FUIJCTICN
DEVICE
DEVICE TYPE
«* TANKS
SERVICE
»* SOLIDS CONCENTRATING/OEUATERINS
DEVICE
NUMBER
*»» SLUDGE
«t TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
» DISPOSAL
NATURE
TYPE
SITE TREATMENT
»* PROCESS CONTROL AND INSTRUMENTATION
CHEMICAL PARAMETERS
CONTROL LEVELS
MONITOR LOCATION
PROCESS CCMTROL MANNER
PROCESS CHEMISTRY MODE
MR
NR
NR
in
N9
NR
NR
NUMBER
1
THICKENER
2
THICKENED
N/A
N/A
N/A
NOME
N/A
PH, PRESSURE DROP
PH 7
IN SECOND STAGE SYSTEM
AUTOMATIC
FEEDBACK
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
7. REMOVAL PER BOILER FSO CAP.
S02 PART. HOIRS HOURS HOU3S FACTOR
0/75 SYSTEM
«« PROBLEMS/SOLUTIONS/COMMENTS
REFER TO THE PERFORMANCE UPDATE INFORMATION FOR DICKERSON 3 LOCATED IN
SECTION 14.
106Z
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
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 - MU
GROSS UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY H/FGD - MM
NET UNIT GENERATING CAPACITY HO/FGO - KM
EQUIVALENT SCRUBBED CAPACITY - MM
»* UNIT DATA - BOILER AND STACK
EOILER SUPPLIER
BOILER TYPE
GOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - M
STACK SHELL
STACK TO? DIAMETER - H
•* FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - X
RANGE ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTENT - X
RAII3E SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
RANGE CHLORIDE CONTENT - X
««* PARTICLE CONTROL
»« MECHANICAL COLLECTOR
NUMBER
INLET FLUE GAS CAPACITY - CU.M/S
•» FABRIC FILTER
NUMBER
TYPE
»• ESP
NUMBER
TYPE
INLET FLUE GAS CAPACITY - CU.M/S
«« PARTICLE SCRUBBER
MUVSER
INITIAL START-UP DATE
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
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.n
PRESSURE DROP - KPA
( .100 LB/MHSTU)
(«***»» LB/MrSTU)
(»*«»»»* LB/MK3TU)
PUBLIC SERVICE OF COLORADO
VALMONT
5A
VALMONT
COLORADO
B
43.
»*»*«*
**«»«»
274
166
157
163
166
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
436.98 ( 926000 ACFM)
126.7 ( 260 F)
«*««*» (***» FT)
»•*«**
««»«»»« (««»«« FT)
COAL
SUEBITUMINOUS
25121.
6.00
5.4-7.0
15.00
12.7-18.3
.70
0.6-0.7
*«**«««»
«««««*
218.5
0
NONE
COLD SIDE
218.5
( 10800 BTU/LB)
******
( 463000 ACFM)
( 463000 ACFM)
1
11/71
PACKED TOMER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
AIR CORRECTION DIVISION. UOP
CARBON STEEL
AISI 1110
ORGANIC
RUBBER
STAINLESS STEEL
3
7.8 (58.3 GAL/1000ACF)
3.7
(15.0 IN-H20)
1063
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
PUBLIC SERVICE OF COLORADO: VALMONT 5A CCONT.)
SUPERFICIAL GAS VELOCITY - M/S
INLET GAS FLOW RATE - CU.M/S
INLET GAS TEMPERATURE - C
S02 REMOVAL EFFICENCY - X
PARTICLE REMOVAL EFFICIENCY - X
*** FGD SYSTEM
3.4
109.2
132.6
45.0
96.0
( 11.0 FT/S)
( 231500 ACFM)
( 271 F)
«» GENERAL DATA
SALEABLE PRODUCT/THROWAHAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
PROCESS ADDITIVES
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
HEU/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY -
UNIT DESIGN S02 REMOVAL EFFICIENCY - X
THROUAUAY PRODUCT
MET SCRU3BIN5
LIMESTONE/ALKALINE FLYASH
NONE
L'OP/PUSLIC SERVICE OF COLORADO
STEARNS-ROGEH
EXPERIMENTAL
RETROFIT
Y. 95.00
85.00
MARKING ««UNMORMALIZED NUMBERCSJ BEINS EDITED FOR OUTPUT**
ENERGY CONSUMPTION - X
CUPRENT STATUS
TERMINATION
INITIAL START-UP
*« DESIGN AND OPERATING PARAMETERS
*« QUEMCHER/FRESATUSATCH
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«« ADSOP3ER
NUTSER
UUM2ER OF SPARES
GENERIC TYPE
SPECIFIC TYPE
TPAOE NAME/COMMON 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
S02 REMOVAL EFFICIENCY - X
»* MIST ELIMINATOR
FHE-HIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COraON TYPE
CONFIGURATION
MUM5ER OF STAGES
NUM3ER OF PASSES PER STAGE
PRESSURE DPOP - KPA
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
WASH WATER SOURCE
*• REHEATER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATURE INCREASE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
** FANS
FUNCTION
APPLICATION
SERVICE
.0
8
3/75
10/74
NR
NR
1
0
PACKED TOHEP
MOBILE BED PACKING
TURBULENT CONTACT AESOR3ER
AIR CORRECTION DIVISION, UOP
CARBON STEEL
AISI 1110
N/A
ORGANIC
SYNTHETIC RUBBER
NEOFRENE LS-576
77.5
PRIMARY COLLECTOR
IMPINGEMENT
BAFFLE
CLOSED VANE
HORIZONTAL
2
7
.1 ( .5 IN-H20)
STAINLESS STEEL
NR
SUPERNATANT
1
IN-LINE
STEAM
NR
36.1 ( 65 F)
NR
HR
BOOSTER
FORCED DRAFT
DRY
1064
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1931
PUBLIC SERVICE OF COLORADO: VALMOST 5A ICONT.I
CONSTRUCTION MATERIAL GENERIC TYPE CARBON STEEL
«* DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«• DUCTWORK
LOCATION
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
«» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
•* TANKS
SERVICE
RECYCLE WATER
«• SOLIDS CONCENTRATING/DEUATERING
DEVICE
»*» SLUDGE
«» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
«« DISPOSAL
NATURE
TYPE
SITE TREATMENT
** WATER BALANCE
MATER LOO? TYPE
EVAPORATION MATER LOSS - LITER/S
NR
NR
NR
HR
NR
HR
NR
OUTLET
CARBON STEEL
AISI 1110
NCNE
N/A
MET BALL MILL
NR
NR
NUMBER
1
THICKENER
BLEED
N/A
N/A
FINAL
POND
NONE
CLOSED
5.5
( 88 GPM)
—PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
7. REMOVAL PER BOILER FGD CAP.
SOZ PART. HOURS HOURS HOURS FACTCR
10/7* SYSTEM
«» PROBLEMS/SOLUTIONS/COMMENTS
REFER TO PERFORMANCE UPDATE INFORMATION FOR VALMONT 5 LOCATED IN SECTICN
14 OF THIS REPORT.
1065
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1961
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT HAKE
WIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION LIMITATION - NG/J
SC2 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
MET PUNT GENERATING CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY M/FGD - MU
NET UNIT GENEPATIN3 CAPACITY UO/FGO - KU
EQUIVALENT SCRUBBED CAPACITY - MU
»» UNIT DATA - BOILER AND STACK
EOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOU - CU.M/S
BOILER FLUE GAS TEMPERATURE - C
STACK HEIGHT - tt
STACK SHELL
STACK TGP 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 - X
AVERAGE MOISTURE CONTENT - V.
RANGE HOI STIPE CONTENT - 7.
AVERAGE SULFUR CONTENT - X
RAN3E SULFUR CONTENT - X
AVERAGE CHLCRI3E CONTENT - X
RANGE CHLOPIDE CONTENT - X
«»» PARTICLE CONTROL
«» MECHANICAL COLLECTOR
NUMBER
TYPE
»* FABRIC FILTER
NUMBER
TYPE
«» ESP
NUMBER
SUPPLIER
PARTICLE REMOVAL EFFICENCY - X
«« PARTICLE SCRUBBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
**» FGO SYSTEM
»« GENERAL DATA
SALEABLE PRODUCT/THROUAUAY PRODUCT
502 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEU/RETROFIT
t .C64 LB/MMSTU)
( .150 LB/MMBTU)
(«*»»*« LB/MMSTU)
SOUTHERN CALIFORNIA EDISON
MOHAVE
1A
LAUGHLIN
NEVADA
B
20.
64.
******
1580
790
790
790
170
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
******** I******* 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
N/A
N/A
THROUAUAY PRODUCT
MET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
PROTOTYPE
RETROFIT
1066
-------
EPA UTILITY FGD SURVEY: CCTC3ER - DECIKEEH 1«31
SOUTHERN CALIFORNIA EDISON: M3HAVE 1A (CONT.)
UMIT DESIGN PARTICLE REMOVAL EFFICIENCY - X 97.20
ENEPGY CONSUMPTION - Y. .0
CL'SPEJIT STATUS 8
7EK«:?.'ATICN 7/75
CCflKESCIAL START-UP 1/74
** DESIGN AND OPERATING PARAMETERS
»• GUENCHER/PPESATUPATCH
CSI.'ST^UCTIOV nATEPIAL GENERIC TYPE
CC TRUCTICH MATERIAL SPECIFIC TYPE
»•
NUK3EP
GENERIC TYPE
SPECIFIC TYPE
TRA" NAHE/CCKMCN TYPE
SUFr.IER
DIVISIONS - FT
SHE... GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATEPIAL TRADE NAnE/COKflON TYPE
LIliEP GEt.'cRIC MATERIAL
LINER SPECIFIC MATERIAL
LINER MATE3IAL TRA3E NAME/COMMON TYPE
GAS CCHTACTIKS DEVICE TYPE
K-JMSE^ OF CCNTACTItiG ZONES
L/G PATIO - L/CU.M
SUrEHFICAL GAS VELOCITY - MXSEC
INLET GAS FLC'J - C'J. tt/S
£02 PEMOVAL EFFICIEfffiY - 7.
PARTICLE REMOVAL EFFICENCY - V.
«» HIST ELIMINATOR
PPE-niST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE HAtlE/CCnrOM TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
HASH FREQUENCY
«» REHEATER
HUM3ES
GENERIC TYPE
SPECIFIC TYPE
TRADE JIAKE/CCMMCN TYPE
TEHPERATUOE INCREASE - C
INLET FLUE 6AS TEMPERATURE - C
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» FANS
NUMBER
APPLICATION
*• DAMPERS
FUNCTION
GENEPIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»• DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LIMcR GENERIC MATERIAL TYPE
LIMES SPECIFIC MATERIAL TYPE
NR
NR
PACKED TCUER
KC3ILE BED PACKING
TURBULENT CONTACT ABSD°EER
AIR CORRECTION DIVISION. UOP
13.0 X 40.0 X 90.0
CARBON STEEL
AISI 1110
N/A
CPGANIC
NATL'PAL PUS3ER
BLACK MATUPAL RUBBER
PLASTIC/RUBBER M03ILE BALLS
4
11.1 ( 63.0 GAL/1000 ACF)
3.8 I 12.6 FT/S)
312.35 ( 450000 ACFM)
95.0
93.0
PRIMARY COLLECTOR
NR
NR
MR
W?
NP
CONTINUOUS
IN-LINE
STEAM
NR
30.6 ( 55 Fl
51.7 ( 125 Fl
HR
NR
BOOSTER
MR
NR
NR
NR
NR
NR
KR
NR
NR
1,'P
NR
1067
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SOUTHERN CALIFORNIA EDISON: H3HAVE 1A (COMT.)
»» REAGEIJT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
NUMBER
«» SOLIDS CONCENTRATINS/DEMATERING
DEVICE
«* SOLIDS CONCENTRATING/OEHATERING
DEVICE
»« SOLIDS CONCENTRATING/DEWATEHING
DEVICE
**» SLUDGE
«» TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
»<* DISPOSAL
NATURE
TYPE
LOCATION
SITE TRANSPORTATION METHOD
SITE TREATMENT
KET BALL HILL
COMPARTMENTED
NR
1
CENTRIFUGE
THICKENER
VACUUM FILTER
FIXATION
PUG MILL
CONVERSION SYSTEMS
FINAL
POND
ON-SITE
TRUCK
NR
. PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION 7. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
10/7* SYSTEM
744
»* PROSLEMS/SQLUTIONS/COMMENTS
TWO PROTOTYPE SULFUR DIOXIDE ABSORBER MODULES MERE INSTALLED IN 1973 AT
THE MOHAVE GENERATING STATION. THE VERTICAL MODULEi A UNIVERSAL OIL PPO-
OUCTS TUPBULENT CONTACT ABSORBER (TCA) WAS TESTED IN TWO KCDES! FIRST AS
A TCA UNIT, FROM NOVEMBER 2, 1974 TO APRIL 30, 1975, AMD SECOND AS A POLY-
GRID PACKED ABSORBER (PPA). UHEN THE "PINS PONG BALLS" MERE REPLACED WITH
A PLASTIC "EGGCRATE" PACKING WITH TESTING CONTINUOUS TO JULY 2, 1975.
STARTUP OF THE MOHAVE 1A EXPERIMENTAL SYSTEM COMMENCED ON OCTOSER 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 1565 HOURS. THE OUTAGE TIME MAS CAUSED BY NECESSARY REPAIRS
TO THE G3IDS, NOZZLES. TRAP-OUT TRAY AND TO REPAIR/REALIGN PPA PACKING.
ADDITIONAL OUTAGE TIME MAS 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 HERE TERMINATED ON JULY 2, 1975. UP TO THIS TIME.
THE SYSTEM LOGGED 4226 HOURS OF OPERATION.
1066
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1961
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
HCX EMISSION LIMITATION - NG/J
NET PLANT GENERATES CAPACITY - MM
GROSS UNIT GENERATING CAPACITY - MH
NET UNIT GENERATING CAPACITY U/FGO - tlU
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MU
«« UNIT DATA - BOILER US STACK
BOILER SUPPLIER
EOILEB TYPE
BOILER SERVICE LOAD
DESIGN BOILER FLUE GAS FLOW - CU.tt/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
RAMSE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTEXT - 7.
RAMSE ASH CONTENT - X
AVERAGE MOISTURE CONTENT - X
RANGE MOISTURE CONTENT - X
AVERAGE SULFUR CONTEXT - X
RAMSE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - X
RANEE CHLORIDE CONTENT - X
*•« PARTICLE CONTROL
»* MECHANICAL COLLECTOR
NUMBER
TYPE
»» FABRIC FILTER
NLT.BEH
TYPE
*• ESP
NUMBER
SUPPLIER
PARTICLE REKOVAL EFFICENCY - Y.
«» PARTICLE SCPUBSER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
••* FGD SYSTEM
»« GENERAL DATA
SALEABLE PROOUCT/THROUAVIAY PRODUCT
SC2 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
SOUTHERN CALIFORNIA EDISON
MCHAVE
2A
LAUGHLIN
NEVADA
B
28.
64.
t .064 LB/MMBTU)
< .150 LB/M.-3TU)
(«»*»«» LB/MM3TU)
1580
790
790
790
160
COMBUSTION ENGINEERING
PULVERIZED COAL
BASE
***«»«»» (»«*»**» ACFMJ
132.2 ( 270 F)
152. ( 500 FT)
»»***»
»•»*»»• (»»4m» FT)
COAL
»»»»*•
26749.
10.00
»*•«*•
( 11500 BTU/LB)
11000-12000
»*»»•»
.40
0
NOME
0
NONE
RESEARCH-COTTRELL
97.2
NONE
N/A
N/A
N/A
THROUAUAY PRODUCT
WET SCRUBBING
LIME
SO. CALIFORNIA EOISON/STEARN5-
STEARNS-ROGER
PROTOTYPE
1069
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SOUTHERN CALIFORNIA EDISON: MOHAVE 2A (CCNT.)
NEW/RETROFIT RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY - X 97.20
WARNING *»UHNORMALIZED NUMBER(S) BEING EDITED FOR OUTPUT**
ENERGY CONSUMPTION - X
C'JSRENT STATUS
TERMINATION
COMMERCIAL START-UP
»» DESIGN AND OPERATIC PARAMETERS
«» CUENCHER/FRESATURATOR
CCMSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
•« ABSORBER
NUMBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SUPPLIER
DIMENSIONS - FT
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
NUKBEH OF CONTACTING ZONES
L/G RATIO - L/CU.M
SUFERFICAL GAS VELOCITY - M/SEC
INLET GAS FLOW - CU. M/S
SOZ REMOVAL EFFICIENCY - X
PARTICLE REMOVAL EFFICEHCY - X .
»» MIST ELIMINATOR
PRE-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TPAOE HAMS/COMMON TYPE
CONFIGURATION
MUII5ER OF STAGES
CONSTRUCTION MATERIAL GENERIC TYPE
CCMSTRUCTION MATERIAL SPECIFIC TYPE
«* REHEATER
KttiSER
GENEPIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
TEMPERATUPE INCREASE - C
INLET FLUE GAS TEMPERATURE - C
CONSTPUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» FANS
NUMBER
APPLICATION
»» DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» DUCTWORK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC MATERIAL TYPE
.0
a
2/75
11/73
NR
NR
SPRAY TOWER
OPEN CROSSCURRENT SPRAY
HORIZONTAL SPRAY CHAMBER
SO. CALIFORNIA EDISON/STEARNS-ROGER
15.0 X 30.0 X 60.0
CARSON STEEL
AISI 1110
N/A
NR
NR
m
NONE
6.6
212.35
95.0
93.0
( 30.0 GAL/1000 ACF)
( 21.6 FT/S)
( 450000 ACFM)
PRIMARY COLLECTOR
NR
NR
NP
VERTICAL
1
NR
NR
INDIRECT HOT AIR
EXTERNAL HEAT EXCHANGER
STEAM TUBE BUNDLE
30.6 ( 55 F)
48.9 ( 120 F)
NR
NR
1
BOOSTER
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
1070
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SOUTHERN CALIFORNIA EDISON: HOHA/E ZA (CONT.)
LINER SPECIFIC MATERIAL TYPE NR
«« REAGENT PREPARATION EQUIPMENT
FUNCTION SLAKER
DEVICE NR
DEVICE TYPE NR
»* SOLIDS CONCENTRATIHG/DEUATERINS
DEVICE NR
»»» SLUDGE
»* TREATMENT
METHOD FIXATION
DEVICE MIX TAW
PROPRIETARY PROCESS DRAVO
*« DISPOSAL
NATURE FINAL
TYPE POND
SITE TREATMENT CLAY LINED
«* UATER BALANCE
WATER LOOP TYPE CLOSED
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
•/. REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
11/73 SYSTEM
«* PHOBLEMS/SOLUTIONS/COMMENTS
TWO PROTOTYPE SULFUR DIOXIDE ABSORBER MODULES WERE INSTALLED IN 1973 AT THE
MOHAVE GENERATING STATION. A FOUR-STAGE HORIZONTAL CHOSSFLOW SPRAY
SCRUBBER MAS INSTALLED ON UNIT Z.
IN NOVEMBER 1973 THE UTILITY OPERATED THE FGO SYSTEM AT MOHAVE £A IN A
SHORT SERIES OF STARTUP TESTS THAT ENDED ON JANUARY 16. 1974 WHEN A FORMAL
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 BALANCE 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 FOR EXTENDED OPERATIONS AND REMOVAL OF A HARDHAT FROM THE THICKENER.
THE TEST PROGRAM MAS TERMINATED ON FEBRUARY 9, 1975 FOLLOWING 5°27 HOURS
OF OPERATION. THE MODULE MAS SUBSEQUENTLY DISMANTLED, TRANSPORTED, AND
REASSEMBLED AT THE FOUR CORNERS PLANT OF ARIZONA PUBLIC SERVICE WHERE
ADDITIONAL TESTING HAS CONDUCTED AND COMPLETED (DECEMBER 1976).
1071
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION 16
DESIGN AND PERFORMANCE DATA FOR DISCONTINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT N.M5ER
CITY
STATE
PECULATOR CLASSIFICATION
PABTICULATE EMISSION LIMITATION - NG/J
SC2 EMISSION LIMITATION - NG/J
NOX EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY - MM
GROSS UNIT GENEPATIN3 CAPACITY - MM
NET UNIT GENERATING CAPACITY M/FGD - MM
NET UNIT GENERATING CAPACITY UO/FGO - MM
EQUIVALENT SCRUBBED CAPACITY - MM
«« UNIT DATA - BOILER AND STACK
BOILER SUPPLIER
BOILER TYPE
BOILER SERVICE LOAD
DESISN B3ILER 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
AVEPAGE ASH CONTENT - 7.
RANGE ASH CONTENT - X
AVERAGE MOISTU3E CONTENT
RANGE MOISTL'PE CONTENT -
AVERAGE SULFU3 CONTENT -
RAN3E SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT
RAN3E CHLORIDE CONTENT -
- 7.
X
X
- X
X
TENNESSEE VALLEY AUTHORITY
SHAKNEE
IOC
PAOUCAH
KENTUCKY
B
43.
516.
««•*»*
I .100 LB/MM3TU)
( 1.200 LB/MMBTU)
(»**»*<• LB/MKSTU)
1750
10
««»•*
10
BABCOCK « MILCOX
PULVERIZED COAL
BASE
*«**»**»
««**»**
Z44.
«««**»
«»«*»»«
COAL
BITUMINOUS
•*«•*«
«»»»««*»
••*»*»
*••»***«
*•**»«
2.90
««»•«*
(»»**»»« ACFM)
(»»»» F)
< BOO FT)
(»«»«* FT)
(*»«««» BTU/LB)
*»***«
»*» PARTICLE CONTROL
•« PARTICLE SCPU2BER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
•»» FGD SYSTEM
** GENERAL DATA
SALEABLE PPOOUCT/THROMAMAY PRODUCT
S02 REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
A-E FIRM
DEVELOPMENT LEVEL
NEM/RETROFIT
PACKED TOWER
MOBILE BED PACKING
TURBULENT CONTACT ABSORBER
PLASTIC SPHERES
THROUAMAY PRODUCT
MET SCRUSBING
LIME/LIMESTONE
COMBUSTION ENGINEERING
BECHTEL
PROTOTYPE
RETROFIT
WARNING ««UNNORMALIZED NUMBER!S) BEING EDITED FOR OUTPUT»«
ENERGY CONSUMPTION - X
CLTCPEUT STATUS
TERMINATION
INITIAL START-UP
•* DESIGN AND OPERATING PARAMETERS
»* QUENCHER/PPESATURATOR
CONSTPUCTICN MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
.0
a
7/73
NR
NR
1072
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
TENNESSEE VALLEY AUTHORITY: SHAUNEE IOC (CONT.)
** ABSORBER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
SHELL GENERIC MATERIAL
SHELL SPECIFIC MATERIAL
SHELL MATERIAL TPADE NAME/COMMON TYPE
LINER GENEPI- MATERIAL
LINER SPECIF:C MATERIAL
LINER MATERIAL TRADE MM1E/COMMON TYPE
GAS CONTACTIN3 DEVICE TYPE
INLET GAS FLOW - CU. tt/S
»« MIST ELIMINATOR
FSE-MIST ELIMINATOR/HIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COHKCN TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»* REHEATER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
«» DAMPERS
FUNCTION
GENERIC TYPE
SPECIFIC TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATEPIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
•» OUCTWOFK
SHELL GENERIC MATERIAL TYPE
SHELL SPECIFIC MATERIAL TYPE
LINER GENERIC KATEPIAL TYPE
LINE? SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
«« SOLIDS CONCENTRATING/DEUATERINS
DEVICE
«** SLUDGE
»« TREATMENT
METHOD
DEVICE
PROPRIETARY PROCESS
*« DISPOSAL
NATURE
TYPE
SITE TREATMENT
PACKED TOMER
STATIC BED PACKING
MARBLE-BED SCRUBBER
NR
NR
NR
NR
NR
NR
GLASS MARBLES
14.16 ( 30000 ACFM)
NR
NR
NR
NR
NR
NR
DIRECT COMBUSTION
N3
OIL
NR
r
-------
EPA UTILITY FGD SURVEY: OCTC3ER - DECEMBER 1981
TENNESSEE VALLEY AUTHORITY: SHAU'NEE IOC CCONT. >
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HOURS HOURS HOURS FACTOR
4/72 SYSTEM 720
«* PROBLEnS/SOLUTIONS/COMMENTS
IN JUNE I960, THE EPA INITIATED A PROGRAM TO TEST PROTOTYPE MET LINE AND
LIMESTONE SCRUBBING SYSTEMS FOR REMOVAL OF SULFUR DIOXIDE AND PARTICLE
MATTER FROM FLUE GAS. THREE PARALLEL MET SCRU33ER SYSTEMS WEPE SELECTED
FOR THE TEST PROJECT: 1) A VENTURI WITH A SPRAY TOWER AFTER THE ABSCRSER;
£) A TURBULENT CONTACT ABSORBER (TCA); AMD 5) A MAFBLE-BED AESORBEP.
THE MAPBLE-BEO A6SOPBER TESTED ON SHAWNEE IOC USED A PACKIUS OF 3/4 INCH
GLASS MARBLE SPHERES AND A TURBULENT LAYER OF LIQUID AliO GAS ABOVE THE
MARBLE LAYER TO ENHANCE MASS TRANSFER.
THE TEST FACILITY HAS DESIGNED SO THAT MODIFICATIONS AND VARIATIONS OF
SCRUS3ER INTERNALS AND PIPING COULD BE READILY EMPLOYED FOR EACH SCRUS3ER
SYSTEM.
THE MARBLE BED ABSORBER AT SHAWNEE IOC COMMENCED OPERATIONS IN APRIL
1972.
THIS MARBLE-BED ABSORBER MAS DISCONTINUED EARLY IN THE TEST PROGRAM. JULY
1973. BECAUSE OF CONTINUED OPERATING PROBLEMS MITH NOZZLE FAILURE AND
SUBSEQUENT PLUGGING OF THE MARBLE-BED.
1074
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION 16
DESIGN AND PERFORMANCE DATA FOR OISCT'ITINUED DOMESTIC FGD SYSTEMS
COMPANY NAME
PUNT MAKE
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 t'KIT GENERATING CAPACITY - MM
NET UNIT GENERATING CAPACITY W/FGO - HU
NET UNIT GENERATING CAPACITY UO/FGD - MU
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
»« FUEL DATA
FUEL TYPE
FUEL GRADE
AVEPASE HEAT CONTENT - J/G
RANGE HEAT CONTENT - BTU/LB
AVERAGE ASH CONTENT - V.
RAM3E ASH CONTENT - 7.
AVERAGE MOISTURE CONTENT - X
RAC3E MOISTUPE CONTENT - 7.
AVERAGE SULFUR CONTENT - X
RANGE SULFUR CONTENT - 7.
AVERAGE CHLORIDE CONTENT - 7.
RAN3E CHLORIDE CONTENT - X
*»« PARTICLE CONTROL
»» PARTICLE SCRUSSER
GENERIC TYPE
SPECIFIC TYPE
TRADE NAME/COMMON NAME
GAS CONTACTING DEVICE TYPE
•«* FGD SYSTEM
*« GENERAL DATA
SALEABLE FRODUCT/THROMAMAY PRODUCT
SOC REMOVAL MODE
PROCESS TYPE
SYSTEM SUPPLIER
DEVELOPMENT LEVEL
NEU/RETROFIT
UNIT DESIGN PARTICLE REMOVAL EFFICIENCY
UNIT DESIGN SOS REMOVAL EFFICIENCY - 7.
ENERGY CONSUMPTION - X
CURRENT STATUS
TERMINATION
INITIAL START-UP
«» DESIGN AND OPERATING PARAMETERS
** (SUENCHER/FRESATUHATOR
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
UNION ELECTRIC
MEREMAC
2
*«»***
MISSOURI
*»»«»«
»»»*»«
«<.**»•«
««»**»
4135
140
125
(*»»«*» LB/MMBTU)
(»*»»»« LB/M.13TU)
(»»«*»» LB/MMBTU)
140
**»«**
PULVERIZED COAL
BASE
*»«»•«»» (*«*•»»* ACFM)
•«•«<»» («««* F)
*«»•»» («*»» FT)
»»»**»
«»»«»*• (•»««* FT)
COAL
«*<**«»
«»»»»*
»*«*»**»
»*«*«*
**«*»**»
«»»*«»
3.40
»««»*»
(»**«*» BTU/LB)
*«»**»
PACKED TCUER
STATIC BED PACKING
MARBLE-BED SCRUBBER
PLASTIC SPHERES
THROUAUAY PRODUCT
WET SCRUBBING
LIMESTONE
COMBUSTION ENGINEERING
FULL SCALE
RETROFIT
X 99.00
83.00
<*
8
0/69
3/68
NR
NR
1075
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
UNICN ELECTRIC: MEREMAC z ICONT.)
«» ABSCP3ER
GZ'JE'IC TYPE
SPECIFIC TYPE
T=AOE NAME/CCT.MON TYPE
SHELL GENc"IC MATEPIAL
SHELL SPECIFIC MATERIAL
EhELL MATERIAL TRADE NAME/COMMON TYPE
LINE:? GEHEPIC MATEPIAL
LINER SPECIFIC r.ATEP-iL
LINER MATERIAL TRADE NAME/COMMON TYPE
»« r.IST ELIMINATOR
F=E-MIST ELIMINATOR/MIST ELIMINATOR
GENERIC TYPE
SPECIFIC TYPE
T5AOE HATE/CCrMON TYPE
CONSTRUCTION MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»« REHEATE?
GENERIC TYPE
SPECIFIC TYPE
TPADE NArE/CCmCN TYPE
CONSTRUCTION MATEPIAL GENEPIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
»» DAMFE-S
FUNCTION
GENSSIC TYPE
SPECIFIC TYPE
CONSTPUCTIOM MATERIAL GENERIC TYPE
CONSTRUCTION MATERIAL SPECIFIC TYPE
LINER GENERIC MATERIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»« DUCTHC-K
SHELL GENSPIC MATE"IAL TYPE
SHELL SPECIFIC MATEPIAL TYPE
LINER GENERIC MATEPIAL TYPE
LINER SPECIFIC MATERIAL TYPE
»» REAGENT PREPARATION EQUIPMENT
FUNCTION
DEVICE
DEVICE TYPE
»» SOLIDS CCNCENTRATING/OEUATERING
DEVICE
»«» SLUDGE
»« TREATMENT
METriCD
DEVICE
PPOPPIETAHY PROCESS
*» DISPOSAL
H4TU3E
TYPE
SITE TREATMENT
»* UATER BALANCE
HATER LOOP TYPE
PACKED TOUER
STATIC BED PACKING
MA7BLE-6EO SCRUS3ER
m
NR
t&
NR
NR
NR
NR
NR
KR
NR
NP
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
NR
WET BALL MILL
NR
NR
NR
NR
NR
FINAL
NR
NR
CLOSED
1076
-------
EPA UTILITY FGO SURVEY: CCTC3ER - DECEASES 1931
UNION ELECTRIC: MEREKAC 2 ICONT.>
PERFORMANCE DATA
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
S02 PART. HCL'SS HOL'SS KC'-^S FACTCP
3/66 SYSTEM 744
i* PROBLEHS/50LUTIONS/CCMMENTS
THE FIRST COMMERCIAL SCRUBBER APPLICATION ON A UTILITY COAL-FIRED BOILER
OCCURRED AT THIS STATION IN EARLY 1968.
THE PROBLEMS ENCOUNTERED DURING OPERATION OF THIS SYSTEM INCLUDED BOILER
TUBE FOULINS BECAUSE OF THE CLOSE TUBE SPACING, WIDESPREAD SCALING, SEVERE
CORROSION, INEFFICIENT MIST ELIMINATOR AND PROBLEMS WITH HASTE DISPOSAL.
THE SCRUBBING PROGRAM MAS EVENTUALLY TERMINATED AND THE INSTALLATION MAS
ABANDONED.
1077
-------
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.
Much of the 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 in-
formation then in the PEDCo files. The utility was asked to ver-
ify the data and fill in any missing information. The PEDCo En-
vironmental staff made a follow-up visit to complete and verify
the data collected. Results of the cost analysis were then for-
warded 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 (a number of 1979 and 1980
forms were also used as available). Utilities are generally re-
quired to complete this form, which includes capital and annual
costs, once per year for operating stations. Although the infor-
mation included in the DOE Form 67 is not as specific and is for-
matted differently from 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, 1979,
and 1980 annual costs were made available by a few utilities via
written transmittals and te-lephone communications.
Draft forms were assembled based on these sources and sent
to each utility involved in this study. Each utility was then
contacted and asked to respond as to the validity of the figures.
A-3
-------
included in the drafts. Corrections were then made and it was
assumed that the figures collected provided a firm base to make
adjustments. In general, it was possible to determine the scope
of the reported costs so that 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 1981 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.
A-4
-------
0 All annual costs are escalated to 1981 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 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. Section A-2 summarizes available cost data for nonopera-
tional 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 FGD SYSTEMS
4l»m ClMlrlc
Totoigntt 2
TcwigMt 1
•riront Cltclric Povtr
4o.ent 2
404cnt 1
Arisen! PuDlfc Strvfct
Cnolli I
f»11« 2
Cmtril Illlnolt llgnt
Oucl CrMi 1
Ctntr.l Illlitoti Futile fonlct
•nton 1
Colorado UU Cltctric
Crilg I
Crilg 2
Column 4 Southm Onto Cltctric
Conttvlllo S
Conti.lllt 6
Cooptrttlra >OOTr Alieclitlwi
CMl Crwk 1
Coil CrM» 2
Ououttnt llgnt
IlriM 1-4
PMIllpi 1-C
iMIintoolll POMr 1 llgnt
••tiriturg 1
Until City POMr t Llgnt
Kntnorn 1
Mvtnorn (
HCygn. 1
Uni» roMr i llgnt
Jlffroy 1
Jiffriy t
MntuCky Utllltlll
Cr»on llnr 1-1
Loulf»lllt CM t Cltctric
Cm «un 4
Ciiw »un i
ClM lun I
Hill Crwk 1
•111 Crnt 1
Pudy'i lun 6
Nlnnttetl Ponr A Light i
City loiMll •
Nlnnutl tntr
•11 ton II young 2
Honongintla POMVF
Pllttinti 1
Pltlltntl 2
Hontlnt Pcxtr
Colitrlo 1
Colitrlo 2
Hnidl Poxtr
Illd Girmr 1
Itla GirBur t
Illd Ctrentr ]
Rortntrn Inalino Public Strvlct
Our. H NIUMll 11
Narthtrn SUtol POMOF
SMrtnirno 1
Sntrauntt 2
PKifie POMF I light
Jli Brtdgtr 4
Nnniylvond POMP
8rm Hintffold 1
Bruct Hinifltld 2
Bruct Hintfttld 1
Public Strvlct of HM Ntilco
Son Jvin 1
Itn Jutn 2
Slit Ilnr Projtct
CorOMdo 1
Cormooo 2
loutn Ctrellnt Public lonln
•Injtn 2
Wnyoh 1
Soutn Mtlllllppl Eloctrle fOMr
1 D Horra.. Sr 1
1 0 Nora. Sr 2
Soutntm Illlnoli PMr
Kirlon 4
Southtrn Indlon Gil 4 (loctrlc
• 1 Iram 1
Sprlngri(1d City Utllltltl
SOUUMMt 1
Iprlngflold UUr. light 4 Pe«tr
Oillm 1
TtnntiiM Vollty telMrlty
Waoiri Crwk a
uun Pc««r 4 Llgnt
Humor 1
IMlur t
HoRtlngtan 1
•»po»l»a
^"TtSTtST""
(.121.100
t.*92.100
a.na OM
7.21I.OU
4.tM.ODO
44.1S2.0M
ii.m.oco
107.111,000
U.ill.UO
U.I10.SOO
20.4U.MO
I0.4U.900
11. (SO. 000
21.MO.OOO
(1.120.000
il, 015. 000
u. en. ooo
1.220.000
1.220.000
44.900.000
2I.106.NO
n.4sa.aoo
1.944.1SS
U.MT.OOO
11.7S1.000
20.S9f.WO
17.U1.900
u.Mf.aao
4.1ZO.OOO
H.SOO.OOO
44.119.400
11.IS2.400
(1.4S2.400
M.SOO.OOO
14.SOO.OOO
S.UI.17S
S.141.17S
12.S99.KO
U. 192 .040
M,a92.020
M.U2.020
4*.441.000
iu.tn.ooo
UO.flt.OOO
199.fS7.200
47.944.400
I7.9BS.OOO
12.424. SOO
12.424.900
(. 644.098
10.742.SOO
10.fM.000
10. 194,000
1S.200.9M
12.4tS.000
lf.744.SOO
M.9I),tOO
47.900.000
24.400.000
2J.UO.OOO
2.709.000
I/tw
27 I
27 1
41 a
17 0
S2 0
Iff 0
74 a
174 a
at s
71 S
SO 1
SO 1
41 4
41.4
120 2
127 0
104 9
29 4
29 4
S) 7
17 9
17 a
U 0
(f f
ff f
71 S
SS 0
42 f
(1.7
171 t
100 1
11) 1
119 1
101 4
101 4
42 9
42 9
100 f
157 4
49 1
49.)
90.1
120 7
120 f
211 f
112 t
117 1
794
79 4
21. 7
If 4
S) 7
SI. 7
17. 9
47 2
ff.l
170.4
87.1
Sf 7
H 2
f 1 0
Annul I
4M.929
414.129
S1.7H
91. 7M
W
1. 001.SU
10,151.000
m
4(2.400
1.121.400
t.f70.S10
a.f7D.S10
1.144.200
1.W.200
21.0Z7.4S1
ia.ioi.ooo
m
144.441
141.441
a.o».o47
121.000
949.900
144,005
940.101
741.44]
W
HA
121.441
H*
18.444.51J
754.445
s.su.aoo
5,532.800
6.178. 000
(.128,000
2S1.S14
251.914
Ill.t24
2.414. M»
2.7K.7S9
2,716.759
M
9.979.900
9.979.900
11.575.UO
M
HA
1.788.000
1.748.000
527,000
HA
H*
HA
fSI.451
i.aso.su
771.749
4. ni. 500
14.57(.400
HA
1.072.400
2.944.400
Hllli/Mfn
0 11
0 11
0 10
0 10
HA
0 75
S 04
HA
0 91
0 48
S 52
5.52
0 41
0 41
7.18
11 00
HA
1 IS
1 IS
S If
0 11
0 29
S 20
1 29
0 92
HA
HA
1 25
HA
S If
0 51
1 41
1 44
2 97
2 97
0 48
0 46
0 21
11 02
0 75
0 75
HA
1 28
1 28
1 11
HA
HA
o as
o as
0 29
HA
HA
HA
0 98
1.10
1.20
4.U
7 74
HA
0 12
1 27
44
^ioiltl
9.754.200
9. 754. 200
11.171. 700
11.W1.900
10.244.100
42.7II.UO
9S.001.000
1(2. 447, (00
49.179.000
41.070.100
40.f57.200
40.857.200
28. (11, 100
2t.411.100
9S.79S.400
ff. 097. 900
M. 227,500
(.909.850
(.909.850
17,498.400
19.710.900
28.840.100
7.510.600
21.882.500
20.474.400
25.290.600
21.127.800
29.U1.000
9.107.100
102.115.100
68.487.500
104.5(2.000
104.512.000
92.S19.fSO
92.SI9.1SO
io.esi.jso
10.891.150
18.866,171
29.411.808
7i.a54.4at
7i.as4.4af
(S.1U.7U
112. 214. OH
112.214.019
14f.041.400
100.111.471
9t.777.St9
I9.StO.700
IS.SfO.TOO
11.141.872
It.f4f.700
24.047.200
24.047.200
20.906.447
2i.4i4.nt
27.t22.U7
19.129.200
tf.9U.12B
12.294.620
11.229.000
J8.H8.607
I/KM
U 1
18 1
(7 5
59 t
81 1
1(2 1
112 2
2U 9
109 9
90 1
99 4
99 4
52 S
92. 1
187 1
210.0
142 1
62 t
62 t
100 1
SS 9
41 2
117 1
US 2
102 4
67 1
(0 4
(4 0
111 0
114 4
US 7
152 9
152 9
145 9
14S 9
17 1
87 1
190 9
294 f
102 f
102 f
118.4
144 2
144 2
111 1
277 9
262 2
ff S
16.5
47 0
ff t
lit S
lit S
120.1
U 4
141 4
194 1
191.1
75 1
72 t
90 0
jkttfl
Annual
4,249 (50
4.249. (SO
1.719 900
1 719 900
4 Ml fOO
10.99fl.100
U. 411. 100
4S.4il.900
u.ne.joo
10.U2.700
14.479.100
14.475.100
8. 411.350
f. 414. ISO
15.711.700
JS.7J1.700
28.565.000
2.912.100
2.112,100
52.715.100
9.151.200
6. 3*6.400
1.754.800
(.422 400
5.784 100
11.071.000
8.107.100
9. (16. 200
4.430.300
40.417.100
14.W6.000
27 951.100
27.951.100
15.642.050
15.442.050
3.617.450
1. (17. 450
4.(17.1fl
11.129J.211
21.0U.19S
21.0U.19S
19.U1.160
S1.122.9U
51.122.918
48.255.200
29 8J6.802
29.423.764
15.119.100
15.119.100
2.697.B96
(.926.700
7.115.990
7.115.990
7.107.121
7.094.110
I.092.2U
15.911.700
tl. 179.071
10.614.532
10.115.700
11.411.652
Mf i| ikl
1 18
1 If
1 75
1 75
4 79
t 22
S 71
11 94
1 11
4 M
( 78
( 78
2 99
2 99
12 89
17 65
9 74
9 25
S 25
11 29
2 42
1 fl
10 99
f 20
S 10
7 21
4 2t
4 OJ
12 2!
14 09
t 44
7 14
7 94
t 27
1 27
1 78
5 78
7 40
20 79
1 41
5 41
t fl
11.11
11 11
10 27
11 (9
16 (9
7 70
7 70
1 84
4 (1
t 94
f 94
7 79
4 98
1 21
14 56
7.28
4 f f
4 SS
S 89
•I coitl not ••llltolt frou tno 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/llne
Alkaline flyash/
lines tone
Dual alkali
Line
Limestone
Sodium carbonate
Uellnan Lord
Reported
Capital
Range. J/kW
23.7-213.6
23.7-213.6
29.4-IS7.4
132.8-18S.O
23.7-213.6
43.4-I73.B
49.3- 49 3
47.2-174.8
29.4-213 6
23.7-170.4
42.9-100.8
132.8-185.0
Average,
t/kW
80.2
80.4
79.7
153.1
75.8
93.9
49.3
97.8
81.8
67.9
69.2
153.1
o
44 3
46.1
39.4
20.6
41.5
44.0
0.0
55.3
43.7
37.2
26.6
20.6
Annual
Range.
nllls/kWh
0 1-13.0
0.1- 5.5
0.5-13.0
13.0-13.0
0.1-11.3
0.4- 5.4
0.8- 0.8
1.3- 1.3
0.3-11.3
0.1- 7.8
0.2- 0.5
13.0-13.0
Average,
ntlls/kUh
2.3
1.7
4.5
13.0
2.1
2.1
0 8
1.3
3.2
1.6
0.4
13.0
o
2.8
1.8
4.4
0.0
2.4
1.9
0.0
0.0
2.7
2.2
0.1
0.0
Adjusted
Capital
Range. J/kM
38.3-282.2
38.3-263.9
60.4-282.2
254.6-282.2
38.3-263.9
52.S-184.4
102.6-102.8
87.8-263.9
60.4-210.0
38.3-194.3
87.1-150.9
254.6-282.2
Average ,
J/kW
118.8
110.8
139.3
271.6
110.9
122.8
102.6
146.7
116.5
98.9
110 9
271.6
a
58.1
48.4
73.8
12.1
47.6
51.4
0.0
82.9
44.2
44.0
26.4
12.1
Annual
Range.
mllls/kWh
1.6-20.8
1.6-14.6
4.3-20.8
16.7-20.8
1.6-17.6
3.0-14.1
5.4- 5.4
5.0-13.9
4.0-17.6
1.6-14.6
5.8- 7.4
16.7-20.8
Average,
mills/Mm
7 6
6.8
9.7
18.1
7.0
7.2
5.4
8 7
8 1
6.1
6.4
18.1
0
4.1
3.2
5.3
1.9
3.4
3.8
0.0
3.8
3 6
3.1
0 7
1.9
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-1981 dollars
using the escalation factors shown in Table A-3.
Actual costs were reported by utilities in dollar
values for years 1970 to 1981. The total figure is
broken down into dollars/year and each year total is
escalated to 1981 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
-------
TABLE A-3.
ESCALATION FACTORS
Year3
1970
1971
1972
1973
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
1985
Capital
Investment0
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
1.94S
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
labor6
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: Department of Commerce.
Reference: Bureau of Mines.
Reference: Department of Labor.
Reference: Engineering News Record.
A-10
-------
All annual costs, represented in mills/kilowatt-hour
(mills/kWh), are expressed in terms of net meaawatts
(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:
0 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
FGO 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
FGO 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 add 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 for 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.
0 Allowance for start-up and shakedown includes the cost
associated with system start-up.
0 Spare parts including pumps, valves, controls, special
piping and fittings, instruments, spray nozzles, and
similar items.
Other Capital Costs
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:
Contingency3
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
Mater
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
$60/ton
$46/ton
S62/ton
$52/tonc
$12/ton
$300/ton
$130/tond
$50/ton
$87/ton
$75/ton
$33 mills/kWh
$0.26/103 gal
$1.60/106 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 replacement6
Taxes
Insurance
Capital costs
$14.40/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
S13.30/ton in 1978. This was escalated to S15.40/ton for 1980.
Long term contract (e.g., Dravo contract).
Nevada Power reported a January 1982 soda ash cost of $115/ton delivered
(transported from Trona, California to Moapa, Nevada). Montana-Dakota
Utilities reported a cost of $151/ton (October 1981 dollars^ delivered
(transported from Green River, Wyoming to Beulah, North Dakota).
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 anri 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 FGO SURVEY: OCTOBER - DECEMBER 1931
SECTION A-I
COSTS FOR OPERATIONAL F6D SYSTEMS
13IIT DESCRIPTION
ALABAMA ELECTRIC
TCM3IGSEE 2
t'i'A £55MU (G303S)
STARTUP 9/78 179KH (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
FEA20DY PROCESS SYSTEMS
ENERGY CONSUMPTION: 3. IX
ALABAMA ELECTRIC
TC"3IGBEE 3
NEU 2S5MW (GROSS)
STARTUP 6/79 179MW (ESC)
COAL
1.15 XS BITUMINOUS
LIMESTONE
FEABC3Y PROCESS SYSTEMS
ENERGY CONSUMPTION: 3.1X
ARIZONA ELECTRIC POWER
APACHE 2
NEU 195MU (GROSS)
STARTUP 8/78 96MU (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4. IX
ARIZONA ELECTRIC POWER
APACHE 3
NEU 195MU (GROSS)
STARTUP 6/79 9CMU (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 4. IX
ARIZONA PUBLIC SERVICE
CHOLLA 1
RETROFIT 119MH (GROSS)
STARTUP 10/73 119KM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: 3.4X
ARIZONA PUBLIC SERVICE
CHOLLA 2
NEU 264KU (GROSS)
STARTUP 4/78 264MM (ESC)
COAL
.50 XS BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: «*»*x
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 9
TOTAL CAPITAL, 5/KUIYEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KKH(YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL. S/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHI YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, RILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KH(YEAR>
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, V.
DIRECT CAPITAL, 4
INDIRECT CAPITAL, »
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KUH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KUIYEAR]
DIRECT ANNUAL, $
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHt YEAR)
REPORTED
65
5826750.
1 i A?^t»n
aos J9U •
**•»**»*««**
27.411978)
434929.
**********
**********
.3(1978)
65
5826750.
1165350.
**********
27.4(1978)
**********
434929.
**********
.3(1978)
65
6154982.
1895044.
78949.
41.8(1977)
48237.
3547.
**********
.1(1979)
65
5449433.
1677814.
69399.
37.0(1977)
48237.
3547.
**********
.1(1979)
*»»
**»**»***»
**********
**********
52.0(1973)
**********
**********
**********
«*****{ 1978 )
65
**********
**********
**********
163.0(1977)
1003566.
**********
**********
.8(1978)
ADJUSTED
65
«**««*»!,*«
«!!*««*!£**
23.3(1931)
2:26150.
132750.
1690750.
3.2(1931)
65
**********
***«»**)t*4
**********
38.3(1931)
2226150.
332750.
1690750.
3.2(1931)
65
**********
**********
****•«*«»»*
67.5(1981)
1568150.
19000.
2151850.
3.8(1931)
65
***********
**********
«.«<(««*****
59.8(1931)
1568150.
19900.
2151850.
3.8(1981)
65
**********
»********,*
**»«**««<<*
81.3(1981)
2049200.
561600.
1993000.
4.8(1931)
65
**********
**********
*»**.< ««***
162.1(1031)
30314...
551300.
7415100.
8.2(1931)
STAf,3A!?CIZi3
ADJ'JSTID
65
**'""""'**»
***»..«»»»
-.-«4rf,*( 0)
»»•••***»*•«»»
*-4«-«**«*4
"•***••»*••*
«»**„*< gj
65
M**.,******
»**,(K«4*4V
******( 0)
**tf)t *>***«
4*4<«(4K4Klf
i*********
*****»( 01
65
**********
*-«*•«* *****
**«***< Q )
**********
y^^4**aiy«t(
**********
******< 0 )
65
K*********
»***»•***«*
**•"*•******
*^»+**( 0 )
**•**-+*****
**-f**,****
**«*^4****
****** ( 0 ]
65
**********
it*********
**********
****«*( Q]
**********
**********
* -'***»**»-»
»*****( 0]
65
**********
**********
**********
***•»*»( 01
*******»*•«
**********
**«**.«( (j )
INDICATES COST FIGURES NOT YET AVAILABLE
A- 21
-------
EPA UTILITY F6D SURVEY: OCTOBER - DECEMBER 1981
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
^IZCNA PUBLIC SERVICE
MEW 37SMM (GROSS)
STARTUP 3/81 1C6MM (ESC)
COAL
.50 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: «*»»X
3ASIN ELECTRIC PCUER
LARAMIE RIVER 1
NEU 57CMW (GROSS)
STARTUP 7/80 570^ (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: *»»»•/.
BASIN ELECTRIC POUEH
LARAMIE RIVER 2
NEM S70MU (GROSS)
STARTUP 7/81 570MW (ESC)
COAL
.81 XS SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: »«»«X
BIG RIVERS ELECTRIC
GREEN 1
NEU 242MM (GROSS)
STARTUP 12/79 242MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: »***x
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
NEU 416MU (GROSS)
STARTUP 7/76 416MU (ESC)
COAL
3.66 XS BITUMINOUS
LIMESTONE
ENVIPONEERING, RILEY STOKER
ENERGY CONSUMPTION: 2.9X
CENTRAL ILLINOIS PUBLIC SERV
NEUTON 1
NEU 617MU (GROSS)
STARTUP 9/79 617MJ4 (ESC)
COAL
2.25 XS BITUMINOUS
O'JIL ALKALI
GE ENVIRONMENTAL SERVICES
EME3GY CONSUMPTION: 2.4X
COST DESCRIPTION
CAPACITY FACTOR. X
INDIRECT CAPITAL. 4
OTHER CAPITAL. 4
TOTAL CAPITAL. 4/KUI YEAR )
DIRECT ANNUAL. 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHf YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL. 4
OVERHEAD COST, $
FIXED CHARGES, 4
TOTAL ANNUAL. MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, S/KWCYEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 4
INDIRECT CAPITAL. 4
OTHER CAPITAL. 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES. 4
TOTAL ANNUAL, MILLS/KMHI YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KUH( YEAR)
CAPACITY FACTOR. X
DIRECT CAPITAL, 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES. 4
TOTAL ANNUAL. MILLS/KUHI YEAR)
RE-OSTED
*«*
*******•«-**
83.01 0)
**********
**********
**»**<•( Q )
***
33600000.
**********
**********
56.0(1930)
2818530.
.9(7300)
***
33600000.
**********
**********
56.0(1980)
2816530.
**********
**********
.9(7800)
10454400.
»*«****»*»
43.2(1976)
**********
**********
******( 0 )
65
***»*****»
74.8(1977)
5163000.
5.0(1980)
**********
174.8(1978)
**********
******( Q)
ADJUSTED
65
**********
******( o )
65
**********
**********
**********
******( Q )
**********
******( o )
65
**********
*»****( Q)
**********
**********
»*****( o )
65
**********
**********
******( Q)
65
**********
132.2(1981)
5634500.
600000.
6198600.
5.8(1981)
65
**»»#«»*«»
**********
263.9(1931)
13332000.
4017400.
28221500.
13.9(1931)
AOJL'STsO
65
*•*•>"•*•*-•)»*
1H*****!*( 0 )
65
«***«**«**
*<****( 0 )
****»*( 0 )
65
**********
**********
*»****( 0 )
a*********
**********
**********
***»**( Q)
65
**********
**********
**********
******( Q )
**********
**********
******( Q )
65
**********
******( 0 )
**********
******( o )
65
**********
**********
******( Q)
**********
***»*»****
******< 0 )
INDICATES COST FIGURES NOT YET AVAILABLE
A- 22
-------
EPA UTILITY F6D SURVEY: CCT03EB - DECEMBER 1931
SECTION A-l
C3STS FOR OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
CINCINNATI GAS i ELECTRIC
EAST BEND 2
ti~i i ACPMU i f*"oec i
NCH ODUnH I wf*Loo J
STARTUP 3/81 650MH (ESC)
COAL
3.00 XS
LIME
EA5CCCK £ UILCOX
ENERGY CONSUMPTION: 2.9X
COLORADO UTE ELECTRIC
CRAIG 1
NEU 455MV4 (GROSS)
STARTUP 10/80 410MH (ESC)
CCAu
.45 XS SU33ITUMINCUS
LIMESTONE
PEA3C3Y PROCESS SYSTEMS
ENERGY CONSUMPTION: i.sx
COLCPAOO UTE ELECTRIC
CRAIG 2
NEU 455MM (GROSS)
STARTUP 12/79 410MVI (ESC)
COAL
.45 XS SUBBITUMINOUS
LIMESTONE
PEABCDY PROCESS SYSTEMS
ENERGY CONSUMPTION: -2. OX
COLUMBUS i SOUTHERN OHIO ELEC
CCNESVILLE 5
NEW • 411MW (GROSS)
STARTUP 1/77 411MW (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: 3.9X
COLUMBUS » SOUTHERN OHIO ELEC
CCNESVILLE 6
NEW 411MW (GROSS)
STARTUP 6/78 411MH (ESC)
COAL
4.67 XS BITUMINOUS
LIME
AIR CORRECTION DIVISION. UOP
ENERGY CONSUMPTION: 3.9X
COMMONWEALTH EDISON
POMERTCN 51
RETROFIT 450MM (GROSS)
STARTUP 4/80 450MM (ESC)
COAL
3.53 XS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 5.6X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL. S
OTHER CAPITAL, 5
TOTAL CAPITAL, $/KH(YEAR)
DIRECT ANNUAL, $
nv/CDuc tn POQT 4
UVCrflCAU I*UO 1 i 9
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHl YEAR)
CAPACITY FACTOR, X
DIPECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL, S/KVUYEAR)
DIRECT ANNUAL, S
OVERHEAD COST, »
FIXED CHARGES. $
TOTAL ANNUAL. MILLS/KHH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. $
INDIRECT CAPITAL. *
OTHER CAPITAL. »
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST. *
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, «
OVERHEAD COST, $
FIXED CHARGES. *
TOTAL ANNUAL, MILLS/KKH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, »
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, $
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KWHl YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, $
OTHER CAPITAL, *
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUA.., MILLS/KUH( YEAR )
REPORTED
***
78000000.
**********
120.01 0)
11718252.
»««**»«***
3.4(7800)
**»
38613500.
**********
**********
86.5(1979)
462600.
**********
**********
.5(1980)
***
32810500.
**********
**********
73.5(1979)
1128400.
**********
**********
.5(1980)
48
20663500.
**********
**********
50.3(1975)
4724280.
443800.
**********
5.5(1978)
48
20663500.
**********
**********
50.3(1975)
4724230.
443800.
**********
5.5(1978)
***
56250000.
**********
**********
125.0(1979)
**********
**********
**********
******( o )
ADJUSTED
65
V*********
***********
*•<*•***.( 0)
***<*»****
**********
******( Q)
65
**»-******
**********
**********
105.9(1981)
3&24500.
174400.
C34«400.
5.3(1931)
65
**********
**********
**********
90.3(1931)
3036100.
229200.
7117400.
4.6(1981)
65
32044850.
8812350.
**********
09.4(1931)
6973350.
559200.
6937550.
6.8(1981)
65
32044850.
8812350.
*******•<**
99.4(1981)
6973350.
559200.
6937550.
6.811S81)
65
*»*>»*****
***********
**********
******( Q )
«»***«*»*»
**********
**********
******( Q )
ST-D'^3?l3ED
65
**•*•«.*•*•*.*•#»
*k,..».,,*
*.„„***( g)
**•»*••»•**•***
**•«*•<»•<•*»
*•»•*••»•*( 0)
65
**********
»***4**4**
******»*-**
******( Q)
*i»***f4rf»*
*•»**•*•****
***********
******( Q)
65
**********
**********
***********
*****»( Q)
*****•#****
**********
**********
******( Q )
65
***•*<****»
*)l»H«*»'«*'«»
*«->*,(*****
**,**»< Q)
**•»*»*****
**********
**********
******( Q)
65
**********
«*****»***
H*#v******
*»****( 0)
**********
**********
**********
******( Q)
65
**********
v*********
**********
*»»***( Q )
**********
**********
**********
******( 0 )
*»***» INDICATES COST FIGURES NOT YET AVAILABLE
A- 23
-------
EPA UTILITY FGO SLAVEY: CCTC2ER - DECEMBER 1981
SECTION A-l
COSTS FOR OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
COOPERATIVE POWER ASSOCIATION
COAL CPEEK 1
N=W 545MW (GROSS)
STARTUP 7/79 327MW (ESC)
COAL
.65 XS LIGNITE
LIME/ALKALINE FLYASH
CCMSUSTION ENGINEERING
ENERGY CONSUMPTION: *»**X
COOPERATIVE POUER ASSOCIATION
COAL CREEK 2
NEW 545MW (GROSS)
STARTUP 7/80 327MW (ESC)
COAL
.63 XS LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: »«*»X
OUQUESNE LIGHT
ELRAMA 1-4
RETROFIT 510MM (GPOSS)
STARTUP 10/75 510MW (ESC)
COAL
Z. 20 XS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 3.SX
DL'QUESME LIGHT
PHILLIPS 1-6
RETROFIT 40SMW (GROSS)
STARTUP 7/73 408MW (ESC)
COAL
2.05 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 3.4X
HOOSIER ENERGY
KEROM 2
NEW 490MW (GROSS)
STARTUP 12/81 441MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****Y.
INDIANAPOLIS POUER » LIGHT
PETERSBURG 3
NEW 532MW (GROSS)
STARTUP 12/77 532MW (ESC)
COAL
3. £5 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 2.4X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, *
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, »
FIXED CHARGES, «
TOTAL ANNUAL, MILLS/KWW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, S/KHtYEAR)
DIRECT ANNUAL. *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL. «/KM(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KUHIYEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL. 9
OTHER CAPITAL, $
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KUHI YEAR)
CAPACITY FACTOR, 7.
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL. «
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, «
FIXED CHARGES. $
TOTAL ANNUAL. MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIPECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, «/KU(YEAR)
DIRECT ANNUAL, «
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWHI YEAR )
REPORTED
***
23650000.
******•»*»*
**********
43.4(1979)
1166200.
««««««««*»
«*»*»**»**
.4(1981)
***
23650000.
**««**»***
**4*«K*»»4
43.4(1979)
1166200.
«*****«*«»
ft«*»*»KKtt*
.4(1981)
69
»*«»****«<•
*»«»*»»<«»*
*«**«****»
120.2(1976)
13441451.
«*»*«»**»*
*»«**«***«
7.2(1979)
55
»****«****
**********
Kt*W*»»»*
«***>(»( Q )
**»
*»)(«««*««»
»«**«*»«**
»*«**««**»
104.9(1976)
tt««N»»**)Ht
»»*»*»*»»»
**********
KiH»«)HH 1978 )
ADJUSTED
65
23469750.
5163350.
ONN044W-***
52.5(1981)
3156450.
295800.
4962100.
3.0(1981)
65
23469750.
5163350.
Kl"f*>f*»*i»*IH»«»
ttffN*«««»
*»***»( 0 )
65
*W»•«<»( 0 )
"*»*»»•«"•'*»*
M»4<»>*Wk^4
»*-*-»X^)C«r«*
*»**«*( 0 )
65
»*-**•«** «MH»
****)»•«<>»=»*
*«»*-«*#»*»
«W(4M( 0 )
<»»)•******>»
»»**•*****»
**•! •*»*<««««
!««****( Q )
65
•»********
*#)»)»»**»*«
tHt***W*>H»»
***#*»( Q)
KOXyNVKMt*
*#**)«<«»*»'»
**»«»*«*»»
**»*-«•*( Q)
65
«t-«V<|«lf)»(«
**********
*»*******»
*****»( 0)
*«**<>XN***
**********
»**#*»*<•**
******( 0 )
65
**********
**•««***»**
**********
**»***( 0 )
**********
it*********
**********
******( 0)
65
**********
**********
**********
**»***( 0)
**»*<«*****
**********
**********
******( Q)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 24
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
KANSAS CITY POWER & LIGHT
HAWTH03N 3
RETROFIT 90MW (GROSS)
STARTUP 11/72 90KM (ESC)
COAL
.60 XS BITUMINOUS
LIKE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2X
KANSAS CITY POWER I LIGHT
HAWTHORN 4
PETPOFIT 90MM (GROSS)
STARTUP 8/72 90KM (ESC)
COAL
.60 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.2X
KANSAS CITY POWER ft LIGHT
LA CYGNE 1
NEW 674MH (GROSS)
STARTUP 2/73 874MM (ESC)
COAL
5.39 XS SUBBITUMINOUS
LIMESTONE
BABCOCK i WILCOX
ENERGY CONSUMPTION: 3.2X
KANSAS POWER 4 LIGHT
JEFFREY 1
NEW 720MW (GROSS)
STARTUP 8/78 540MW (ESC)
COAL
.32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *»««X
KANSAS POWER & LIGHT
JEFFREY Z
NEW 70CMW (GROSS)
STARTUP 1/80 490MW (ESC)
COAL
.30 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: **»»X
KENTUCKY UTILITIES
GREEN RIVER 1-3
RETROFIT 64HW (GROSS)
STARTUP 9/75 64MW (ESC)
COAL
4.00 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 3. IX
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, «
OTHER CAPITAL, $
TOTAL CAPITAL, S/KWIYEAR)
DIRECT ANNUAL, S
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL. MILLS/KUHI YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. $
INDIRECT CAPITAL. »
OTHER CAPITAL. $
TOTAL CAPITAL, S/KWfYEAR)
DIRECT ANNUAL. $
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHC 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, «/KM(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, *
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. $
INDIRECT CAPITAL, 4
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL. »
OVERHEAD COST, $
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, $/KH(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH( YEAR)
REPORTED
35
*HMf JUMUMHfW
**********
»**•***«•«**
£9.4(1972)
346441.
**********
**********
1.1(1978)
35
*****«***«
«***«*****
M«***tt**K*
29.4(1972)
346441.
****»*»»*«
tt««»*»**«*
1.1(1978)
21
«*****«**»
***»***»**
**********
53.7(1972)
8060047.
**N*«**X*)t
**********
5.4(1979)
50
25530000.
1776900.
**********
37.9(1978)
321000.
**********
**********
.1(1978)
55
**********
**********
**********
37.8(1980)
**********
**********
**********
.3(1980)
13
**********
**********
**********
62.0(1975)
364005.
******»*««
***y*tt»***
5.2(1978)
ADJUSTED
65
**********
**********
62.8(1981)
1466330.
31'«700.
1131100.
5.2(1981)
65
**********
**********
**********
62.8(1981)
1466300.
314700.
1131100.
5.2(1981)
65
*****»***»
**>«*******
**********
100.1(1981)
28360400.
9211400.
15163500.
11.3(1981)
65
**********
**********
**********
55.9(1981)
2350100.
121300.
6881800.
2.4(1981)
65
ft*********
**********
**********
41.2(1981)
1083000.
315400.
49«8000.
1.6(1981)
65
**********
**»******-»
**********
117.8(1981)
2012200.
430500.
1312100.
11.0(1981)
STANCAPCIIED
ADJUSTED
65
***********
«*VK»4**»*
*-t**~*{ 0 )
**********
******•*•*•**
«*««•**•«***
****+*( Q )
65
**********
**********
**********
******( Q )
**********
***********
**********
******( 0 1
65
**»*»***«*
**********
**********
******( 0 )
**********
**********
**********
*«•«***( 0 )
65
K*********
**********
**********
****»*( Q)
**********
**********
**********
******( Q)
65
«»H»****ft*
WKVfMXrf**
*»»»*»>•<*»
******( Q )
**********
**********
**********
«««*«it( Q )
65
»***»*»»**
**********
**********
******( Q )
WKINKWKtVt
»*<«#»lt)t»)»
WKgtKtVCt**
******( 0 )
•«•«»• INDICATES COST FIGURES NOT YET AVAILABLE
A- 25
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
LOUISVILLE GAS 4 ELECTRIC
CANE RUN 4
RETROFIT 188MM (GROSS)
STARTUP 8/76 188MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENERGY CONSUMPTION: 1.6X
LOUISVILLE GAS ft ELECTRIC
CANE RUN 5
RETROFIT 200MU (GROSS)
STARTUP 12/77 200MVI (ESC)
COAL
3.75 XS BITUMINOUS
LIKE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: i.sx
LOUISVILLE GAS I ELECTRIC
CANE RUN 6
RETROFIT 299MW (GROSS)
STARTUP 4/79 299MW (ESC)
COAL
4.80 XS BITUMINOUS
DUAL ALKALI
THYSSEN/CEA
ENERGY CONSUMPTION: l.OX
LOUISVILLE GAS t ELECTRIC
MILL CREEK 1
RETROFIT 358MM (GROSS)
STARTUP 12/80 358MM (ESC)
COAL
3.75 XS BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: i.4X
LOUISVILLE GAS & ELECTRIC
MILL CREEK 3
NEW 427MU (GROSS)
STARTUP 8/78 427MW (ESC)
COAL
3.75 XS BITUMINOUS
LIME
AMERICAN AIR FILTER
ENESGY CONSUMPTION: *«»*/£
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
RETROFIT 72MU (GROSS)
STARTUP 4/73 72MW (ESC)
COAL
2.50 XS BITUMINOUS
LIME
CCM2USTIOH ENGINEERING
ENERGY CONSUMPTION: 2.8X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KM(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST. 9
FIXED CHARGES. 9
TOTAL ANNUAL. MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH< YEAR >
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KM(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES. 9
TOTAL ANNUAL, MILLS/KMH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL. 9
TOTAL CAPITAL. 9/KH(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST. 9
FIXED CHARGES. 9
TOTAL ANNUAL, MILLS/KWHt YEAH )
CAPACITY FACTOR. X
DIRECT CAPITAL. 9
INDIRECT CAPITAL. 9
OTHER CAPITAL. 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL. 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL. 9/KM(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWHt YEAR)
REPORTED
47
10847000.
1800000.
**********
66.6(1975)
96C301.
**********
**********
1.3(1978)
SO
**********
**********
**********
68.8(1977)
763443.
**********
**********
.9(1978)
***
**********
**********
**********
71.5(1973)
**********
**********
**********
******( 1978)
**»
17661500.
**********
**********
55.0(1980)
**********
***********
**********
******( Q )
70
**********
**********
****«»*»**
42.6(1977)
321463.
**********
**********
1.3(1978)
***
**********
**********
**********
61.7(1973)
**********
**********
**********
****»»( 1978)
ADJUSTED
65
**********
**********
**********
115.2(1931)
2853600.
373300.
3190500.
6.2(1981)
65
**********
**********
**********
102.4(1931)
C050900.
283100.
3450300.
5.3(1931)
65
**********
**********
**********
87.8(1981)
5465000.
691300.
4716700.
7.2(1981)
65
**********
**********
**********
60.4(1931)
' 3925700.
433300.
3748100.
4.3(1981)
65
**********
**********
**********
66.0(1931)
4335300.
247000.
5053900.
4.0(1981)
65
**********
**********
**********
133.0(1981)
2201900.
562400.
1666000.
12.2(1981)
c,.>rn. „.,,., E.j
AC-UST30
65
**********
*»«-• r*v***
*****»•**>*»
*»*»*•«( Q)
**********
**********
**********
**«***( Q)
65
**********
**********
**********
******( Q )
************
**********
ft*********
*»****( 0 )
65
**********
**********
**********
*****»( Q)
**********
**********
**********
******( Q)
65
**********
**********
**********
******( Q)
**********
**v**»**»*
**********
******( 0 )
65
**********
**********
**********
******( o )
***********
**********
**********
******( 0 )
65
**********
**********
**********
******( Q)
*******)>**
**********
**********
»*****( Q)
«**««» INDICATES COST FIGURES NOT YET AVAILABLE
A- 26
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEASES 1931
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
MINNESOTA POWER & LIGHT
CLAY BCSWELL 4
LICU CR&MLJ r Rcn^Q i
ntH SanrH 1 unU39 J
CTl DTI ID &./Afl &TRMU f P^f* \
3 1 AK 1 U" H/OU **y 3riM 1 C9U 1
COAL
.94 xs SUSBITUMINCUS
LIME/ALKALINE FLYASH
PEAS03Y PROCESS SYSTEMS
ENERGY CONSUMPTION: 1.3X
HIU'iKOTA POWER
MILTON R. YOUNG 2
NEW 440MW (GROSS)
STARTUP 9/77 ISSM'rl (ESC)
COAL
.70 XS LIGNITE
LIKE/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 1.6X
MONCNGAHELA POWER
PLEASANTS 1
NEH 668MVI (GROSS)
STARTUP 3/79 668MV4 (ESC)
COAL
3.00 XS BITUMINOUS
LIME
BAECOCK ( UILCOX
ENERGY CONSUMPTION: MMHfX
MONONGAHELA POWER
PLEASANTS 2
MEM 668MU (GROSS)
STARTUP 10/80 668MW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
BABCOCK t MILCOX
ENERGY CONSUMPTION: «***X
MONTANA POWER
COLSTRIP 1
NEW 360MW (GROSS)
STARTUP 9/75 360MW (ESC)
COAL
.77 XS SUBBITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
MONTANA POWER
COLSTRIP Z
HEM 360MW (GROSS)
STARTUP 5/76 360MW (ESC)
COAL
.77 XS SU2BITUMINOUS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: 3.3X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL. *
TJJTtTDCPT PAQTTAI ft
IHUXKCI* 1 vArl 1 ALt 9
flTWJTD CADTTAI A.
U 1 ilCK \.Arl 1 AL f 9
TOTAL CAPITAL. S/KWCYEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KHH( YEAH )
CAPACITY FACTOR. X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL. S/KU(YEAR)
DIRECT ANNUAL. $
OVERHEAD COST, $
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, »
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST. *
FIXED CHARGES. $
TOTAL ANNUAL. MILLS/KWH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. »
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL. «/KM(YEAR)
DIRECT ANNUAL. *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL. MILLS/KWHl YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, »
TOTAL ANNUAL, MILLS/KWHl YEAH )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, t
TOTAL CAPITAL, $/KW(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES. 4
TOTAL ANNUAL. MILLS/KWHt YEAR)
REPORTED
ao
e&oooooo.
ft Jt^lf Mff# V4tV
173.8(1979)
<«•*<«*:«*#*»«
»*»**»««**
**********
5.4(1980)
40
30066200.
14052400.
**********
100.3(1976)
754445.
***********
*****»*»**
.5(1978)
70
**********
**********
**********
119.1(1978)
5532800.
**********
**********
1.5(1980)
70
**********
**********
**********
119.1(1978)
5532800.
**********
**********
1.5(1980)
71
**********
**********
**********
101.4(1975)
**********
**********
•tttfKVW***
3.0(1979)
71
**********
**********
**********
101.4(1975)
**********
**********
**********
3.0(1979)
A3.,bs :ED
65
€6530300.
1 S C^iC^fl
15 3 0*0 UU •
1S4. 4(1981)
15544100.
7123COO.
17705200.
14.1(1981)
65
**********
**********
***»*»****
155.711981)
C481COO.
616100.
11868900.
6.4(1981)
65
**********
**********
***»**»*»*
152.9(1981)
8857900.
972800.
181206CO.
7.9(1981)
65
**********
**********
KMMVftNt**
152.9(1981)
6857900.
972800.
18120600.
7.9(1981)
65
**********
**********
**********
145.9(1981)
5275300.
1265050.
9101700.
8.3(1981)
65
**********
**********
**********
145.9(1931)
5275300.
1265050.
9101700.
8.3(1981)
STAI 3£'3IZEO
ADJ'JSTsO
65
«*•»**«««*«
*»*)>*•*( 0)
y»**4-**4*«
****•****•«»
**•«*•**»*»*
»**.**.*( Q )
65
**********
**********
***********
**•»-**( Q)
*•»*•«**•**#*
**********
**4«#**4**
******( Q )
65
**********
**********
**********
******( Q)
***»**«*»*
*»******!»*
**********
*****»( Q)
65
**»****»4*
********"»»
**********
*»****( Q)
*-«**»*****
**********
**********
******( Q)
65
****<•****»
**********
**********
**«**•*( Q )
»«»»****«*
***********
**********
*****«( o)
65
**********
**********
**********
******( 0 )
**********
**********
**********
***»*-4( g )
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 27
-------
EFA UTILITY FGD S'JPVEY: CCTC3ER - DECEMBER 1981
SECTICN A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
NEVADA FOWE3
REID GARDNER 1
RETROFIT liSm (GROSS)
STARTUP 3/74 IZSK'J (ESC)
COAL
.53 XS BITUMIUQUS
SODIUM CARBONATE
THYSSEN/CEA
ENERGY CONSUMPTION: **»»X
NEVADA POWER
REID GARDNER 2
RETROFIT 125MV4 (GROSS)
STARTUP 4/74 125MW (ESC)
COAL
.50 7.S BITUMINOUS
SODIUM CARBONATE
THYSSEH/CEA
ENERGY CONSUMPTION: **»*X
NEVADA POWER
REIO GARDNER 3
NEW 125MW (GROSS)
STARTUP 6/76 125MW (ESC)
COAL
.50 XS BITUMINOUS
SODIUM CARBONATE
Tm SSEN/CEA
ENERGY CONSUMPTION: ****•/.
NCRTHERN INDIANA F'J3 SERVICE
DEAN H. MITCHELL 11
RETROFIT 116MU (GROSS)
STARTUP 7/76 115MW (ESC)
COAL
3.50 XS
UELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 12. ix
NCRTHERN STATES POWER
SHERtJRNE 1
NEW 740MW (GROSS)
STARTUP 3/76 74CMU (ESC)
COAL
.30 XS SUB3ITUMIKOUS
LIMESTONE/ALKALINE FLYASH •
COMBUSTION ENSINEERINS
ENERGY CONSUMPTION: 2.7X
NCRTHERN STATES POWER
SKERBURNE Z
NEW 740MW (GROSS)
STARTUP 3/77 740MW (ESC)
COAL
.80 XS SUSBITUMIMOUS
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: 2.7X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL. »
INDIRECT CAPITAL, *
OTHER CAPITAL. *
TOTAL CAPITAL, $/KU( YEAR )
DIRECT ANNUAL. $
OVERHEAD COST, *
FIXED CHARGES. 4
TOTAL ANNUAL. MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, $
OTHER CAPITAL, »
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, *
OVEPHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. *
INDIRECT CAPITAL, *
OTHER CAPITAL, «
TOTAL CAPITAL, «/KH(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, *
OTHER CAPITAL. S
TOTAL CAPITAL, $/KH(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, $
TOTAL CAPITAL, «/KU(YEAR)
DIRECT ANNUAL. *
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHI YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL. $
OVERHEAD COST, *
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR )
REPORTED
56
2681660.
2681715.
**********
42.9(19731
251514.
**********
«***M*M«V*
.5(1978)
56
2681660.
2681715.
**********
42.9(1973)
251514.
**********
***** *****
.5(1978)
59
**********
a*********
**********
100.8(1975)
131824.
**********
****»**«*«
.2(1978)
23
11951830.
6240210.
***K*»***«
157.4(1976)
665890.
«**K»N**4*
***«*«**»«
13.0(1978)
61
34982020.
r*
87.1(1931)
1487650.
03550.
2031250.
5.8(1981)
65
**««****»*
***********
***«»»**»»
87.1(1981)
1487650 .
9S550.
C031C50.
5.8(1931)
65
**********
**********
**********
150.9(1981)
1317125.
50530.
3269508.
7.4(1981)
65
**********
»*>•*****»»
**********
254.6(1981)
1793207.
697816.
8638236.
20.8(1981)
65
72507042.
22207992.
**********
102.6(1981)
6219212.
**********
12798<»82.
5.4(1981)
65
72507042.
22207992.
**********
102.6(1981)
8219212.
**********
12798982.
5.4(1981)
STAf.2A-2:ZS3
A3 JUSTED
£5
«*»V*.4»**t»
»»*<«>» -4 -.•»•**
»*•*••»****•«
*•*•****( 0)
***»»•**»**
«*»****«**
**********
***•**»( 0)
65
**********
**********
*****.«*»**
****#«( Q)
**********
********-*
«****•«****
*«****( Q)
65
**********
**********
**********
******( Q)
**********
**********
**********
******( 0)
65
**********
***********
**********
*»*»**( Q)
***********
**********
**********
******( 0)
65
**********
**********
**********
**•«***( Q)
**********
**********
**********
*****»( 0 )
65
**********
**********
**********
******( Q)
**********
**********
**********
******( 0 )
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 28
-------
EPA UTILITY F6D SUBVEY: OCTOBER - OECEKSER 1961
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
PACIFIC POWER 1 LIGHT
Jin EHICGER 4
NEW 550MVI (GROSS)
5TAPTTIP 9V7Q 55QPU fF^n
COAL
56 XS SUBBITUHINOUS
SODIUM CARBONATE
AIR CORRECTIOtl DIVISION, UOP
ENERGY CONSUMPTION: .27.
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
NSU 917MH ( GROSS 1
STARTUP 12/75 917MH (ESC)
COAL
3.00 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 6. OX
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
NEW 917HW (GROSS)
STARTUP 7/77 917KW (ESC)
COAL
3.00 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 6. OX
PENNSYLVANIA POWER
ERUCE MANSFIELD 3
NEW 917MU (GROSS)
STARTUP 6/60 917MW (ESC)
COAL
3.00 XS
LIME
M.W. KELLOGG
ENERGY CONSUMPTION: «**«x
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN I
RETROFIT 361MU (GROSS)
STARTUP 4/78 361MW (ESC)
COAL
.SO XS SUB3ITUMINOUS
UELLMAN LORD
DAVY (1CKEE
ENERGY CONSUMPTION: 4.4X
PUBLIC SERVICE OF HEW MEXICO
SAN JUAN 2
RETROFIT 350MU (GROSS)
STARTUP 8/78 35QMW (ESC)
COAL
.SO XS SUBBITUMINOUS
UELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 4.6X
COST DESCRIPTION
CAPACITY FACTOR i X
DIPECT CAPITAL, $
INDIRECT CAPITAL, *
TOTAL CAPITAL. $/XW«»tt»4X»
K»
-------
EPA UTILITY FC-D SURVEY: CCTGSER - DECEMBER 1981
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
NEW 534MW (G90SS)
STARTUP 12/79 534MW ( ESC J
COAL
.so ;:s SUSBITUMINOUS
HELLMAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: 3.6X
SALT RIVER PROJECT
CCRONAOO 1
MEW 350MH (GROSS)
STARTUP 11/79 280MU (ESC)
COAL
.50 XS SUSBITUMINOUS
LIMESTONE
M.U. KELLOGG
ENERGY CONSUMPTION: *.3x
SALT RIVER PROJECT
CO-OMADO 2
NEU 350MW (GROSS)
STARTUP 7/80 280MW (ESC)
COAL
.50 XS SUBBITUMINOUS
LIMESTONE
M.U. KELLOGG
ENERGY CONSUMPTION: 4.3X
SOUTH CAROLINA PUBLIC SERVICE
UINYAH 2
NEW 280MM (GROSS)
STARTUP 7/77 140MH (ESC)
COAL
1.10 XS BITUMINOUS
LIMESTONE
BABCOCK t UILCOX
ENERGY CONSUMPTION: 1.1X
SOUTH CAROLINA PUBLIC SERVICE
UINYAH 3
NEU 280MH (GROSS)
STARTUP 5/80 280MH (ESC)
COAL
1.10 XS
LIMESTONE
BABCCCK & UILCOX
ENERGY CONSUMPTION: 2.1X
SOUTH MISSISSIPPI ELEC PUR
R.O. MORROU, SB. 1
NEU 200KW (GROSS)
STARTUP 8/78 124MW (ESC)
COAL
1.30 XS BITUMINOUS
LIMESTONE
ENVXRONEERINS. RILEY STOKER
ENERGY CONSUMPTION: 5.5X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, */KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES. •
TOTAL ANNUAL, MILLS/KMH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, *
OTHER CAPITAL. *
TOTAL CAPITAL, «/KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, 4
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, *
OTHER CAPITAL, 9
TOTAL CAPITAL. */KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, $
TOTAL ANNUAL. MILLS/KMH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, *
OTHER CAPITAL, 9
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, *
FIXED CHARGES, *
TOTAL ANNUAL. MILLS/KWW YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. *
INDIRECT CAPITAL, f
OTHER CAPITAL. *
TOTAL CAPITAL, 9/KW(YEAH)
DIRECT ANNUAL, *
OVERHEAD COST, 9
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, 9
OTHER CAPITAL. *
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, «
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KUHIYEAH )
REPORTED
***
98790000.
**********
»"•**»* *•**•»
185.0(1978)
**********
**********
**********
»«»»»*( Q)
50
1889QOOO.
13725500.
**********
7« 4(1979)
1738000.
***«****«*
*»«**»*»*»
.8(1980)
50
18899000.
13725500.
««***»**»*
79.4(1979)
1738000.
**********
**********
.8(1980)
60
6026098.
520000.
100000.
23.7(1976)
527000.
**MI>H«****
**********
.3(1978)
***
10742500.
•ON*******
**********
38.4(1979)
yt********
**********
**********
******( Q )
***
10250000.
646000.
**********
53.7(1975)
**********
**********
**********
»»»*»«»( 1978)
ADJUSTED
65
*****»*»**
65
**********
**********
**********
******( Q)
**********
**********
**********
»•*»*>*( 0 )
65
**********
**********
**********
«»#**»( 0 )
*»*•«»*****
**Xrf*»*N*«
**********
***•***( Q )
65
**********
**********
**********
******( Q)
**********
**********
**********
***«*«( 0 )
65
**********
**********
**********
******l 0 )
***««»»***
**********
**********
**#***( 0 )
65
*»«***«*«*
**********
**********
******l Q )
**********
**********
**********
******( 0 )
*»***« INDICATES COST FIGURES NOT YET AVAILABLE
A- 30
-------
EPA UTILITY FGO SURVEY: OCTC3ER - DEC :ES 1931
SECTION A-l
COSTS FOR OPERATIONAL FGD SYSTEMS
U1IT DESCRIPTION
SCUTH MISSISSIPPI ELEC FWH
R.D. MCRKO'J, SR. 2
STARTUP 6/79 124KW (ESC)
CCAL
1.30 XS BITUMINOUS
LIMESTONE
ENVIHONEERING, RILEY STOKER
ENERGY CONSUMPTION: 5.5X
SOUTHERN ILLINOIS POKER
MARION 4
NEU 173MW (GROSS)
STARTUP 5/79 173MW (ESC)
COAL/REFUS
3.75 XS BITUMINOUS
LIMESTONE
B« nrnrv • UTI CflY
*OUUUf\ a Wl LIUA
ENEPGY CONSUMPTION: 2.3X
SOUTHERN INDIANA GAS ft ELEC
A.B. BROWN 1
NEU 265MW (GROSS)
STARTUP 3/79 265MW (ESC)
COAL
3.35 XS BITUMINOUS
DUAL ALKALI
FHC
ENERGY CONSUMPTION: .ex
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
HZU 194MM (GROSS)
STARTUP 4/77 194MU (ESC)
COAL
3.50 XS BITUMINOUS
LIMESTONE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION: 4.6X
SPRINGFIELD MATER, LIGHT t PUR
DALLMAN 3
NEU 20SMU (GROSS)
CTAPTtlD 1 ?yAO 1 A^MU 1 F*)<*.**( oi
65
**********
**********
**********
*#****( Q)
**•*•*•******
**********
******( 0)
65
*K>4»K»**)t
**********
**********
**»***( Q)
**********
**********
ttK********
*»****{ 0)
65
**********
**********
**********
******( Q)
**********
**********
**********
******( Q)
65
**********
**********
******( Q)
y**U4«.«*lt*
(*t«»
**********
******( 0,
65
**********
**********
**********
******( Q)
tt*********
**********
**********
******( 0)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 31
-------
EPA UTILITY FGO SURVEY: OCTOBER - DECEMBER 1981
SECTION A-l
COSTS FOR OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
TENNESSEE VALLEY AUTHORITY
WIDCWS CREEK 8
RETROFIT 550MW (GROSS)
STARTUP 5/77 SSOMH (ESC)
COAL
3.70 XS BITUMINOUS
LIMESTONE
TENNESSEE VALLEY AUTHORITY
ENERGY CONSUMPTION: 4.7X
TEXAS UTILITIES
MONTICELLO 3
NEU flOOMM (GROSS)
STARTUP 5/78 800MVI (ESC)
COAL
1.50 XS LIGNITE
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ****•/.
UTAH POKER & LIGHT
HUNTER 1
NEW 400MW (GROSS)
STARTUP 5/79 360MU (ESC)
COAL
.55 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «»*«X
UTAH POWER I LIGHT
HUNTER 2
NEW 400MW (GROSS)
STARTUP 6/80 360MM (ESC)
COAL
.55 XS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: »»»*•/.
UTAH POWER I LIGHT
HUNTINGTON 1
NEW 430MW (GROSS)
STARTUP 5/78 366MW (ESC)
COAL
.55 XS BITUMINOUS
LIME
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: 1.6X
COST DESCRIPTION
CAPACITY FACTOR f X
DIRECT CAPITAL. 9
INDIRECT CAPITAL. 9
OTHER CAPITAL. $
TOTAL CAPITAL. $/KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES. »
TOTAL ANNUAL, MILLS/KWH( YEAH )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, S/KUCYEAR)
DIRECT ANNUAL. «
OVERHEAD COST, $
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KUH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, $
OTHER CAPITAL, *
TOTAL CAPITAL, $/KM(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST, 9
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, »
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL. niLLS/KUH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWHf YEAR )
REPORTED
41
**********
**********
**********
87.1(1976)
**********
*****«»***
*»*****»»*
7.8(1978)
*»*
**********
**«»*»****
*»**«»«•«»
25.0(1978)
*» *3»*k«**lt
**********
**********
*»****( Q )
***
H**«»*»»*»
«W**»*4**»
**********
56.7(1978)
**»**»****
**«**»*«*»
M*M*tt«W»*«
»*»***( 1978)
96
**»******»
»»*»•»****»
»»»M**KWK*
60.2(1979)
**********
*»*******«
**********
.3(1930)
80
**********
**********
**********
63.0(1977)
2946400.
**********
**********
1.3(1978)
ADJUSTED
65
**tt**W*«*»
a*********
**********
153.K1931)
5159337.
»»«*******
16219666.
7.3(1981)
65
**********
**********
**********
**»***( Q)
*<«*«««»«»«
****)C«ft4«**K*
**********
-»»»*t*( Q)
**********
**********
**********
******( 0 )
65
**********
**********
**********
******( Q)
**********
**********
**********
******( Q )
65
**********
**********
**********
******( 0 )
*
**********
wowvvwt**
»»«**>»( 0 )
65
«***««***»
*»lt*
-------
EPA UTILITY F60 SURVEY: OCTOBER - OECErSEH
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
BASIN ELECTRIC POWER
ANTELOPE VALLEY 1
MEM 440MU (GROSS)
STARTUP 10/03 440MW (ESC)
COAL
.68 XS LIGNITE
LIME/SPRAY DRYING
JOY MFG/NIKO ATCMIZER
ENERGY CONSUMPTION: ****•/.
BASIH ELECTRIC PCUER
ANTELOPE VALLEY 2
MEW 440tfJ < GROSS)
STAPTUP 10/85 440MW (ESC)
COAL
.63 XS LIGNITE
LIME/SFPAY DRYING
JOY MFG/NIRO ATOMIZER
ENERGY CONSUMPTION: »*»»X
BASIN ELECTRIC POKER
LARAMIE RIVER 3
HEM S70HW (GROSS)
STARTUP 11/82 570HW (ESC)
COAL
.54 XS SUBBITUMINDUS
LIME/SPRAY DRYING
BAB COCK S UILCOX
ENERGY CONSUMPTION: »*»»x
BOSTON EDISON
MYSTIC 6
RETROFIT 150MH (GROSS)
STARTUP 4/72 150MW (ESC)
OIL
Z.OO XS NO. 6
MAGNESIUM OXIDE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: *«**X
COMMONWEALTH EDISON
MILL COUNTY 1A
RETROFIT 167MH (GROSS)
STARTUP 2/72 167MM (ESC)
COAL
1.50 XS
LIMESTONE
BABCGCK & MILCOX
ENERGY CONSUMPTION: 4.2X
DETROIT EDISON
ST. CLAIR 6A
RETROFIT 325MU (GROSS)
STARTUP 6/75 163MI4 (ESC)
COAL
.35 XS SUBBITUMINOUS
LIMESTONE
PEABCOY PROCESS SYSTEMS
ENERGY CONSUMPTION: 2.8X
COST DESCRIPTION
CAPACITY FACTOR • X
DIRECT CAPITAL i $
Tj-nTapfT TAPTTAI fi
XfiUAKCWI l.ArllMk, '
OTHER CAPITAL, 4
TOTAL CAPITAL, S/KW(YEAH)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, «
INDIRECT CAPITAL, 4
OTHER CAPITAL, $
TOTAL CAPITAL, 9/KkHYEAP)
DIRECT ANNUAL, *
OVERHEAD COST, $
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/XWHI YEAR 1
CAPACITY FACTOR, X
DIRECT CAPITAL, $
INDIRECT CAPITAL, $
OTHER CAPITAL, 9
TOTAL CAPITAL, S/KWCYEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES. 9
TOTAL ANNUAL. MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. »
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL, MILLS/KWH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL. 4
INDIRECT CAPITAL. 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KU(YEAR)
DIRECT ANNUAL, 4
OVERHEAD COST, 4
FIXED CHARGES, 4
TOTAL ANNUAL. MILLS/KWHl YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. 4
INDIRECT CAPITAL, 4
OTHER CAPITAL, 4
TOTAL CAPITAL, 4/KM(YEAR)
DIRECT ANNUAL. 4
OVERHEAD COST, 4
FIXED CHARGES. 4
TOTAL ANNUAL, MILLS/KWHC YEAR)
REPORTED
75
**********
tt iMf 3Hf K IMMf It
**»««**»**
75.2(1991)
«»**«*****
*******»«»
»*****»»*»
.8(1961)
»HM
47960000.
«»»«»»«»*«
*»**tt**»*M
109.01 0)
1797596.
**********
** ********
.8(7800)
75
*****tH»***
**********
**»*»»****
83.0(1981)
»******«<(*
»********»
»**»**»***
.6(1981)
»**
««*««*«***
*»**«*****
*«M«M**)IH»
63.4(1972)
• IftifHWKKN*
»*»»*****»
»NN**N»IIII*
3.0(1974)
49
»»**»*****
»»******«*
»*M*K-4*II*»
113.0(1972)
**M **)>****
«***»*****
**********
13.1(1975)
***
**********
**********
«*»***i,***
80.3(1976)
**********
***»***»*»
**********
9.6(19761
ADJUSTED
65
**********
3f jtft 4(46 K H^Jf>******)>*
******* ***
***«**( Q )
65
**********
**********
**********
******( Q)
**********
**********
««»(«<(•(*»**
******( o )
65
**********
**********
**********
******( 0)
**********
**********
**********
*****»( Q)
65
**********
**********
**********
******( Q )
a*********
**********
**********
*****»( Q)
65
**********
**********
**********
******( o ]
**********
**********
**********
******( Q )
STiJOiFSISED
ASJ'JSTID
63
»*» ».*»>«•»»
)><•*- .-*<»*
••»*- -»C 0)
*»«*>*„***
*t*-»^*i.i**
**•»*»**-*•**
*.HV>H4>( 0 )
o5
**•»***•**•»*
*»»*,-«)(.*,*
****4,4«*«
*»****( 0|
**•»**•«»***
********-•*
**rf*
-------
EPA UTILITY FGD SURVEY: OCTOBER - DECEMBER 1981
SECTION A-2
COSTS FOR NON-OPERATIONAL FGO SYSTEMS
UNIT DESCRIPTION
HCOSIER ENERGY
MEROM 1
NEU 490MU (GROSS)
STARTUP 5/82 441MU (ESC)
COAL
3.50 XS
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****•/.
ILLINOIS POWER COMPANY
U'COD RIVER 4
RETROFIT 110MM (GROSS)
STARTUP 9/72 110MM (ESC)
COAL
3.10 XS
CATALYTIC OXIDATION
MONSANTO ENVIRO CHEM SYSTEMS
ENERGY CONSUMPTION: ****•/.
LAKELAND UTILITIES
MCINTOSH 3
NEU 364KH (GROSS)
STARTUP 1/82 364MH (ESC)
COAL
2.56 XS BITUMINOUS
LIMESTONE
BABCOCK & UILCOX
ENERGY CONSUMPTION: »***•/.
MONTANA POUER
COLSTRIP 3
NEU 700MW (GROSS)
STARTUP 10/83 700MU (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: ****•/.
MONTANA PCUER
COLSTRIP 4
NEU 700MM (GROSS)
STARTUP 0/84 700MM (ESC)
COAL
.70 XS
LIME/ALKALINE FLYASH
THYSSEN/CEA
ENERGY CONSUMPTION: iHHWX
PHILADELPHIA ELECTRIC
EDOYSTONE 1A
RETROFIT 120MU (GROSS)
STARTUP 9/75 120MH (ESC)
COAL
2.60 XS BITUMINOUS
MAGNESIUM OXIDE
UNITED ENGINEERS
ENERGY CONSUMPTION: ****X
COST DESCRIPTION
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KUIYEAR)
DIRECT ANNUAL. 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KUW YEAR J
CAPACITY FACTOR. X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL. 9/KU(YEAR)
DIPECT ANNUAL. 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KWH( YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL. 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL. MILLS/KKW YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KW(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES. 9
TOTAL ANNUAL. MILLS/KWH( YEAR )
CAPACITY FACTOR. X
DIRECT CAPITAL, 9
INDIRECT CAPITAL, 9
OTHER CAPITAL, 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWH(YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, 9
INDIRECT CAPITAL. 9
OTHER CAPITAL. 9
TOTAL CAPITAL, 9/KU(YEAR)
DIRECT ANNUAL, 9
OVERHEAD COST, 9
FIXED CHARGES, 9
TOTAL ANNUAL, MILLS/KWHt YEAR )
REPORTED
***
24500000.
***«»**»»*
**********
50.01 0)
**********
**********
**********
******( 0 )
***
**********
**********
**********
82.5(1972)
**********
**********
**********
******( Q )
**»
11775400.
**********
**********
32. 4( 0)
****«**««*
**********
**********
******( o )
***
76643000.
**»*»«*««»
»*****«*«»
109.51 0)
**********
**********
**********
»*****( 0 )
*»«
70686000.
**********
**********
101.01 0)
**********
**********
**********
******( 0 )
65
*««****»»*
**»*«»»*»»
*«*****«*«
285.7(1973)
*«»**K*K»»
*»**«K*«tt»
**********
6.4(1979)
ADJUSTED
65
**********
**********
**********
******( Q)
**********
**********
**********
«*****( 0 )
65
***** *****
**********
**********
******! Q)
**********
**********
**********
******( 0 1
65
**********
**********
**********
****»*{ Q )
******»»**
**********
**********
*»»*»*( Q )
65
*»****»»««
**********
**********
******( o )
**********
**********
**********
******( Q )
65
**********
**********
**********
»»»*»*( Q)
«««*»K*4H>*
*«**«*****
**********
******l 0 )
65
«««>«Itlt***«
**********
**********
******( o )
***»**»»**
**********
**********
******( 0 )
STA.'Oi=3I2ED
ADJUSTED
o5
**********
**********
itM^voyvk^^
******•( 0 }
**********
***-***•***•*
**********
**+**»( 0 )
65
**#******#
**********
**********
*.***•<*( Q )
**********
**********
**********
******{ Q )
65
»«*****»**
**********
**********
**,****( 0 )
KM K* *«*»**
**********
**********
******( 0 )
65
****>«****»
**********
**********
******{ Q)
*•»»<»"»»»«»»
**********
**********
******( Q)
65
**********
**********
**********
******( Q)
M<(*<(K)f4)fl(M
**********
**********
******( Q)
65
**********
**********
**********
******( Q )
**********
**********
**********
******( o )
»•««•» INDICATES COST FIGURES NOT YET AVAILABLE
A- 34
-------
EPA UTILITY FGD SURVEY: OC70SER - DECEMBER 1931
SECTION A-2
COSTS FOR NON-OPERATIONAL FGD SYSTEMS
UNIT DESCRIPTION
PUBLIC SERVICE OF COLORADO
VALMCNT 5 A
RETROFIT 166MW (GROSS)
STARTUP 10/74 166HVJ (ESC)
COAL
.70 XS SU33ITUMINCUS
LIMESTONE/ALKALINE FLYASH
UOP/PUBLIC SERVICE OF COLORADO
ENERGY CONSUMPTION: 3.6X
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
NEW 500MU (GROSS)
STARTUP 5/88 500MW (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: **»*X
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
NEW 500MW (GROSS)
STARTUP 11/83 500MH (ESC)
COAL
1.80 XS BITUMINOUS
LIMESTONE
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****•/.
TENNESSEE VALLEY AUTHORITY
PARADISE 1
RETROFIT 704MW (GROSS)
STARTUP 0/83 704MW (ESC)
COAL
4.20 XS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: ***»•/.
TENNESSEE VALLEY AUTHORITY
PARADISE Z
RETROFIT 704MU (GROSS)
STARTUP 0/83 704MU (ESC)
COAL
4.20 XS
LIMESTONE
GE ENVIRONMENTAL SERVICES
ENERGY CONSUMPTION: «»M*X
COST DESCRIPTION
CAPACITY FACTOR, X
DIPECT CAPITAL. S
INDIRECT CAPITAL, *
OTHER CAPITAL i $
TOTAL CAPITAL. S/KW( YEAR )
DIPECT ANNUAL, «
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWH( YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, *
INDIRECT CAPITAL, *
OTHER CAPITAL, $
TOTAL CAPITAL, »/KU(YEAR)
DIRECT ANNUAL, $
OVERHEAD COST, $
FIXED CHARGES, $
TOTAL ANNUAL, MILLS/KWW YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL, »
INDIRECT CAPITAL. *
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, *
OVERHEAD COST. $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHC YEAR )
CAPACITY FACTOR, X
DIRECT CAPITAL. $
INDIRECT CAPITAL, $
OTHER CAPITAL, *
TOTAL CAPITAL, $/KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, $
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR)
CAPACITY FACTOR, X
DIRECT CAPITAL. *
INDIRECT CAPITAL, 9
OTHER CAPITAL, *
TOTAL CAPITAL, */KU(YEAR)
DIRECT ANNUAL, »
OVERHEAD COST, *
FIXED CHARGES, *
TOTAL ANNUAL, MILLS/KWHt YEAR )
REPORTED ADJUSTED STA(OAR3:ZZ3
ADJUSTED
*»» 65 65
********** *****«*<"«* **.«.«*»*»<,«
********** ********** **********
37.0(1974) .«»*)«***( 0) <***',*{ 0)
********** *•«»•«****»* *»•••***•»***
********** ********** »**»**«***
********** ********** **********
******( 0) *»****( 0) ******( 0)
»*» 65 65
*«*****«*« ********** **!.*******
*»*»**#*** ****»**>«** XV********
********** ********** **********
40. 0( 0) »**»*»( 0) ««**•«•<( 0)
*»****x*** ********** **********
********** ********** »•*****»•***
********** ********** **********
******( Q) ******( Q) *****»( 0)
»** 65 65
*******»*» ********** **********
********** ********** **********
KM******** ********** **********
40. 0( 0) JHHHI1HK 0) »»<•**»( 0)
»»**»***»* ********** **********
*******),** ********** **********
********** ********** **********
***T«**( 0) ******( 0) ******( 0)
*** 65 65
52500000. ********** **********
********** ********** **********
********** ********** **********
74. 6( 0) »***»*( 0) «*****( 0)
******»»** ********** **********
********** ********** ***********
********** ********** **********
*«****( 0) ******( 0) ******( 0)
*** 65 65
52500000. ****»**»»» **********
********** ********** **********
********** ********** ***********
74. 61 0) ***«»*( 0) ****•*•*( 0)
********** ********** **>»*******
********** ********** **********
********** ********** **********
******( 0) ******( 0) **»***( Q)
****** INDICATES COST FIGURES NOT YET AVAILABLE
A- 35
-------
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
Total Unit S02 Design
Removal Efficiency
B-2
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.
The actual percentage of SO2
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 deGermi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod. In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .
Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage. This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time. The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable. In addi-
tion, an undefined value can
result when the FGD system is
not called upon to operate 'for
a given period (e.g., turbine
or boiler outage when FGD sys-
tem is available) .
Hours that the FGD system op-
erated divided by total hours
in period. This parameter is
a relative stress factor for
the FGD system. It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The SO2 removed from the flue
gas is 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 S02 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 1
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 SO2 regulation.
Considering an FGD system as
well as alternative methods.
Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.
Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.
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 502
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
SO2 Removal Mode
Spare Capacity Index - %
Spare Component Index
System Supplier
Total Controlled Capacity
(TCC)
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.
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
-------
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.
Unit Rating
Gross Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.
Net w/FGD Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.
Net w/o FGD Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
B-8
-------
APPENDIX C
TABLE OF UNIT NOTATION
C-l
-------
TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Haas/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
Pl» fi
lb/10 Btu
ftj/min
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
(actual)
Ib
t
in. 11^0
•F
ft1
Acrc-ft'
Survey Report
Notation
ACRE
SO -FT
GR/SCF
PPM
LB/NMBTU
ACFM
GPH
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
1.B
T
IN. HjO
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
Meqagran
Kllopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
"2
M*
ppm
ng/J
liter/s
kg/s
M t/d
H t/h
J/g
m
cm
km
liter/m1
kg
Mg
kPa
•C
»J
Survey Report
Notation
SO.M
SQ.M
G/CU.H
PPM
NG/J
CU.M/S
LITER/S
KG/S
M T/D
M T/H
J/G
M
CM
KM
LITER/CU.M
KG
HG
KPA
C
CU.M
CU.M
o
K)
-------
APPENDIX D
FGD PROCESS FLOW DIAGRAMS
D-l
-------
o
NJ
UWSTOM StUMT
ID Mil 1
Alabama Electric,
Simplified Process Flow Diagram for Tombigbee 2 and 3
-------
V
Ul
SINCLC LOUVER
DAMPER
DOUBLE LOUVER
DAMPER
STACK
1.0. FAN
. TO DISPOSAL POND
DOUBLE-BLADCO
GUIUOTINE
DAMPER
r — ]
*\
\
-|
LIQUID
TO PROCESS
SEAL HATER
(SERVICE MATER)
TOTAL PROCESS
MAKE-UP WATER
(COOLING TOWER
ILOUOOUN)
DISTRIBUTOR
LIMESTONE
STORAGE UN
MILL
TO UNIT NO. 3
FROM UNIT NO. 3
-» TO UNIT NO. 3
Arizona Electric Power Coop, Apache 2 and 3
Process Flow Diagram
-------
"!S"
o
-M
igmm
Hxf
iom>
SUM
±
t -
—
M k I LOJMI
-V
i^r^
r ra,~£-
n«
Ml
SO. MUMII
-
IM
"MM
I eilUOIM
HMfilCW UIWKIIUIW
WKI MUUV
1
ISUUMII
J
•nu >
•5H-UMXII |
Will
j
.-
s
'
p.
l.J
."«"
«aM*»
1
,("
t^
s
V*
n
«j
x^
r
MITIMtnl
KMIU 1
li""1
« rSnJ*1"
i 1
1 IIMU nu 1 1 SIMU UM 1
ID
Arizona Public Service, Cholla 1:
Simplified Process Flow Diagram
-------
WCHWIW1.
OUSr COLLCCTOHS
DISC
scsue«t
£ —^
I ""*•
i
»
j
]
--
(.«
Jp»
fl
IB
..
5
urol
»t»
IT n
HUT
TiU
5w!
A
is
»
11
&TE
rr
t
•^ — •
^
[—(
>
4—i
W
J
/ P ^r-T— i
ito
••••
1
•^
•H
••
IJ
-
n
u
-
UVCR
HPER
1
r
IPLT
fJWS
n. COOED
MTH
Arizona Public Service, ChoHa 2:
Simplified Process Flow Diagram
D-5
-------
o
at
Central Illinois Light,
Simplified Process Flow Diagram of Duck Creek 1
Power Plant and Emission Control System
-------
o
-J
1 BOOSTER FAN
2 CHLORIDE/FLVASH PRECOOLER
3 FlYASH THICKENER
4 ABSORBER
S NEUTRAL 17ER
6 REACTOR-CLARIFIER
7 CAUSTICIZCRS
8 THICKENER
9 HORIZONTAL BELT FILTER
10 REHEAT FACILITY (EXPERIMENTAL)
«||SODA ASH||
(MAKEUP)
Central Illinois Public Service, Newton 1:
Simplified Process Flow Diagram Showing One of Four Absorbers
-------
HfKEUP M»TE«
(POND MUTER)
TO STACK - FlOt 6ASE5
HIST ELIMINATOR
0
I
03
TO OTHER
RECYCLE TftNK
• OVERFLOW
TO ASH POND
FROM OTHER
- RECYCLE TANK
•• TO IUCS
Columbus and Southern Ohio Electric, Conesville 5 and 6:
Simplified Process Flow Diagram for a Given Module
-------
To Stock
D
Reaction Tank
In-Tank
From
Precipitator
Flyash Silo
Lime Silo
Flyash Wet'G
Tank
Lime
Feed Pumps
Lime
Feed Tank
Strainer
To Disposal
Cooperative Power Association, Coal Creek 1 and 2:
Simplified Process Flow Diagram
-------
I
I-1
o
Flue gas
from boilers
Mnkeup from
overflow
Sproy
waler gos
Adjustable
. throat
dampers
Fuel Combus I ion
oil oir
Damper
">»— operator
housing
eliminator
To thickener
pumps
Bleed to
thickener •*—
nd clorifier
To thickener
XX Recycle
pump
(rough K
Service woler
Lime slurry feed line
.'..
Lime
sloroge
silo
\=2
rolor
<;
r-— c
i
j. s
Dy£oss_^_
-------
D
1ST STAGE
ADJUSTABLE VENTURI
FOR FLY ASH/S02
CaS03/S04
FLY ASM SLURRY
TO
STABILIZATION
FACILITIES
S02 ABSORBER SCRUBBER
RECYCL : RETURN SYSTEM
n^
'THICKENER ,| -
Duquesne Light, F. R. Phillips FGD System:
General Diagram.
-------
fBOM DISPOSAL POHD
D
I
H
to
SURGE
TANK
(EXISTING
K-103 1 V-103
EPRI SfST.
FLANGED
CONNECTION TO \—;
CIHHVS DUCT
FILTER CAKE
MASH MATER
SODA ASH
TANK I
AGITATO*
REACTOR NO. 4
AND AGITATOR
RfACIOR NO. 4
ADO AGIIMOR
Gulf Power, Scholz 1:
Simplified Process Flow Diagram of the Demonstration
Soda Ash/Limestone Dual Alkali Process
-------
AIR
HEATER
MOBILE PACKING
PRE-SATURATION SPRAY
FLUE GAS IN
TO STORAGE AREA
CLEAN GAS OUT TO STACK
MIST ELIMINATOR
WASH
WASTE
LURRY TANK
PUMP
Indianapolis Power and Light, Petersburg 3:
Simplified Process Flow Diagram for One of Four Absorbers
D-13
-------
STACK
I.D. FAN
a
H
COAL
SUPPLY
FEEDER
PULVERIZER
AIR HEATER
DEMISTER
RECYCLE
PUMP
Kansas City Power and Light, Hawthorn Units 3 and 4:
Simplified Process Flow Diagram of the Lime Scrubbing Process
LIME
PREPARATION
TANK
CLARIF1ER
MAKE UP
WATER
TO ASH DISPOSAL
POND
-------
o
H1
Ul
STEAM COI
REHEATE
ABSORBER
RE£IRCULATION
PUMPS
POND
RETURN
PUMPS
AIR
HEATERS TO
RECIRCULATI
TANKS
ENTURI
SCRUBBER
VENTURI
RECIRCULATION
PUMPS
HYDROCLONE
CLASSIFIER
LIMESTONE
BUNKER
LIMESTONE
SLURRY _
STORAGE^
BOILER
160 ACRE
SETTLING POND
WET BALL
MILL
Kansas City Power and Light,
LaCygne 1 FGD System: General Diagram
-------
FURNACE
DAMPERS
D
(-••
en
TWO PRECIPITATORS
FOUR I.D. FANS
ONE
STACK
WATER RETURN TO
REACTION TANKS
BLEED PUMP
SPRAY' PUMP TTRANSFER TANK
FOUR,
REACTION
TANKS
SLUDGE DISPOSAL
POND
Kansas Power and Light,
Schematic of Jeffrey Steam Generator and Emission Control Equipment
-------
u»u> tot
to 01KM
SOUMO NOQULC
UNDERFLOW PUMPS
Kansas Power and Light,
Lawrence 4 Operational FGD System:
Simplified Process Flow Diagram
-------
lUCSTMt UtHU rot
itff'.t uunriw
Dltuiiw und luxe
UOITIVI STMACE KCIUUUTIM 1UW)
T«W 60 SOI IDS
O
H
00
I
Kansas Power,and Light,
Lawrence 5 Operational FGD System:
Simplified Process Flow Diagram
-------
a
M
vo
(LECTRICAL
GENERATING
UNIT NO. I
ELECTRICAL
GENERATING
UNIT NO. 2
SPARE
SPARE
Kentucky Utilities,
Green River FGD System: General Process Diagram
-------
QUENCHER
HIST
ELIMINATOR
(CHEVRON)
ELECTROSTATIC
PRECIPITATOR
BOILER
FLUE
GAS
O
to
O
Louisville Gas and Electric, Cane Run 4
FGD System: Simplified Process Flow Diagram
-------
IN LINE REHEATER (STEAM)
to
H
I.D. BOOSTER FANS
TO STACK-
'MIST ELIMINATOR
,9. HIST ELIMINATOR WASH
BULK ENTRAINHEHT
StPARATOR
FROM LIME
MAKEUP
WATER
SPRAY PUMPS
IN-TANK STRAINER
TO DISPOSAL-
PUMPS
UNDERFLOW PUMPS
M.E.WASM
RECYCLE RUMP
TANK
Louisville Gas and Electric, Cane Run 5
FGD System: Simplified Process Flow Diagram
-------
COMBUSTION AH
> EXISTING < NO. 2 OIL
I CMIMIEY -"I
-1 1 ' - OIL FIRED
REHCATER 1
fi"Si_ I
^3-
FAN
" /•
II FROM ABSORBER A-201 . _ /
EXISTING!! BY CEA ("IVER WATER)
II * P* EMERGENCY WATER
JL JL FROM REMEATER SUPPLY
BOOSTER TO ABSORBER — {
FAN A-201 I
* ,*\ T* w C^. A-J
>1* Si/ BOOSTER
.X. TT FA"
EXISTING
, PRECIPITATOR !
I1 -•
EXISTING | FROM ABSORBER A-201 PRIMARY REACTOR
"1 OF TRAIN 2
|l 1 SECONDARY -
FROM ABSOR8CR A-101 OF Y*1*
r
1 1 REACTOR
BT O™8" tjOF TRAIN 1
7X1 SECONDARY
— J1^!
OF TRAIN
_^J ^/ .
I
ORBER
01
u
REACTOR
TRANSFER
PUMP
1
C
•
-4
"JHil'
^- -f*
j_
; ABSORBER
A-101
MIST ELIMINATOR
FROM THICKENER HOLD TANK
"•
M9*
RECYaE PUMP '
TYPICAL FOR (2)
RECYCLE PUMPS
,OVERaOW
1 * r-W
THICKENER *"
\
L--H
UN
WASH
AKE —
^
i
DERFLOW
PUMPS
M
2 '
•NsSjtt-P HOL
TTER \\hfr '*"
FILTERS El
1 ,
1
SODA ASH
sour ION
3
KAKE-UP
i .
' jH
SODA ASH
SILO
RIVER WATER
-L (START UP) ^ v.j ^
WEIGH FEEDER
i
rr
SODA ASH
SOLUTION
TANK^?
^ V OVFRFLOW
TO THICKENER
RIVER WATER
" 1.
HOLD TANK Tf| mvmlFR
TRANSFER
PUMPS
RCACTANT WACTOH TRANSFER S
FEED PUMK PUNT
Louisville Gas and Electric, Cane Run 6
Dual Alkali FGO System: Simplified Process Flow Diagram
D-22
-------
to
u>
I.D. BOOSTER FANSv
TO STACK*
BYPASS
IN LINE REHEATER (STEAM)
•MIST ELIMINATOR
P MIST ELIMINATOR WASH
-cJd —
IN-TANK STRAINER
TO DISPOSAL"
THICKNER
M.E.UASH
PUMPS "YAM" PUMP
UNDERFLOW PUMPS
Louisville Gas and Electric,
Mill Creek 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
V
K)
CAS INLET
Louisville Gas and Electric,
Paddys Run 6 FGD System:
Simplified Process Flow Diagram
-------
.STACK
TREATED-GAS
DUCT
SPRAY TOWER
ABSORBER
"WET" VENTURI
SCRUBBER
Minnesota Power and Light, Clay Boswell 4:
General Diagram
D-25
-------
RFI**T BY -PASS
0
to
CT\
FILTER CAKC
Minnkota Power Cooperative, Milton R. Young 2:
Simplified Process Flow Diagram for One of Two Absorbers
-------
a
M
S02 BOOSTER FANS
FLUE GAS}
"QUENCHER
TO STACK
LIME FEED
SYSTEM
-OCLONE
j, |
?!
LJ
fp
1
j
-j
»
RECYCLE TANK
WASH TRAY
-ABSORBER TRAY
RECYCLE
LIQUOR
THICKENER
*- 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
FLUE
GAS
EMERGENCY WATER
PLENUM
BLEED
MIST
ELIMINATORS
3 »-CLEAN FLUE GAS
00-SEAL WATER SUPPLY
UNDERSPRAY _MAKEIIP
WATER
;POND
ETURN
WASH TRAY POND
FLY ASH POND
Montana Power, Col strip 1 and 2:
Process diagram nf a given FGD module.
-------
TO CMINNCT
I
HfCHANlCAl
DUST
COUECTM
(MUUIClOhlS)
PWVERIM*
Nevada Power, Reid Gardner 1,2 and 3:
Process diagram of a given FGD system.
-------
DISCHARGE
TO STACK
CONDENSER
TRAY TOWER
ABSORBER
Na2C03
MAKE-UP
PRESCRUBBER
(VARIABLE-THROAT
VENTURI)
FLUE GAS FROM
UNIT 111
OJ
o
FLY ASH PURGE TO POND
EVAPORATOR/
^CRYSTALLIZER
TREATED
PURGE STREAM
STORAGE
BIN
Y
DRIED
SULFATE
PRODUCT
CENTRIFUGE
SODIUM SULFATE
CAKE
TO S02
REDUCTION
PLANT
CRYSTALLIZER
COMPRESSOR
Northern Indiana Public Service,
D. H. Mitchell 11 WeiIman. Lord/Allied System:
General Process Diagram.
-------
•Hti MtTIt
IIISTM
nuciiin '••• '**
«*,.<«» \/\ A /
iu inn iu» V/ \/ V/
•MMiJt M W COUCCTI
DISfOSM
IT tWC>
Simplified Process Flow Diagram
Spray Dryer Cutaway View
Northern States Power, Riverside 6,7: FGD System Flow Diagrams
-------
U)
to
FLUE GAS
TO
SCRUBBER
REHEATER
LIMESTONE —i
MIST
ELIMINATOR
OVERFLOW POTS
AND MARBLE BED
ASH POND
RETURN PUMP
Northern States Power, Sherburne 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
OJ
u>
_"... , i~~ «n*»
_PZ ,» .LI, "T""
—i—H J{—rsn=r K™ 1 K7 | I
- ED ""'g
Pennsylvania Power, Bruce Mansfield FGD System:
Process Flow Diagram for Unit 1 or 2
-------
FLUE GAS FROM
UPPER ESP
FLUE GAS FROM
LOWER ESP
X
STACK INLET
DAMPERS (2)
(1 EACH SIDE)
HOT REHEAT GAS
EXHAUST PLENUM
EXHAUST
ISOLATION
DAMPERS
(4 PER UNIT)
INLET
PLENUM
INLET ISOLATION
DAMPERS (4 PER UNIT)
BOOSTER FAN FLOW
CONTROL DAMPERS
(4 PER UNIT)
STACK
ABSORBERS
(4 PER UNIT)
VENTURIS
(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.
-------
JRP FLUE
SCRUBBER-
OUTLET
DUCTWORK
MIST
ELIMINATOR
REACTION
MIX TANK
FLUE GAS FROM
. ELECTROSTATIC
[ PRECIPITATORS
INDUCED-
DRAFT FANS
BOOSTER FANS
PRESATURATOR
OJ
ui
TO SEAL-HATER SYSTEM
TO FLUSH CONNECTIONS
TO ALKALI-PREPARATION SYSTEM
MIST-
ELIMINATOR
WASH
/TANK A
.FORTH-STAGE
/ SPRAY PUMP
ABSORBER-A
(BOOSTER
FAN
TO
ABSORBER-B
BOOSTER FAN
TO STACK
FROM ABSORBER B
MAKEUP
HATCH
TO ABSORBER B
TO ABSORBER B
LIMESTONE-SLURRY
MAKEUP
FROM ABSORBER B
FLOCCULENT
ADDITION
TO
ABSORBER 8
.F-m TO SLUDGE
STORAGE TANKS
Salt River Project, Coronado 1 and 2 FGD System:
Simplified Process Flow Diagram
-------
a
RECYCLE
WATER
TANK
Y^V FjROM ESP
\J ID BOOST!
TO POND
QUENCHEII
PUMP
ABSORBER QUENCHER
TANK TANK
RECYCLE WATER
PUMP
South Carolina Public Service Authority, Winyah 2: Simplified Process Flow Diagram
-------
BOILER
EXISTING
ELEC P8ECIP.
W/W
AIR
HEATER
\
FA FAN
LJ
•J
LIMESTONE
FEED BIN
(ONE IN USE
FOR TWO
BOILERS)
STACK
(EXISTING)
HEIGH FEEDER
(ONE IN USE)
HIST ELIMINATOR
I PUMP
(ONE IN USE
ONE SPARE)
MIXER—v
(ONE IN USE)
MET BALL MILL
(ONE IN USE)
MILL SLURRY
VENTURI SOR8ER
SCRUBBERTN
(ONE IN USE)
FROM THICKENER
TO THICKENER
TANK
PU*P
(
(ONE IN USE) } (ONE IN USE)
RECTUE TANK
(ONE IN USE)
ONE SPARE)
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
-------
LIMESTONE SLURRY
STORAGE TANK
TO OTHER ABSORBER
LIMESTONE
SILO
LIMESTONE
FEEOE
ABSORBER MODULE
LIMESTONE
TRANSFER
PUMP
CYCLONE
SEWRATOR S
MILL PRODUCT PUMP
QUENCHER
REC1RCULATING
PUMP
MILL PRODUCT TANK
BOTTOM ASH
OE WATERING
BIN
ASH CONVEYOR
I PLUG MILL
SLUDGE
TRANSFER PUMP
SLUDGE
CONVEYOR
CENTRATE SUMP
Southern Illinois Power Coop, Marion 4: Simplified Process Flow Diagram
-------
V
U)
FROM
ESP
BY-
PASS
STACK
*
>X
SODA ASH
STORAGE
BOOSTER
S
LIME
STORAGE
Na2C03
/ USE /SLAKER Ca(OH)2
/•r^BIN/
WATER
LIME REACTOR
5SULFUR DIOXIDE ABSORPTION
Na2S03 + S02 * H20 »2 NaHS03 | SURGE
£aS03/CaS04
FILTER
CAKE
SODIUM REGENERATION
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
V
o
PRECIPITATOR
INLET TEST
PORT LOUT ION
"B" ABSORBER
NODULE
TOP OF STACK
ELEVATION 1645'
TEST PORT
ELEVATION 1516'
-TOP OF OUTLET BREECHING
ELEVATION IJ72'-2 1/8"
-TOP OF BYPASS BREECH INS
ELEVATION 1307'- 8 1/2*
SCRUBBER INLET
TEST PORT LOCATION
mm CM
imiuwn
faun m
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
SULFUR PRODUCT
FLOTATION
SULFUR PRECIPITATION
AND RECOVERY
St. Joe Z1nc, G.F. Weaton 1:
Citrate FGD System Simplified Process Flow Diagram
D-41
-------
o
to
I AIR
JFUEL OIL>— ^REHEATER--,
TCA
SCRUBBER1
| FLUE GAS
|LIMESTONE
• • • •
l-V-5
T
HAKEUP UATERj ''
SAMPLE POINTS
OGAS COMPOSITION
SPARTICIPATE COMPOSITION & LOADING
©SLURRY OR SOLIDS COMPOSITION
®
GAS STREAM
LIQUOR STREAM
BLEED
i
STAC
r—QIAKEUP WATERJ
PROCESS
WATER
HOLD
TANK
DISCHARGE
SETTLING POND
Tennessee Valley Authority,
Shawnee IDA Prototype Test Unit:
General Process Diagram.
-------
FLUE GAS
D
u>
CLARIFIED LIQUOR
WATER
D
SPRAY TOWER EFFLUENT
HOLD TANK
!
c
3
C
! t
i
DESUPERSATURATION
TANK
Tennessee Valley Authority, Shawnee 10B Prototype Test Unit:
Modified Venturi/Spray Tower System for 2-Stage Oxidation Testing.
BLEED TO
DEWATERING
_, SYSTEM^
-------
I AIR > -^
I FUEL OIL >—»| REHEATEJT[—--.
PROCESS
WATER
HOLD TANK
SCRUBBER
EFFLUENT
HOLD
TANK
SAMPLE POINTS
OGAS COMPOSITION
®PARTICULATE COMPOSITION & LOADING
©SLURRY OR SOLIDS COMPOSITION
GAS STREAM
LIQUOR STREAM
SETTLING POND
Tennessee Valley Authority, ShawneelOB Prototype Unit:
General Process Diagram.
-------
O
ui
TO ASH
REHEATER
STEAM
7
ENTRAPMENT
SEPARATOR
DISPOSAL POND
TO STACK PLENUM
N
X,
f 1
r
TO TRAINS
B.C. AND D
£
FROM ESP
FAN
.. FROM B. C. AND 0 TRAIN.
VENTURI CIRCULATION"
CM
TO SETTLING POND
SLURRY PUMP
SEAL HATER
, HEADER
/••I m
RIVER HATER
PUHPS
FROM POND HATER
RECYCLE PUHPS
FROM LIMESTONE SLURRY
I TRANSFER PUMPS
VENTURI
CIRCULATION
TANK AND
PUMPS
ABSORBER
CIRCULATION
TANK AND
PUMPS
TO TRAINS / |.
B.C. AND D] „
LIMESTONE SLURRY
STORAGE TANK
EFFLUENT SLURRY
SURGE TANK AND PUMPS
LIMESTONE SLURRY
FEED PUMPS
Tennessee Valley Authority, Widows Creek 8 FGD System:
Process Flow Diagram for One of the Four Scrubber Trains
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fAlt OUTICT OAWEIK
- TWCI IKCT 0*Mf t«
FKM »OILt«
Alt PttHUTEtS
PUHP SEAL UATU.
MIL Hill COMIW
AND HOSE STATrats
SWf UP UATED TO
HHtSIWIE AREA
ASM ran
RETURN HATER
(KCTCLE HATE*)
Texas Utilities,
Simplified Process Flow Diagram for One of the Three Identical
Martin Lake FGD Systems
-------
10 SPRAY TOUCR 101
TO SPRA« TOUCH 201
O
FROM
LIMESTONE STORAGE
TO SPRAY TOUCR 101
TO SPRAY TOUCR 201
TO SPRAY TOUCR 101
TO SPRAY TOUCR 201
LIMESTONE
STORACt
BIN
TO SPRA( TOHER 101
TO SPRAT TOWER 201
rllKVIl
r
SERVICE HATER
| LINCSIONE CRINOIN6
I SYSTEM
LIMESTONE SLURRY
TANK AGITATOR
etPASS
TO SPRAY IOUER 101
'0 SPRAf IOUER 201
ElIM
M ST
BYPASS ,
FROM SPRAY TOUIR 101 \
FROM SPRAT TOUER 201 ]
BYPASS :
NATOR
1
IN
raws
•niiiniuin
SPRAY TOUCR
N
101
RHITTEMT
f
-------
REHEATEK FAN
D
*-
CO
FROM
ELECTROSTATIC
PRECIPITATORS
SUPERHEATED
STEAM
FROM OTHER
ABSO
m
BOOSTER FAN
LIME
TO OTHER
ABSORBERS
I
a
1 MIST 1
LIMlNATOf
;:::v.:::.:::.:.:.;.::v:v.
ABSORBER
ABSORBER
AGITATORS
hj
F
f>
MIST
ELIMINATOR
HATER
FROM OTHER
ABSORBERS
MAKEUP
WATER
VIBRATING
HOPPER
Utah Power & Light, FGD System Simplified Process Flow Diagram for Hunter 1, 2 or Huntington 1
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