AEPA
          United States
          Environmental Protection
          Agency
          Industrial Environmental Research  EPA-600/7-80-029d
          Laboratory          October 1980
          Research Triangle Park NC 27711
EPA Utility FGD Survey:
July - September  1980

Interagency
Energy/Environment
R&D Program Report

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                   RESEARCH REPORTING SERIES


 Research reports of the Office of Research and Development, U.S. Environmental
 Protection Agency, have been grouped into nine series. These nine broad cate-
 gories were established to facilitate further development and application of en-
 vironmental technology. Elimination of traditional  grouping  was consciously
 planned to  foster technology transfer and a maximum interface in related fields.
 The nine series are:

     1. Environmental Health Effects Research

     2. Environmental Protection Technology

     3. Ecological Research

     4. Environmental Monitoring

    5. Socioeconomic Environmental Studies

    6. Scientific and Technical Assessment Reports (STAR)

    7. Interagency Energy-Environment Research and Development

    8. "Special" Reports

    9. Miscellaneous Reports

 This report has been assigned to the INTERAGENCY  ENERGY-ENVIRONMENT
 RESEARCH AND DEVELOPMENT series. Reports in  this series result from the
 effort funded under the 17-agency Federal Energy/Environment Research and
 Development Program. These studies relate to EPA's mission to protect the public
 health and welfare from adverse effects of pollutants associated with energy sys-
 tems. The goal of the Program is to assure the rapid development of domestic
 energy supplies in an environmentally-compatible manner by providing the nec-
 essary environmental data and control technology. Investigations include analy-
 ses of the transport of energy-related pollutants and their health and ecological
 effects, assessments of, and development of,  control technologies for energy
 systems;  and integrated assessments of a wide range of energy-related environ-
 mental issues.
                        EPA REVIEW NOTICE
This report has been reviewed by the participating Federal Agencies, and approved
for publication. Approval does not signify that the contents necessarily reflect
the views and policies of the Government, nor does mention of trade names or
commercial products constitute endorsement or recommendation for use.

This document is available to the public through the National Technical Informa-
tion Service, Springfield, Virginia 22161.

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                                 EPA-600/7-80-029d

                                         October 1980
EPA Utility FGD Survey:
  July  - September  1980
                    by

    M. Smith, M. Melia, N. Gregory, and M. Groeber

           PEDCo Environmental, Inc.
              11499 Chester Road
             Cincinnati, Ohio 45246
            Contract No. 68-02-3173
                 Task No. 17
           Program Element No. C2KN1E
         EPA Project Officer: Norman Kaplan

      Industrial Environmental Research Laboratory
   Office of Environmental Engineering and Technology
         Research Triangle Park, NC 27711
                 Prepared for

     U.o. ENVIRONMENTAL PROTECTION AGENCY
         Office of Research and Development
             Washington, DC 20460

                    and

     U.S. ENVIRONMENTAL PROTECTION AGENCY
              Office of Enforcement
             Washington, DC 20460

-------
                              NOTICE


      This report (prepared by PEDCo Environmental, Inc., Cincin-
 nati, Ohio under EPA Contract No. 68-01-4147, Task No. 143)  is
 provided as an information transfer document.  Data in this
 report are supplied voluntarily by utility representatives;  flue
 gas desulfurization (FGD)  system designers and suppliers;  regula-
 tory personnel;  and others.   Neither EPA nor the designated  con-
 tractor warrants the accuracy or completeness of information
 contained in this report.

      Initial distribution  of the report (generally one copy  per
 company)  is limited to organizations and individuals  indicating
 a  specific interest in the field of FGD technology.   Additional
 copies  of this report  and  succeeding issues can be purchased from
 National  Technical  Information  Service,  Springfield,  Virginia
 22151.

      This report  presents  a  summary of  the FGD system design and
 performance  data  stored  in the  Flue Gas  Desulfurization  Infor-
 mation  System  (FGDIS), a computerized data base from  which it is
 generated.   Plans are  currently being formulated  to allow access
 to the  FGDIS by private  users  (subject  to  the  limitations ex-
 pressed in  the first paragraph  above).   It is  anticipated that
 this  will  be implemented during  the fourth quarter, 1980, at which
 time  the  service  will  be available  to the  public  through the
 National  Technical  Information  Service for a usage charge (non-
 profit) .  Users will have  the capability to access the additional
design  and performance data stored  within  the  data base that can-
not be  conveniently printed in this  report.  In addition, users
will  be able to tabulate the data in a manner  consistent with
 their specific information needs, as well  as perform  statistical
analyses  of  the numerical data  (e.g., average  liquid  to gas  ratio
for limestone FGD systems).  When this service becomes available,
the current recipients of this report will  be  notified; and
classes will be provided on the use of the  system.
                               ii

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                       USE OF THIS REPORT
     This report is the third of three supplementary issues to
the October - December 1979 report.  Supplementary issues are
cumulative, so that it is necessary to retain only the latest
issue and the October - December 1979 report (EPA-600/7-80-029a).

     It should be noted that along with the design and performance
data for operational FGD systems contained in Section 3, this
report also contains a number of tables presenting tabulations of
some of the key data.  The Executive Summary contains the number
and capacity of FGD systems as of the end of September 1980,
future projections  (December 1990) of controlled and uncontrolled
generating capacity, and unit by unit summaries of status changes
and performance during the period.

     Recent additions to this report include a section containing
design and performance data for U.S. operational particle scrub-
bers (Section 14) and a section containing design and performance
data for coal-fired operational Japanese FGD systems  (Section
15).  The regulatory classifications were recently modified to
accomodate the revised New Source Performance Standards  (6/79)
and, as a result, the categories will differ slightly from those
of previous issues.

     Appended to this report is a section containing reported and
adjusted cost data  for U.S. FGD systems in which operational sys-
tems are stressed  (Appendix A).  Also included in the appendices
are definitions, a  table of unit notation, and FGD process flow
diagrams.
                                iii

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                             ABSTRACT
     This  report  is  the  third of three supplements updating the
October  -  December 1979  report  (EPA-600/7-80-029a) and should be
used in  conjunction  with it.  The report, which is generated by a
computerized data base system, presents a survey of operational
and planned domestic utility flue gas desulfurization  (FGD) sys-
tems, operational domestic particle scrubbers, and Japanese
coal-fired utility boiler FGD installations.  It summarizes in-
formation  contributed by the utility industry, process suppliers,
regulatory agencies, and consulting engineering firms.  It pre-
sents data on system design, fuel characteristics, operating
history and actual performance.  Unit by unit dependability
parameters are included  and problems and solutions associated
with the boilers, scrubbers, and FGD systems are discussed.

     The domestic FGD systems are tabulated alphabetically by
development status (operational, under construction, or in the
planning stages), utility company, system supplier, process,
waste disposal practice, and regulatory class.  FGD system
economic data, definitions, and a glossary of terms are appended
to the report.  Current  data for domestic FGD systems show 76
systems in operation, 39 systems under construction, and 93
planned systems.   Projected 1990 FGD controlled capacity in the
U.S. is 99,252 MW.
                               IV

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                            CONTENTS
Notice
Use of This Report
Abstract
Tables
Executive Summary and Highlights
Section 1

Section 2

Section 3
Summary List of FGD Systems                    1

Status of FGD Systems                          8

Design and Performance Data for Operational
 FGD Systems                                  44

Alabama Electric
  Tombigbee 2                                 44
  Tombigbee 3                                 46
Arizona Electric Power
  Apache 2                                    48
  Apache 3                                    50
Arizona Public Service
  Cholla 1                                    52
  Cholla 2                                    54
  Four Corners 1                              56
  Four Corners 2                              58
  Four Corners 3                              60
Basin Electric Power Coop
  Laramie River 1                             62
Big Rivers Electric
  Green 1                                     65
Central Illinois Light
  Duck Creek 1                                67
Central Illinois Public Service
  Newton 1                                    70
Colorado Ute Electric Assn.
  Craig 2                                     73
Columbus & Southern Ohio Electric
  Conesville 5                                75
  Conesville 6                                77
Commonwealth Edison
  Powerton 51                                 79

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        CONTENTS (continued)
 Cooperative Power Association
   Coal Creek 1                                82
   Coal Creek 2                                84
 Delmarva Power & Light
   Delaware City 1                             87
   Delaware City 2                             90
   Delaware City 3                             93
 Duquesne Light
   Elrama 1-4                                  96
   Phillips 1-6                                99
 Indianapolis Power & Light
   Petersburg 3                               102
 Kansas City Power & Light
   Hawthorn 3                                 104
   Hawthorn 4                                 106
   LaCygne 1                                  108
 Kansas Power & Light
   Jeffrey 1                                  111
   Jeffrey 2                                  113
   Lawrence 4                                 115
   Lawrence 5                                 117
 Kentucky Utilities
   Green River  1-3                             119
 Louisville Gas &  Electric
   Cane Run 4                                 121
   Cane Run 5                                 123
   Cane Run 6                                 125
   Mill Creek 3                                127
   Paddy's  Run  6                               129
Minnesota  Power & Light
   Clay Boswell 4                              131
Minnkota  Power Cooperative
   Milton  R.  Young 2                           135
Monongahela  Power
   Pleasants  1                                138
Montana Power
   Colstrip 1                                 140
   Colstrip 2                                 142
Nevada Power
   Reid Gardner 1                             144
   Reid Gardner 2                             147
   Reid Gardner 3                             150
Northern Indiana Public Service
  Dean H. Mitchell 11                        152
                 VI

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Section 4

Section 5
       CONTENTS (continued)

                                             Page

Northern States Power
  Sherburne 1                                154
  Sherburne 2                                156
Pacific Power & Light
  Jim Bridger  4                             158
Pennsylvania Power
  Bruce Mansfield 1                          160
  Bruce Mansfield 2                          152
  Bruce Mansfield 3                          154
Public Service Company of New Mexico
  San Juan 1                                 166
  San Juan 2                                 169
  San Juan 3                                 172
Salt River Project
  Coronado 1                                 174
  Coronado 2                                 176
South Carolina Public Service Authority
  Winyah 2                                   179
  Winyah 3                                   181
South Mississippi Electric
  R.D. Morrow, SR. 1                         183
  R.D. Morrow, SR. 2                         185
Southern Illinois Power Coop
  Marion 4                                   187
Southern Indiana Gas & Electric
  A.B. Brown 1                               190
Springfield City Utilities
  Southwest 1                                193
St. Joe Zinc
  G.F. Weaton 1                              196
Tennessee Valley Authority
  Shawnee 10A                                198
  Shawnee 10B                                199
  Widows Creek 8                             201
Texas Utilities
  Martin Lake 1                              204
  Martin Lake 2                              206
  Martin Lake 3                              208
  Monticello 3                               210
Utah Power & Light
  Hunter 1                                   212
  Hunter 2                                   214
  Huntington 1                               216

Summary of FGD Systems by Company            218

Summary of FGD Systems by System Supplier    220
                              VI1

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                       CONTENTS  (continued)
Section 6

Section 7


Section 8


Section 9

Section 10

Section 11

Section 12

Section 13


Section 14
                                              Page

 Summary of FGD Systems by Process            222

 Summary of Operating FGD Systems by
  Process and Unit                            223

 Summary of End-Product Disposal
  Practices for Operational FGD Systems       225

 Summary of FGD Systems in Operation          227

 Summary of FGD Systems Under Construction     231

 Summary of Contract Awarded FGD Systems       233

 Summary of Planned FGD Systems               235

 Total  FGD  Units and Capacity (MW)
  Installed by  Year                           238

 Design and Performance Data for
  Operational Particle  Scrubbers              239

 Commonwealth Edison
  Will County  1                              239
 Detroit Edison
  St.  Clair 6                                 242
 Minnesota  Power and Light
  Syl  Laskin 1                                244
  Syl  Laskin 2                                246
  Clay Boswell  3                              248
 Montana-Dakota  Utilities
  Lewis  &  Clark  1                             250
 Pacific  Power  and  Light
  Dave  Johnston  4                            252
 Potomac Electric Power
  Dickerson 1                                253
  Dickerson 2                                255
  Dickerson 3                                257
Public Service of Colorado
  Arapahoe 4                                 259
  Cherokee 1                                 261
  Cherokee 4                                 263
  Valmont 5                                  265
Southwestern Public Service
  Harrington 1                               267
                              viii

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                      CONTENTS (continued)
Section 15
Appendix A
Appendix B

Appendix C

Appendix D
Design and Performance Data for
 Operational Foreign FGD Systems

Chugoku Electric
  Shimonoseki 1

Electric Power Development Company
  Isogo 1
  Isogo 2
  Takasago 1
  Takasago 2
  Takehara 1

FGD System Cost Data:  Operational
 and Nonoperational Systems

Introduction
Approach
Description of Cost Elements
Definition of Cost Elements
Costs for Operational FGD Systems
Costs for Nonoperational FGD Systems

Definitions

Table of Unit Notation

FGD Process Flow Diagrams
Page


269


269
                                                            271
                                                            273
                                                            275
                                                            277
                                                            279
A-l

A-2
A-4
A-7
A-l 5
A-20
A-25

B-l

C-l

D-l
                                IX

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                              TABLES


 N£I.                                                         Page

 I          Number and Total  Capacity of  FGD  Systems             xi

 II         Summary of Changes,  July  - September  1980          xiii

 III        Performance of Operational Units,
           July - September 1980                             xiv



                             FIGURE


No.                                                          Page

 1        Computerized Data Base Structure Diagram           xii

-------
                          EXECUTIVE SUMMARY
     This report is prepared quarterly  (every three months)  by
PEDCo  Environmental,  Inc.,  under contract  to the Industrial
Environmental Research Laboratory/Research Triangle Park  and the
Division  of Stationary Source Enforcement  of the U.S. Environ-
mental  Protection Agency.   It is generated by a computerized data
base system, the structure  of which is  illustrated in Figure 1.

     Table I summarizes  the status of FGD  systems in the  United
States  at the end of  September 1980.  Table II lists the  units
that have changed status during the third  quarter 1980, and  Table
III shows the performance of operating  units during this  period.


             TABLE I.  NUMBER AND TOTAL  CAPACITY  OF FGD SYSTEMS
Status
Operational
Under construction
Planned:
Contract awarded
Letter of intent
Requesting/evaluating bids
Considering only FGD
systems
TOTAL
No. of
units
76
39
30
7
18
38
208
Total
controlled
capacity, MW*
28,564
17,155
15,014
5,590
9,709
23,220
99,252
Equivalent
scrubbed ,
capacity, MW
25,832
16,442
14,164
5,590
9,709
23,000
94,737
* Total Controlled Capacity (TCC)  is the summation of the gross unit
  capacities (MW) brought into compliance with FGD systems regardless
  of the percent of the flue gas scrubbed by the FGD system(s).
  Equivalent Scrubbed Capacity (ESC) is the summation of the effective
  scrubbed flue gas in equivalent  MW based on the percent of flue gas
  scrubbed by the FGD system(s).
                                XI

-------
X
p-
                             Figure 1.   Computerized data base structure diagram.

-------
                             TABLE  II.   SUMMARY  OF  CHANGES
                                  JULY  - SEPTEMBER 19.80

FGD status report
June 30, 1980
Atlantic City Electric
Cumberland Station )
Basin Electric Power
Coop.
Laramie River 1
Big Rivers Electric
D. B. Wilson 1
D. B. Wilson 2
Central Power S Light
Coleto Creek 2
Cooperative Power
Association
Coal Creek 2
Oeseret Gen. ft Trans.
Coop.
Moon Lake 1
Grand Haven Brd. of
Light S Power
J. B. Sims 3
Louisville Gas S
Electric
Trinble County 1
Trimble County 2
Northern States Power
Sherburne 3
Pacific Power S Light
Jim Bridger 1
Jim Bridger 2
Jim Bridger 3
Public Service of Indiana
Gibson 5
Salt River Project
Coronado 2
Southwestern Electric
Power
Dolet Hills 1
Oolet Hills 2
United Power Association
Stanton 1A
Utah Power 1 Light
NJuqhton
west Texas Utilities
Ok 1 dun Ion 1
TOTAL

Operational
No.
73




+1







+1



















+ 1










76
MW« „
21,655°




570







327



















280










25,832
Under
construction
No.
38




-1







-1





+1











+1

-1





+ 1

»1


39
MW"
16,524




570







327





65











650

280





50

330


16,442
Contract
awa
No.
29






+1
*1







+1


-1











-1




+1


-1




30
ded
MW*
13,919






440
440







410


65











650




720


50




14,164
Letter
Of 1
No.
7











































7
tent
MWa
5,590











































5,590
Requesting/
eval bids
No.
15















-1





+1
+ 1

-1

tl
«1
+1














18
MWa
8,179b















410





575
575

860

560
550
550














9,709
Considering
FGD
No.
38

+1




-1
-1

*1











-1
-1













+1





+1
38
MWa
22,540

330




440
440

720











575
575













720





720
23,000

T tal
No.
200

*1







*1














-1

+1
»1
+1






+ 1
+1



»1

+1
208
MW*
90,407b

330







720














860

550
550
550






720
720



330

720
94.737
' Equivalent scrubbed capacity.
b This value was modified slightly due to a MM correction.
                                              Xlll

-------
                        TABLE III.
PERFORMANCE OF OPERATIONAL UNITS
JULY - SEPTEMBER 1980
Plant
loobigbec 2
Toacigbee 3
Apache 2
Apache 3
Cholla 1
Cholla 2
Four Corntn 1
Four Corner* 2
Four Corners 3
larwie River 1
Green 1
Duck Creek 1
Newton 1
Craig 2
Conesvllle 5
Conesvllle 6
Powerton 51
Coal Creek 1
Coal Creek 2
Delaware City 1
Delaware City 2
Delaware City 3
Elrama 1-4
Phillips 1-6
Petersburg 3
Hawthorn 3
Hawthorn 4
La Cygne 1
Jeffrey 1
Jeffrey 2
Lawrence 4
Lawrence 5
Green River 1-3
Cane Run 4
Cane Run S
Cane Run 6
FGO tyttea
capacity.
179
179
96
98
119
264
175
175
229
570
242
416
617
400
411
411
450
327
327
60
60
60
510
408
532
90
90
820
540
490
125
420
64
188
200
299
Flue gas
S scrubbed
70
70
50
50
100
100
100
100
100
100
100
100
100
87
100
100
100
60
60
100
100
100
100
100
100
100
100
100
75
70
100
100
100
100
100
100
FGD capacity
on line
during
perjog.
179
179
98
98
119




570

416
617
400
411
411
450
327
327
60
60
60
510
408

90
90
820
540
490
125
420
64
188
200
299
No information
for this
period, l*r





264
175
175
229

242













532











Shutdown
throughout
period.




































July 1980
Dependability V1
AVL
SO
100
100
29
100






88
2
67
90
98

100

97
50
95
100
95



97
100
100
97
100
100
86
79
100
OPR
49
68
86
30
99






76
2
55
76
87

100

97
SO
95
83
87

100
100
96
100
100
97
100

93
88
100
RtL
50
100
86
90
100






85
2
56
78
88

100

97
SO
95
98
95



96
100
100
97
100

93
88
100
UTL
27
59
85
29
99






66
2
47
47
85

87

91
50
95
83
87

65
78
77
69
95
97
96
0
86
79
83
August 1980
Dependability Jr1'
AVL
50
100
97
99







91
54
67
97
94



100
93
73
100
92



97
100
100
100
100
100
100
50
99
OPR
42
94
66
67







85
16
65
86
76



100
93
73
98
83



96
100
100
100
100

99
58
95
RtL
42
100
95
95







91
40
67
88
78



100
93
73
100
92



97
100
100
100
100

99
58
95
UTL
9
74
63
54







82
36
59
50
55



100
93
73
98
83



70
85
100
100
82
0
77
50
85
September 1980
Dependability X '
AVL











46
99
78
88
94











98
100
100
97
100
100
100
87
99
OPR











44
68
77
79
90











91
100
100
100
100

100
98
99
REL











46
83
79
80
90











97
100
100
100
100

100
98
100
UTL











44
33
77
79
89











54
100
100
40
96
0
36
87
87
X
H-
  (continued)

-------
TABLE III (continued)
Plant
Mill Creek 3
Paddy's Run 6
Clay Boswell 4
Hilton R. Young Z
Pleasants 1
Col strip 1
Colstrlp 2
Reid Gardner 1
Reid Gardner 2
Reid Gardner 3
Dean H. Mitchell 11
Sherburne 1
Sherburne 2
Jin Brldger 4
Bruce Mansfield 1
Bruce Mansfield 2
Bruce Mansfield 3
San Juan 1
San Juan 2
San Juan 3
Coronado 1
Coronado 2
Winy ah 2
Winy ah 3
R.D. Morrow, Sr. 1
R.D. Morrow, Sr. 2
Marlon 4
A.B. Brown 1
Southwest 1
C.F. weaton 1
Shawnee 10A
Shawnee 108
Widows Creek 8
Martin Lake 1
Martin Lake 2
Martin Lake 3
FGO syste*
capacity.
442
72
475
185
618
360
360
125
125
125
115
740
740
550
917
917
917
361
350
534
280
280
140
280
124
124
173
265
194
60
10
10
550
595
595
595
Flue gas
X scrubbed
100
100
85
42
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
80
80
50
100
62
62
100
100
100,.
N/A*
N/*H
N/Ad
100
75
75
75
FGD capacity
on line
during
>#*•
442
72
475
185
618


125
125
125
115
740
740
550



361
350
534
280
280
140
280
124
124
173
265
194
60
10
10
550
595
595
595
No information
for this
period, MW^





360
360







917
917
917



















Shutdown
throughout
period,




































July 1980
Dependability JT'"
AVI
92
100

65



87
88
96
100
100
100
98



100
98
76


100
13
94
80
97
92
69



99



OPR
91

96
65



95
77
96
0
100
100
83



92
77
90


100
13
99
81
100
93
54



73



REL
91

100
66



87
86
96

100
100
98





90


100
13
99
81
100
93
72



98



JTL
84
0
95
52



84
75
95
0
100
83
80



92
68
75


100
13
94
80
96
88
54



66



August 1980
Dependability JT'
AVL
59
100

99



86
97
100
84
100
100
96



100
98
83


98
18
100
99
100
95
73







OPR1
82

76
99



86
96
100
66
100
100
85



95
85
82


98
20
100
100
100
95
61







REl
82

100
99



84
96
100
66
100
100
95



93
100
83


98
20
100
100
100
95
62







UTL
59
0
66
98



72
80
100
31
99
100
78



95
81
80


88
18
100
99
91
95
61







September 1980
Dependability if'*
AVL
57
100

100



91
100
97
69
100
100




61
99
97


97
0
99
99
100
100
68







OPR
60

80
98



91

97
S3
100
100




93
56
59


100
0
100
100
100
100
43







RE Li
60

100
100



91

97
53
100
100




95
63
59


100
0
100
100
100
100
44







UTL
57
0
80
90



90
0
97
45
100
100




51
52
46


87
0
92
99
100
100
39







(continued)

-------
  TABLE   III  (continued)


FCO system
capacity.
Plant MM"
Montlcello 3 800
Hunter 1 360
Hunttr 2 360
Hunting ton 1 366
TOTAL


Flu* gas
X scrubbed
100
90
90
85

FGO capacity
on line
during
•»»•
800
360
360
366
20.512


No information
for this
period. MW*




s.oaa

Shutdown
throughout
period.




0


July 1980
Dependability V1"
AVL





OPR

100
100
100

RtL





UTL

100
99
87



August 1980
Dependability JT1"
AVL

100
100
100

OPR





RtL





UTL







September 1980
Dependability X0'*
AVL


100
0

OPR





REL





UTL





X
<
H-
* Equivalent scrubbed capacity.
b This category includes the flue gas capacity being handled by the FGO system at least part of the time during the  report period.
  The percent figures listed are average  values for all  system scrubbing trains during the period.
  Flue gas X scrubbed for prototype *nd demonstration units 1s not applicable unless the  system is  designed to bring a unit into compliance
  with SO, emission standard.
' Availability, operability, reliability, and utilization  as defined 1n Appendix C of this report.

-------
As indicated in Table I, 76 power generating units  (all coal-
fired) are now equipped with operating FGD systems.  These units
represent a total controlled capacity of 28,564 MW.  Current pro-
jections indicate that the total power generating capacity of the
U.S. electric utility industry will be approximately 833 GW by
the end of 1990.a  (This value reflects the annual loss resulting
from the retirement of older units, which is considered to be 0.4
percent of the average generating capacity at the end of each
year.b)  Approximately 370 GW or 44 percent of the 1990 total
will come from coal-fired units.  The distribution of power
generation sources, both present (December 1979) and future
(December 1990) is as follows:3

December 1979
December 1990
Coal
39%
44%
Nuclear
9%
14%
Oil
25%
20%
Hydro
13%
11%
Gas
13%
10%
Other
1%
1%
GW (total)
603
833
Based on the known commitments to FGD by utilities as presented
in Table I, the percentage of electrical generating capacity
controlled by FGD for both the present  (September 1980) and the
future  (December 1990) is as follows:

September 1980*
December 1990
Coal-fired generating
capacity, %
12.1
27.1
Total generating
capacity, %
4.7
11.9
In light of the revised New Source Performance Standards, actual
FGD control is expected to be greater than what is reflected by
the figures above.  For example, about 40 to 50 systems repre-
senting approximately 20,000 to 25,000 MW of generating capacity
presently fall into the uncommitted category.  These are systems
that cannot be included in the committed group at this time
because information regarding their status is not ready for
public release.

In an effort to show general FGD usage and projected usage
trends, the table below gives a current  (September 1980) and a
projected (December 1990) breakdown of throwaway product systems
versus salable product systems as a percent of the total known
commitments to FGD as of the end of the third quarter 1980:
  The number of committed FGD systems is as of September  1980;
  however, the figure used for the total generating capacity and
  coal-fired generating capacity is based on the available
  December 1979 figures.
                               xvi i

-------

Throwaway product process
Wet systems
Lime
Limestone
Dual alkali
Sodium carbonate
N/Aa
Dry systems
Lime
Sodium carbonate
Salable product process
Byproduct
Gypsum
Sulfur
Sulfuric acid
Process undecided

Total
Percent of total MW
September 1980


39.5
46.1
4.6
3.6

-

3.4
2.8
-
100.0
December 1990


21.1
36.0
2.1
3.3
6.7

3.2
0.5

2.4
1.1
2.7
20.9
100.0
 aNA - Not available (these systems are committed to a throwaway product
  process; however, the actual process is unknown at this time).


                   HIGHLIGHTS:  JULY - SEPTEMBER  1980

The  following paragraphs highlight FGD system developments during
the  third  quarter 1980.

Alabama Electric Cooperative reported that the Tombigbee  3 FGD
system achieved availabilities of 100% for both July and  August
with no major mechanical problems being  encountered.  Operational
data for the  month of September are not  yet available.

Atlantic City Electric has  announced plans to construct Cumber-
land Station  1 in Millville,  New Jersey.   The unit will have  a
gross rating  of 330 MW and  will fire a 3.25%  sulfur  coal.   The
utility is considering only FGD for SC-2  control, although  a
specific process  type has not been decided.   Initial operations
are expected  to begin in January 1988.
                               XVlll

-------
Initial and commercial FGD operations began on July 1, 1980, at
Laramie River 1 of Basin Electric Power Cooperative.  This unit,
which is rated at 570 MW (gross), fires a subbituminous coal with
an average sulfur content of 0.81%.  The FGD system, which is
preceeded by a cold side ESP for primary particle control, con-
sists of five Research Cottrell limestone packed tower modules.
The design SC>2 removal efficiency of the system is 90%.  The flue
gas exits the system through a 600 foot acid resistant brick
lined stack.  No initial system start up problems have been re-
ported .

A contract was awarded during the third quarter 1980 to Pullman
Kellogg by Big Rivers Electric for the installation of two wet
limestone FGD systems to control SC>2 emissions from the planned
D.B. Wilson units 1 and 2.  Each unit will be rated at 440 MW
(gross).  Currently, initial operations are scheduled to begin  in
1984 and 1985 for units 1 and 2, respectively.

Central Power and Light has announced plans to construct unit  2
at its Coleto Creek station in Fannin, Texas.  The unit will fire
a subbituminous coal with an average sulfur content of 0.39%.
Central and Southwestern Services, the holding company for
Central Power and Light, will construct the unit.  Only dry
scrubbing is being considered as a SC-2 control strategy.  Startup
of the system is scheduled for September 1986.

Initial operations began at Coal Creek 2 of Cooperative Power
Association during July 1980.  The unit is rated at 545 MW
(gross) and fires a pulverized lignite with an average sulfur
content of 0.63%.  The lime/alkaline flyash FGD system was
supplied by Combustion Engineering and treats 60% of  the  flue  gas
before it exits through a 650 foot stack.  The remaining gas is
used for bypass reheat.  A cold side ESP preceeds the FGD system
to provide primary particle control.  The sludge is stabilized
with flyash before being disposed of in a clay lined  pond.
Operational data are not yet available from the utility.

Deseret Generation and Transmission Coop announced  that a con-
tract has been awarded to Combustion Engineering for  the  in-
stallation of a wet limestone FGD  system on the Moon  Lake 1 unit.
The boiler, which will be located  in Vernal, Utah,  will fire coal
having an average sulfur content of 0.50% and will  be rated at
410 MW  (gross).  The FGD system will feature a fabric filter
supplied by Ecolaire for primary particle control.  Operations at
Moon Lake 1 are scheduled to commence in September  1984.

Grand Haven Board of Light and  Power announced that construction
began in July 1980 on the FGD system being  supplied by Babcock
and Wilcox to control SO2 emissions from the new J.B.  Sims  3
unit.  This unit, which is being constructed  in Grand Haven,
Michigan, will be rated at 65 MW  (gross) and will burn coal with
                                xix

-------
 an average sulfur content of 2.75%.   The wet lime FGD system will
 consist of two spray towers with an  overall design S02 removal
 efficiency of 90%.   Initial operations are expected to begin in
 June 1983.

 Kansas  City Power and Light reported that the La Cygne FGD system
 achieved availabilities of 97%,  97%, and 98% for the months of
 July, August,  and September,  respectively.   No major FGD  related
 problems were encountered during the three month period.

 Kansas  Power and  Light reported  100% availability for the third
 quarter 1980 for  both the Jeffrey 1  and  2 FGD systems.  The only
 problems reported for the three  month period at each unit were
 boiler  related.

 Kansas  Power and  Light also reported that the Lawrence  4  FGD
 system  achieved availabilities of 97%,  100%,  and 97% for  the
 months  of July, August,  and September,  respectively.   The only
 major FGD related problem occurred during July when a storage
 tank eroded  causing  a two day outage.  The  Lawrence 5 FGD system
 was  available  100% of the time during the third quarter,  1980
 with no FGD  related  problems being experienced.

 The dual alkali system installed  on  the  Cane  Run 6  unit of
 Louisville Gas and Electric achieved availabilities of  100%,  99%,
 and  99%  for  the months of July, August,  and  September,  respec-
 tively.   An  acceptance test that  took place during  July indicated
 that the system was  attaining a  95.1%  SC>2 removal efficiency
 level.

 Louisville Gas and Electric announced  that bids  for a wet scrub-
 bing system  to control S02  emissions from the  planned Trimble
 County  units 1 and 2  are  currently being  requested/evaluated.
 Each unit  will be rated at  575 MW (gross) and  will  burn bitumin-
 ous coal with an  average  sulfur content  of 4.0%.  ESP's will be
 utilized  for primary  particle control.   Operations  for units 1
 and 2 are  scheduled to commence in 1985  and  1988, respectively.

 Northern  States Power  reported that  the  FGD  systems installed on
 Sherburne  1 and 2 each had  availabilities of  100% for the entire
 third quarter of  1980.  The only  problems reported  for this
 period were boiler related.

Northern States Power  announced during the third quarter  1980
 that plans for a unit  3 at  the Sherburne County  station have been
 suspended.  The utility is  planning  further engineering studies
 and is considering locating this  new unit at  a  different  site.

 Pacific Power and Light is  currently requesting/evaluating  bids
 for sodium carbonate FGD  systems  to  be retrofitted  on units  1,  2,
 and 3 at the Jim Bridger  station  located  in Rock Springs, Wyoming.
Each boiler is rated  at 550 MW (gross) and fires subbituminous

                               xx

-------
coal with an average sulfur content of 0.56%.  Initial FGD
operations are scheduled to begin in 1988, 1984, 1986 for units 1,
2, and 3, respectively.

Construction began on the FGD system being installed at Public
Service of Indiana's Gibson 5 during July 1980.  The FGD system
is being supplied by Pullman Kellogg and will utilize a magnesium
promoted limestone process.  The system will consist of four
horizontal Weir absorber modules.  Initial operation is scheduled
to begin in 1982.

Salt River project announced that initial operations of the
limestone FGD system at Coronado 2 commenced in July.  The FGD
system, which was supplied by Pullman Kellogg, consists of two
limestone horizontal Weir absorber modules.  Primary participate
matter removal is provided by two hot side ESP's.  The utility
reports that bearing inspection has been completed and the unit
is expected to begin commercial operations in November.

South Mississippi Electric Power reported availabilities of 94%,
100%, and 99% for the R.D. Morrow, Sr. 1 FGD system during July,
August, and September, respectively.  During July some FGD system
outage time was caused by a malfunction of the ball mill.  The
R.D. Morrow, Sr. 2 FGD system achieved availabilities of 80%,
99%, and 99% during the same three month period, respectively.
The lower availability experienced during July was attributed to
ball mill repairs.

Southern Indiana Gas and Electric reported that the A.B. Brown  1
FGD system achieved availabilities of 92%, 95%, and 100% for the
months of July, August, and September, respectively.  Problems
with recirculation pumps and sludge disposal equipment were
reported for this three month period.

Southwestern Electric Power announced that a contract has been
awarded to the Air Correction Division, UOP for the installation
of a wet limestone FGD system to control S02 emissions from unit
1 at the new Dolet Hills station.  This unit is located in
Mansfield, Louisiana, and will be rated at 720 MW  (gross).  The
FGD system will be preceeded by an ESP for primary particle
removal.  Initial system operations are expected to begin in
1986.

Southwestern Electric Power has also announced plans for a second
unit to be installed at the Dolet Hills station.  Unit 2 is
scheduled to become operational in 1988, and the utility is
currently considering a wet limestone FGD  system for S(>2 control.

United Power Association announced that the FGD system being
supplied by Research-Cottrell at the Stanton station,  located  in
Stanton, North Dakota, is now under construction.  The FGD system
will utilize a lime/spray drying process to control SC>2  emissions

                               xx i

-------
 from  the  50 MW  (gross)  boiler,  followed by a  fabric  filter  for
 primary particle  control.   Initial  start up of  the system is
 projected for June  1982.

 The FGD System being retrofitted on the Naughton  3 unit  of  Utah
 Power and Light is  currently under  construction.  This boiler,
 which is located  in Kemmerer, Wyoming, is rated at 330 MW (gross)
 and fires coal with an  average  sulfur content of  0.55%.  The FGD
 system is being supplied by the Air Correction  Division, UOP, and
 will use a wet sodium    carbonate process.  Initial system start up
 is scheduled for June 1981.

 West Texas Utilities announced plans during the third quarter
 1980 for a new unit to  be located near Oklaunion, Texas.  The
 unit will be rated at 720 MW (gross).  Currently, the utility is
 considering only FGD as a means for S02 control.  Initial opera-
 tions are scheduled to  begin in 1987.

                           REFERENCES

 a.   U.S.  Department of Energy.  Energy Information  Administra-
     tion.  Office of Coal and Electric Power Statistics.   Elec-
     tric*Power Statistics Division.  Inventory of Power Plants
     in the United States, December 1979.  Publ.  No. DOE/EIA-0095
     (79).

b.   Rittenhouse,  R.C.  New Generating Capacity:  When,  Where,
     and by Whom.   Power Engineering 82(4):57.  April 1978.
                               xxii

-------
                                            EPA  UTILITY  FGD  SURVEY:  JULY  -  SEPTEMBER  1980
                                           SECTION  1
                                  SUMMARY  LIST  OF  FGD  SYSTEMS
COMPANY NAME/
UNIT NAME
ALABAMA ELECTRIC COOP
TOMBIGBEE
TOMBIGBEE
ARIZONA ELECTRIC POWER COOP
APACHE
APACHE
ARIZONA PUBLIC SERVICE
CHOLLA
CHOLLA
CHOLLA
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
FOUR CORNERS
ASSOCIATED ELECTRIC COOP
THOMAS HILL
ATLANTIC CITY ELECTRIC
CUMBERLAND
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY
ANTELOPE VALLEY
LARANIE RIVER
LARAMIE RIVER
LARA1IE RIVER
BIG RIVERS ELECTRIC
D.B. UILSOM
D.B. WILSON
SREEM
GREEN
CAJUN ELECTRIC POWER COOP
SIS CAJUN III
CENTRAL ILLINOIS LIGHT
DUCK CREEK
DUCK CREEK
CENTRAL ILLINOIS PUBLIC SERV
NEWTON
CENTRAL ILLINOIS PUBLIC SERVIC
NEWTON
CENTRAL MAINE POWER
SEARS ISLAND
CENTRAL POWER S LIGHT
COLETO CREEK
CINCINNATI GAS ( ELECTRIC
EAST BEND
EAST BEND
UNIT

2
3

2
3

1
Z
t
1
2
3
4
5

3

1

1
2
1
2
3

1
2
1
2

1

1
2

1

2

1

2

1
2
NO. UNIT LOCATION

LEROY
LEROV

COCHISE
COCHISE

JOSEPH CITY
JOSEPH CITY
JOSEPH CITY
FARMIN6TON
FARHINGTON
FARMINGTON
FARHINGTON
FARMINGTON

MOBERLY

MILLVILLE

BEULAH
BEDLAM
WHEATLAND
WHEATLAND
WHEATLAND



SEBREE
SEBREE

DE SOTO PARISH

CANTON
CANTON

NEUTON

NEWTON

PENOBSCOT BAY

FANNIN

RABBITHASH
RABBITHASH


ALABAMA
ALABAMA

ARIZONA
ARIZONA

ARIZONA
ARIZONA
ARIZONA
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO
NEW MEXICO

MISSOURI

NEW JERSEY

NORTH DAKOTA
NORTH DAKOTA
WYOMING
UYOHING
WYOMING



KENTUCKY
KENTUCKY

LOUISIANA

ILLINOIS
ILLINOIS

ILLINOIS

ILLINOIS

MAINE

TEXAS

KENTUCKY
KENTUCKY
START-UP
DATE

9/78
6/79

8/78
6/79

10/73
4/78
6/81
11/79
11/79
11/79
0/82
0/82

1/82

1/88

4/83
10/8$
7/80
6/81
4/82

7/84
1/86
12/79
11/80

0/85

7/76
1/86

9/79

12/82

1/89

9/86

10/87
12/80
STATUS

1
1

t
1

1
1
2
1
1
1
3
3

2

6

2
5
1
2
2

3
3
1
2

6

1
5

1

7

6

6

6
2
REG
CLASS

B
B

t
D

C
C
C
C
C
C
C
C

A

C

D
C
C
C
C

A
A
B
B

A

B
A

B

A

A

A


B
1.  OPERATIONAL UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
4.  PLANNED - LETTER OF    INTENT SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
6.  PLANNED - CONSIDERING ONLY FGD. SYSTEMS
7.  PLANNED - CONSIDERING FGD SYSTEMS; ALSO  ALTERNATIVE  METHODS
A.  FEDERAL NSPSC6/79)
B.  FEDERAL NSPSH2/71)
C.  STAMDARD(S) MORE STRINGENT THAN NSPS(6/79)
D.  STANDARO(S) MORE STRINGENT THAN NSPSM2/71) BUT NOT MORE  STRINGENT  THAN  NSPS<6/79>
E.  STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPS(12/71>

-------
EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
                                            SECTION 1
                                   SUMMARY LIST Of F6P SYSTEMS
COMPANY NAME/
UNIT NAME
COLORADO UTE ELECTRIC ASSN
CRAIG
CRAIG
CRAI6
COLU1BUS ( SOUTHERN OHIO ELEC
CONESVILLE
CONESVILLE
POSTON
POSTON
COMMONWEALTH EDISON
POWERTON
COOPERATIVE POWER ASSOCIATION
COAL CREEK
COAL CREEK
DELNARVA POWER I LIGHT
DELAWARE CITY
DELAWARE CITY
DELAWARE CITY
VIENNA
DESERET GEN 1 TRANS COOP
MOON LAKE
HOON LAKE
DUflUESNE LIGHT
ELRAMA
PHILLIPS
EAST KENTUCKY POWER COOP
J.K. SMITH
J.K. SMITH
SPURLOCK
FLORIDA POWER K LIGHT
MARTIN
MARTIN
6ENERAL PUBLIC UTILITIES
COAL
COAL
COAL
COAL
COHO
SEWARD
GRAND HAVEN BRD OF LIGHT I PUR
J.B. SIMS
HOOSIE& ENERGY
HER DPI
NEROM
HOUSTON LIGHTING C POWER
LIMESTONE
LIMESTONE
tf.A. PARISH
1. OPERATIONAL UNITS
2. UNITS UNDER CONSTRUCTION
3. PLANNED - CONTRACT AWARDED

A. FEDERAL NSPS(6/79)
B. FEDERAL NSPS<12/71>
C. STANDARD(S) "ORE STRINGENT
D. STANDARD(S) MORE STRINGENT
UNIT

1
2
3

5
6
5
6

51

1
2

1
2
3
9

1
2

1-4
1-6

1
2
2

3
4

1
2
3
4
1
7

3

1
2

1
Z
8
4.
5.
6.
7.


THAN
THAN
NO. UNIT LOCATION

CRAIG COLORADO
CRAIG COLORADO
CRAIG COLORADO

CONESVILLE OHIO
CONESVILLE OHIO
NELSONVILLE OHIO
NELSONVILLE OHIO

PEKIN ILLINOIS

UNDERWOOD NORTH DAKOTA
UNDERWOOD NORTH DAKOTA

DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
DELAWARE CITY DELAWARE
VIENNA MARYLAND

VERNAL UTAH
VERNAL UTAH

ELRAMA PENNSYLVANIA
SOUTH HEIGHT PENNSYLVANIA



MAYSVILLE KENTUCKY

MARTIN COUNTY FLORIDA
MARTIN COUNTY FLORIDA

UNDECIDED UNDECIDED
UNDECIDED UNDECIDED
UNDECIDED UNDECIDED
UNDECIDED UNDECIDED
GIRARD PENNSYLVANIA
EAST WHEATFIELDPENNSYLVAN1A

GRAND HAVEN MICHIGAN

SULLIVAN INDIANA
SULLIVAN INDIANA

JEWITT TEXAS
JEW1TT TEXAS
BOOTH TEXAS
PLANNED - LETTER OF INTENT SIGNED
PLANNED - REQUESTIN6/EVALUATTNC BIDS
START-UP
DATE

10/80
12/79
0/82

1/77
6/78
8/86
0/89

4/80

7/79
7/80

5/80
5/80
5/80
6/87

9/84
0/88

10/75
7/73

1/85
1/87
1/81

0/87
0/89

12/92
5/94
12/95
5/97
5/91
5/87

6/83

5/82
9/81

12/84
12/85
11/82


STATUS

2
1
3

1
1
6
6

1

1
1

1
1
1
6

3
5

1
1

6
6
2

7
7

6
6
6
6
5
5

2

2
2

5
5
2


REG
CLASS

D
D
D

D
D
D
D

E

B
B

E
E
E
A

A
A

D
D

A
A
B











A

B
B

A
A
A


PLANNED - CONSIDERING ONLY F6D SYSTEMS
PLANNED - CONSIDERING F6D SYSTEMS; ALSO ALTERNATIVE


NSPS<6/79>






METHODS



NSPSM2/71) BUT NOT MORE STRINGENT THAN NSPS(6/79)
E. STANDARD(S) EQUAL TO OR LESS STRINGENT THAN NSPSM2/71)

-------
                                            EPA UTILITY  F6D  SURVEY:  JULY - SEPTEMBER 1980
                                           SECTION  1
                                  SUMMARY LIST OF F6D  SYSTEMS
COMPANY NAME/
UNIT NAME
INDIANAPOLIS POWER t LIGHT
PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
IOWA ELECTRIC LIGHT ( PWR
GUTHRIE CO.
JACKSONVILLE ELEC AUTHORITY
NEM PROJECT
NEW PROJECT
KANSAS CITY POWER I LI6NT
HAWTHORN
HAWTHORN
LA CYGNE
KANSAS POUER t LIGHT
JEFFREY
JEFFREY
LAWRENCE
LAWRENCE
UNIT NO.

1
2
J
3
4

1

1
2

3
4
1

1
Z
4
5
UNIT LOCATION

PATRIOT
PATRIOT
PATRIOT
PETERSBURG
PETERSBURG
/
PANORA

EAST PORT SITE
EAST PORT SITE

KANSAS CITY
KANSAS CITY
LA CYGNE

WAMEGO
WAMEGO
LAURENCE
LAWRENCE


INDIANA
INDIANA
INDIANA
INDIANA
INDIANA

IOWA

FLORIDA
FLORIDA

MISSOURI
MISSOURI
KANSAS

KANSAS
KANSAS
KANSAS
KANSAS
START-UP
DATE

0/87
O/ 0
O/ 0
12/77
10/84

11/84

12/85
6/87

11/72
8/72
2/73

8/78
4/80
1/76
11/71
STATUS

6
6
6
1
2

5

6
6

1
1
1

1
1
1
1
REG
CLASS

C
C
C
B
B

A

A
A

D
D
E

D
D
D
D
KENTUCKY UTILITIES
   GREEN RIVER                  1-3

LAKELAND UTILITIES
   NCINTOSH                     3

LANSING BOARD OF WATER & LIGHT
   ERICKSON                     2
LOS ANGELES DEPT OF YTR I  PWR
   INTERMOUNTAIN                1
   INTERMOUNTAIN                2
   INTERMOUNTAIN                3
   INTERMOUNTAIN                4

LOUISVILLE GAS I ELECTRIC
   CANE RUN                     4
   CANE RUN                     5
   CANE RUN                     6
   HILL CREEK                   1
   MILL CREEK                   2
   KILL CREEK                   3
   MILL CREEK                   4
   PADDY'S RUN                  6
   TRIMBLE COUNTY               1
   TRIMBLE COUNTY               2

MAR3UETTE BOARD  OF  LIGHT  ( PWR
   SHIRAS                       3

MICHIGAN SO CENTRAL PWR AGENCY
   PROJECT                      1

MIDDLE SOUTH UTILITIES
   ARKANSAS LIGNITE             5
   ARKANSAS LIGNITE             6

1.  OPERATIONAL  UNITS
2.  UNITS UNDER  CONSTRUCTION
3.  PLANNED - CONTRACT AWARDED
        CENTRAL CITY
        LAKELAND
                       KENTUCKY
                       FLORIDA
                                         DELTA TOWNSHIP MICHIGAN
        DELTA          UTAH
        DELTA          UTAH
        DELTA          UTAH
        DELTA          UTAH
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        LOUISVILLE     KENTUCKY
        BEDFORD        KENTUCKY
        BEDFORD        KENTUCKY
        MARfiUETTE      MICHIGAN
        LITCHFIELD     MICHIGAN
                        ARKANSAS
                        ARKANSAS
                                          9/75
                                          8/81
                                          1/87
0/86
0/87
0/88
0/89
8/76
12/77
4/79
1/81
12/81
8/78
6/82
4/73
7/85
7/88
10/82
6/82
0/90
0/92
6
6
6
6
1
1
1
2
2
1
2
1
5
5
5
3
4
4








E
D
B
E
A
A
A
A
1
«
4.  PLANNED - LETTER  OF     INTENT  SIGNED
5.  PLANNED - REQUESTING/EVALUATING BIDS
6.  PLANNED - CONSIDERING  ONLY FGD SYSTEMS
7.  PLANNED - CONSIDERING  FGD SYSTEMS; ALSO ALTERNATIVE METHODS
A.  FEDERAL  NSPSC6/79J
B.  FEDERAL  NSPS(12/71)
C.  STANDARDCS)  MORE  STRINGENT THAN NSPSC6/79)
D.  STANDARDCS)  MORE  STRINGENT THAN NSPSM2/71) BUT NOT MORE  STRINGENT THAN NSPS(6/79>
E.  STANDARDCS)  EBUAL TO  OR LESS STRINGENT THAN NSPSM2/71)

-------
 EPA  UTILITY F6D SURVEY: JULY - SEPTEMBER  19f»C
                                              SECTION 1
                                    SUMMARY  LIST  OF  F6D SYSTEMS
COMPANY NAME/
UNIT NAME
MIDDLE SOUTH UTILITIES
UN ASSIGNED
UNASSIGNED
MILTON
dILTON

UNIT

1
2
1
2

NO. UNIT LOCATION



CONVENT
CONVENT



LOUISIANA
LOUISIANA
LOUISIANA
LOUISIANA
START-UP
DATE

0/89
0/93
0/88
0/91

STATUS

4
t
4
4
REG
CLASS

A
A
A
A
 MINNESOTA POWER  g  LIGHT
    CLAY BOSWELL                 4

 MINNKOTA POWER COOPERATIVE
    MILTON R.  YOUNG             2

 MONONGAHELA POWER
    PLEASANTS                    1
    PLEASANTS                    2

 MONTANA POWER
    COLSTRIP                     1
    COLSTRIP                     2
    COLSTRIP                     3
    COLSTRIP                     4

 MONTANA-DAKOTA UTILITIES
    COYOTE                       1

 MUSCATINE POWER  I  WATER
    MUSCATINE                    9

 NEBRASKA PUBLIC  POWER DISTRICT
    FOSSIL III                    1
 NEVADA POWER
    HARRY ALLEN
    HARRY ALLEN
    HARRY ALLEN
    HARRY ALLEN
    REID  GARDNER
    REID  GARDNER
    REID  GARDNER
    REID  GARDNER
    EARNER  VALLEY
    EARNER  VALLEY
NEW  YORK  STATE £LEC I
   SOMERSET
                       GAS
NIAGARA  MOHAWK POWER COOP
   CHARLES  R.  HUNTLEY

NORTHERN  INDIANA  PUB SERVICE
   DEAN  H.  MITCHELL
   SCHAHFER
   &CH1HFER

NORTHERN  STATES POWER
   RIVERSIDE
   SHER9URNE
   SHERBURNE
66
11
17
18
6,7
1
2
          COHASSET
          CENTER
          BELMONT
          BELMONT
          COLSTRIP
          COLSTRIP
          COLSTRIP
          COLSTRIP
          BEULAH
          MUSCATINE
                                          SARGENT
                                         SOMERSET
         BUFFALO
GARY
WHEATFIELD
WHEATFIELD
MINNEAPOLIS
BECKER
BECKER
                          MINNESOTA
                          NORTH  DAKOTA
                WEST VIRGINIA
                WEST VIRGINIA
                MONTANA
                MONTANA
                MONTANA
                MONTANA
                NORTH DAKOTA


                IOWA


                NEBRASKA
1
2
3
4
1
2
3
4
1
2
LAS VEGAS
LAS VEGAS
LAS VEGAS
LAS VEGAS
MOAPA
MOAPA
KOAPA
MOAPA
ST. GEORGE
ST. GEORGE
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
NEVADA
UTAH
UTAH
                                                         MEW YORK
                         NEW YORK
INDIANA
INDIANA
INDIANA
MINNESOTA
MINNESOTA
MINNESOTA
                                            4/80
                                            9/77
                   3/79
                  10/80
                   9/75
                   5/76
                   5/83
                   3/84
                                            3/81
                                            9/82
                                                                            3/87
                                                                           6/84
                                           4/82
 7/76
 6/83
 6/85
11/80
 3/76
 3/77
6/86
6/87
6/8?
6/89
3/74
4/74
6/76
4/83
6/85
6/86
6
6
6
6
1
1
1
4
5
5
A
A
A
A
6
B
B
A
A
A
1.  OPERATIONAL UNITS
2.  UNITS UNDER CONSTRUCTION
3.  PLANNED - CONTRACT  AWARDED
 4.   PLANNED - LETTER  OF     INTENT SIGNED
 5.   PLANNED - REOUESTING/EVALUATING BIDS
 6.   PLANNED - CONSIDERING  ONLY FGD SYSTEMS
 7.   PLANNED - CONSIDERING  FGO  SYSTEMS; ALSO ALTERNATIVE METHODS
A.  FEDERAL NSPSC6/79)
B.  FEDERAL NSPSM2/71)
C.  STANDARD(S) MORE  STRINGENT THAN NSPS(6/79)
D.  STANDARDCS) MORE  STRINGENT THAN NSPSM2/711 BUT NOT MORE  STRINGENT THAN NSPSC6/79)
E.  STANDARDCS) E8UAL TO  OR LESS STRINGENT THAN NSPSC12/71)

-------
                                             EPA  UTILITY FGO SURVEY: JULY - SEPTEMBER  1980
                                            SECTION 1
                                   SUMMARY  LIST  Of  FGO SYSTEMS
COMPANY NAME/
UNIT NAME
PACIFIC GAS R ELECTRIC
MONTEZUNA
•
D.  STANDARD(S)  MORE  STRINGENT THAN NSPS<12/71) BUT  NOT  MORE  STRIliGENT THAN NSPS<6/79)
E.  STANOARDfS)  EOUAL TO OR LESS STRINGENT THAN NSPS(12/71)

-------
EPA  UTILITY  FGD  SURVEY: JULT - SEPTEMBER 1980
                                             SECTION 1
                                    SUMMARY LIST OF F&O SYSTEMS
 COMPANY NAME/
    UNIT NAME
                                 UNIT NO. UNIT LOCATION
                                                                     START-UP
                                                                       DATE
                                   REG
                           STATUS  CLASS
 SOUTH CAROLINA PUBLIC  SERVICE
    WINYAH                       4

 SOUTH MISSISSIPPI  ELEC  PMR
    R.D. MORROW, SR.             1
    R.O. MORROW, SR.             2

 SOUTHERN ILLINOIS  POWER COOP
    MARION                       4
    MARION                       5

 SOUTHERN INDIANA GAS & ELEC
    A.B. BROWN                   1

 SOUTHWESTERN ELECTRIC POKER
    DOLET HILLS                  1
    DOLET HILLS                 2
    HENRY w.  PJRKEY             1

 SPRINGFIELD  CITY  UTILITIES
    SOUTHWEST                   1

 SPRINGFIELD  WATER,  LIGHT t PWR
    BALL1AN                      3

 ST.  JOE  ZINC
    G.F.  WEATON                  1

 SUNFLOWER ELECTRIC  COOP
    HOLCOMB                      1

 TAMP* ELECTRIC
    9IG SEND                     4
TENNESSEE VALLEY  AUTHORITY
   JOHNSONVILLE
   PARADISE
   PARADISE
   SNAWNEE
   SNAWNEE
   WIDOWS CREEK
   WIDOWS CREEK

TEXAS MUNICIPAL POWER  AGENCY
   GIBBONS CREEK

TEXAS POWER » LIGHT
   SANDOW
   THIN OAKS
   TWIN OAKS

TEXAS UTILITIES
   FOREST GROVE
   MARTIN LAKE
   MARTIN LAKE
   MARTIN LAKE
   MARTIN LAKE
   HILL CREEK
   MILL CREEK
   MONTICELLO
                            1-10
                            1
                            2
                            10A
                            10B
                            7
                            B
                                      GEORGETOWN
                                      HATTISBURG
                                      HATTISBURG
                                     MARION
                                     MARION
                                                     SOUTH CAROLINA
MISSISSIPPI
MISSISSIPPI
ILLINOIS
ILLINOIS
                                     WEST  FRANKLIN   INDIANA
                                     MANSFIELD       LOUISIANA
                                     MANSFIELD       LOUISIANA
                                     HALLSVILLE      TEXAS
                                     SPRINGFIELD     MISSOURI


                                     SPRINGFIELD     ILLINOIS


                                     MONACA          PENNSYLVANIA


                                     HOLCOMB         KANSAS
                                     TAMPA
                                                     FLORIDA
                                     NEW JOHNSONVILLTENNESSEE
PARADISE
PARADISE
PADUCAH
PADUCAH
BRIDGEPORT
BRIDGEPORT
CARLOS
ROCKDALE
8REMOND
BREMOND
ATHENS
TATUM
TATUM
TATUM
TATUM
HENDERSON
HENDERSON
MT. PLEASANT
KENTUCKY
KENTUCKY
KENTUCKY
KENTUCKY
ALABAMA
ALABAMA
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
TEXAS
7/81
8/78
6/79
5/79
0/88
3/79
0/86
0/88
12/84
4/77
10/80
11/79
9/83
12/84
12/81
3/82
6/82
4/72
4/72
9/81
5/77
2
1
1
1
6
1
3
6
3
1
2
1
3
3
3
2
2
1
1
2
1
A
B
B
B
A
B
A
A
B
B
B
B
A
A
E
E
E
E
E
E
E
                                                                       1/82
                                                                      11/80
                                                                      8/84
                                                                      8/85
                                                                      0/87
                                                                      4/77
                                                                      5/78
                                                                      2/79
                                                                      0/85
                                                                      0/85
                                                                      0/86
                                                                      5/78
1.  OPERATIONAL  UNITS
2.  UNITS UNDER  CONSTRUCTION
3.  PLANNED - CONTRACT  AWARDED
A.
B.
C.
D.
E.
                             4.   PLANNED  - LETTER OF    INTENT SIGNED
                             s.   PLANNED  - REQUESTING/EVALUATING BIDS
                             6.   PLANNED  - CONSIDERING ONLY FGO SYSTEMS
                             ?.   PLANNED  - CONSIDERING FGD SYSTEMS; ALSO ALTERNATIVE METHODS
FEDERAL NSPS(6/79)
FEDERAL NSPSC12/71)
STANDARD(S) MORE STRINGENT THAN NSPS(6/79)
STANDARD(S) MORE STRINGENT THAN NSPS(12/71)  BUT  NOT MORE STRINGENT THAN NSPSC6/79)
STANDARD(S) E8UAL TO OR LESS STRINGENT  THAN  NSPSC12/71)

-------
                                             EPA UTILITY  FGO  SURVEY:  JULY  - SEPTEMBER 1980
                                           SECTION  1
                                  SUMMARY  LIST  OF  FOO  SYSTEMS
COMPANY NAME/
   UNIT NAME
                               UNIT NO.  UNIT  LOCATION
                                       START-UP          DEC
                                         DATE    STATUS CLASS
TUCSON ELECTRIC POWER
   SPRINGERVILLE               1
   SPH1NGERV1LLE               2

UNITED POWER ASSOCIATION
   STANTON                     1A

UTAH POWER & LIGHT
   HUNTER                      1
   HUNTER                      2
   HUNTER                      3
   HUNTER                      t,
   HUNTINGTON                  1
   NAUGHTON                    3

WEST PENN POWER
   KITCHELL                    33

WEST TEXAS UTILITIES
   3KLAUNION                   1
        SPRINGERVILLE
        SPRINGERVILLE
        STANTON
        CASTLE  DALE
        CASTLE  DALE
        CASTLE  DALE
        CASTLE  DALE
        PRICE
        KEWMERER
        COURTNEY
                                         OKLAUNION
ARIZONA
ARIZONA
                       NORTH DAKOTA
UTAH
UTAH
UTAH
UTAH
UTAH
WYOMING
                       PENNSYLVANIA
                                                        TEXAS
1/85
3/87
                                         6162
5/79
6/80
6/83
6/85
5/78
6/81
                  8/82

                 12/86
1.  OPERATIONAL  UNITS
2.  UNITS UNDER  CONSTRUCTION
3.  PLANNED  -  CONTRACT AWARDED
4.  PLANNED - LETTER OF     INTENT  SIGNED
5.  PLANNED - REQUESTING/EVALUATING  BIDS
6.  PLANNED - CONSIDERING ONLY  FGft SYSTEMS
7.  PLANNED - CONSIDERING F6D SYSTEMS;  ALSO  ALTERNATIVE METHODS
 A.   FEDERAL  NSPS(6/79)
 B.   FEDERAL  NSPSM2/71)
 C.   STANDARDfS)  MORE STRINGENT THAN NSPS<6/79)
 D.   STANDARD(S)  MORE STRINGENT THAN NSPSCI2/71) BUT NOT MORE  STRINGENT THAN NSPS(6/79)
 E.   STANDARD(S)  EQUAL TO OR LESS STRINGENT THAN NSPS(12/71)

-------
  EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 19RC
                                               SECTION  2
                                         STATUS OF  FGD  SYSTEMS
 JUT IDENTIFICATION
                                                                    ABSTRACT
 ALABAtA ELECTRIC COOP
 T3OIG9EE
 2
 NEW       255.0 MM (GROSS)
           179.0 MW (ESC)
 C3AL
  1.15 XS  BITUMINOUS
 LIMESTONE
 PEABODY PROCESS SYSTEMS
 ENERGY CONSUMPTION:  3.1X
 STATUS 1     STARTUP  9/76
 TOMB1GBEE  2 Of ALABAMA ELECTRIC  COOP  IS  A  PULVERIZED COAL BOILER LOCATED
 IN  LEROY,  ALAPAKA. THE BOILER GENERATES  A  MAXIMUM FLUE GAS FLOW OF 953,000
 ACFM  AND  BURNS BITUMINOUS COAL WITH AN AVERAGE  SULFUR CONTENT OF 1.151 AND
 AN  AVERAGE  HEAT CONTENT OF 11,500 BTU/LB.  THE UNIT S02 EMMJSSION LIMITA-
 TION  VALUE  IS  1.2 LB/MMBTU. PRIMARY PARTICULATE  MATTER CONTROL IS PROVID-
 ED  BY  A HOT SIDE  ESP. THE S02 REMOVAL. E8UIPMENT  CONSISTS OF TWO SPRAY
 TOWERS SUPPLIED BY PEABODY PROCESS SYSTEMS WHICH UTILIZE A LIMESTONE REA-
 GENT.  A CHEVRON MIST ELIMINATOR  IS INCLUDED FOR  EACH TOWER AND THE FLUE
 GAS is REHEATED .ITH BYPASSED GAS BEFORE BEING  VENTED TO A 400 FOOT ACID-
 BRICK  LINED STACK. THE SYSTEM OPERATES IN  AN  OPEN WATER LOOP MODE AND
 SPENT  APSORBENT IS DISPOSED OF IN AN ON-SITE  LINED POND.
 4LABA-U  ELECTRIC COOP
 I01BIGBEE
 3
 1EW        255.0 *u (GROSS)
           179.0 «« (ESC)
 C3AL
  1.15  XS  BITUMINOUS
 LIMESTONE
 PEABOOY  PROCFSS SYSTEMS
 ENERGY  CONSUMPTION:  3.IX
 STATUS  1     STARTUP  6/79
TOMB1GBFE  3  OF  ALABAMA ELECTRIC COOP  IS  A  PULVERIZED  COAL BOILER LOCATED
IN LEROY,  ALABAMA.  THE BOILER GENERATES  A  MAXIMUM  FLUE GAS FLOW OF 953,000
ACFM AND BURNS  PITUM1NOUS COAL WITH AN AVERAGE  SULFUR CONTENT OF 1.15* AND
AN AVERAGE HEAT CONTENT OF 11,500 BTU/LB.  THE  UNIT S02 EMISSION LIMITATION
VALUE IS 1.2  LB/MMBTU. PRIMARY PARTICULATE  CONTROL IS PROVIDED BY A MOT
SIDE ESP.  THE SOt  REMOVAL E8UIPMENT CONSISTS  OF  TWO SPRAY TOUERS SUPPLIED
BY PEABODY PROCESS  SYSTEMS WHICH UTILIZE A  LIMESTONE  REAGENT. A CHEVRON
MIST ELIMINATOR IS  INCLUDED IN EACH TOWER,  AND  THE FLUE GAS IS REHEATED
WITH BYPASSED GAS  BEFORE BEING VENTED  TO A  400  FOOT ACID BRICK LINED
STACK. THE SYSTEM  OPERATES IN AN OPEN  WATER LOOP MOBE, AND SPENT ABSORBENT
IS DISPOSED  IN  AN  ON-SITE LINED POND.
 ARIZONA  ELECTRIC POWER COOP
 APACHE
 2
 1EW        195.0  RW  (GROSS)
            98.Cl  MW  (ESC)
 COAL
   .55 XS   BITUMINOUS
 LIMESTONE
 USEARCH-COTTRELL
 ENERGY CONSUMPTION:   4.1X
 STATUS 1      STARTUP   8/78
APACHE 2 OF  ARIZONA  ELECTRIC POWER COOP  IS  LOCATED  IN COCHISE, ARIZONA AND
IS A DRY POTTOM  PULVERIZED COAL  FIRED  UNIT  WITH  A  FLUE GAS FLOW OF 735,000
ACFM. BITUMINOUS  COAL WITH A HEATING VALUE  OF  10,000 BTU/LB, A SULFUR CON-
TENT OF 0.55X  AND AN ASH CONTENT OF 15*  IS  THE  FUEL USED FOR THIS UNIT.
PHRTICULATE  CONTROL  IS EFFECTED  BY A HOT  SIDE  ESP.   HALF THE FLUE GAS
PASSES THROUGH TWO PACKED TOWERS EMPLOYING  LIMESTONE ABSORBENT AND
HAVING A DESIGN  S02  REMOVAL OF 85X WERE  SUPPLIED BY RESEARCH-COTTRELL.
MIST ELIMINATION  IS  PROVIDED BY  CHEVRON  TYPE  ELIMINATORS. NO REHEAT IS
EMPLOYED. A  400  FT COLE BRAND CXL2000  LINED  STACK  IS IN USE. THE SYSTEM
OPERATES IN  AN OPEN  WATER LOOP MODE AND  WASTE  MATERIAL IS DISPOSED OF IN
OFF-SITE SLUDGE  PONDS. OPERATIONS COMMENCED  IN AUGUST 1978.
ARIZONA ELECTRIC  POWER  COOP
APACHE
I
NEW        195.0 MW  (GROSS)
           98.0 MW  (ESC)
COAL
  .55 tS   BITUMINOUS
LI1ESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  4.1*
STATUS 1      STARTUP   6/79
APACHE 3 OF  ARIZONA  ELECTRIC POWER COOP IS A  DRY  BOTTOM,  PULVERIZED COAL
FIRED UNIT  IN  COCHISE, ARIZONA. LOW CC.55X) SULFUR  BITUMINOUS COAL WITH AN
AVERAGE HEATING  VALUE OF 10,000 BTU/LB PRODUCES A MAXIMUM FLUE GAS FLOW OF
735,000 ACFM.  HALF  OF THE FLUE 6AS PAjSSES THROUGH A HOT  SIDE ESP TO TWO
RESEARCH COTTRELL  PACKED TOWERS, WHERE LIMESTONE  IS USED  TO REMOVE 85* OF
THE S02. THE  GAS EXITS A HORIZONTAL CHEVRON MIST  ELIMINATOR INTO ITS OWN
CEILCOTE LINED FLUE  IN THE 400 FOOT STACK IT  SHARES WITH  UNIT 2. THE FGD.
WHICH HAS BEEN OPERATIONAL SINCE JUNE OF 1979, USES NO REHEAT. THE SYSTEM
OPERATES IN  AN OPEN  WATER LOOP AND SLUDGE IS  DISPOSED OF  IN TWO OFF SITE
LINED PONDS  WITH 20  YEARS' EXPECTED LIFESPAN. TWO ADDITIONAL PONDS ARE
PLANNED, WHICH WOULD ADD ANOTHER 20 YEARS' CAPACITY.
ARIZONA PUBLIC  SERVICE
CHOLLA
1
RETROFIT  119.0  MW  (GROSS)
          119.0  MW  (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  3.4*
STATUS 1      STARTUP  10/73
ARIZONA PUBLIC  SERVICE'S CHOLLA 1 IS LOCATED  IN JOSEPH  CITY. ARIZONA AND
IS A TANGENTIALLV  FIRED, WET BOTTOM PULVERIZED COAL  UNIT.  IT IS FUELED BY
BITUMINOUS COAL  THAT  HAS A SULFUR CONTENT OF  0.5*  AND A HEATING VALUE OF
10,150 BTU/LB.  PARTICULATE MATTER IS CONTROLLED BY TWO  FLOODED DISC SCRUB-
BERS. THE FGD SYSTEM  BEGAN IN OCTOBER, 1973 AND IS NOW  OPERATIONAL. S02 Is
CONTROLLED BY ONE  TOWER  WITH MUNTERS PACKING  EMPLOYING  A LIMESTONE
ABSORBENT.  THE  UNIT  WAS SUPPLIED BY RESEARCH COTTRELL  AND HAS A DESIGN
REMOVAL OF 92*.  CHEVRON MIST ELIMINATORS ARE LOCATED PRIOR  TO AN IN-LINE
STEAM REHEAT SYSTEM.  THE TREATED FLUE GAS IS  VENTED  TO  A 256 FT ACID BRICK
LINED STACK.  THE  FGD SYSTEM OPERATES IN AN OPEN WATER  LOOP  MODE AND THE
UNTREATED WASTE  IS  DISPOSED OF IN AN ON-SITE  UNLINED POND.
ARIZONA PUBLIC  SERVICE
CHOLLA
2
NEW        264.0 MW  (GROSS)
           264.0 MW  (ESC)
COAL
  .51? XS   BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION: **««X
STATUS 1      STARTUP  4/78
CHOLLA 2 OF ARIZONA  PUBLIC  SERVICE IS LOCATED IN JOSEPH  CITY,  ARIZONA. THE
BOILER BURNS PULVERIZED  BITUMINOUS COAL (0.5* S, 10,150  BTU/LB).  MECHANI-
CAL COLLECTORS PROVIDE PRIMARY PARTICULATE CONTROL.   FOUR  PARALLEL
FLOODED DISC AND PACKED  TOWER S02 ABSORBER TRAINS  (THREE ARE  REQUIRED FOR
FULL LOAD) REMOVE THE FLUE  GAS S02.   THE DESIGN S02  REMOVAL  fOR  THE
SYSTEM, WHICH BEGAN  OPERATIONS IN APRIL, 1978, IS  751.   THE CLEANED  GAS
PASSES THROUGH AN IN-LINE  STEAM REHEfcTER INTO AN ACID BRICK LINED STACK.
THE OPEN WATER LOOP  SYSTEM  DEPOSITS ITS SLUDGE INTO A FLY  ASH  POND.

-------
                                               EPA UTILITY FGO SURVEY: JULY  -  SEPTEMBER  1980
                                              SECTION 2
                                        STATUS OF FGD SYSTEMS
JVIT IDENTIFICATION
                                                                  ABSTRACT
ARIZONA PUBLIC SERVICE
CrfOLLA
4
NEK       375.0 «W (GROSS)
          126.D »W (ESC)
C3AL
  ,5n XS
L11ESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  «***X
STATUS 2     STARTUP   6/81
                                CHOLLA  I.  OF  ARIZONA PUBLIC SERVICE IS PRESENTLY  UNDER CONSTRUCTION IN
                                JOSEPH  CITY, ARIZONA. THE PULVERIZED COAL  (0.5X  S,  10,ISO BTU/LB) FIRED
                                BOILER  WILL  EXHAUST FLUE GAS THROUGH AN  ESP  TO A  DOUBLE  LOOP COMBINATION
                                TOWER  (RESEARCH-COTTRELL DESIGN) WHICH WILL  TREAT 36X OF THE GAS WITH
                                LIMESTONE.  THE SYSTEM IS SCHEDULED TO START  UP IN JUNE 1981.
ARIZONA PUBLIC SERVICE
FOUR CORNERS
1
RETROFIT  175.C1 "y  (GROSS)
          175.0 NW  (ESC)
C3AL
  .75 XS  SUBBITUMINOUS
LINE/ALKALINE FLTASH
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: »***X
STATUS 1     STARTUP  11/79
                                ARIZONA  PUBLIC SERVICE HAS UPGRADED THE  OPERATIONAL PARTICULATE SCRUBBERS
                                AT  FOUR  CORNERS 1, 2, AND 3 IN  FARMINGTON,  NEW MEXICO TO HANDLE ADDITIONAL
                                302 REMOVAL. INITIALLY, THE FRONT  FIRED,  DRY  BOTTOM, PULVERIZED COAL  (SUB-
                                BITUMINOUS,  0.75X S, 9650 BTU/LB)  UNITS  1  AND 2 SUPPLY 814,000 ACFM EACH
                                INTO  2 CHENICO VENTURI SCRUBBERS PER  UNIT  FOR PRIMARY PARTICULATE CONTROL
                                AND APPROXIMATELY 30X S02 REMOVAL  USING  ALKALINE FLY ASH. THE DESIGN  S02
                                REMOVAL  EFFICIENCY SINCE THE  CONVERSION  TO LIME AND ALKALINE FLY ASH
                                SCRUBBING IS 67.SX. OPERATIONS  COMMENCED  IN NOVEMBER, 1979.
ARIZONA PUBLIC SERVICE
F3UR CORNERS
2
RETROFIT  175.0 WW  (GROSS)
          175.0 NW  (ESC)
COAL
  .75 XS  SUBBITUMINOUS
LIIE/ALKALINE FLTASH
CHEMICO DIVISION,  ENVIROTECH
ENERGY CONSUMPTION:  ***«X
STATUS 1     STARTUP  11/79
                                ARIZONA PUBLIC SERVICE HAS UPGRADED  THE  OPERATIONAL PARTICULATE SCRUBBERS
                                AT FOUR CORNERS 1,2, AND 3 IN  FARMINGTON,  NEW MEXICO TO HANDLE ADDITIONAL
                                502  REMOVAL. INITIALLY, THE  FRONT  FIRED. DRY BOTTOM, PULVERIZED COAL  (SUB-
                                BITUMINOUS, 0.75X S, 6650 BTU/LB)  UNITS  1  AND 2 SUPPLY 814,000 ACFM EACH
                                INTO 2 CHEMICO VENTURI SCRUBBERS PER UNIT  FOR PRIMARY PARTICULATE CONTROL
                                AND  APPROXIMATELY 30X S02 REMOVAL  USING  ALKALINE FLY ASH. THE DESIGN  S02
                                REMOVAL EFFICIENCY SINCE THE  CONVERSION  TO LIME AND ALKALINE FLY  ASH
                                SCRUBBING IS 67.SX. OPERATIONS COMMENCED IN NOVEMBER, 1979.
ARIZONA PUBLIC  SERVICE
F3UR CORNERS
3
RETROFIT  229.0  My  (GROSS)
          229.0  WU  (ESC)
C3AL
  .75 XS  SUflBITUMINOUS
LUE/ALKALINE  FLYASH
CHEMICO DIVISION,  F.NVIROTECH
ENERGY CONSUMPTION: ***«X
STATUS 1     STARTUP  11/79
                                ARIZONA PUBLIC SERVICE HAS  UPGRADED  THE OPERATIONAL PARTICULATE  SCRUBBERS
                                AT FOUR CORNERS 1,2, AND  3  IN  FARMINGTON, NEW MEXICO TO HANDLE ADDITIONAL
                                SC2 REMOVAL. INITIALLY,  THE FRONT FIRED, DRY BOTTOM, PULVERIZED  COAL  (SUB-
                                BITUMINOUS, 0.75X S, 8650 BTU/LB) UNIT 3 SUPPLIES 1,030,000 ACFM  INTO 2
                                CHEMICO VENTURI SCRUBBERS FOR  PRIMARY PARTICULATE CONTROL AND APPROXIMATE-
                                LY 5 OX SO? REMOVAL USING  ALKALINE FLY ASH. THE DESIGN S02 REMOVAL EFFICI-
                                ENCY SINCE THE CONVERSION TO LIME AND ALKALINE FLY ASH SCRUBBING  IS  67.5X.
                                OPERATIONS COMMENCED IN  NOVEMBER. 1979.
ARIZONA PUBLIC  SERVICE
F3UR CORNERS
4
RETROFIT  755.0  iy  (GROSS)
          755.0  MH  (ESC)
COAL
   .75 XS
LME
JMITED ENGINEERS
E1ERGY CONSUMPTION: •*«*X
                                ARIZONA PUBLIC SERVICE  AWARDED  A  CON.TRACT TO UNITED ENGINEERS  FOR  A  LIME
                                FGD SYSTEM TO BE RETROFITTED  ONTO UNITS 4 AND 5 AT ITS FOUR  CORNERS  STA-
                                TION IN FARMINGTON,  NEW  MEXICO. BASED ON THE PROTOTYPE HORIZONTAL  SCRUB-
                                BING PROGRAM CONDUCTED  BY  THE UTILITY, A HORIZONTAL SYSTEM WAS  CHOSEN  TO
                                CONTROL THE EMISSIONS FROM THESE  COAL (0.75X S, 8650 BTU/LB) FIRED UNITS.
                                THE PARTICULATE  EMISSIONS  ARE HANDLED* BY AN ESP. START UP  IS EXPECTED  IN
                                1982.
STATUS 3
              STARTUP   0/82
ARIZONA PUBLIC  SERVICE
F3UR CORNERS
5
RETROFIT   755.0 NW  (GROSS)
           755.0 «W  (ESC)
C3AL
   .75 XS
LIKE
JUITED  ENGINEERS
EVERGY  CONSUMPTION: ***«X
STATUS  3      STARTUP  0/82
                                ARIZONA PUBLIC SERVICE  AWARDED A CONTRACT TO UNITED ENGINEERS  FOR  A  LIME
                                FGD SYSTEM TO BE  RETROFITTED  ONTO UNITS 4 AND S AT ITS FOUR  CORNERS  STA-
                                TION IN FARMINGTON,  MEW MEXICO. BASED ON THE PROTOTYPE HORIZONTAL  SCRUB-
                                BING PROGRAM CONDUCTED  BY  THE UTILITl, A HORIZONTAL SYSTEM  WAS CHOSEN TO
                                CONTROL THE EMISSIONS  FROM THESE COAL (0.75X S, 8650  BTU/LB) FIRED UNITS.
                                THE PARTICULATE  EMISSIONS  ARE HANDLED BY AN ESP. START UP  IS EXPECTED IN
                                1982.

-------
  EPA UTILITY FED SURVEY: JULY -  SEPTEMBER  1980
                                               SECTION 2
                                         STATUS  Of  FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 ASSOCIATED ELECTRIC COOP
 THOMAS HILL
 }
 1EW       737.0 flU {GROSS)
           670.0 MW (ESC)
 COAL
  4.80 XS
 LIMESTONE
 PULLMAN KELLOGG
 ENERGY CONSUMPTION: *••**
 STATUS 2     STARTUP  1/82
 THOMAS  HILL  3 OF ASSOCIATED ELECTRIC COOP  IS  A  PULVERIZED  COAL  (4.8X S,
 9,700 BTU/LB) FIRED UNIT UNDER CONSTRUCTION IN  MOBERLY,  MISSOURI.  TUO COLD
 SIDE  ESP'S  WILL PRECEDE THE FOUR 91.SX EFFICIENT  PULLMAN KELL06G  HORIZONTA
 WEIR  FGD  MODULES USING MAGNESIUM-PROMOTED  LIMESTONE  AS THE  ABSORBENT. THE
 CLEANED GAS  HILL PASS THROUGH A VERTICAL CHEVRON  MIST ELIMINATOR  TO  A 620
 FOOT  BRICK  LINED STACK. REHEAT WILL BE ACCOMPLISHED  BY BYPASS.  DRY FIXATED
 SLUDGE  WILL  BE TRUCKED TO AN ACTIVE STRIP  MINE. THE  SYSTEM  WILL USE  A
 CLOSED  HATER LOOP. THE FGD SYSTEM IS UNDER CONSTRUCTION  AND  START  UP IS
 EXPECTED  IN  JANUARY 1982.
 ATLANTIC  CITY ELECTRIC
 CUMBERLAND
 1
 NEW        330.0 MW (GROSS)
           330.0 MW (ESC)
 COAL
 3.25  XS   BITUMINOUS
 PROCESS NOT  SELECTED
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTION: ****!
 STATUS  6      STARTUP   1/88
 CUMBERLAND  1  IS A PULVERIZED COAL (7.25XS) FIRED BOILER  TO  BE  LOCATED IN
 MILLVILLE,  NEW JERSEY.  THE UTILITY IS CONSIDERING  AN  FGD SYSTEM  WITH A
 THROWAHAY PRODUCT FOR S02 CONTROL.  OPERATIONS ARE  SCHEDULED TO BEGIN IN
 JANUARY  1988.
3ASIN  ELECTRIC  POWER  COOP
ANTELOPE  VALLEY
1
«EW        440.0 MU  (GROSS)
           440.0 KW  (ESC)
COAL
  .68  XS   LIGNITE
L11E/SPRAY  DRYING
J3Y MFG/NIRO  ATOMIZER
ENERGY  CONSUMPTION:    .OX
STATUS  2      STARTUP   4/83
UNIT  1  OF.BASIN  ELECTRIC POWER COOP'S ANTELOPE VALLEY PLANT  IS PRESENTLY
UNDER  CONSTRUCTION IN BEULAH, NORTH DAKOTA. THIS UNIT WILL BURN  PULVERIZED
COAL  (0.6SX  S,  6600 BTU/LB LIGNITE) AND SUPPLY 2.055,000 ACFM TO  *  DRY
LIME  FGD  SYSTEM  SUPPLIED BY WESTERN PRECIPITATION. THE 62X EFFICIENT
SYSTEM  WILL  CONSIST OF S NIRO ATOXZZER SPRAY DRYERS AND TWO  BAGHOUSES.
THE CLEANED  GAS,  ALONG WITH A 4X BYPASS REHEAT, WILL EXIT A  600  FOOT
PVC LINED STACK.  THE SYSTEM WILL USE A CLOSED WATER LOOP AND THE  DRV
POWDER  WILL  BE  USED FOR LANDFILL IN A COAL MINE. START UP IS EXPECTED
IN APRIL  1983.
BASIN ELECTRIC  POWER  COOP
ANTELOPE VALLEY
2
1EU       440.0 MU  (GROSS)
          440.0 MW  (ESC)
COAL
  .68 XS  LIGNITE
LUE/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION:    .OX
STATUS 5     STARTUP  13/85
ANTELOPE  VALLEY  2  OF  BASIN ELECTRIC POWER COOP HILL BE LOCATED IN BEULAH,
NORTH DAKOTA.  THE  UTILITY IS  PRESENTLY CONSIDERING VARIOUS FGD PROCESSES
FOR THIS  LIGNITE  (0.68X  S, 6600 BTU/LB) FIRED UNIT. THE UNIT WILL BE
REQUIRED  TO  COMPLY WITH  STATE EMISSIONS STANDARDS VIA BEST AVAILABLE
CONTROL TECHNOLOGY.  START UP  IS SCHEDULED FOR OCTOBER 1985.
JASIN ELECTRIC  POWER  COOP
LARAMIE RIVER
1
MEW       57".0 MW  (GROSS)
          570.0 MW  (ESC)
COAL
  .81 XS  SUBBITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:    .OX
STATUS 1     STARTUP   7/80
BASIN ELECTRIC  POWER  COOP'S  LARAMIE  RIVER 1 IS A PULVERIZED COAL
(0.8X S, 8139 BTU/LB)  FIRED  UNIT LOCATED IN WHEATLAND, WYOMING.
THE BOILER  FEEDS  2,300,000 ACFN  OF  FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH  COTTRELL  LIMESTONE PACKED TOWER MODULES, WHICH
REMOVE 90X  OF THE  S02.  THE CLEANED  GAjS EXITS FROM A VERTICAL CHEVRON
DEMISTER INTO A 600  FOOT  ACID  BRICK  LINED STACK. NO REHEAT IS USED.
THE FLYASH  FIXATED SLUDGE  IS  DEWATERfcD TO 83X SOLIDS BEFORE BEING
LANDFILLED, AND THE  SYSTEM EMPLOYS  A CLOSED WATER LOOP. OPERATIONS
BEGAN ON JULY 1,  1980.
3ASIN ELECTRIC POWER  COOP
LARAMIE RIVER
2
*EW       570.0 MW  (GROSS)
          570.0 MU  (ESC)
C3AL
  .61 XS  SUBBITUMINOUS
LIMESTONE
»ESEARCH-COTTRELL
ENERGY CONSUMPTION:    .OX
STATUS 2     STARTUP   6/81
BASIN ELECTRIC POWER  COOP'S  LARAMIE  RIVER 2 IS PRESENTLY UNDER CONSTRUC-
TION IN WHEATLAND. WYOMING.  THE  PULVERIZED COAL (0.81X S. 8139 BTU/LB)
FIRED BOILER WILL  FEED  2,300,000 ACFH OF FLUE GAS THROUGH A COLD SIDE
ESP TO FIVE RESEARCH  COTTRELL  LIMESTONE  PACKED TOWER MODULES, WHICH WILL
REMOVE 90X OF THE  S02.  THE CLEANED GAS WILL EXIT FROM A VERTICAL CHEVRON
DENISTER INTO A 600 FOOT ACID  BRICK  LINED STACK. NO REHEAT WILL BE USED.
THE FLYASH FIXATED SLUDGE WILL BE DEWATERED TO 83X SOLIDS BEFORE BEING
LANDFILLED, AND THE SYSTEM WILL  EMPLOY A CLOSED WATER LOOP. START UP IS
SCHEDULED FOR JUNE 1981.
                                                 10

-------
                                               EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS OF  FGD SYSTEMS
JNIT IDENTIFICATION
                                                                  ABSTRACT
3ASIN ELECTRIC POWER COOP
LARAMIE RIVER
5
MEW       570.0 MW (GROSS)
          57P.O MW (ESC)
CDAL
  .54 XS  SUB8ITUMINOUS
LIME/SPRAY DRYING
3ABCOCK ! WILCOX
ENERGY CONSUMPTION:    .31
STATUS 2     STARTUP   4/82
LARAMIE RIVER 3 OF BASIN ELECTRIC  POWER  COOP  IS  UNDER CONSTRUCTION IN
WHEATLAND, WYOMING, AND WILL UTILIZE  FOUR  DRY LIME  INJECTION MODULES.
AND A COLD SIDE ESP. THE BOILER  WILL  FIRE  PULVERIZED COAL (0.5*1 S,
8100 BTU/LB) AND WILL SUPPLY 2,800,000 ACFM OF FLUE GAS TO THE FGD
SYSTEM, WHICH WILL REMOVE 85X OF THE  SO? BEFORE  THE GAS EXITS THROUGH
A 600 FOOT ACID BRICK LINED STACK.  A  3X  BYPASS WILL BE USED FOR REHEAT.
THE SYSTEM WILL OPERATE IN A CLOSED WATER  LOOP.  AND WILL LANDFILL THE
DRY POWDER WASTE. OPERATIONS ARE SCHEDULED TO COMMENCED IN APRIL
1982.
316 RIVERS ELECTRIC
D.B. WILSON
1
NEW       44?.0 MW  (GROSS)
          440.0 MW  (ESC)
COAL
***** XS  BITUMINOUS
LIMESTONE
PULLMAN KELLOG
ENERGY CONSUMPTION: ****X
STATUS 3     STARTUP   7/84
BIG RIVERS ELECTRIC  HAS  PLANS  FOR  TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED COAL  FIRED  BOILERS  WILL HAVE  A  MW RATING OF 440 EACH.
PULLMAN KELL06 HAS BEEN  AWARDED  A  CONTRACT FOR A WET LIMESTONE FGD
SYSTEM.  STARTUP IS  SCHEDULED  FOR  JULY 1984.
31G RIVERS ELECTRIC
D.B. tflLSON
2
NEW       44C.O MW  (GROSS)
          440.0 MW  (ESC)
COAL
***** XS  BITUMINOUS
LIMESTONE
PULLMAN KELLOG
ENERGY CONSUMPTION: ****X
STATUS 3     STARTUP   1/86
BIG RIVERS ELECTRIC  HAS  PLANS  FOR TWO NEW UNITS, D.B. WILSON 1 AND 2.
THE PULVERIZED  COAL  FIRED  BOILERS WILL HAVE A HW RATING OF 440 EACH.
PULLMAN KELLOG  HAS BEEN  AWARDED A CONTRACT FOR A WET LIMESTONE FGD
SYSTEM.  STARTUP  IS  SCHEDULED  FOR JANUARY 1986.
JIG RIVERS ELECTRIC
SSEEN
1
NEW       242.0 MW  (GROSS)
          242.0 MW  (ESC)
C3AL
 3.75 XS  BITUMINOUS
LIME
AMERICAN AIR  FILTER
ENERGY CONSUMPTION:  ****X
STATUS 1      STARTUP  12/79
UNIT 1 OF BIG  RIVERS  ELECTRIC'S GREEN STATION IS LOCATED IN
SEBREE,KENTUCKY.  THE  DRY  BOTTOM PULVERIZED COAL (3.75X S. 9750  BTU/LB)
FIRED BOILER SUPPLIES  1,000,000 ACFM TO A COLD SIDE ESP FOLLOWED  BY
TWO AMERICAN AIR  FILTER  LIME  SPRAY TOWERS WHICH WILL REMOVE 90Z OF THE
S02. THE  CLEANED  GAS  PASSES THROUGH A CHEVRON MIST ELIMINATOR AND
EXITS A  SAUERtSEN 72  LINED STACK AfTER IT IS HEATED BY STEAM COIL
REHEATER. THE  SLUDGE  FROM THE CLOSED WATER LOOP SYSTEM IS POZ-0-TEC
STABILIZED. OPERATIONS COMMENCED IN DECEMBER 1979.
316 RIVERS  ELECTRIC
SHEEN
2
NEW       242.0 MW  (GROSS)
          242.0 MW  (ESC)
CDAL
 S.75 XS  BITUMINOUS
LIME
AMERICAN AIR  FILTER
ENERGY  CONSUMPTION:  *«**X
STATUS  2      STARTUP  11/80
UNIT  2  OF  BIG  RIVERS ELECTRIC'S GREEN STATION IS BEING  CONSTRUCTED  IN
SEBREE,  KENTUCKY.  THE DRV BOTTOM PULVERIZED COAL (3.75X  S,  9750 BTU/LB)
FIRED BOILER  WILL  SUPPLY 1,000.000 ACFM TO A COLD SIDE  ESP  FOLLOWED BY
TWO AMERICAN  AIR  FILTER LIME SPRAY TOWERS WHICH WILL REMOVE  90S OF  THE
S02.  THE  CLEANED  GAS WILL PASS THROUGH A CHEVRON MIST ELIMINATOR AND
WILL  EXIT  A  SAUERISEN 72 LINED STACK AFTER IT IS HEATED  BY  STEAM COIL
REHEATER.  THE  SLUDGE FROM THE CLOSED WATER LOOP SYSTEM  WILL  BE  POZ-0-TEC
STABILIZED.  START  UP IS SCHEDULED FOR NOVEMBER 1980.
CAJUN  ELECTRIC  POWER  COOP
316  CAJUN  III
1
NEW        540.0 MW  (GROSS)
           540.C1 MW  (ESC)
COAL
*****  XS   LIGNITE
IUOCESS  NOT  SELECTED
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION: ****X
STATUS  6      STARTUP   0/85
 CAJUN  ELECTRIC HAS PLANS TO CONSTRUCT A  540 MW UNIT,  BIG  CAJUN  3.  TO BE
 LOCATED  IN  DE SOLO PARISH, LOUISIANA.  THE UTILITY  IS PRESENTLY CONSIDER-
 ING  A  DRY SCRUBBING PROCESS TO CONTROL EMISSIONS  FROM THE  PULVERIZED
 COAL  FIRED  BOILER.  THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN 1985.
                                                  11

-------
  EPA UTILITY  F60  SURVEY:  JULY  - SEPTEMBER 198C
                                               SECTION 2
                                         STATUS Of FGO SYSTEMS
 JNIT IDENTIFICATION
                                                                   ABSTRACT
 CENTRAL ILLINOIS LIGHT
 BJCK. CREEK
 1
 NEW       (16.0 MW (GROSS)
           416.T MW 
-------
                                               EPA  UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS OF  FGO SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
CINCINNATI GAS t ELECTRIC
EAST SEND
1
MEU       650.0 My (GROSS)
          650.0 MU (ESC)
COAL
••*** IS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  2.9X
STATUS 6     STARTUP 10/87
CINCINNATI GAS AND ELECTRIC HAS  PLANS  FOR  A  NEW  UNIT,  EAST BEND 1, TO
BE LOCATED ADJACENT TO EAST BENT  2 AT  THE  RABBITHASH,  KENTUCKY SITE.  THE
COAL FIRED BOILER VILL HAVE A GENERATING CAPACITY  OF  650 My.  THE UNIT IS
SCHEDULED TO STARTUP IN OCTOBER  1987.
CINCINNATI GAS & ELECTRIC
EAST BEND
2
MEM       650.0 MW (GROSS)
          650.0 My (ESC)
CDAL
 5.00 IS
LIME
9ABCOCK K UILCOX
ENERGY CONSUMPTION:   2.9X
STATUS i     STARTUP  12/80
EAST BEND 2 OF CINCINNATI  GAS  AND  ELECTRIC  IS  A PULVERIZED COAL (51 S)
FIRED BOILER UNDER CONSTRUCTION  IN RABBITHASH, KENTUCKY. THE EMISSION
CONTROL SYSTEM CONSISTS  OF A  HOT SIDE  ESP FOLLOWED BY THREE BABCOCK AND
UILCOX LIME FGD MODULES.  THE  87Z CLEANED  GAS WILL PASS THROUGH A CHEVRON
MIST ELIMINATOR BEFORE BEING  WARMED BY AN INDIRECT HOT AIR REHEATER AND
EXITING THROUGH A BRICK  LINED  65C  FOOT STACK.  THE SLUDGE FROM THIS CLOSED
y*TER LOOP SYSTEM WILL BE  P02-0-TEC STABILIZED BEFORE DISPOSAL IN Ah ON
SITE LANDFILL. START  UP  IS EXPECTED IN DECEMBER 1980.
COLORADO UTE ELECTRIC  ASSN
CRAIG
1
HEW       4*7.0 My  (GROSS)
          447.0 MU  (ESC)
COAL
  .45 IS  SU9BITUMINOUS
LIMESTONE
PEABOOY PROCESS SYSTEMS
ENERGY CONSUMPTION:   5.4X
STATUS 2     STARTUP  10/80
THE COLORADO UTE  ELECTRIC  ASSN IS PRESENTLY CONSTRUCTING CRAIG 1  IN  CRAIG,
COLORADO. BOTH UNITS  WILL  FIRE PULVERIZED SUBBITUMINOUS COAL  (0.45X  S,
10,000 BTU/LB).  THE  EMISSION  CONTROL SYSTEM FOR THIS UNIT yILL CONSIST OF
A HOT SIDE ESP AND FOUR  MAGNESIUM PROMOTED LIMESTONE SPRAY TOWERS  FOR
REMOVAL OF PARTICULATE MATTER AND 85X OF THE S02. THE SCRUBBER EXHAUST
WILL Bt HEATED BY AN  IN-LINE  STEAM COIL REHEATER AND WILL PASS THROUGH A
600 FOOT ACID LINED  STACK. THE SYSTEM WILL OPERATE IN A CLOSED WATER LOOP
AND THE STABILIZED SLUDGE  WILL BE DISPOSED OF IN AN OFF SITE  M1NEFUL.
UNIT 1 START UP  IS EXPECTED IN OCTOB6R 1980.
COLORADO UTE  ELECTRIC  ASSN
CRAIG
2
VI*       45S.O  My  (GROSS)
          400.0  My  (ESC)
COAL
   .45  XS  SUBBITUMINOUS
LIMESTONE
PEABODY PROCESS  SYSTEMS
ENERGY  CONSUMPTION:  1.5X
STATUS  1      STARTUP  12/79
THE CRAIG  2  UNIT  OF  THE  COLORADO UTE ELECTRIC ASSN IS LOCATED  IN  CRAIG,
COLORADO  AND FIRES  PULVERIZED SUBBITUMINOUS COAL  (0.45XS,  10,000  PTU/LB).
THE EMISSION CONTROL SYSTEM FOR THIS UNIT CONSISTS OF A HOT  SIDE  ESP  AND
FOUR MAGNESIUM  PROMOTED  LIMESTONE SPRAY TOWERS FOR REMOVAL OF  PARTICULATE
MATTER  AND 85X  OF THE S02. THE SCRUBBER EXHAUST IS HEATED  BY AN  IN-LINE
STEAM COIL REHEATER  AND  PASSES THROUGH A 6CO FOOT ACID BRICK LINED  STACK.
THE SYSTEM OPERATES  IN A CLOSED LOOP, AND THE STABILIZED  SLUDGE  IS  DIS-
POSED OF  IN  AN  OFF  SITE  MINEFILL. START UP OF UNIT 2 WAS  IN  DECEMBER  1979.
COLORADO  UTE  ELECTRIC  ASSN
CRAIG
S
«E»        447.0  MW  (GROSS)
           447.0  MW  (ESC)
COAL
   .45  XS   SUBBITUMINOUS
LIME/SPRAY  DRYING
3ABCOCK  t WILCOX
ENERGY CONSUMPTION: ****X
STATUS 3      STARTUP  0/82
 COLORADO  UTE  ELECTRIC ASSN. HAS PLANS FOR A NEW UNIT,  CRAIG  3,  TO BE
 LOCATED  IN  CRAIG,  COLORADO ALONG WITH UNITS 1 AND  2.   THE  UNIT  WILL FIRE
 PULVERIZED  SUBBITUMINOUS COAL (0.45X S,  1C,000 BTU/LB).  A CONTRACT HAS
 BEEN  AyARDED  TO  BABCOCK AND WILCOX FOR A DRY SCRUBBING SYSTEM UTILIZING
 LIME  INJECTION.   THE UNIT WILL HAVE A FABRIC FILTER  FOR  PARTICLE  CONTROL.
 THE UNIT  IS SCHEDULED TO COMMENCE OPERATIONS IN 1982.
COLUMBUS  I  SOUTHERN OHIO ELEC
CDNESVILLE
5
1EW       411.0  MW  (GROSS)
          411.0  MW  (ESC)
COAL
 4.67  XS  BITUMINOUS
LIME
AIR  CORRECTION  DIVISION, UOP
ENERGY  CONSUMPTION:  3.9X
STATUS  1      STARTUP  1/77
 CONESVILLE  5  OF  COLUMBUS AND SOUTHERN OHIO ELECTRIC  IS  A  DRY  BOTTOM,
 PULVERIZED  BITUMINOUS COAL (4.67X S, 10,850 BTU/LB)  FIRED UNIT LOCATED
 IN  CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES  1,393,893 ACFM  OF FLUE
 GAS  AND  PASSES IT TO TWO THIOSORBIC LIME TCA MODULES  SUPPLIED BY UOP.
 THE  S02  REMOVAL  EFFICIENCY OF THE TWO MODULES, WHICH  BEGAN INITIAL
 OPERATION  IN  JANUARY 1977, IS 89.51 (DESIGN).  EACH MODULE HAS ONE
 BULK  ENTRAINMENT SEPARATOR AND TWO CHEVRON MIST  ELIMINATORS.  THE
 CLEANED  GAS EXITS THROUGH AN 800 FOOT TALL ACID  BRICK LINED  STACK.
 THE  POZ-0-TEC STABILIZED SLUDGE IS PUMPED INTO AN ON  SITE DIKED LAND-
 FILL.  THE  SYSTEM OPERATES IN AN OPEN WATER LOOP.
                                                  13

-------
  EPA JTILITT  FGD SURVEY:  JULY  -  SEPTEMBER  1980
                                               SECTION 2
                                         STATUS Of fGO SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 COLUM9US I SOUTHERN OHIO ELEC
 CONESYILLE
 &
 MEW       411.0 MW (GROSS)
           411.0 MW (ESC)
 COAL
  4.67 XS  BITUMINOUS
 LIME
 MR CORRECTION DIVISION, UOP
 ENERGY CONSUMPTION:  3.9X
 STATUS 1     STARTUP  6/78
                                CONESVILLE 6 OF COLUMBUS AND SOUTHERN OHIO ELECTRIC  IS  A  DRY BOTTOM,
                                PULVERIZED BITUMINOUS COAL (4.67X S, 10,850 BTU/LB)  FIRED  UNIT  LOCATED
                                IN  CONESVILLE, OHIO. A COLD SIDE ESP RECEIVES  1.393.893 ACFM OF  FLUE
                                GAS  AND  PASSES IT TO TyO THIOSORBIC LIME TCA MODULES  SUPPLIED BY  UOP.
                                THE  S02  REMOVAL EFFICIENCY OF THE TWO MODULES, WHICH  BEGAN INITIAL
                                OPERATION  IN JUNE 1978, IS 89.5X (DESIGN). EACH MODULE  HAS ONE
                                BULK  ENTRAPMENT SEPARATOR AND TWO CHEVRON MIST ELIMINATORS. THE
                                CLEANED  GAS  EXITS THROUGH AN 800 FOOT TALL ACID BRICK LINED  STACK.
                                THE  POI-0-TEC  STABILIZED SLUDGE IS PUMPED INTO AN ON  SITE  DIKED LAND-
                                FILL.  THE  SYSTEM OPERATES IN AN OPEN WATER LOOP.
 COLUMBUS
 POSTON
 5
 NEW
         I SOUTHERN OHIO ELEC
          425.0 MW (GROSS)
          375.0 MW (ESC)
COAL
••*** xs
PROCESS NOT SELECTFD
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  4.7X
COLUMBUS AND SOUTHERN OHIO ELECTRIC  HAS  PLANS  FOR  TWO NEW UNITS. POSTON S
AND 6, TO BE LOCATED IN ATHENS.  OHIO.  THE  COAL (2.5X S. 11,000 BTU/LB)
FIRED UNITS WILL UTILIZE  EITHER  A  LIME,  LIMESTONE. OR DUAL ALKALI FGD
SYSTEM. START UP OF UNIT  5 IS EXPECTED IN  1986.
 STATUS 6
              STARTUP  8/86
 COLUM3US  t  SOUTHERN OHIO ELEC
 POSTON
 &
 NEH        425.0 MW (GROSS)
           375.0 MW (ESC)
 COAL
 2.5P XS
 PROCESS NOT  SELECTED
 VENDOR  NOT  SELECTED
 ENERGY  CONSUMPTION:  4.7X
 STATUS  6      STARTUP  0/89
                               COLUMBUS  AND  SOUTHERN OHIO ELECTRIC HAS PLANS FOR TWO NEW UNITS,  POSTON  5
                               AND 6,  TO BE  LOCATED  III ATHENS, OHIO. THE COAL (2.5X S. 11,000 BTU/LB)
                               FIRED UNITS  WILL  UTILIZE EITHER A LIME, LIMESTONE, OR DUAL ALKALI  FGD
                               SYSTEM. START  UP  OF  UNIT 6 IS EXPECTED IN 1989.
 COMMONWEALTH  EDISON
 P3WEPTON
 51
 RETROFIT   450.0  MW  (GROSS)
           450.0  MW  (ESC)
 COAL
 J.53  XS
 LI1ESTONE
 AIR CORRECTION DIVISION,  UOP
 ENERGY  CONSUMPTION:  5.6*
 STATUS  1      STARTUP   4/80
                               COMMONWEALTH  EDISON  HAS  RETROFITTED BOILER NUMBER 51 AT ITS POWERTON
                               STATION KITH  A UOP LIMESTONE  FGD SYSTEM. UNIT 51 IS ONE OF TWO IDENTICAL
                               BOILERS SUPPLYING STEAM  TO  AN 850 MW TURBINE. THE PULVERIZED COAL
                               (7.53X S, 10,500 BTU/LB)  FIRED BOILER FEEDS FLUE 6AS THROUGH AN ESP
                               TO 3 TCA MODULES WHICH ARE  DESIGNED TO REMOVE 74X OF THE S02. A STEAM
                               INDIRECT HOT  AIR REHEATER BOOSTS THE TEMPERATURE BEFORE THE £AS EXITS
                               AN ACID BRICK LINED  STACK.  THE SYSTEM OPERATES IN A CLOSED WATER LOOP,
                               AND THE SLUDGE IS POZ-0-TEC STABILIZED AND DISPOSED OF IN A LANDFILL.
                               THE FGD SYSTEM COMMENCED  OPERATION IN APRIL,  1980.
COOPERATIVE  POWER  ASSOCIATION
C3AL  CREFK
1
NEW       545.0  MW  (GROSS)
          327.0  MW  (ESC)
COAL
  .67 XS  LIGNITE
LIME/ALKALINE  FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ***»X
STATUS 1     STARTUP  7/79
                               COAL CRFEK 1 AND 2 ARE TWO PULVERIZED  LIGNITE (9.63X S, 6258 BTU/LB) FIRED
                               UNITS OWNED BY THE COOPERATIVE  POWER  ASSN AND UNITED POWER. A COLD SIDE
                               ESP RECEIVES 2,200,000 ACFM  OF  FLUE GAS  AND EXHAUSTS IT TO FOUR COUNTER-
                               CURRENT SPRAY TOWERS. HIST ELIMINATION  IS PROVIDED BY A BULK ENTRAPMENT
                               SEPARATOR AND TWO CHEVRON MIST  ELIMINATORS. A MINIMUM OF 40X BYPASS REHEAT
                               IS PROVIDED BEFORE THE CLEANED  GAS EXITS  THE  650 FOOT ACID BRICK
                               LINED STACK. THE TOWER DESIGN S02 REMOVAL EFFICIENCY IS 90S. THE SYSTEM
                               OPERATES IN AN OPEN WATER LOOP,  AND THE  FLVASH STABILIZED SLUDCE IS
                               DISPOSED IN A CLAY LINED POND.   UNIT  1  OPERATIONS BEGAN IN JULY 1979.
COOPERATIVE POWER  ASSOCIATION
COAL CREEK
2
NEW       545.0 MW  (GROSS)
          327.0 MW  (ESC)
COAL
  .6? IS  LIGNITE
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: «**«X
STATUS 1     STARTUP  7/80
                               COAL CREEK 1 AND 2 ARE TWO PULVERIZED  LIGNITE  (0.63X  S,  6258 BTU/LB) FIRED
                               UNITS OWNED BY THE COOPERATIVE POWER ASSN  AND  UNITED  POWER.  A COLD SIDE
                               ESP RECEIVES ?,200,000 ACFM OF FLUE GAS  AND  EXHAUSTS  IT  TO FOUR COUNTER-
                               CURRENT SPRAY TOWERS. MIST ELIMINATION IS  PROVIDED  8V A  BULK ENTRAPMENT
                               SEPARATOR AND TWO CHEVRON MIST ELIMINATORS.  A  MINIMUM OF 40X BYPASS REHEAT
                               IS  PROVIDED BEFORE THE CLEANED GAS EXITS THE 650  FOOT ACID BRICK
                               LINED STACK. THE TOWER DESIGN S02 REMOVAL  EFFICIENCY  IS  90X. THE SYSTEM
                               OPERATES IN AN OPEN WATER LOOP, AND THE  FLVASH STABILIZED SLUDGE IS
                               DISPOSED OF IN A CLAY LINED POND. UNIT 2 COMMENCED  OPERATIONS IN JULY
                               1980.
                                                 14

-------
                                               EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980
                                              SECTION 2
                                        STATUS Of FGD SYSTEMS
J«IT IDENTIFICATION
                                                                  ABSTRACT
DELMARVA POWER & LIGHT
DELAWARE CITY
1
RETROFIT   60.0 MW  (GROSS)
           60.0 MW  (ESC)
COKE
 7.00 XS  FLUID PETROLEUM  COKE
4ELLHAN LORD
DAVY MCKEE
ENERGY CONSUMPTION: *«**X
STATUS 1     STARTUP  5/80
                               DELAWARE  CITY  1,  2,  AND  3  OF OELHARVA POWER AND LIGHT ARE THREE  RETRO-
                               FITTED COKE  (7-81 S)  FIRED BOILERS WHICH HAVE A STEAM CAPACITY OF  500*
                               LB/HR EACH.  THE  BOILERS GENERATE STEAM AS WELL AS ELECTRICITY FOR GETTY
                               REFINING  AND MARKETING.   EACH BOILER SUPPLIES 295,000 ACFM Of FLUE GAS  TO
                               A MECHANICAL COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR PARTICULATE
                               CONTROL.   THE  FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE HIST ELIMINATOR
                               TO A WET  ESP FOR  BOTH PARTICULATE AND ACID MIST REMOVAL.  A  FOUR  STAGE
                               MELLMAN-LORO SYSTEM,  WHICH IS DESIGN FOR 90X REMOVAL, IS  USED FOR  S02 CON-
                               TROL.  HOT  AIR  INJECTION REHEAT IS USED BEFORE THE GAS EXITS OUT  A 500  FT.
                               STACK.  THE  EMISSION  CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE.   IT IS A
                               CLOSED LOOP  WATER SYSTEM.   IT WAS MADE OPERATIONAL IN MAY 1980.
DELMARVA POUFB & LIGHT
DELAWARE CITY
2
RETROFIT   60.0 "W  (GROSS)
           60.0 MM  (ESC)
C3KE
 7.00 XS  FLUID PETROLEUM  COKE
BELLMAN LORD
DAVY HCKEE
ENERGY CONSUMPTION:  •«*«%
STATUS 1     STARTUP   5/80
                               DELAWARE  CITY  1,  2,  AND J OF CELFIARVA POWER AND LIGHT ARE  THREE  RETRO-
                               FITTED COKE  (7-8X S)  FIRED BOILERS WHICH HAVE A STEAM CAPACITY  Of  500K
                               LB/HR EACH.   THE  BOILERS GENERATE STEAM AS WELL AS ELECTRICITY  FOR GETTY
                               REFINING  AND  MARKETING.  EACH BOILER SUPPLIES 295,000 ACFM OF  FLUE GAS TO
                               A MECHANICAL  COLLECTOR THEN TO A VENTURI PARTICLE SCRUBBER FOR  PARTICULATE
                               CONTROL.   THE  FLUE GAS THEN PASSES THROUGH A CHEVRON TYPE  HIST  ELIMINATOR
                               TO A WET  FSP  FOR  BOTH PARTICULATE AND ACID MIST REMOVAL.   A FOUR STAGE
                               yELLMAN-LORD  SYSTEM,  WHICH IS DESIGN FOR 90X REMOVAL, IS USED  FOR  S02 CON-
                               TPOL.  HOT AIR INJECTION REHEAT IS USED BEFORE THE GAS  EXITS OUT A 500 FT.
                               STACK.   THE  EMISSION  CONTROL SYSTEM IS SUPPLIED BY DAVY MCKEE.   IT IS A
                               CLOSED LOOP  WATER SYSTEM.  IT WAS HADE OPERATIONAL IN HAY  1980.
DELMARVA POWER * LIGHT
DELAWARE CITY
}
RETROFIT   6C.O "W  (GROSS)
           60.0 MW  (ESC)
C OKE
 7.CO XS  FLUID PETROLEUM  COKE
riELLMAN LORD
DAVY NCKEE
ENERGY CONSUMPTION:  »«*«X
STATUS 1      STARTUP  5/80
                                DELAWARE  CITY  1,  2,  AND 3 OF DELMARVA POWER AND LIGHT  ARE  THREE RETRO-
                                FITTED  COKE  (7-8X S)  FIRED BOILERS WHICH HAVE  A STEAM  CAPACITY Of 500K
                                LB/HR EACH.   THE  BOILERS GENERATE STfcAH AS WELL AS  ELECTRICITY FOR GETTY
                                REFINING  AND  MARKETING.  EACH BOILER SUPPLIES  295,000  ACFM OF FLUE GAS TO
                                A  MECHANICAL  COLLECTOR THEN TO A VENTURI PARTICLE  SCRUBBER FOR PARTICULATE
                                CONTROL.   THE  FLUE GAS THEN PASSES THROUGH A CHEVRON  TYPE  MIST ELIMINATOR
                                TO  A WET  ESP  FOR  BOTH PARTICULATE AND ACID HIST REMOVAL.   A FOUR STAGE
                                WELLMAN-LORD  SYSTEM,  WHICH IS DESIGN FOR 90X REMOVAL,  IS  USED FOR S02 CON-
                                TROL.   HOT AIR INJECTION REHEAT IS USED BEFORE THE  GAS EXITS OUT A 503 FT.
                                STACK.   THE  EMISSION  CONTROL SYSTEM IS SUPPLIED BY  DAVY MCKEE.  IT IS A
                                CLOSED  LOOP  WATER SYSTEM.  IT WAS MADE OPERATIONAL  IN  MAY  1980.
DELMARVA POWER  ft  LIGHT
VIENNA
?
HEW        550.0 MW  (GROSS)
           550.0 MW  (ESC)
COAL
 2.70 XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6      STARTUP   6/87
                                DELMARVA  POWER AND LIGHT IS PLANNING A NEW  550  MW  (GROSS) UNIT, VIENNA 9,
                                BE  CONSTRUCTED IN VIENNA, MARYLAND.  THE  UTILITY  IS PRESENTLY CONSIDERING
                                A LIMESTONE  FGD UNIT FOR EMISSION CONTROL.   THE PULVERIZED COAL FIRED UNIT
                                WILL  BURN COAL WITH AN AVERAGE SULFUR CONTENT  OF  2.7X AND IS EXPECTED TO
                                COMMENCE  OPERATIONS IN JUNE 1987.
DESERET GEN ( TRANS COOP
NOON LAKE
1
NEW       410.0 MW (GROSS)
          410.0 MW (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 3     STARTUP  9/84
                                MOON LAKE 1 IS A PULVERIZED  COAL  (0.5X S, 10,500 BTU/LB)  FIRED  UNIT
                                PLANNED BY DESERET GENERATION  AND TRANSMISSION COOP TO BE LOCATED  IN
                                VERNAL, UTAH. A CONTRACT  WAS AWARDED TO COMBUSTION ENGINEERING  FOR
                                A WET LIMESTONE SCRUBBING SYSTEM  HAVING A S02 REMOVAL EFFICIENCY OF 951.
                                THE SYSTEM WILL FEATURE  A BAGHOUSE, SUPPLIED BY ECOLAIRE, TO REMOVE 99.6X
                                OF THE PARTICULATE MATTER.  THE  UNIT WILL OPERATE IN A CLOSED WATER LOOP
                                WITH SLUDGE DISPOSAL  ON  SITE IN  A LANDFILL.  OPERATIONS ARE SCHEDULED  TO
                                COMMENCE IN SEPTEMBER  1984.
DESERET  GEN  8
NOON  LAKE
2
NEW
               TRANS COOP
          410.0 MW  (GROSS)
          410.0 MW  (ESC)
COAL
  .50 XS  BITUMINOUS
LIMESTONE
VENDOR NOT  SELECTED
ENERGY CONSUMPTION: *•••*
STATUS 5      STARTUP   0/88
MOON LAKE 2 IS A PULVERIZED  COAL  (0.5X S, 10,500 BTU/LB) FIRED UNIT
PLANNED BY DESERET GENERATION  AND TRANSMISSION COOP TO BE LOCATED  IN
VERNALi UTAH.  THE UTILITY  IS  PRESENTLY REQUESTING BIDS FOR A MET  LIME-
STONE SCRUBBING SYSTEM  HAVING  A  S02  REMOVAL EFFICIENCY OF 95X.   THE  SYSTEM
WILL FEATURE A BAGHOUSE DESIGNED  TO  REMOVE 99.6X OF THE PARTICULATE.   THE
UNIT WILL OPERATE  IN  A  CLOSED  WATER  LOOP WITH SLUDGE DISPOSAL ON SITE
IN A LANDFILL.  OPERATIONS  ARE SCHEDULED TO COMMENCE IN 1988.
                                                  15

-------
  EPA UTILITY  FGO  SURVEY: JULY - SEPTEMBER 198C
                                                SECTION 2
                                         STATUS Of  FGD SYSTEMS
 JNIT IDENTIFICATION
                                                                    ABSTRACT
 DUQUESNE LIGHT
 ELRAMA
 1-4
 RETROFIT  510.0  MM  (GROSS)
           510.0  MW  (ESC)
 COAL
  2.20 XS
 LIME
 CrtENICO DIVISION, FNVIPOTECH
 ENERGY CONSUMPTION:   3.5X
 STATUS 1     STARTUP  10/75
 ELRAMA 1-4 Of DUQUESNE LIGHT  CONSISTS OF FOUR PULVERIZED  COAL  (2.2Z S,
 11,350 BTU/LB) FIRED  UNITS  LOCATED IN ELRAMA, PENNSYLVANIA.  THE  EMISSION
 CONTROL SYSTEM ON THIS SITE  CONSISTS OF AN ESP FOLLOWED BY  A MECHANICAL
 COLLECTOR AND FIVE VARIABLE  THROAT VENTURI LIME ABSORBER  MODULES  SUPPLIED
 BY  CHEMICO, WHICH ARE DESIGNED  TO REMOVE 83* OF THE  S02 FROM THE  FLUE GAS.
 THE  CLEANED GAS PASSES THROUGH  A  DIRECT OIL FIRED REHEATER  BEFORE  EXITING
 A 400 FOOT ACID BRICK LINED  STACK. THE SYSTEM OPERATES IN AN OPEN  WATER
 LOOP, AND THE POZ-0-TEC  STABILIZED SLUDGE IS HAULED  TO AN OFF  SITE  LAND-
 FILL. THE SYSTEM HAS  BEEN OPERATIONAL SINCE OCTOBER  1975.
 BJQUESNE LIGHT
 PHILLIPS
 1-6
 9ETROFIT  408.0 MW (GROSS)
           408.0 MW (ESC)
 COAL
  1.92 XS  BITUMINOUS
 LIME
 CHEMICO DIVISION, ENVIROTECH
 ENERGY  CONSUMPTION:  3.4X
 STATUS  1     STARTUP  7/73
 THE  PHILLIPS POWER STATION  OF  DUBUESNE LIGHT CONSISTS OF  SIX  DRY  POTTOM
 PULVERIZED COAL (1.92* S,  11,350 BTU^LB)  FIRED UNITS LOCATED  IN  SOUTH
 HEIGHT,  PENNSYLVANIA. PARTICULATE CONTROL IS ACCOMPLISHED BY  SIX  ESP/
 MECHANICAL COLLECTOR COMBINATIONS (ONE/BOILER). ONE TWO STAGE  AND  THREE
 SINGLE  STAGE VARIABLE THROAT VENTURI  LIME FGD MODULES SUPPLIED BT  CHEMICO
 ARE  DESIGNED TO REMOVE 832  OF  THE S02 FROM THE FLUE GAS.  TWO  CHEVRON  MIST
 ELIMINATORS/MODULE ARE FOLLOWED  BY  A  DIRECT OIL FIRED REHEATER WHICH  RAIS-
 ES THE  GAS TEMPERATURE BY  20 DEC F  BEFORE IT LEAVES VIA A 340  FOOT TALL
 ACID  BRICK LINED STACK. THE SYSTEM  OPERATES IN AN OPEN WATER  LOOP, AND
 THE  POZ-0-TEC STABILIZED SLUDGE  IS  TRUCKED TO AN OFF SITE LANDFILL. THE
 SYSTEM  HAS BEEN OPERATIONAL SINCE JUDY 1973.
 EAST  KENTUCKY POWER COOP
 J.K.  S11TH
 1
 1EW        650.0 MW (GROSS)
           650.0 MW (ESC)
 COAL
 ••••*  XS
 HOCESS  NOT SELECTED
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTION: *****
 STATUS  6      STARTUP  1/85
THE  EAST  KENTUCKY POWER COOP HAS  PLANS  TO FIRE TWO NEW UMTS.  THE  J.K.
SMITH  UNITS 1 AND 2 WILL UTILIZE  EITHER A DRY PROCESS OR A WET LIME
PROCESS  FOR EMISSION CONTROL.   UNIT  1  IS EXPECTED TO START UP IN  JANUARY
1985.
EAST  KENTUCKY POWER COOP
J.K.  SMITH
2
NEW       650.0 MW (GROSS)
          650.0 MW (ESC)
COAL
• •*•*  XS
»ROCFSS NOT  SELECTED
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION: *****
STATUS  6      STARTUP  1/87
THE  EAST  KENTUCKY POwER COOP HAS PLANS  TO  FIRE  TWO NEW UMTS.  THE  J.K.
SPITH UNITS  1  AND 2 WILL UTILIZE EITHER  A  ORY  PROCESS OR A WET LIME
PROCESS  FOR  EMISSION CONTROL.  UNIT 2  IS  EXPECTED TO START UP IN JANUARY
m?.
EAST KENTUCKY  POWER COOP
SPURLOCK
2
NEW        500.0  MW (GROSS)
           500.0  MW (ESC)
CDAL
 3.50 XS
LME
COMBUSTION  EQUIP ASSOCIATES
ENERGY CONSUMPTION: *****
STATUS 2     STARTUP  1/81
SPURLOCK  2  Of  EAST KENTUCKY POWER COOPERATIVE  IS  A BALANCED DRAFT PULVER-
IZED COAL  (3.5*  S, 11.UOO BTU/LB) FIRED  UNIT UNDER CONSTRUCTION IN MAYS-
VILLE, KENTUCKY.  THE  EMISSION CONTROL  SYSTEM WILL CONSIST OF AN ESP  FOL-
LOWED BY  AN  ADL/COMBUSTION EQUIPMENT ASSOCIATES  LIME FGD SYSTEM (90S
DESIGN SO?  REMOVAL EFFICIENCY). FLUE GAS  FROM  UNIT ONE WILL BE USED  TO
REHEAT THE  CLEANED GAS. THE SYSTEM, SLATED  FOR START UP IN JANUARY 1981,
WILL EMPLOY  A  CLOSED  WATER LOOP AND POZ-0-TEC  SLUDGE STABILIZATION.
FLORIDA POWER  S  LIGHT

-------
                                               EP*  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS Of  F6D SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
FLORIDA POWER I LIGHT
NARTIN
4
NEW       800.0 MW (GROSS)
          800.0 «W (ESC)
CDAL
FLORIDA POWER AND LIGHT HAS PLANS  FOR  TWO  NEW  UNITS,  MARTIN 3 AND 4 TO BE
LOCATED IN MARTIN COUNTY, FLORIDA.  THE  PULVERIZED  COAL  FIRED BOILERS
WILL HAVE A MW RATING OF 800  EACH.  THE  UTILITY  IS  CONSIDERING F6D AND
ALTERNATIVE METHODS FOR EMISSION CONTROL.   THE START  UP  FOR UNIT 4 IS
PROJECTED FOR 1989.
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGT CONSUMPTION: ****X
STATUS 7     STARTUP  0/89
SENERAL PUBLIC UTILITIES
CDAL
1
NEW       625.0 MW  (GROSS)
          625.0 MW  (ESC)
C3AL
 3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 6      STARTUP  12/92
GENERAL PUBLIC UTILITIES  HAS  PLANS  TO  CONSTRUCT A 625 MW UNIT, COAL 1.
THE UTILITY IS PRESENTLY  CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL FIRED  (3.51  S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1992.
GENERAL PUBLIC  UTILITIES
COAL
I
NEW       625.0 MV  (GROSS)
          625.0 MM  (ESC>
CDAL
 3.50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **»*X
STATUS 6      STARTUP   5/94
GENERAL PUBLIC UTILITIES  IS  PLANNING TO CONSTRUCT A 625 MW UNIT,  COAL  2.
THE UTILITY  IS PRESENTLY  CONSIDERING ONLY FGD AS THE EMISSION CONTROL
STRATEGY. THE COAL  FIRED  (3.5X S) UNIT IS SCHEDULED TO COMMENCE OPERATIONS
IN 1994.
SENERAL PUBLIC  UTILITIES
COAL
3
NEW        625.0 MM  (GROSS)
           625.0 ly  (ESC)
COAL
 3.5T XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6      STARTUP  12/95
GENERAL PUBLIC UTILITIES  IS PLANNING TO CONSTRUCT A 625 MW UNIT,  COAL  3.
THE UTILITY  IS PRESENTLY  CONSIDERING ONLY FGD AS THE  EMISSION  CONTROL
STRATEGY. THE COAL  FIRED  (3.5X S) UNIT IS SCHEDULED TO COMMENCE  OPERATIONS
IN 1995.
SENERAL PUBLIC  UTILITIES
C3AL
t
NEW        625.0 MV  (GROSS)
           625.0 MW  (ESC)
COAL
 3.50  XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ***»»
STATUS 6      STARTUP   5/97
GENERAL PUBLIC  UTILITIES HAS PLANS TO CONSTRUCT A 625 MW  UNIT,  COAL  4.
THE UTILITY  IS  PRESENTLY CONSIDERING ONLY FGD AS THE EMISSION  CONTROL
STRATEGY.  THE COAL FIRED (3.5X S) UNIT IS SCHEDULED  TO  COMMENCE OPERATIONS
IN 1997.
SENERAL  PUBLIC  UTILITIES
COHO
1
NEW        690.0 MW  (GROSS)
           690.0 MW  (ESC)
COAL
  3.50  XS
PROCESS  NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  9.4X
STATUS 5     STARTUP  5/91
COHO  1  IS  A  (3.5X S)  COAL FIRED UNIT PLANNED BY GENERAL  PUBLIC  UTILITIES T
BE LOCATED IN  ERIE,  PENNSYLVANIA. PRESENTLY BIDS ARE  BEING  REQUESTED. THE
UTILITY  IS PRIMARILY  CONSIDERING A LIME OR LIMESTONE  NON-SLURRY TYPE  FGD
SYSTEM.  OPERATIONS ARE SCHEDULED TO COMMENCE IN MAY  1991.
                                                  17

-------
  EPA UTILITY FGO SURVEY: JULY  -  SEPTEMBER  1980
                                               SECTION 2
                                         STATUS Of FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 SENERAL PUBLIC UTILITIES
 SEUARD
 T
 NEW       690.0 NW (GROSS)
           690.0 HU (ESO
 COAL
 ***** xs
 PROCESS NOT SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION:  9.4X
 STATUS 5     STARTUP  5/87
                      GENERAL  PUBLIC UTILITIES IS PLANNING A NEW UNIT,  SEUARD  7,  TO  BE  BUILT IN
                      SEUARD,  PENNSYLVANIA. THE UTILITY IS PRESENTLY  REQUESTING BIOS FOP  AN  F6D
                      SYSTEM,  WITH NON-SLURRY TYPE LIME AND LIMESTONE SYSTEMS  BEING  THE
                      PRIMARY  CONSIDERATION. START UP IS EKPECTED  IN  MAY  1987.
 GRAND HAVEN BRD OF LIGHT I
 J.B.  SINS
 s
 NEW

 COAL
  2.75  XS
 LIME
 9ABCOCK  t
 65.0 MU (GROSS)
 65.0 MU (ESC)

BITUMINOUS

WILCOX
PWR THE GRAND HAVEN BOARD OF  LIGHT  AND  POWER'S  J.B. SIMS 3 IS A BITUMINIOUS
    COAL (2.75X S, 11,000 BTU/LB)  FIRED BOILER  UNDER CONSTRUCTION IN
    GRAND HAVEN, MICHIGAN.  A  CONTRACT  HAS  BEEN AWARDED TO BABCOCK AND WILCOX
    TO SUPPLY TWO SPRAY TOWERS  TO CONTROL  S02 EMISSIONS.  EACH SCRUBBER SYSTEM
    WILL UTILIZE A CHEVRON MIST  ELIMINATOR  AND  AN IN-LINE REHEATER.  THE
    SLUDGE IS TO BE DISPOSED  OF  IN  AN OFF  SITE  LANDFILL.  OPERATIONS ARE TO
    COMMENCE IN JUNE 1983.
 ENERGY  CONSUMPTION: *****
 STATUS  2      STARTUP  6/83
 HOOSIER  ENERGY
 1EROM
 1
 NEU        490.0 MU  (GROSS)
           441.0 MU  (ESC)
 COAL
 3.50  SS
 LIMESTONE
 MITSUBISHI  HEAVY INDUSTRIES
 ENERGY CONSUMPTION: «***X
 STATUS 2      STARTUP  5/82
                     MEROH 1 AND  2  ARE  TWO  NEW UNITS BEING BUILT BY HOOSIER ENERGY IN  SULLIVAN
                     INDIANA.  THESE PULVERIZED COAL (3.5X S) FIRED UNITS WILL PRODUCE  1,732,000
                     ACFM OF FLUE GAS WHICH WILL  BE CLEANED BY A COLD SIDE ESP UPSTREAM OF A
                     MITSUBISHI LIMESTONE GRID TOWER ABSORBER (90X DESIGN S02 REMOVAL). THE
                     SYSTEM WILL  UTILIZE  BYPASS REHEAT AND A 700 FOOT STACK. THE SLUDGE WILL
                     BE STABILIZED  AND  LANDFILLED,  AND THE SYSTEM WILL OPERATE IN A CLOSED
                     WATER LOOP MODE. START UP OF UNIT 1  IS SCHEDULED FOR MAY 1982.
HOOSIER  ENERGY
4EROM
2
NEW        490.0  MU  (GROSS)
           441.0  MU  (ESC)
COAL
 3.50 XS
LIMESTONE
MITSUBISHI  HEAVY INDUSTRIES
ENERGY CONSUMPTION: ****X
SIATUS 2      STARTUP  9/61
                     MEROH 1 AND 2 ARE  TWO  NEU  UNITS  BEING BUILT BY HOOSIER ENERGY IN SULLIVAN.
                     INDIANA. THESE PULVERIZED  COAL  (3.5X  S)  FIRED UNITS WILL PRODUCE 1,732,000
                     ACFM OF FLUE GAS WHICH  WILL  BE  CLEANED BY A COLD SIDE ESP UPSTREAM OF A
                     MITSUBISHI LIMESTONE GRID  TOWER  ABSORBER  (90X DESIGN S02 REMOVAL). THE
                     SYSTEM WILL UTILIZE BYPASS REHEAT AND. A  700 FOOT STACK. THE SLUDGE WILL
                     BE STABILIZED AND  LANDFILLED, AND THE SYSTEM WILL OPERATE IN A CLOSED
                     WATER LOOP MODE. START  UP  OF UNIT 2  IS SCHEDULED FOR SEPTEMBER 1981.
HOUSTON LIGHTING  (  POWER
LIMESTONE
1
NEW       750.0 MM  (GROSS)
          750.0 MU  (ESC)
COAL
 1.08 XS  LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****x
STATUS 5     STARTUP  12/84
                     HOUSTON LIGHTING AND  POWER  CO  HAS  PLANS  FOR TWO NEW UNITS, LIMESTONE 1
                     AND 2, TO BE LOCATED  IH  JEUITT,  TEXAS.   THE PULVERIZED COAL (1.081 S,
                     6177 BTU/LB) FIRED BOILER UILL UTILIZE A  VET LIMESTONE SCRUBBING PROCESS
                     FOR PRIMARY S02 COLLECTION.  A COLD  SIDE  ESP WILL ALSO BE USED FOR PRIMARY
                     PARTICLE CONTROL.  THE UTILITY IS  PRESENTLY REOUESTING/EVALUATING BIDS
                     FOR THE FGO SYSTEM.   UNIT 1  IS SCHEDULED  TO COMMENCE OPERATIONS IN 1984.
HOUSTON LIGHTING t POWER
LIMESTONE
2
MEW       750.0 MU (GROSS)
          750.0 MU (ESC)
COAL
 1.08 XS  LIGNITE
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 5     STARTUP  1?/85
                     HOUSTON LIGHTING AND POWER CO HAS  PLANS  FOR  TWO NEW  UNITS, LIMESTONE 1
                     AND 2, TO BE LOCATED IN JEUITT,  TEXAS,.   THE  PULVERIZED COAL (1.08X S,
                     6177 BTU/LB) FIRED BOILER UILL UTILIZE A  WET LIMESTONE SCRUBBING PROCESS
                     FOR PRIMARY S02 COLLECTION.  A COLD  SIDE  ESP WILL  ALSO BE USED FOR PRIMARY
                     PARTICLE CONTROL.  THE UTILITY IS  PRESENTLY  REQUESTING/EVALUATING BIDS
                     FOR THE FGD SYSTEM.  UNIT 2  IS SCHEDULED  TO  COMMENCE  OPERATIONS IN 198S.
                                                 18

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                                               EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
                                              SFCTION 2
                                        STATUS  OF  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
HOUSTON LIGHTING I POWER
4.A. PARISH
S
NEW       600.P MW (GROSS)
          492.0 WW (ESC)
COAL
  .60 XS  SUBBITUPIINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION: *»**X
STATUS 2     STARTUP 11/82
W.A. PARISH 8 OF HOUSTON LIGHTING  1 POWER IS  A  PULVERIZED COAL C0.6X S,
8700 BTU/LB) FIRED UNIT UNDER  CONSTRUCTION IN THOMPSONS, TEXAS. CHEMICO
WILL SUPPLY A LIMESTONE FGD  SYSTEM WHICH  WILL REMOVE 82X OF THE FLUE
GAS S02. REHEAT WILL BE PROVIDED BY BYPASSING 18X OF THE PARTICULAR
CLEANED FLUE GAS. SLUDGE WILL  BE OEWATERED, BLENDED WITH FLYASH, AND
DISPOSED IN AN ON SITE LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE
IN NOVEMBER 1082.
INDIANAPOLIS POWER K LIGHT
PATRIOT
1
NEW       650.0 MW CGROSS)
          65?.0 MW (ESC)
COAL
 3.5? XS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  **»*X
STATUS 6     STARTUP   0/87
INDIANAPOLIS POWER AND LIGHT  HAS  PLANS  FOR THREE NEW UNITS, PATRIOT 1, 2,
AND 3, TO BE LOCATED  IN  PATRIOT,  INDIANA.  THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD  PROCESS  FOR  EMISSION  CONTROL.
INDIANAPOLIS POWER  fc  LIGHT
PATRIOT
2
NEW       650.0 MW  (GROSS)
          650.0 MW  (ESC)
COAL
 3.5" XS
LIMESTONE
VENDOR NOT  SELECTED
ENERGY CONSUMPTION: **«*X
STATUS 6     STARTUP   O/  0
INDIANAPOLIS POWER  AND  LIGHT HAS  PLANS FOR THREE NEW UNITS, PATRIOT  1,  2,
AND 3, TO BE LOCATED  IN PATRIOT,  INDIANA.  THE UTILITY PLANS ON UTILIZING
A LIMESTONE FGD  PROCESS FOR  EMISSION CONTROL.
INDIANAPOLIS  POWER  t  LIGHT
PATRIOT
S
NEW        650.0  NW  (GROSS)
           650.0  MW  (ESC)
COAL
 S.5P XS
LIMESTONE
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION: ***«X
STATUS  6      STARTUP   O/  0
INDIANAPOLIS  POWER  AND  LIGHT HAS PLANS FOR THREE NEW UNITS.  PATRIOT  1,  2,
AND 3, TO BE  LOCATED  IN PATRIOT, INDIANA.  THE UTILITY PLANS ON  UTILIZING
A LIMESTONE FGD  PROCESS FOR EMISSION CONTROL.
INDIANAPOLIS  POWER  t LIGHT
PETERSBURG
3
NEW        53?.0 MW  (GROSS)
           532.0 MW  (ESC)
COAL
 3.25  XS   BITUMINOUS
LIMESTONE
AIR  CORRECTION  DIVISION, UOP
ENERGY CONSUMPTION:  2.4X
STATUS 1      STARTUP 12/77
PETERSBURG  3  OF INDIANAPOLIS POWER AND LIGHT  IS LOCATED  IN  PETERSBURG,
INDIANA,  AND  BURNS 3.2SX S BITUMINOUS COAL  (11,000 BTU/LB).  TWO COLD SIDE
ESP'S  ARE LOCATED UPSTREAM OF 4 85X EFFICIENT UOP LIMESTONE  TCA MODULES.
A  HORIZONTAL  MIST ELIMINATOR PRECEDES AN  INDIRECT HOT  AIR REHEATER THAT
BOOSTS THE  GAS TEMPERATURE BY 30 DEC F BEFORE IT EXITS THE  616 FOOT RI6I-
FLAKE  4850  LINED STACK. STABILIZED SLUDGE IS  DISPOSED  IN AN  ON SITE POND,
AND  THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.  THIS UNIT HAS BEEN
OPERATIONAL SINCE DECEMBER 1977.
INDIANAPOLIS  POWER  I LIGHT
PETERSBURG
4
NEW        530.0 MW  (GROSS)
           530.0 My  (ESC)
COAL
  3.50 XS   BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  2.1X
STATUS 2      STARTUP 10/84
 PETERSBURG 4 OF INDIANAPOLIS POWER AMD LIGHT  IS  A  BITUMINOUS COAL (3.501 S
 11,000 BTU/LB) FIRED BOILER UNDER CONSTRUCTION IN  PETERSBURG, INDIANA. THE
 LIMESTONE FGD SYSTEM FOR THIS UNIT MILL  BE  SUPPLIED  BY  RESEARCH COTTRELL.
 THE  SYSTEM WILL OPERATE IN A CLOSED WATER LOOP,  AND  SLUDGE WILL BE POZ-0-
 TEC  STABILIZED BEFORE PONDING. START UP  IS  SLATED  FOR OCTOBER 198*.
                                                  19

-------
  EPA UTILITY FGD  SURVEY:  JULY - SEPTEMBER 198C
                                               SECTION  2
                                         STATUS OF FGO  SYSTEMS
 JNIT IDENTIFICATION
                                                                    ABSTRACT
 IOWA ELECTRIC LIGHT  I  PWR
 GUTHRIE CO.
 1
 NEW       730.0 MW (GROSS)
           720.0 MW CESC)
 COAL
   .40 XS  SUBBITUMINOUS
 LIMESTONE
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION:  **•*»
 STATUS 5     STARTUP 11/84
 IOWA ELECTRIC LIGHT AND POWER  HAS  PLANS TO CONSTRUCT A 720 MW UNIT,
 GUTHRIE  COUNTY 1, TO BE LOCATED  IN  PANORA, IOWA.  THE PULVERIZED  SUBBITU-
 HINDUS COAL (9.4X S, 8180 BTU/LB)  FIRED BOILER WILL UTILIZE A WET LIME-
 STONE SCRUBBING SYSTEM AND  AN  ESP  FOR  EMISSION CONTROL.  THE CLEANED
 FLUE GAS WILL EXIT A 650 FOOT  STACK.   THE  UTILITY STARTED REQUESTING/
 EVALUATING BIDS IN JANUARY  1960  AND HAS PROJECTED THE STARTUP TO  BE
 IN  OCTOPER 1984.
 JACKSONVILLE ELEC AUTHORITY
 NEW PROJECT
 1
 NEW       600.0 MW (GROSS)
           600.C MW (ESC)
 COAL
  3.or xs
 LIMESTONE
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: *****
 STATUS 6     STARTUP  12/85
 THE  JACKSONVILLF ELECTRIC AUTHORITY HAS  PLANS  FOR  TWO NEk UNITS, NEW
 GENERATING PROJECT 1 AND 2, TO BE LOCATED  IN  EAST  PORT, FLORIDA. EACH
 UNIT  WILL BURN PULVERIZED COAL (2-4%  S)  AND  SUPPLY 2,660,000 ACFM TO A
 hET  LIMESTONE FGD PROCESS AND AN ESP  FOR  EMISSION  CONTROL.  THE CLEANED
 FLUE  GAS  IS TO EXIT A 285 FOOT STACK.  UNIT  1  IS SCHEDULED TO COMMENCE
 OPERATIONS IN 1965.
 JACKSONVILLE ELEC AUTHORITY
 NEW  PROJECT
 2
 NEW        630.0 MW (GROSS)
           600.0 MW (ESC)
 COAL
  3.00 TS
 LIMESTONE
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: *****
 STATUS 6      STARTUP  6/87
 THE  JACKSONVILLE ELECTRIC AUTHORITY HAS  PLANS  FOR  TWO NEk UNITS, NEW
 GENERATING  PROJECT 1 AND 2, TO BE LOCATED  IN  EAST  PORT, FLORIDA. EACH
 UNIT  WILL BURN PULVERIZED COAL (2-41 S)  AND  SUPPLY 2,660,000 ACFM TO A
 WET  LIMESTONE FGD PROCESS AND AN ESP FOR  EMISSION  CONTROL.  THE CLEANED
 FLUE  GAS  IS  TO EXIT A 285 FOOT STACK.  UNIT  2  IS  SCHEDULtD TO COMMENCE
 OPERATIONS  IN 1
-------
                                               EPA UTILITY FGD SURVEY:  JULY  - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS Or FGD SYSTEMS
UNIT IDENTIFICATION
                                                                   ABSTRACT
KANSAS POMER t LIGHT
JEFFREY
1
NEW       720.0 MU  (GROSS)
          5*0.0 MU  (ESC)
COAL
  .32 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: *****
STATUS 1     STARTUP  8/78
KANSAS CITY POMER AND  LIGHT'S  JEFFRE* 1 IS A TANGENTIAL FIRED PULVERIZED
COAL (0.32X S. 8125  BTU/LB)  UNIT  IN UAMEGO, KANSAS. THE EMISSION  CONTROL
SYSTEM FOR THIS UNIT CONSISTS  OF  A  COLD SIDE ESP FOLLOWED BY SIX  (ONE
SPARE) LIMESTONE SPRAY TOWER MODULES SUPPLIED BY COMBUSTION ENGINEERING.
THE DESIGN SO? REMOVAL EFFICIENCY IS SOX (INCLUDING A 30X BYPASS  REHEAT).
THE UNIT HAS BEEN OPERATIONAL  SINCE AUGUST 1978.
KANSAS POUER I  LIGHT
JEFFREY
2
NEW       700.0 MU  (GROSS)
          490.0 MU  (ESC)
COAL
  .30 XS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION:  ****X
STATUS 1     STARTUP   4/80
UNIT 2, PRESENTLY OPERATING  AT KANSAS POWER AND LIGHT'S  JEFFREY  ENERGY
CENTER IN JEFFREY,  KANSAS, BURNS 0.3X S PULVERIZED COAL  (8100  BTU/LB).
THIS UNIT'S EMISSION  CONTROL SYSTEM CONSISTS OF A COLD SIDE  ESP
AND COMBUSTION  ENGINEERING LIMESTONE SPRAY TOWERS. A  30X FLUE  GAS
BYPASS PROVIDES  REHEAT  OF  THE CLEANED. GAS BEFORE IT  EXITS  THROUGH A
6CO FOOT STACK.  THE SYSTEM OPERATES IN A CLOSED WATER LOOP MODE. AND
THE SLUDGE  IS STABILIZED  WITH BOTTOM ASH AND PIPED TO AN ON-SITE CLAY
LINED POND. INITIAL OPERATIONS COMMENCED IN APRIL 198C.
KANSAS POUER &  LIGHT
LAURENCE
4
RETROFIT   125.0 MW  (GROSS)
           125.0 MU  (ESC)
COAL
  .55 XS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1     STARTUP   1/76
LAWRENCE 4 OF KANSAS  POUER  AND LIGHT IS A BALANCED DRAFT,  TANGENTIAL FIREt
PULVERIZED COAL  (0.551 S, 10,000 BTU/LB) UNIT LOCATED  IN  LAWRENCE, KANSAS.
A NEW COMPUSTION  ENGINEERING LIMESTONE ROD DECK/SPRAY  TOWER SYSTEM
REPLACED THE  EXISTING MARBLE BED TAIL END SCRUBBER IN  JANUARY 1977. THE
SYSTEM TREATS 403,000 ACFM  OF FLUE GAS, WITH A DESIGN  S02  REMOVAL OF
73X. MIST ELIMINATION IS  ACCOMPLISHED BY TWO CHEVRONS  AND  ONE BULK
ENTRAPMENT SEPARATOR FOLLOWING EACH OF THE TUO MODULES.  A FINNED TUBE
REHEATER BOOSTS  THE  TEMPERATURE OF THE CLEANED GAS BY  20  DE6 F BEFORE
IT IS EXHAUSTED  THROUGH A 120 FOOT STACK. THE SLUDGE  IS  DISPOSED IN AN
UNLINED INTERIM  POND, WHICH OVERFLOWS INTO A FINAL DISPOSAL POND. THE
SYSTEM OPERATES  IN  A  CLOSED WATER LOOP.
KANSAS POWER  &  LIGHT
LAURENCE
5
RETROFIT   420.0 MW  (GROSS)
           420.0 MU  (ESC)
COAL
   .55 XS
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 1      STARTUP  11/71
LAURENCE  5  OF  KANSAS POUER AND LIGHT IS A BALANCED  DRAFT, TANGENTIAL FIRED
PULVERIZED  COAL  (0.55X S, 10,000 BTU/LB) UNIT  LOCATED IN LAURENCE, KANSAS.
A NEW COMBUSTION  ENGINEERING LIMESTONE ROD  DECK/SPRAY TOWER SYSTEM
REPLACED  THE  EXISTING MARBLE BFD TAIL END SCRUBBER  IN APRIL 1978. THE
SYSTEM  TREATS  403,000 ACFM OF FLUE GAS, UITH  A DESIGN S02 REMOVAL OF
73X. MIST ELIMINATION IS ACCOMPLISHED BY TUO  CHEVRONS AND ONE BULK
ENTRAINMENT SEPARATOR FOLLOWING EACH OF THE TUO MODULES. A FINNED TUBE
REHEATER  BOOSTS  THE TEMPERATURE OF THE CLEANED GAS  BY 20 DEG F BEFORE
IT  IS EXHAUSTED  THROUGH A 120 FOOT STACK. THE  SLUDGE  IS DISPOSED IN AN
UNLINED  INTERIM  POND, WHICH OVERFLOUS INTO  A  FINAL  DISPOSAL POND. THE
SYSTEM  OPERATES  IN A CLOSED UATER LOOP.
KENTUCKY  UTILITIES
GREEN  RIVER
1-3
RETROFIT   64.0 MU (GROSS)
           64.0 MU (ESC)
COAL
 4.OH  XS   BITUMINOUS
LIME
AMERICAN  AIR  FILTER
ENERGY CONSUMPTION:  3.1X
STATUS 1      STARTUP  9/75
GREEN  RIVER  1-3  OF KENTUCKY UTILITIES  ARE  THREE  DRV BOTTOM PULVERIZED
BITUMINOUS  COAL  (4X S, 11,000 BTU/LB)  FIRED  UNITS LOCATED IN CENTRAL
CITY,  KENTUCKY.  EACH BOILER SUPPLIES 360.000 ACFM OF FLUE GAS TO A
VARIABLE  THROAT  VENTURI FOLLOUED BY AN AMERICAN  AIR FILTER LIME MOBILE
BED  CONTACTOR  (BOX DESIGN S02 REMOVAL  EFFICIENCY).  A RADIAL VANE MIST
ELIMINATOR  IS  FOLLOUED BY A STEAM TUBE REHEATER  AND A 165 FOOT STACK.
SLUDGE IS DISPOSED IN AN ON-SITE UNLINED POND, AND  THE SYSTEM OPERATES
IN A  CLOSED  WATEK LOOP. THE SYSTEM HAS BEEN  OPERATIONAL SINCE SEPTEMBER
1975.
LAKELAND  UTILITIES
MCINTOSH
J
NEU        364.0 MU (GROSS)
           364.0 MU (ESC)
COAL
 2.56  XS   BITUMINOUS
LIMESTONE
BABCOCK  t UILCOX
ENERGY CONSUMPTION: ***«X
STATUS 2      STARTUP  8/81
 MCINTOSH  3  OF  LAKELAND UTILITIES IS HE IN 6  CONSTRUCTED IN LAKELAND,
 FLORIDA.  PABCOCK AND UILCOX HAS BEEN  AWARDED  A CONTRACT TO SUPPLY AN
 85X  EFFICIENT  (S02) LIMESTONE FGD SYSTEM FOR  THIS UNIT. THE EMISSION CON-
 TROL  SYSTEM UILL CONSIST OF A COLD SIDE  ESP  FOLLOWED BY TWO PARALLEL FGD
 MODULES  AND A  25G FOOT ACID BRICK LINED  STACK. THE SYSTEM UILL OPERATE  IN
 A  CLOSED  UATER LOOP, AND THE POZ-0-TEC  STABILIZED SLUDGE UILL BE USED AS
 A  CONSTRUCTION BASE. CONSTRUCTION BEGAN  IN NOVEMBER 1979 AND START
 UP IS SCHEDULED TO BE IN AUGUST 1981.
                                                  21

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  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980
                                               SECTION 2
                                         STATUS  OF  FGO SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 LANSIN6 BOARD OF WATER I LI6HT THE ERICKSON  2  STATION  OF THE LANSING BOARD OF WATER AND LIGHT IS A
 ERICKSON
 2
 NEW       160.Q MW (GROSS)
           160.0 NW 
 COAL
 ***** xs
 PROCESS NOT SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: ****X
 STATUS 6     STARTUP  1/87
 PLANNED  UNIT TO BE LOCATED IN DELTA TOWNSHIP, MICHIGAN.   THE  UNIT  WILL
 HAVE  A MW  RATING OF BETWEEN UO AND 250, DEPENDING ON WHETHER OTHER  MUNI-
 CIPALITIES WILL JOIN IN THIS PROJECT.  THE UTILITY IS PRESENTLY  CONSIDER-
 ING  THE  USE  OF FGD FOR EMISSION CONTROL.  OPERATIONS ARE  SCHEDULED TO
 COMMENCE IN  1987.
 LOS  ANGELES DEPT OF WTR * PWR
 INTERNOUNTAIN
 1
 NEW        820.0 MW (GROSS)
           820.0 MW (ESC)
 COAL
   .79 XS  SUBBITUHINOUS
 LIME
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: **»*Z
 STATUS 6     STARTUP  0/86
 THE  LOS  ANGELES  DEPARTMENT OF WATER AND POWER HAS PLANS  FOR FOUR  NEW
 BOILERS,  INTERMOUNTAIN 1, 2, 3 AND «, TO BE LOCATED IN DELTA, UTAH.
 EACH  820  MW  BOILER WILL FIRE PULVERISED COAL (0.79X S, 10,200 BTU/LB)
 AND  WILL  SUPPLY  5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM,
 A HORIZONTAL WEIR TYPE SCRUBBER ALONG WITH A HOT SIDE ESP IS UNDER
 CONSIDERATION BY THE  UTILITY FOR EMISSION CONTROL.  THE  CLEANED FLUE GAS
 WILL  EXIT A  750  FOOT  STACK.  UNIT 1 IS SCHEDULED TO COMMENCE OPERATIONS
 IN 1986.
 LOS  ANGELES  DEPT OF WTR t PWR
 1NTERNOUNTAIN
 2
 NEW        820.0 MW  (GROSS)
           820.0 MW  (ESC)
 COAL
   .79 XS   SUBBITUMINOUS
 LIME
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTIONt *****
 STATUS  6     STARTUP  0/87
THE LOS  ANGELES  DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS,  INTERMOUNTAIN 1, 2, 3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820  KW  BOILER WILL FIRE PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL  SUPPLY  5,400,000 ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM.
A HORIZONTAL WEIR  TYPE SCRUBBER ALOfufc WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE  UTILITY FOR EMISSION CONTROL.  THE CLEANED FLUE GAS
WILL EXIT A  750  FOOT  STACK.  UNIT Z IS SCHEDULED TO COMMENCE OPERATIONS
IN 1987.
LOS  ANGELES  DEPT  OF WTR 8 PWR
INTERNOUNTAIN
3
NEW        820.0 MW  (GROSS)
           820.0 MW  (ESC)
COAL
  .79 XS   SUBBITUMINOUS
LIME
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 6     STARTUP  0/88
THE LOS  ANGELES  DEPARTMENT OF WATER AND POWER HAS PLANS FOR FOUR NEW
BOILERS,  INTERMOUNTAIN  1,  2,  3 AND 4, TO BE LOCATED IN DELTA, UTAH.
EACH 820  MW  BOILER  WILL FIRE  PULVERIZED COAL (0.79X S, 10,200 BTU/LB)
AND WILL  SUPPLY  5,400,000  ACFM OF FLUE GAS TO A WET LIME SCRUBBING SYSTEM,
A HORIZONTAL WEIR TYPE  SCRUBBER ALONfi WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE  UTILITY  FOR EMISSION CONTROL.  THE CLEANED FLUE GAS
WILL EXIT A  750  FOOT  STACK.   UNIT 3 IS SCHEDULED TO COMMENCE OPERATIONS
IN 1988.
LOS ANGELES DEPT  OF  WTR  K PWR
INTERMOUNTAIN
4
NEW       820.0 MW  (GROSS)
          820.0 MW  (ESC)
COAL
  .79 XS  SUBBITUMINOUS
LINE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 6     STARTUP  0/89
THE LOS ANGELES  DEPARTMENT  OF  WATER  AND POWER HAS PLANS FOR FOUR NEW
BOILERS, INTERMOUNTAIN  1,  2,  3 AND  4,  TO BE LOCATED IN DELTA, UTAH.
EACH 820 MW BOILER WILL FIRE  PULVERIZED COAL (C.79X S, 10,200 BTU/LB)
AND WILL SUPPLY  5,400,000  ACFM OF FLUE  GAS TO A WET LIME SCRUBBING SYSTEM,
A HORIZONTAL WEIR TYPE  SCRUBBER  ALONG  WITH A HOT SIDE ESP IS UNDER
CONSIDERATION BY THE  UTILITY  FOR EMISSION CONTROL.  THE CLEANED FlUE GAS
WILL EXIT A 750  FOOT  STACK.   UNIT 4  IS  SCHEDULED TO COMMENCE OPERATIONS
IN 1989.
LOUISVILLE GAS  »  ELECTRIC
CANE RUN
4
RETROFIT  188.0 MW  (GROSS)
          188.0 MW  (ESC)
COAL
 3.75 XS  BITUMINOUS
LINE
AMERICAN AIR FILTER
ENERGY CONSUMPTION:   1.6*
STATUS 1     STARTUP   8/76
UNIT 4 AT LOUISVILLE GAS  AND  ELECTRIt'S  CANE RUN STATION IS A PULVERIZED
BITUMINOUS COAL  (3.75*  S,  11,500 BTU/LB)  FIRED UNIT IN LOUISVILLE, KEN-
TUCKY. AN ESP AND TWO AMERICAN  AIR  FILTER CARBIDE LIME MOBILE BED ABSORBER
MODULES (85* DESIGN S02 REMOVAL)  TREAT 734,000 ACFM OF FLUE GAS FROM THE
BOILER. TWO CHEVRON HIST  ELIMINATORS/NODULE  ARE FOLLOWED BY A DIRECT
COMBUSTION REHEATER AND A  250 FOOT  STACK. THE WATER LOOP IS OPEN. AND
THE SLUDGE IS DISPOSED  IN  AN  ON-SITE  LINED POND. THIS RETROFIT SYSTEM
HAS BEEN OPERATIONAL SINCE AUGUST 1976.
                                                 22

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                                               EPA  UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS OF  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
RETROFIT  200.0 MW (GROSS)
          200.0 NW (ESC)
COAL
 3.75 XS  BITUMINOUS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:   1.5X
STATUS 1     STARTUP  1Z/77
CANE RUN 5 OF LOUISVILLE CAS  AND  ELECTRIC  IS  A PULVERIZED BITUMINOUS COAL
(3.75X S, 11,500 BTU/LB) FIRED  UNIT  LOCATED  IN LOUISVILLt, KENTUCKY. THE
BOILER SUPPLIES 700,000 ACFM  OF  FLUE  GAS  TO  AN EMISSION CONTROL SYSTEM
CONSISTING OF AN ESP  FOLLOWED AND TWO COMBUSTION  ENGINEERING 85X EFFICIENT
(DESIGN) CARBIDE LIME SPRAY  TOWERS.  A STEAM  TUBE  REHEATER RAISES THE GAS
TFMPERATURE 40 DEC F. THE SYSTEM  OPERATES  IN  AN OPEN WATER LOOP MODE, AND
THE SLUDGE IS POZ-0-TEC STABILIZED.  OPERATION OF  THIS RETROFIT SYSTEM
BEGAN IN DECEMBER 1977.
LOUISVILLE GAS t ELECTRIC
CANE RUN
6
RETROFIT  299.0 MW  (GROSS)
          299.0 MW  (ESC)
COAL
 4.80 XS  BITUMINOUS
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION:   1.0*
STATUS 1     STARTUP   4/79
LOUISVILLE GAS AND ELECTRIC'S  CANE  RUN  6  IS A PULVERIZED BITUMINOUS COAL
(4.BOX S, 11,500 BTU/LB)  FIRED UNIT IN  LOUISVILLE, KENTUCKY. AOL/COMBUS-
TION EQUIPMENT ASSOCIATES  SUPPLIED  A RETROFIT DUAL ALKALI DEMONSTRATION
FGD SYSTEM FOR THIS  UNIT.  THE  EMISSION  CONTROL SYSTEM, DESIGNED TO REMOVE
951 OF THE FLUE GAS  SOZ,  CONSISTS OF A  COLO SIDE ESP AND TWO TRAY TOWER
MODULES. THE CLEANED  GAS  PASSES THROUGH A CHEVRON MIST ELIMINATOR AND TWO
DIRECT COMBUSTION REHEATERS  BEFORE  EXITING A 518 FOOT STACK. THE WATER
LOOP IS OPEN, AND THE SLUDGE IS DISPOSED  IN AN ON-SITE CLAY LINED POND.
FOR A ONE YEAR PERIOD FOLLOWING THE FIRST QUARTER OF OPERATION (WHICH BE-
GAN IN APRIL 1979),  THE  U.S.EPA WILL SUBSIDIZE A MAX OF $4.5 MM FOR OPER-
ATION, R&D, AND REPORT WRITING (NOT APPLIED TO ANY CAPITAL EXPENDITURES).
LOUISVILLE GAS t  ELECTRIC
HILL CREEK
1
RETROFIT  358.0 MW  (GROSS)
          358.0 NW  (ESC)
COAL
 3.75 XS
LIME
COMBUSTION ENGINEERING
ENERGY CONSUMPTION:  1.4*
STATUS 2      STARTUP   1/81
MILL CREEK  1  OF  LOUISVILLE  GAS  AND ELECTRIC IS LOCATED IN LOUISVILLE, KEN-
TUCKY. A RETROFIT  LIME/LIMESTONE  FGD SYSTEM IS PRESENTLY UNDER CONSTRUC-
TION ON THIS  PULVERIZED  COAL (3.75X S, 11,500 BTU/L8) FIRED UNIT.
COMBUSTION  ENGINEERING  IS  SUPPLYING THE LIME/LIMESTONE FGD SYSTEM
WHICH WILL  COMPLY  WITH  LOCAL EMISSION STANDARDS BY APRIL 1981.
LOUISVILLE 6AS  ft  ELECTRIC
HILL  CREEK
2
RETROFIT  350.0 MU  (GROSS)
          350.0 MW  (ESC)
COAL
 J.75 XS
LIME
COMBUSTION ENGINEERING
ENERGY  CONSUMPTION:  1.4X
STATUS  2      STARTUP 12/81
MILL CREEK  2  OF  LOUISVILLE GAS AND ELECTRIC IS LOCATED IN LOUISVILLE,  KEN-
TUCKY.  A  RETROFIT LIME/LIMESTONE FGD SYSTEM IS PRESENTLY UNDER  CONSTRUC-
TION ON THIS  PULVERIZED COAL (3.75X S, 11,500 BTU/LB) FIRED  UNIT.
COMBUSTION  ENGINEERING IS SUPPLYING THE LIME/LIMESTONE FGD SYSTEM  WHICH
WILL COMPLY WITH LOCAL EMISSION STANDARDS BY APRIL 1982.
LOUISVILLE  GAS  t ELECTRIC
MILL  CREEK
3
NEW       442.0 MW  (GROSS)
          442.0 NW  (ESC)
COAL
 3.75  XS  BITUMINOUS
LIME
AMERICAN  AIR  FILTER
ENERGY  CONSUMPTION:  1.6X
STATUS  1      STARTUP  8/78
LOUISVILLE  GAS  AND ELECTRIC'S MILL CREEK 3 IS A 3.75X  S  COAL  (11,500 BTU/
LB)  FIRED UNIT  LOCATED IN LOUISVILLE, KENTUCKY. AMERICAN AIR  FILTER  SUP-
PLIED  A  CARBIDE LIME FGD SYSTEM FOR THIS UNIT WHICH  WAS  DESIGNED  TO  REMOVE
85X  OF THE  SO?  FROM THE FLUE GAS. AN ESP IS FOLLOWED BY  FOUR  MOBILE  BED
SPRAY  TOWERS  AND A STEAM TUBE REHEATER. THE WATER LOOP IS OPEN,  AND  THE
FLYASH AND  LIME STABILIZED SLUDGE IS PONDED. THIS UNIT HAS BEEN  OPERATION-
AL SINCE AUGUST 1978.
LOUISVILLE  GAS  £ ELECTRIC
MILL  CREEK
4
NEW        S30.0 MW (GROSS)
           495.0 MW (ESC)
COAL
 5.75 XS
LIME
AMERICAN  AIR FILTER
ENERGY CONSUMPTION: • •••X
STATUS 2      STARTUP  6/82
 MILL  CREEK  4 OF LOUISVILLE GAS AND ELECTRIC  IS  A PULVERIZED  BITUMINOUS
 COAL  (3.75X S, 11,500 BTU/LB) FIRED UNIT UNDER  CONSTRUCTION  IN  LOUISVILLE,
 KENTUCKY. THE EMISSION CONTROL SYSTEM WILL CONSIST OF  AN  ESP AND FOUR
 MOBILE  BED  SPRAY TOWERS. THE SYSTEM'S WATER  LOOP WILL  BE  CLOSED, AND
 THE  SLUDGE  WILL BE STABILIZED WITH LIME AND  FLVASH.  STEAM TUBES HILL
 PROVIDE  REHEAT Of THE CLEANED GASES. THE SYSTEM IS SCHEDULED TO START
 UP  IN JUNE  1982.
                                                  23

-------
  EPA UTILITY  FGD  SURVEY: JULT - SEPTEMBER  19f»0
                                                SECTION  1
                                         STATUS Of  FGO  SYSTEMS
 UNIT IDENTIFICATION
                                                                    ABSTRACT
 LOUISVILLE SAS &  ELECTRIC
 PADDY'S RUN
 6
 RETROFIT   72.0 MW  (GROSS)
            72.P MW  (ESC)
 COAL
  2.5P XS  BITUMINOUS
 LIME
 COMBUSTION ENGINEERING
 ENERGY CONSUMPTION:  2.8X
 STATUS 1     STARTUP  4/73
                                 UNIT 6 AT LOUISVILLE  GAS  AND  ELECTRIC'S PADDY'S RUN  STATION  IS  A  DRY BOT-
                                 TOM PULVERIZED COAL  (2.5X  S,  11,500 BTU/LB) FIRED UNIT  IN  LOUISVILLE, KEN-
                                 TUCKY. A RETROFIT CARBIDE  LIME  F6D SYSTEM BY COMBUSTION  ENGINEERING  TREATS
                                 400,000 ACFM OF FLUE  GAS  FROM THE  BOILER. AN ESP IS  FOLLOWED  BY TWO  MARBLE
                                 BED ABSORBERS, A DIRECT COMBUSTION REHEATER, AND A 250  FOOT  STACK.  MIST
                                 ELIMINATION IS PROVIDED BY  ONE  CHEVRON/MODULE. THE LIME  FIXATED SLUDGE IS
                                 TRUCKED TO AN UNLINED POND, AND  THE HATER LOOP IS CLOSED.  THE FGD SYSTEM
                                 BEGAN INITIAL OPERATIONS  IN APRIL  1973.
 LOUISVILLE GAS & ELECTRIC
 TRIMBLE COUNTY
 1
 NEW        575.0 MW (GROSS)
           575.0 MW (ESC)
 COAL
 4.OP XS  BITUMINOUS
 PROCESS NOT SELECTED
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTION: • »***
 STATUS  5     STARTUP  7/85
                                 LOUISVILLE GAS AND ELECTRIC  WILL  BE  INSTALLING FGD SYSTEMS  ON  TWO  OF  THE
                                 FOUR  BOILERS AT THE UTILITY'S  PLANNED TRIMBLE COUNTY  STATION  IN  BEDFORD,
                                 KENTUCKY.  THE PULVERIZED  4X  S  (IF NO COAL WASH IS INCLUDED)  COAL  FIRED
                                 UNITS'  FLUE GAS WILL BE CLEANED  BY ESP'S AND WET SCRUBBING  (90*  RFMOVAL
                                 EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT  1  IS  SCHEDULED
                                 FOR  START  UP IN JULY 1985.
LOUISVILLE  GAS I ELECTRIC
TRIMBLE  COUNTY
2
NEW        575.0 MW  (GROSS)
           575.0 MW  (ESC)
COAL
 4.00 XS   BITUMINOUS
PROCESS  NOT  SELECTED
VENDOR NOT  SELECTED
ENERGY CONSUMPTION: ***»X
STATUS 5      STARTUP  7/88
                                LOUISVILLE GAS AND ELECTRIC  WILL  BE  INSTALLING FGD SYSTEMS ON  TWO  OF  THE
                                FOUR  BOILERS AT THE UTILITY'S  PLANNED TRIMBLE COUNTY STATION IN  BEDFORD,
                                KENTUCKY.  THE PULVERIZED  4X  S  (IF NO COAL WASH IS INCLUDED) COAL  FIRED
                                UNITS'  FLUE GAS WILL B£ CLEANED BY ESP'S AND WET SCRUBBING (90X  REMOVAL
                                EFFICIENCY). SLUDGE DISPOSAL STRATEGY IS UNDECIDED. UNIT 2 IS  SCHEDULED
                                FOR  START  UP IN 1988.
MAROUETTE BOARD  OF  LIGHT £ PWR
SH1RAS
3
NEW         44.0  MW  (GROSS)
            44.0  MW  (ESC)
COAL
**••• XS
LIME/SPRAY  DRYING
VENDOR NOT  SELECTED
ENERGY CONSUMPTION: • ***!
STATUS 5      STARTUP 10/82
                                 SHIRAS  3  OF THE MARQUETTE BOARD  OF  LIGHT  AND POWER IS K PULVERIZED  COAL
                                 FIRED BOILER PLANNED FOR LOCATION  IN  MARBUETTE, MICHIGAN.  PRESENTLY,
                                 THE  UTILITY IS REQUESTING BIDS  FOR  A  DRY  LIME SCRUBBING PROCESS  TO
                                 CONTROL EMISSIONS.  THE UTILITY  WILL  UTILIZE A FABRIC FILTER TO  OBTAIN
                                 A PARTICLE REMOVAL EFFICIENCY OF 99.8X.   THE UNIT IS SCHEDULED TO
                                 COMMENCE  OPERATIONS IN OCTOBER  1982.
MICHIGAN SO  CENTRAL PWR AGENCY  THE  PROJECT 1 UNIT OF MICHIGAN  SOUTH  CENTRAL POWER AGENCY IS TO  BE  CON-
           55.0  MW  (GROSS)
           55.0  MW  (ESC)
PROJECT
t
NEW

COAL
 2.25 XS
LIMESTONE
9ABCOCK t  WILCOX
ENERGY CONSUMPTION: •***X
STATUS 3      STARTUP  6/62
STRUCTED  IN  LITCHFIELD, MICHIGAN, AND WILL UTILIZE  A  UET LIMESTONE FGD
PROCESS.  THE  PULVERIZED COAL FIRED BOILER WILL  FEED  ITS FLUE GAS THROUGH
A HOT SIDE ESP FOLLOWED BY A BABCOCK AND WILCOX  LIMESTONE SPRAY TOWER.
THE CLEANED  GAS  WILL  PASS THROUGH A MIST ELIMINATOR  BEFORE BEING WARMED
BY AN IN-LINE  REHEATER  AND EXITING A 250 FOOT  STACK.   THE SLUDGE IS TO
BE DISPOSED  OFF  SITE. START UP IS SCHEDULED FOR  JUNE  1982*
MIDDLE SOUTH  UTILITIES
ARKANSAS LIGNITE
5
NEW       890.0 MW (GROSS)
          890.0 MW (ESC)
COAL
  .50 XS  LIGNITE
PROCESS NOT  SELECTED
VENDOR NOT  SELECTED
ENERGY CONSUMPTION: • *•*»
STATUS 4      STARTUP  0/90
                                UNIT  1  OF  THE  ARKANSAS ENERGY LIGNITE  CENTER  IS A LIGNITE (.5* S) FIRED
                                BOILER.  MIDDLE SOUTH UTILITIES HAS  SIGNED  A  LETTER OF INTENT WITH
                                COMBUSTION ENGINEERING FOR A WET LIMESTONE SCRUBBING SYSTEM TO CONTROL
                                EMISSIONS. OPERATIONS ARE SCHEDULED TO  COMMENCE IN 1990.
                                                  24

-------
                                               EPA UTILITY FGO SURVEY: JULY - SEPTEMBER  1980
                                              SECTION 2
                                        STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
MIDDLE SOUTH UTILITIES
ARKANSAS LIGNITE
&
NEW       890.0 MW (GROSS)
          890.0 AW (ESC)
COAL
  .50 XS  LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  **«»t
STATUS 4     STARTUP  0/92
UNIT Z Of THE ARKANSAS  ENERGY  LIGNITE  CENTER IS A LIGNITE (.51 S) FIRED
BOILER. MIDDLE SOUTH  UTILITIES HAS  SIGNED A LETTER OF INTENT WITH
COMBUSTION ENGINEERING  FOR  A  WET  LIMESTONE SCRUBBING SYSTEM TO CONTROL
EMISSIONS. OPERATIONS ARE SCHEDULED TO COMMENCE IN 1992.
KIDDLE SOUTH UTILITIES
UNASSIGNED
1
NEW       890.0 MW  (GROSS)
          890.0 MM  (ESC)
COAL
  .50 XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS I     STARTUP  0/89
MIDDLE SOUTH UTILITIES  HAS  SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING FOR  A  WET LIMESTONE SCRUBBING SYSTEM TO CONTROL EMISSIONS,
THE PLANT NAME HAS NOT  BEEN ASSIGNED.  THE PL1NT WILL BE LOCATED
SOMEWHERE IN LOUISIANA.   STARTUP IS SCHEDULED FOR 1989.
KIDDLE SOUTH UTILITIES
UNASSIGNED
2
NEW       890.0 Mw  (GROSS)
          890.0 MW  (ESC)
COAL
  .5H XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 4     STARTUP   0/93
MIDDLE SOUTH UTILITIES  HAS SIGNED A LETTER OF INTENT WITH COMBUSTION
ENGINEERING  FOR  A  WET LIMESTONE SCRUBBING SYSTEM TO CONTROL  EMISSIONS.
THE PLANT NAME HAS NOT  BEEN ASSIGNED.  THE PLANT WILL BE LOCATED
SOMEWHERE IN LOUISIANA.  STARTUP IS SCHEDULED FOR 1993.
IIDCILE  SOUTH  UTILITIES
41LTON
1
NEW        890.0  MW  (GROSS)
           890.0  MW  (ESC)
COAL
   .50 XS
PROCESS NOT  SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION: **«*X
STATUS  4      STARTUP   0/88
WILTON  1  IS  A  COAL  (.501 S) FIRED BOILER TO BE LOCATED  IN  CONVENT, LOUI-
SIANA.   MIDDLE SOUTH UTILITIES HAS SIGNED A LETTER OF INTENT WITH COMBUS-
TION  ENGINEERING  FOR A WET LIMESTONE SCRUBBING SYSTEM FOR  EMISSION
CONTROL.   STARTUP IS SCHEDULED FOR 1988.
MIDDLE  SOUTH  UTILITIES
MILTON
2
NEW        890.0  MW  (GROSS)
           890.0  MW  (ESC)
COAL
   .50 XS
PROCESS NOT  SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION: ****X
STATUS  4      STARTUP  0/91
WILTON  2  IS  A  COAL (.SOX S) FIRED BOILER TO  BE  LOCATED  IN CONVENT, LOUI-
SIANA.  MIDDLE SOUTH UTILITIES HAS SIGNED  A  LETTER  OF  INTENT WITH COMBUS-
TION  ENGINEERING FOR A WET LIMESTONE SCRUBBING  SYSTEM  FOR EMISSION
CONTROL.   STARTUP IS SCHEDULED FOR 1991.
MINNESOTA  POWER  t  LIGHT
CLAY  BOSWELL
4
NEW        554.0  MW (GROSS)
           475.0  MW (ESC)
COAL
   .94 XS   SUBBITUMINOUS
LIME/ALKALINE  FLYASH
PEABODY PROCESS  SYSTEMS
ENERGY CONSUMPTION:  1.JX
STATUS 1      STARTUP  4/80
 CLAY  BOSWELL 4 OF MINNESOTA POWER AND LIGHT  IS  A  SUBBITUMINOUS COAL (0.94X
 S,  8896  BTU/LB) FIRED UNIT LOCATED IN COHASSET, MINNESOTA. PEABODY
 PROCESS  SYSTEMS HAS SUPPLIED A LIME/ALKALINE  FLYASH SYSTEM WHICH
 IS  DESIGNED TO REMOVE 64.6X OF THE S02  IN  THE  FLUE  GAS.  TWO HOT SIDE ESP'S
 ARE  FOLLOWED BY VENTURI/SPRAY TOWER JRAINS.  MIST  ELIMINATION IS PROVIDED
 BY  A  SIEVE  TRAY FOLLOWED BY A SPIN VANE  CHEVRON,  AND REHEAT IS SUPPLIED
 BY  BYPASSING 5X OF THE FLUE GAS. THE SYSTEM  OPERATES IN  A CLOSED WATER
 LOOP  MODE,  AND THE SLUDGE IS DISPOSED IN  A LINED  POND. OPERATIONS
 COMMENCED IN APRIL 1980.
                                                  25

-------
  EPA UTILITY FED SURVEY: JULY  -  SEPTEMBER  1980
                                               SECTION I
                                         STATUS  OF FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 MINNKOTA POWER COOPERATIVE
 HILTON R. YOUN6
 2
 MEW       440.0 MW (GROSS)
           185.0 'NW (ESC)
 COAL
   .70 XS  LIGNITE
 LIME/ALKALINE FLYASH
 COMBUSTION EQUIP ASSOCIATES
 ENERGY CONSUMPTION:  1.6Z
 STATUS 1     STARTUP  9/77
 MINNKOTA POWER COOPERATIVE'S HILTON R. YOUNG 2 IS A  CYCLONE  FIRED  LIGNITE
 (0.70XS, 6500 BTU/LB) BOILER LOCATED IN CENTERt NORTH DAKOTA. THE  BOILER
 PRODUCES 2,021,400 ACFH OF FLUE GAS, HALF OF WHICH IS CLEANED BY TWO  ESP'S
 AND  TWO  ADL/COMBUSTION EQUIPMENT ASSOCIATES LIME/ALKALINE FLYASH SPRAY
 TOWERS  (75X  DESIGN S02 REMOVAL EFFICIENCY). THE CLEANED GAS  PASSES  THROUGH
 A  CHEVRON MIST ELIMINATOR BEFORE IT JOINS A 151 BYPASS REHEAT. ALONG  WITH
 THE  UNSCRUBBED CAS, EXITS A 550 FOOT STACK. THE WATER LOOP IS OPEN, AND  TM
 SLUDGE  IS TRUCKED TO AN OFF-SITE MINEFILL.  OPERATIONS BEGAN IN 1977.
 MONONGAHELA POWER
 PLEASANTS
 1
 NEW        618.0 MW (GROSS)
           618.0 MW (ESC)
 COAL
  3.70 XS  BITUMINOUS
 LIME
 BABCOCK  I WILCOX
 ENERGY CONSUMPTION: ****X
 STATUS 1     STARTUP  3/79
NONONGAHELA  POWER PLEASANTS 1 IS A BITUMINOUS COAL (3.70S S, 12,150
BTU/LB)  FIRED  BOILER IN BELMONT, WEST VIRGINIA. BABCOCK AND WILCOX SUP-
PLIED  A  LINE FGD SYSTEM DESIGNED TO REMOVE 90X OF THE FLUE GAS SO? FROM
THIS UNIT. THE EMISSION CONTROL SYSTEM INCLUDES AN ESP UPSTREAM OF FOUR
SPRAY  TOWER  ABSORBERS. A FLUE GAS BYPASS SYSTEM PROVIDES REHEAT OF THE
CLEANED  GAS  BEFORE IT IS DISCHARGED THROUGH A 1200 FOOT PLACITE LINED
STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP. THE FGD SYSTEM ON THIS
UNIT HAS BEEN  OPERATIONAL SINCE MARCH 1979.
 HONONGAHELA POWER
 PLEASANTS
 2
 NEW        618.0 MW (GROSS)
           618.0 NW (ESC)
 COAL
 4.50 XS  BITUMINOUS
 LIME
 BABCOCK  S WILCOX
 ENERGY CONSUMPTION: *****
 STATUS 2     STARTUP 10/80
HONONGAHELA  POWER  PLEASANTS 2 IS A BITUMINOUS COAL U.5X Si 12.15C
BTU/LB)  FIRED  BOILER  UNDER CONSTRUCTION IN BELMONT, WEST VIRGINIA. BABCOCK
AND WILCOX  IS  SUPPLYING  A LIME F60 SYSTEM DESIGNED TO REMOVE 90X OF THE
BOILER  FLUE  GAS  S02.  THE EMISSION CONTROL SYSTEM ON THIS UNIT WILL INCLUDE
AN ESP  UPSTREAM  OF FOUR  SPRAY TOWER ABSORBERS. A FLUE GAS BYPASS SYSTEM
WILL PROVIDE REHEAT OF THE CLEANED 6*5 BEFORE IT IS DISCHARGED THROUGH A
1200 FOOT PLACITE  LINED  STACK. THE SYSTEM WILL OPERATE IN AN OPEN WATER
LOOP. F60 SYSTEM START UP IS  EXPECTED IN OCTOBER 1980.
MONTANA  POWER
COLSTRIP
1
NEW        360.0  MW  (GROSS)
           360.0  MW  (ESC)
COAL
   .77 XS  SUBBITUMINOUS
LIME/ALKALINE  FLYASH
COMBUSTION  EQUIP ASSOCIATES
ENERGY CONSUMPTION:   3.3X
STATUS 1    STARTUP   9/75
COLSTRIP  1 OF MONTANA  POWER  IS  A  SUBBITUMINOUS COAL (0.77X S, 8843 6TU/LB>
FIRED UNIT LOCATED  IN  COLSTRIP. MONTANA.  ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A  LIME/ALKALINE  FLYASH  FGD  SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS.  THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON  HIST ELIMINATORS,  A STEAM TUBE REHEATER, AND A 500
FOOT STACK. THE  UNSTABILIZED SLUDGE  IS DISPOSED IN AN ON-SITE LINED POND
THE WATER LOOP IS CLOSED. OPERATIONS  INITIALLY BEGAN IN SEPTEMBER 1975.
MONTANA POWER
COLSTRIP
2
NEW       360.0 MW  (GROSS)
          360.0 MW  (ESC)
COAL
  .77 XS  SUBBITUMINOUS
LIME/ALKALINE  FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION:   3.3X
STATUS 1     STARTUP   5/76
COLSTRIP 2 Of MONTANA POWER  IS  A  SUBBITUMINOUS COAL (C.77X S, 8843 BTU/LB)
FIRED UNIT LOCATED  IN COLSTRIP, MONTANA.  ADL/COMBUSTION EQUIPMENT ASSOCI-
ATES SUPPLIED A LIME/ALKALINE FLYASH  FGD  SYSTEM CONSISTING OF THREE
VENTURI SCRUBBER/SPRAY TOWER ABSORBER TRAINS.  THE ABSORBERS ARE FOLLOWED
BY HORIZONTAL CHEVRON MIST ELIMINATORS.  A STEAM TUBE REHEATER, AND A SCO
FOOT STACK. THE UNSTABILIZED SLUDGE IS DISPOSED IN AN ON-SITE LINED POND
THE WATER LOOP IS CLOSED. OPERATIONS  INITIALLY BEGAN IN MAY 1976.       *
MONTANA POWER
COLSTRIP
3
NEW       700.0 NW  (GROSS)
          700.0 HW  (ESC)
COAL
  .70 XS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: *«*«X
STATUS 2     STARTUP  5/83
MONTANA POWER'S COLSTRIP 3  IS  A  LOW  SULFUR  COAL  (0.7X S,  8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION  IN COLSTRIP,  MONTANA.  A CONTRACT  HAS BEEN
AWARDED TO ADL/COHBUSTION EQUIPMENT ASSOCIATES FOR A  LIME/ALKALINE FLYASH
FGD SYSTEM ON THIS UNIT.  START  UP IS  SCHEDULED  FOR  1983.
                                                 26

-------
                                               EPA  UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS Of  FGD SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
MONTANA POWER
COLSTRIP
4
NEW       700.0 MW (GROSS)
          700.0 MW (ESC)
COAL
  .70 XS
LIKE/ALKALINE FLVASH
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: *«**X
STATUS 2     STARTUP  3/84
MONTANA POWER'S COLSTRIP 4  IS A  LOU  SULFUR  COAL (0.7X S, 8800 BTU/LB)
FIRED UNIT UNDER CONSTRUCTION IN  COLSTRIP,  MONTANA.  A CONTRACT HAS BEEN
AWARDED TO ADL/COMBUST10N EQUIPMENT  ASSOCIATES  FOR A LIME/ALKALINE FLYASH
FED SYSTEM ON THIS UNIT.  START  UP IS  SCHEDULED FOR  1984.
MONTANA-DAKOTA UTILITIES
COYOTE
1
NEW       440.0 MM  (GROSS)
          440.0 MW  (ESC)
COAL
  .87 XS  LIGNITE
SODIUM CARBONATE/SPRAY  DRYING
MHEELABRATOR-FRYE/R.I.
ENERGY CONSUMPTION:   1.1X
STATUS 2     STARTUP  3/81
COYOTE 1 IS A CYCLONE FIRED  PULVERIZED  LIGNITE (0.87X S, 70SO BTU/LB)
BOILER UNDER CONSTRUCTION  IN BEULAH,  NORTH DAKOTA. THIS UNIT IS JOINTLY
OWNED BY FIVE UTILITIES. WITH MONTANA-DAKOTA UTILITIES BEING THE MAJOR
OWNER AND CONSTRUCTOR.  A SODIUM  CARBONATE DRV fGD SYSTEM DESIGNED TO
REMOVE 70X OF THE  S02 IS BEING SUPPLIED BY WHEELABRATOR-FRYE AND ROCKWELL
INTERNATIONAL. THE SPRAY DRYER/6A6HOUSE SYSTEM IS SCHEDULED TO START UP
IN 1981.
HUSCATINE POWER I WATER
NUSCATINE
9
NEW       166.0 MW  (GROSS)
          166.0 MW  (ESC)
COAL
 3.00 XS  BITUMINOUS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:   4.6X
STATUS 3      STARTUP   9/82
HUSCATINE 9 IS A PULVERIZED  BITUMINOUS COAL (31 S, 11,200 BTU/LB) fIRED
UNIT PLANNED BY MUSCATINE  POWER  AND WATER TO BE LOCATED IN MUSCAT1NE,
IOWA. A CONTRACT WAS  AWARDED TO  RESEARCH COTTRELL FOR A LIMESTONE UNIT  FOR
EMISSION CONTROL.  THE  FGD  SYSTEM WILL FEATURE AN ESP, TWO 100X CAPACITY
TOWERS, STEAM COIL REHEAT, A CLOSED WATER LOOP. AND FORCED OXIDATION OF
THE SLUDGE BEFORE  LANDFILL.  THE  DESIGN S02 REMOVAL WILL BE 94X. START UP
WILL TAKE PLACE IN 1982.
NEBRASKA PUBLIC POWER  DISTRICT  FOSSIL  III 1 IS A PULVERIZED SUBBITUMINOUS  COAL  (0.36X S,  8500 BTU/LB)
FOSSIL III
1
NEW       650.0 MW  (GROSS)
          650.0 MW  (ESC)
COAL
   .36 XS  SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••«*X
STATUS 6      STARTUP   3/87
FIRED UNIT  PLANNED  BY THE NEBRASKA PUBLIC POWER DISTRICT TO BE LOCATED
NEAR SARGENT,  NEBRASKA.   THE  UTILITY IS CONSIDERING A DRY SCRUBBING
FGD PROCESS TO CONTROL EMISSIONS FROM THE 650 MW BOILER.  STARTUP  FOR
THE UNIT  IS SCHEDULED FOR 1987.
NEVADA  POWER
HARRY ALLEN
1
NEW        500.0  MW  (GROSS)
           500.0  MW  (ESC)
COAL
••*•* XS
PROCESS NOT SELECTED
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION: *****
STATUS  6      STARTUP   6/86
NEVADA  POWER'S  HARRY  ALLEN 1 IS A PLANNED COAL FIRED  UNIT  TO  BE  LOCATED  IN
LAS  VEGAS,  NEVADA. THE UTILITY IS CONSIDERING A HOT  SIDE ESP  IN  CONJUNC-
TION  WITH  AN  FGD  SYSTEM. SPECIFICATIONS HAVE NOT YET  BEEN  PREPARED.  START
UP  IS SCHEDULED FOR JUNE 1986.
NEVADA  POWER
HARRY ALLEN
2
NEW        500.0 MW (GROSS)
           500.0 MW (ESC)
COAL
***** XS
PROCESS NOT  SELECTED
VENDOR  NOT SELECTED
ENERGY  CONSUMPTION: ****!
STATUS  6      STARTUP  6/87
 NEVADA  POWER'S HARRY ALLEN 2 IS A PLANNED COAL  FIRED  UNIT  TO  BE  LOCATED IN
 LAS  VEGAS,  NEVADA. THE UTILITY IS CONSIDERING A HOT  SIDE  ESP  IN  CONJUNC-
 TION WITH AN FGD SYSTEM. SPECIFICATIONS HAVE NOT YET  BEEN  PREPARED.  START
 UP  IS SCHEDULED FOR JUNE 1987.

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  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980
                                               SECTION 2
                                         STATUS  OF  FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 NEVADA POWER
 HARRY ALLEN
 3
 NEW
 COAL
500.0 MW (GROSS!
500.0 MW (ESC)
                     NEVADA POWER'S  HARRY  ALLEN 3  IS  A PLANNED COAL FIRED UNIT TO BE LOCATED  IN
                     LAS VEGAS,  NEVADA.  THE  UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
                     TION WITH AN  FGD  SYSTEM.  SPECIFICATIONS HAVE NOT VET BEEN PREPARED. START
                     UP IS SCHEDULED  FOR JUNE  1988.
 PROCESS NOT SELECTED
 VENDOR  NOT SELECTED
 ENERGY  CONSUMPTION: ****X
 STATUS  6     STARTUP  6/86
NEVADA POWER
HARRY ALLEN
4
NEW 500. 0 MW (GROSS)
500.0 MW (ESC)
NEVADA POWER'S HARRY ALLEN * IS A PLANNED COAL FIRED UNIT TO BE LOCATED IN
LAS VEGAS, NEVADA. THE UTILITY IS CONSIDERING A HOT SIDE ESP IN CONJUNC-
TION WITH AN FGD SYSTEK. SPECIFICATIONS HAVE NOT YET BEEN PREPARED. START
UP IS SCHEDULED FOR JUNE 1989.
 COAL
       XS
 PROCESS  NOT  SELECTED
 VENDOR  NOT  SELECTED
 ENERGY  CONSUMPTION: *****
 STATUS  6      STARTUP  6/89
 NEVADA  POWER
 REID  GARDNER
 1
 RETROFIT   125.0 MW  (GROSS)
           125.0 MW  (ESC)
 COAL
   .50 XS   BITUMINOUS
 SODIUM  CARBONATE
 COMBUSTION  EQUIP ASSOCIATES
 ENERGY  CONSUMPTION:  ****!
 STATUS  1      STARTUP   5/74
                     REID GARDNER 1 IS A  WET BOTTOM  LOW  SULFUR COAL (0.5X S, 12,450 BTU/LB)
                     FIRED UNIT OWNED BY  NEVADA  POWER, LOCATED IN MOAPA, NEVADA. A SODIUM CAR-
                     BONATE-BASED (TRONA) SCRUBBING  SYSTEM  BY  ADL/COMBUSTION EQUIPMENT ASSOCI-
                     ATES CONSISTS OF ONE MODULE  CONTAINING TWIN  VARIABLE THROAT VENTURIS FOL-
                     LOWED BY A SEPARATOR IN SERIES  WITH  A  SINGLE STAGE PEFORATED PLATE WASH
                     TOWER. PRIMARY PARTICULATE  CONTROL  IS  PROVIDED BY UPSTREAM MULTICLONES.
                     A RADIAL VANE MIST ELIMINATOR PRECEDES AN INDIRECT STEAM HOT AIR PEHEATER
                     AND A 200 FOOT STACK. THE SYSTEM OPERATES IN AN OPEN WATER LOOP, AND THE
                     SLUDGE IS DISPOSED IN AN ON-SITE CLAY  LINED  SOLAR EVAPORATION POND. THE
                     DESIGN S02 REMOVAL EFFICIENCY IS 901.  THE SYSTEM HAS BEEN OPERATIONAL
                     SINCE MARCH 1974.
NEVADA  POWER
REID  GARDNER
2
RETROFIT   125.0  MU  (GROSS)
           125.0  MW  (ESC)
COAL
  .50 XS   BITUMINOUS
SODIUM  CARBONATE
COMBUSTION  EQUIP ASSOCIATES
ENERGY  CONSUMPTION:  ••••X
STATUS  1      STARTUP   4/74
                     REID GARDNER 2 IS A  WET BOTTOM  LOW  SULFUR  COAL (O.SX «, 12,450 BTU/LB)
                     FIRED UNIT OWNED BY  NEVADA POWER, LOCATED  IN  MOAPA, NEVADA. A SODIUM CAR-
                     BONATE-BASED (TRONA) SCRUBBING  SYSTEM  BY  ADL/COMBUSTION EQUIPMENT ASSOCI-
                     ATES CONSISTS OF ONE MODULE CONTAINING TWIN  VARIABLE THROAT VENTURIS FOL-
                     LOWED BY A SEPARATOR IN SERIES  WITH  A  SINGLE  STAGE  PEFORATED PLATE WASH
                     TOWER. PRIMARY PARTICIPATE CONTROL  is  PROVIDED BY UPSTREAM MULTICLONES.
                     A RADIAL VANE MIST ELIMINATOR PRECEDES AN  INDIRECT  STEAM HOT AIR flEHEATER
                     AND A ZOO FOOT STACK. THE SYSTEM OPERATES  IN  AN OPEN WATER LOOP, AND THE
                     SLUDGE IS DISPOSED IN AN ON-SITE CLAY  LINED  SOLAR EVAPORATION POND. THE
                     DESIGN SO? REMOVAL EFFICIENCY IS 90X.  THE  SYSTEM HAS BEEN OPERATIONAL
                     SINCE APRIL 1974.
NEVADA POWER
REID GARDNER
3
NEW       125.0 MW  (GROSS)
          125.0 MW  (ESC)
COAL
  .50 XS  BITUMINOUS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION: ****X
STATUS 1     STARTUP  6/76
                     REID GARDNER 3 IS A WET BOTTOM LOW  SULFUR  COAL  (O.SX  S, 12,450 BTU/LB)
                     FIRED UNIT OWNED BY NEVADA POWER, LOCATED  IN  MOAPA,  NEVADA. A SODIUM CAR-
                     BONATE-BASED (TRONA) SCRUBBING SYSTEM BY ADL/COMBUST ION EQUIPMENT ASSOCI-
                     ATES CONSISTS OF ONE MODULE CONTAINING  TWIN VARIABLE  THROAT VENTURIS FOL-
                     LOWED BY A SEPARATOR IN SERIES WITH A SINGLE  STAGE PEFORATED PLATE WASH
                     TOWER. PRIMARY PARTICULATE CONTROL  IS PROVIDED  BY UPSTREAM MULTICLONES.
                     A  RADIAL VANE MIST ELIMINATOR PRECEDES  AN  INDIRECT STEAM HOT AIR REHEATER
                     AND  A 200 FOOT STACK. THE SYSTEM OPERATES  IN  AN OPEN  WATER LOOP, AND THE
                     SLUDGE IS DISPOSED IN AN ON-SITE CLAY LINED SOLAR EVAPORATION POND. THE
                     DESIGN S02 REMOVAL EFFICIENCY IS 90T. THE  SYSTEM HAS  BEEN OPERATIONAL
                     SINCE JUNE 1976.
NEVADA POWER
REID GARDNER
4
NEW       250.0 MW (GROSS)
          25P.O MW (ESC>
COAL
  .75 XS
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
ENERGY CONSUMPTION:  •••*:
STATUS 4     STARTUP  4/83
                     REID  GARDNER 4 OF NEVADA POWER IS A COAL  (0.75X  S,  12,450 BTU/LB)  FIRED
                     UNIT  PLANNED FOR LOCATION IN MOAPA, NEVADA.   A LETTER  OF  INTENT HAS BEEN
                     SIGNED WITH COMBUSTION EQUIPMENT ASSOCIATES  TO PROVIDE A  SODIUM CARBONATE
                     FGD  SYSTEM.  A BAGHOUSE WILL PRECEED  THE  FGD  SYSTEM FOR PARTICLE
                     CONTROL' CONSTRUCTION IS EXPECTED TO  BEGIN IN 1980, AND START UP IS
                     EXPECTED IN 1983.
                                                 28

-------
                                               EPA UTILITY F60  SURVEY:  JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
                                                                   ABSTRACT
NEVADA POWER
EARNER VALLEY
1
NEW       295.0 MW  (GROSS)
          295.0 MW  (ESC)
COAL
 1.15 XS  SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 5      STARTUP   6/85
                  NEVADA POWER'S WARNER VALLEY  1  IS  A  PLANNED COAL (1.15X S) FIRED  UNIT  TO
                  BE  LOCATED IN ST. GEORGE,  UTAH.  THE UTILITY IS CURRENTLY EVALUATING BIDS
                  FOR AN FGD SYSTEM.  NO  ANNOUNCEMENTS HAVE VET BEEN MADE CONCERNING  THE
                  EMISSION CONTROL STRATEGY  FOR THIS  UNIT.   START UP IS EXPECTED  IN JUNE
                  1985.
NEVADA POWER
EARNER VALLEY
2
NEW       295.0 MW  (GROSS)
          295.0 MW  (ESC)
COAL
 1.15 XS  SUBBITUMINOUS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ****X
STATUS 5     STARTUP   6/86
                  NFVADA POWER'S WARNER  VALLEY  2  IS A PLANNED COAL (1.15X  S>   FIRED  UNIT TO
                   TO BE LOCATED IN  ST.  GEORGE, UTAH. THE UTILITY IS CURRENTLY EVALUATING
                  FOR AN FGD SYSTEM. NO  ANNOUNCEMENTS HAVE YET BEEN MADE CONCERNING  THE
                  EMISSION CONTROL STRATEGY  FOR THIS UNIT. START UP IS  EXPECTED  IN  JUNE
                  1986.
NEW YORK STATE  ELEC  &  GAS
SOMERSET
1
NEW        625.0 MU  (GROSS)
           625.0 MW  (ESC)
COAL
 2.29 XS   BITUMINOUS
LIMESTONE
VENDOR  NOT  SELECTED
ENERGY  CONSUMPTION:  ****X
STATUS  S      STARTUP  6/84
                  THE SOMERSET  1 UNIT  OF  THE  NEW YORK STATE ELECTRIC t  6AS  CORP.  IS A
                  PULVERIZED COAL  BOILER  LOCATED IN SOMERSET, NEW YORK.   THE  BOILER
                  GENERATES A FLUE  GAS FLOW OF 2,227,000 ACFM AND FIRES  A BITUMINOUS COAL
                  WITH AN AVERAGE  SULFUR  CONTENT OF 2.2X AND AN AVERAGE  HEAT  CONTENT OF
                  12,400 BTU/LB.   A COLD  SIDE ESP WITH A DESIGN EFFICIENCY  OF 99.771! WILL
                  PROVIDE THE PRIMARY  PARTICULATE REMOVAL.  A LIMESTONE  ABSORBER  WITH A
                  DESIGN REMOVAL EFFICIENCY OF 90X WILL BE USED FOR  S02  REMOVAL.   THE
                  SYSTEM WILL OPERATE  IN  A CLOSED LOOP MODE.  THE SLUDGE IS TO BE DEWATERED
                  AND STABILIZED BEFORE BEING LANDFILLED. OPERATIONS ARE SCHEDULED FOR 1984.
NIAGARA  MOHAWK  POWER  COOP
CHARLES  R.  HUNTLEY
66
RETROFIT  100.0 *w  (GROSS;
           100.0 MW  (ESC)
COAL
 1.80  XS
A8UEOUS  CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
ENERGY CONSUMPTION: ****X
STATUS 2     STARTUP   4/82
                  CHARLES R. HUNTLEY  66 OF  NIAGARA POWER COOP  IS  A  PULVERIZED COAL (1.8X S,
                  12,500 BTU/LB)  FIRED  UNIT LOCATED IN BUFFALO, NEW YORK.  A CONTRACT WAS
                  AWARDED TO ROCKWELL INTERNATIONAL FOR THE DESIGN  AND  INSTALLATION OF A 9CX
                  EFFICIENT RETROFIT  AQUEOUS CARBONATE FGD SYSTEM WHICH WILL PRODUCE ELEMEN-
                  TAL SULFUR AS  AN  END  PRODUCT. FUNDS ARE BEING PROVIDED BY THE U.S.EPA AND
                  THE EMPIRE STATE  ELECTRIC ENERGY RESEARCH CORP. A SPRAY DRYER WILL BE
                  FOLLOWED BY  TWO BANKS OF  EIGHT CYC LOWES AN ESP, AND  A 200 FOOT STEEL LINED
                  STACK. THE WATER  LOOP WILL BE OPEN. START UP OF THE  FGD SYSTEM WILL BE IN
                  1982.
NORTHERN  INDIANA PUB SERVICE
DEAN  H. MITCHELL
11
RETROFIT   116.0 MW (GROSS)
           115.0 RW (ESC)
COAL
  $.50 XS
WELLNAN LORD
DAVY  MCKFE
ENERGY CONSUMPTION
STATUS  1
       12.U
STARTUP  7/76
                  NORTHERN  INDIANA  PUBLIC SERVICE'S DEAN H.  MITCHELL 11 IS A COAL (3.5X S,
                  11,000  BTU/LB)  FIRED UNIT LOCATED IN GARY, INDIANA. A RETROFIT UELLMAN
                  LORD  FGD  SYSTEM BY DAVY POWERGAS HAS BEEN  OPERATING ON THIS UNIT SINCE
                  JULY  1976.  AN  ESP IS FOLLOWED BY A VARIABLE  THROAT VENTURI SCRUBBER
                  AND A TRAY  TOWER  ABSORBER (90X DESIGN  S02  REMOVAL EFFICIENCY). A DIRECT
                  COMBUSTION  RAISES THE CLEANED GAS TEMPERATURE  SO DEG F BEFORE THE GAS
                  IS DISCHARGED  THROUGH A 166 FOOT STAINLESS STEEL AND FRP LINED STACK.
                  ELEMENTAL SULFUR  AND SULFATE IS PRODUCED BY  THE PROCESS DEVELOPED BY
                  ALLIED  CHEMICAL.  THE SYSTEM OPERATES IN  A  CLOSED WATER LOOP MODE.
NORTHERN  INDIANA PUB SERVICE   SCHAHFER  17  OF  NORTHERN INDIANA PUBLIC  SERVICE  IS A 3.2X SULFUR COAL  FIRED
 SCHAHFER
 17
 NEW        421.0 MW (GROSS)
           421.0 HW (ESC)
 COAL
  3.20 XS  BITUMINOUS
 DUAL  ALKALI
 FMC
 ENERGY CONSUMPTION: ****X
 STATUS 3     STARTUP  6/83
                   UNIT  PLANNED FOR CONSTRUCTION IN UHEATFIELD, INDIANA. THE UTILITY HAS
                   AWARDED  A CONTRACT TO FMC FOR THE  INSTALLATION OF A DUAL ALKALI
                   FGD SYSTEM AT THIS UNIT. PARTICULATE  MATTER  WILL BE COLLECTED BY  AN  ESP
                   AND THE  SYSTEM WILL INCLUDE A REHEATED.   START UP OF THIS UNIT IS
                   SCHEDULED FOR JUNE 1983.
                                                  29

-------
  EPA UTILITY  FGD  SURVEY:  JULY  - SEPTEMBER 1980
                                               SECTION 2
                                         STATUS OF F6D SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 NORTHERN INDIANA PUB  SERVICE
 SCHAHFER
 IB
 NEW       421.0 NW  (GROSS)
           421.0 MW  
-------
                                              EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980
                                              SECTION  2
                                        STATUS OF  FGD  SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
PACIFIC POWER ( LIGHT
JIN BRIDGER
1
RETROFIT  550.0 MW (GROSS)
          S5D.O MW (ESC)
COAL
  .56 XS  SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *«**X
STATUS %     STARTUP  0/88
PACIFIC POWER AND LIGHT'S JIM BRID6E8  1  IS A  DRV  BOTTOM  PULVERIZED SUB-
BITUMINOUS COAL (O.S6XS, 9300 BTU/LB.) FIRED  BOILER  LOCATED  IN  ROCK
SPRINGS, WYOMING.  THE UTILITY IS EVALUATING  BIDS FOR  A  RETROFIT FGD
SYSTEM FOR SO? CONTROL.  A WET,  SODIUM CARBONATE  SYSTEM,  WHICH  TREATS
2,700,000 ACFM OF FLUE GAS, IS BEING PLANNED.   A  COLD-SIDE  ESP  IS CURRENT-
LY IN OPERATION FOR PRIMARY PARTICULATE  CONTROL.   STARTUP IS SCHEDULED
FOR 1988.
PACIFIC POWER t LIGHT
JIM BRID6ER
Z
RETROFIT  550.0 HW (GROSS)
          550.0 MW (ESC)
COAL
  .56 XS  SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  ••««!
STATUS 5     STARTUP  0/84
PACIFIC POWER AND LIGHT'S JIM BRIDGED  2  IS  A  DRV  BOTTOM PULVERIZED SUB-
BITUMINOUS COAL  C0.56XS, 9300 BTU/LB.)  FIRED  BOILER LOCATED IN ROCK
SPRINGS, WYOMING.  THE UTILITY  IS  EVALUATING  BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL.  A  WET,  SODIUM  CARBONATE  SYSTEM, WHICH TREATS
2,700,000 ACFM OF FLUE GAS,  IS  BEING PLANNED.  A  COLD-SIDE ESP IS CURRENT-
LY IN OPERATION  FOR PRIMARY  PARTICULATE  CONTROL.   STARTUP IS SCHEDULED
FOR 1984.
PACIFIC POWER ( LIGHT
JIM BRIDGER
3
RETROFIT  SSO.O MW  (GROSS)
          5SO.O MW  (ESC)
COAL
  .56 XS  SUBBITUMIOUS
SODIUM CARBONATE
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  ««**X
STATUS 5     STARTUP  0/86
PACIFIC POWER AND LIGHT'S  JIM  BRIDGED  3 IS A DRV BOTTOM PULVERIZED SUB-
BITUMINOUS COAL  (0.56XS, 9300  BTU/LB.) FIRED BOILER LOCATED IN ROCK
SPRINGS, WYOMING.  THE UTILITY IS EVALUATING BIDS FOR A RETROFIT FGD
SYSTEM FOR S02 CONTROL.  A WET,  SODIUM CARBONATE SYSTEM, WHICH TREATS
2,700,000 ACFW OF FLUE GAS,  IS BEING PLANNED.  A COLD-SIDE ESP IS CURRENT-
LY IN OPERATION  FOR  PRIMARY  PARTICULATE CONTROL.  STARTUP IS SCHEDULED
FOR 1986.
PACIFIC POWER t LIGHT
JIM BRIDGER
4
HEW       550.0 MW  (GROSS)
          550.0 MW  (ESC)
COAL
  .56 XS  SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION  DIVISION,  UOP
ENERGY CONSUMPTION:   .21
STATUS 1      STARTUP   9/79
PACIFIC POWER AND LIGHT'S  JIM  BRIDGES 4 IS A DRV BOTTOM PULVERIZED
SUBBITUMINOUS COAL  (0.56X  S,  9300 BTU/LB) FIRED BOILER LOCATED IN
ROCK SPRINGS, WYOMING.  A 91X  EFFICIENT SODIUM CARBONATE FGD SYSTEM FOR
THIS UNIT WAS SUPPLIED  BY  THE  AIR CORRECTION DIVISION OF UOP. A COLO
SIDE ESP TREATS  2,720,000  ACFM OF FLUE GAS, FOLLOWED BY THREE SIEVE
TRAY ABSORBERS.  THE  SYSTEM OPERATES IN A CLOSED WATER LOOP MODE.  A
SYSTEM CHECK OUT WAS  CONDUCTED IN JULY 1979, AND OPERATIONS BEGAN
IN SEPTEMBER 1979.
PENNSYLVANIA  POWER
BRUCE MANSFIELD
1
NEW       917.0  MW  (GROSS)
          917.0  HW  (ESC)
COAL
 3.00 XS  BITUMINOUS
LIME
CHEMICO DIVISION,  ENVIROTECH
ENERGY CONSUMPTION:   6.OX
STATUS 1      STARTUP  12/75
BRUCE MANSFIELD  1  OF  PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED  DRAFT
BOILER  FIRING  PULVERIZED  COAL (3.OX S, 11,500 BTU/LB) IN  SHIPPIN6PORT,
PENNSYLVANIA.  A  CHEMICO  TH10SORBIC LIME FGD SYSTEM WAS DESIGNED  TO  REMOVE
FLYASH  AND  S02 (92.1X)  FROM 3,350,000 ACFM OF FLUE GAS. THE FGD  SYSTEM
CONSISTS  OF  SIX  VARIABLE  THROAT VENTURI SCRUBBERS FOLLOWED BY  SIX  FIXED
THROAT  VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT  COMBUS-
TION REHEATERS,  AND  A 950 FOOT FLAKE6LASS STACK SHARED BY UNITS  1  AND 2.
THE WATER LOOP IS  OPEN,  AND THE CALCILOX STABILIZED SLUDGE IS  DISPOSED  IN
AN OFF  SITE  LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE DECEMBER
1975.
PENNSYLVANIA  POWER
BRUCE MANSFIELD
2
NEW        917.0  MW  (GROSS)
           917.0  MW  (ESC)
COAL
 3.00 XS   BITUMINOUS
LIME
CHEMICO  DIVISION*  ENVIROTECH
ENERGY  CONSUMPTION:  6.OX
STATUS  1      STARTUP   7/77
BRUCE MANSFIELD  2  OF  PENNSYLVANIA POWER IS A SUPERCRITICAL, BALANCED  DRAFT
BOILER  FIRING PULVERIZED COAL (3.OX S, 11,500 BTU/LB) IN  SHIPPINGPORT,
PENNSYLVANIA. A  CHEMICO THIOSORBIC LIME FGD SYSTEM WAS DESIGNED  TO  REMOVE
FLYASH  AND  SO? (92.1X) FROM 3,350,000 ACFM OF FLUE GAS. THE F6D  SYSTEM
CONSISTS  OF  SIX  VARIABLE THROAT VENTURI SCRUBBERS FOLLOWED BY  SIX  FIXED
THROAT  VENTURI ABSORBERS, HORIZONTAL MIST ELIMINATORS, TWO DIRECT  COMBUS-
TION REHEATERS,  AND  A 950 FOOT FLAKECLASS STACK SHARED BY UNITS  1  AND 2.
THE WATER LOOP IS  OPEN, AND THE CALCILOX STABILIZED SLUDGE IS  DISPOSED IN
AN OFF  SITE  LANDFILL. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY  1977.
                                                  31

-------
  EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980
                                               SECTION I
                                         STATUS Of F6D SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 PENNSYLVANIA POWER
 9RUCE MANSFIELD
 J
 NEW       917.0 MW (GROSS)
           917.0 NW 
-------
                                               EPA UTILITY FGO SURVEY: JULY -  SEPTEMBER  1980
                                              SECTION 2
                                        STATUS OF F60 SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
PUBLIC SERVICE INDIANA
GIBSON
5
NEW       450.0 Mw  (GROSS)
          6SO.O MW  
COAL
   .80 XS   SUBBITUMINOUS
riELLMktt LORD
DAVY HCKEE
ENER6Y  CONSUMPTION:  4.6X
STATUS  1      STARTUP  8/78
SAN JUAN  2  OF  PUBLIC  SERVICE OF NEW MEXICO IN WATERFLOW,  NEW  MEXICO IS A
COAL  (0.8X  S,  8100  BTU/LB) FIRED BOILER WHICH SUPPLIES  1,319,000  ACFH OF
FLUE  GAS  TO  A  RETROFIT WELLMAN LORD fGD SYSTEM BY DAVY  POVERGAS.  THE  EMIS-
SION  CONTROL SYSTEM,  OPERATIONAL SINCE AUGUST 1978,  CONSISTS  OF A HOT
SIDE  ESP  FOLLOWED BY  FOUR (ONE SPARE) VENTURI SCRUBBER/SPRAY  TOWER ABSOR-
BER TRAINS  WHICH WERE DESIGNED TO REMOVE 85X OF THE  FLUE  GAS  S02. AN  IN-
DIRECT HOT  AIR REHEATER PRECEDES A BRICK LINED STACK. END PRODUCT ELEMEN-
TAL SULFUR  IS  PRODUCED BY THE ALLIED CHEMICAL PROCESS.  THE WATER  LOOP IS
CLOSED.
PUBLIC  SERVICE  OF NEW MEXICO
SAN  JUAN
3
NEW        534.0 MU (GROSS)
           534.0 MU (ESC)
COAL
   .80 XS  SUBBITUMINOUS
WELLMAN  LORD
DAVY MCKEE
ENERGY  CONSUMPTION:  3.6X
STATUS  1     STARTUP 12/79
SAN  JUAN  3  IS  A  COAL (0.8X S, 8100 BTU/L8) FIRED  UNIT  OF  THE PUBLIC
SERVICE  OF  NEW MEXICO AND IS LOCATED IN WATERFLOW,  NEW MEXICO. THE FGD
SYSTEM,  SUPPLIED BY DAVY POWERGAS IS AN INTEGRATION OF THE  WELLNAN
LORD  502  RECOVERY PROCESS AND ALLIED CHEMICAL'S S02 REDUCTION TO SULFUR
PROCESS.  FIVE  (OKE SPARE) VENTURI SCRUBBER/SPRAY  TOWER ABSORBER (90X DE-
SIGN  SO?  REMOVAL) TRAINS FOLLOW A HOT SIDE ESP. AN  INDIRECT HOT AIR
REHEATER  BOOSTS  THE GAS TEMPERATURE 50 DEG F.  THE SYSTEM  OPERATES
IN A  CLOSED  WATER LOOP MODE. OPERATIONS COMMENCED IN DECEMBER 1979.
 PUBLIC  SERVICE OF NEW MEXICO
 SAN  JUAN
 t
 NEW        534.0 MU (GROSS)
           534.0 HU (ESC)
 COAL
   .80 XS  SUBBITUHINOUS
 rfELLMAN LORD
 DAVY MCKEE
 ENERGY  CONSUMPTION:  3.6X
 STATUS  2     STARTUP  6/82
 SAN  JUAN 4 IS A COAL (0.8X S, 8100 BTU/LB)  FIRED  UNIT OF THE PUBLIC SER-
 VICE  OF  NEW MEXICO UNDER CONSTRUCTION  IN  WATERFLOW,  NEW MEXICO. THE F6D
 SYSTEM BEING SUPPLIED BY DAVY POWERGAS  IS AN  INTEGRATION OF THE WELLMAN
 LORD  S02 RECOVERY PROCESS AND ALLIED CHEMICAL'S  S02  REDUCTION TO SULFUR
 PROCESS. FIVE (ONE SPARE) VENTURI SCftUBBER/SPRAY  TOWER ABSORBER (90X DE-
 SIGN  SOZ REMOVAL) TRAINS WILL FOLLOW A  HOT  SIDE  ESP. AN INDIRECT HOT MR
 REHEATER WILL BOOST THE GAS TEMPERATURE 50  DEG  F.  THE SYSTEM WILL OPERATE
 IN A  CLOSED WATER LOOP MODE. START UP  IS  EXPECTED  IN JUNE 1982.
 PWR  AUTHORITY OF STATE OF NY
 FOSSIL

 NEW        700.0 MU (GROSS)
           700.0 MU (ESC)
 COAL
  3.00 XS
 PROCESS NOT SELECTED
 VENDOR NOT SELECTED
 ENERGY CONSUMPTION: «***X
 STATUS 6     STARTUP  4/87
 THE  POWER AUTHORITY OF NEW YORK  PLANS  A  NEW  3.OX SULFUR COAL FIRED UNIT
 WHICH WILL BE LOCATED AT THE  ARTHUR KILL FACILITY ON STATEN ISLAND. THE
 UTILITY IS PRESENTLY CONSIDERING  FGD  SYSTEMS FOR THIS UNIT. PUBLIC SERVICE
 COMMISSION HEARINGS ARE CURRENTLY  IN  PROGRESS.  START UP IS EXPECTED IN
 APRIL 1987.
                                                  33

-------
  EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS Of F60 SYSTEMS
 UNIT IDENTIFICATION
                                   ABSTRACT
 SALT RIVER  PROJECT
 CORONADO
 1
 NEW        350.0 HW (CROSS)
           280.0 MW (ESC)
 COAL
  1.00 XS  SUBBITUMINOUS
 LIMESTONE
 PULLMAN  KCLL06G
 ENERGY  CONSUMPTION:   4.31
 STATUS  1     STARTUP  11/79
 SALT  RIVER  PROJECT'S  CORONADO  1  IS  A  DRY  BOTTOM PULVERIZED SUBBITUHINOUS
 COAL  (1.0X  S,  8300  BTU/LB)  FIRED  BOILER  LOCATED IN ST. JOHNS.
 ARIZONA.  PULLMAN  KELLOGG  SUPPLIED THE TWO LIMESTONE HORIZONTAL WEIR SPRAV
 TOWERS WHICH REMOVES  82.SX  OF  THE S02 FROM THE FLUE GAS PASSED THROUGH
 THEM. VERTICAL HEIL HIST  ELIMINATORS  PRECEDE  A 500 FOOT STACK. A MINIMUM
 OF 20X BYPASS  PROVIDES  REHEAT. THE  WATER  LOOP IS AN OPEN MODEi AND THE
 UNSTABILIZED SLUDGE IS  DISPOSED  IN  AN UNLINED POND. START UP  HAS
 IN NOVEMBER 1979.
SALT RIVER  PROJECT
CORONADO
2
NEW       350.0 Mu  (GROSS)
          280.0 MU  (ESC)
COAL
 1.00 XS  SUBBITUMINOUS
LIMESTONE
PULLMAN KELL066
ENERGY CONSUMPTION:  4.3X
STATUS 1     STARTUP  7/80
SALT RIVER PROJECT'S CORONADO  2  IS  *  DRY  BOTTOM  PULVERIZED  SUBBITUMINOUS
COAL (1.0X S, 8300 BTU/LB)  FIRED  BOILER  LOCATED  IN  ST.  JOHNS,  ARIZONA.
PULLMAN KELLOGG  SUPPLIED  TWO LIMESTONE HORIZONTAL WEIR  SPRAY TONERS
WHICH REMOVES 82.SX  OF  THE  S02 FROM THE  FLUE  GAS PASSED THROUGH
THEM. VERTICAL HEIL  HIST  ELIMINATORS  PRECEDE  A 500  FOOT STACK. A  MINIMUM
OF 20X BYPASS PROVIDES  REHEAT. THE  WATER  LOOP IS AN OPEN MODE, AND  THE
UNSTABILIZED SLUDGE  IS  DISPOSED  IN  AN UNLINED POND. START UP WAS  IN
JULY 1980.
SALT RIVER PROJECT
CORONADO
3
NEW       400.0 HW (GROSS)
          280.0 MW (ESC)
COAL
  .60 XS  SUBBITUMINOUS
LIMESTONE
VENDOR NOT SELECTED
ENERGY CONSUHPTION:  3.8X
STATUS 6     STARTUP  0/89
CORONADO 3 IS A DRV BOTTOM  PULVERIZED  SUBBITUMINOUS  COAL  (.60*  S,  8300 BTU
/LB) FIRED UNIT PLANNED BY  SALT  RIVER  PROJECT  TO  BE  LOCATED  IN  ST. JOHN'S,
ARIZONA. THE UTILITY  IS PRESENTLY  CONSIDERING  THE INSTALLATION  OF  TWO HOR-
IZONTAL SPRAY TOWERS  UTILIZING LIMESTONE  AS  THE ABSORBENT. PLANS  FOR  AN
EMISSION CONTROL SYSTEM HAVE  NOT BEEN  FINALIZED.  THE SYSTEM  WILL  HAVE A
20X BYPASS REHEAT, AND THE  SLUDGE  WILL PROBABLY BE PONDED. SCHEDULED  OPER-
ATION DATE IS 1989.
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL
1
NEW       400.0 MW (GROSS)
          400.0 MW (ESC)
COAL
 1.7C XS  LIGNITE
LIMESTONE
BABCOCK ( WILCOX
ENERGY CONSUMPTION:  5.OX
SAN MIGUEL 1 OF THE  SAN MIGUEL ELECTRIC  COOP  IS  A  LIGNITE  (1.7X  S,  5000
BTU/LB) FIRED RADIANT BOILER UNDER CONSTRUCTION  IN SAN  MIGUEL, TEXAS.  THE
EMISSION CONTROL SYSTEM ON THIS UNIT WILL  CONSIST  OF  A  COLD  SIDE  ESP  FOL-
LOWED BY FOUR BABCOCK AND WILCOX 86X EFFICIENT LIMESTONE TCA  MODULES.
CHEVRON HIST ELIMINATORS WILL PRECEDE AN IN-LINE REHEATER  AND AN  ACID
BRICK LINED STACK. THE WATER LOOP WILL BE  CLOSED,  AND THE  DEWATERED  SLURRY
WILL BE MIXED WITH FLVASH BY RESEARCH COTTRELL AND DISPOSED  IN AN OFF  SITE
LANDFILL. OPERATIONS ARE SCHEDULED TO COMMENCE IN  NOVEMBER 1980.
STATUS 2
             STARTUP 11/80
SEMINOLE ELECTRIC
SEMINOLE
1
NEW       620.0 MW (GROSS)
          620.0 MW (ESC)
COAL
 2.7S XS  SUBBITUHINOUS
LIMESTONE
PEABODV PROCESS SYSTEMS
ENERGY CONSUMPTION: *****
STATUS 3     STARTUP  3/83
SEMINOLE 1 OF SEMINOLE ELECTRIC  IS A COAL  (2.75X  S,  11.700  BTU/LB)  FIRED
UNIT PLANNED FOR LOCATION IN PALATKA. FLORIDA. THE EMISSION  CONTROL  SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE F6D  SYSTEM. THE  F6» SYSTEM  WILL  BE
SUPPLIED BY PEABODV PROCESS SYSTEMS. START UP IS  EXPECTED IN MARCH
1983.
SEMINOLE ELECTRIC
SEMINOLE
2
NEW       620.0 MW (GROSS)
          620.0 MW (ESC)
COAL
 2.75 XS  SUBBITUMINOUS
LIMESTONE
PEABODV PROCESS SYSTEMS
ENERGY CONSUMPTION:  ***«X
STATUS 3     STARTUP  3/85
SEMINOLE 2 OF SEHINOLE ELECTRIC IS A COAL (2.7SX S,  11,700 BTU/LB)  FIRED
UNIT PLANNED FOR LOCATION IN PALATKA, FLORIDA. THE EMISSION CONTROL  SYSTEM
WILL CONSIST OF ESP'S AND A LIMESTONE FGD SYSTEM. THE F6D SYSTEM WILL BE
SUPPLIED BY PEABODY SYSTEMS. START Uf> 1$ EXPECTED IN MARCH 1985.
                                                 34

-------
                                               EPA  UTILITY  F6D SURVEY:  JULY - SEPTEMBER 1980
                                              SECTION  2
                                       STATUS OF  FGD  SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
SIERRA PACIFIC POWER
VALMV
2
NEW       376.0 MW (GROSS)
          276.0 MW (ESC)
COAL
***** XS
LINE/SPRAY DRYING
VENDOR NOT SELECTED
ENERGY CONSUMPTION: *****
STATUS 7     STARTUP  8/84
SIERRA PACIFIC POWER HAS PLANS TO CONSTRUCT  A  276  MU  UNIT  TO  BE  LOCATED
IN VALMY, NEVADA.  THE FOSTER WHEELER PULVERIZED COAL FIRED BOILER  AT  THE
VALHV 2 STATION WILL UTILIZE AN  FGD SYSTEM OR  FIRE LOU SULFUR COAL  TO
CONTROL S02 EMISSIONS.  IF FGD IS SELECTED,  A  DRV  LIME SYSTEM WILL  BE
THE UNIT IS SCHEDULED TO COMMENCE OPERATIONS IN AUGUST 1984.
SIKESTON BRD OF MUNICIPAL UTIL
SIKESTON
1
NEW       235.0 MW (GROSS)
          235.0 MU (ESC)
COAL
 2.80 XS
LIMESTONE
BABCOCK 8 WILCOX
ENERGY CONSUMPTION:   1.61
STATUS 2     STARTUP   3/81
THE SIKESTON BOARD OF MUNICIPAL  UTILITIES'  SIKESTON  1  IS  A PULVERIZED COAL
(2.8X S, 11,340 BTU/LB)  FIRED BOILER  UNDER  CONSTRUCTION  IN SIKESTON, MIS-
SOURI. BABCOCK AND WILCOX  IS SUPPLYING  AN EMISSION CONTROL SYSTEM CONSIST-
ING OF TWO ESP'S AND THREE  SOX CAPACITY LIMESTONE  VENTURI FGD MODULES. THE
CLEANED GAS WILL PASS THROUGH CHEVRON MIST  ELIMINATORS BEFORE EXITING A
450 FOOT FRP LINED FLUE  (A  SECOND  CARBON STEEL  LINED FLUE, USED FOR EMER-
GENCY BYPASS, IS ALSO IN THE STACK).  THE HATER  LOOP  WILL  BE OPEN, AND THE
SLUDGE WILL BE PONDED. START UP  IS SLATED FOR MARCH  1981.
SOUTH CAROLINA PUBLIC  SERVICE
CROSS
1
NEW       500.0 MW  (GROSS)
          500.0 MW  (ESC)
COAL
 1.60 XS  BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION: ****X
STATUS 3      STARTUP   3/85
SOUTH CAROLINA PUBLIC  SERVICE  HAS PLANS TO CONSTRUCT TWO NEW UNITS,
CROSS 1 AND 2, TO BE LOCATED  IN  CROSS,  SOUTH CAROLINA.  EACH 500 MW
BOILER WILL FIRE COAL  WITH  A  SULFUR  CONTENT RANGING BETWEEN 1.G AND 2.3X.
THE UTILITY HAS SIGNED A  CONTRACT WITH  PEABODY PROCESS SYSTEMS FOR THE
INSTALLATION OF A WET  LIMESTONE  SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS.  UNIT 1 IS  SCHEDULED  TO COMMENCE OPERATIONS IN MARCH 1985.
SOUTH CAROLINA  PUBLIC  SERVICE
CROSS
2
NEW        SOO.O MU  (GROSS)
           500.0 MW  (ESC)
COAL
 1.80 XS   BITUMINOUS
LIMESTONE
PEABODY PROCESS SYSTEMS
ENERGY CONSUMPTION:  *«**X
STATUS 3      STARTUP  11/83
SOUTH CAROLINA  PUBLIC  SERVICE  HAS PLANS TO CONSTRUCT TWO NEW UNITS.
CROSS 1 AND  2,  TO  BE  LOCATED IN CROSS, SOUTH CAROLINA.  EACH 500 MW
BOILER WILL  FIRE COAL  WITH A SULFUR CONTENT RANGING BETWEEN 1.0 AND 2.3X,
THE UTILITY  HAS SIGNED A  CONTRACT WITH PEABODY PROCESS SYSTEMS FOR THE
INSTALLATION OF A  WET  LIMESTONE SCRUBBING SYSTEM TO CONTROL S02
EMISSIONS.   UNIT 2 IS  SCHEDULED TO COMMENCE OPERATIONS IN NOVEMBER 1983.
SOUTH  CAROLINA  PUBLIC  SERVICE
UINYAH
2
NEK        280.0 MW  (GROSS)
           140.0 MW  (ESC)
COAL
 1.70  XS   BITUMINOUS
LIMESTONE
BABCOCK I  WILCOX
ENERGY CONSUMPTION:  1.1X
STATUS 1      STARTUP   7/77
WINTAH  2  OF  SOUTH CAROLINA PUBLIC SERVICE IS A PULVERIZED BITUMINOUS  COAL
(1.70X  S, 11,500 BTU/LB) FIRED UNIT LOCATED IN GEORGETOWN,  SOUTH  CAROLINA,
A COLD  SIDE  ESP AND A BABCOCK AND WILCOX VENTURI SCRUBBER/LIMESTONE TRAY
TOWER ABSORBER  TRAIN DESIGNED TO REMOVE 45X OF THE S02  FROM THE BOILER
FLUE GAS  MAKE UP THE EMISSION CONTROL SYSTEM ON THIS UNIT.  THE SYSTEM
OPERATES  IN  AN  OPEN WATER LOOP, AND THE SLUDGE IS DISPOSED  IN AN  ON-SITE
UNLINED POND. THIS SYSTEM HAS BEEN OPERATIONAL SINCE JULY 1977.
SOUTH  CAROLINA  PUBLIC  SERVICE
3
NEW        280.0 MW  (GROSS)
           280.0 MW  (ESC)
COAL
  1.70 XS
LIMESTONE
BABCOCK  t  WILCOX
ENERGY CONSUMPTION:  2.ix
STATUS 1      STARTUP  5/80
WINVAN  3  OF  SOUTH CAROLINA PUBLIC SERVICE IS A DRY BOTTOM BOILER  WHICH
FIRES  1.7X SULFUR COAL (11,500 BTU/LB) AND IS LOCATED  IN GEORGETOWN,
SOUTH  CAROLINA. AN ESP PRECEDES A BABCOCK AND WILCOX LIMESTONE  FGG
SYSTEM  AND AN INDIRECT STEAM REHEATER. THE SYSTEM OPERATES  IN  A CLOSED
WATER  LOOP MODE. OPERATIONS COMMENCED IN MAY 1980.
                                                  35

-------
  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980
                                              SECTION  2
                                        STATUS OF  FGD  SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 SOUTH CAROLINA PUBLIC SERVICE
 t
 NEU        280.0 MW  (GROSS)
           280.0 MW  <£SC>
 COAL
 1.75 XS  BITUMINOUS
 LIMESTONE
 AMERICAN AIR FILTER
 ENERGY CONSUMPTION:  2.tX
 STATUS 2     STARTUP  7/81
 SOUTH  CAROLINA  PUBLIC SERVICE'S UINYAH * IS A  BITUMINOUS COAL (1.70X  S,
 11,500 BTU/LB)  FIRED  UNIT UNDER CONSTRUCTION IN GEORGETOWN, SOUTH
 CAROLINA.  TWO AMERICAN AIR FILTER LIMESTONE SLURRY SPRAY TOWERS MILL
 FOLLOW AN  ESP.  THE  TEMPERATURE OF THE CLEANED GAS HILL BE RAISED BY AN
 INDIRECT STEAM  REHEATED.  THE SYSTEM HILL OPERATE IN A CLOSED WATER LOOP
 MODE.  START  UP  IS  EXPECTED IN JULY 1981.
 SOUTH  MISSISSIPPI  ELEC PWR
 R.O. MORROW,  SR.
 1
 NEW        200.0 MU (CROSS)
           124.0 MM (ESC)
 COAL
 1.30  XS   BITUMINOUS
 LIMESTONE
 ENVIRONEERING,  RILEY STOKER
 ENERGY CONSUMPTION:  5.5X
 STATUS 1      STARTUP  8/78
R.D. MORROW  1  OF  SOUTHERN  MISSISSIPPI ELECTRIC IS A PULVERIZED COAL (1.3X
S. 12.000  BTU/LB)  FIRED  UNIT IN HATTISBURG. MISSISSIPPI. THE EMISSION  CON-
TROL SYSTEM  FOR  THIS  UNIT  CONSISTS Of A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD  ABSORBER  SUPPLIED BY RILEY STOKER/ENVIRONEERING. AFTER
THE CLEANED  GAS  PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT  IS
JOINED BY  A  38Z  BYPASS REHEAT BEFORE IT IS DISCHARGED THROUGH A 4C8 FOOT
STACK SHARED BY  UNITS 1  AND  2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER  LOOP IS CLOSED. AND THE FLTASH STABILIZED SLUDGE IS
HAULED BY  TRUCK  TO  AN OFF  SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE AUGUST 1978.
SOUTH  MISSISSIPPI  ELEC  PWR
R.D. MORROW,  SR.
2
NEW        200.0 MH  (GROSS)
           124.0 MW  (ESC)
COAL
 1.30  XS   BITUMINOUS
LIMESTONE
ENVIRONEERING,  RILEY  STOKER
ENERGY  CONSUMPTION:  S.SX
STATUS  1      STARTUP   6/79
R.D. MORROW  2  OF  SOUTHERN  MISSISSIPPI ELECTRIC IS A PULVERIZED COAL  (1.3X
S. 12.000 BTU/LB)  FIRED  UNIT IN HATTISBURG, MISSISSIPPI. THE EMISSION  CON-
TROL SYSTEM  FOR  THIS  UNIT  CONSISTS  OF A HOT SIDE ESP FOLLOWED BY A LIME-
STONE VENTRI-ROD  ABSORBER  SUPPLIED  BY RILEY STOKER/ENVIRONEERlNfi. AFTER
THE CLEANED  GAS  PASSES THROUGH A VERTICAL CHEVRON MIST ELIMINATOR, IT  IS
JOINED BY A  38X  BYPASS REHEAT BEFORE  IT IS DISCHARGED THROUGH A 4C8  FOOT
STACK SHARED BY  UNITS 1  AND  2 (EACH UNIT HAS ITS OWN ACID BRICK LINED
FLUE). THE WATER  LOOP IS CLOSED, AND  THE FLYASH STABILIZED SLUDGE IS
HAULED BY TRUCK  TO  AN OFF  SITE LANDFILL. THE SYSTEM HAS BEEN OPERATIONAL
SINCE JUNE 1979.
SOUTHERN  ILLINOIS  POWER COOP
HAR10N
4
HEW        173.0  MW  (GROSS)
           173.0  MW  (ESC>
COAL/REFUS
 3.75 XS   BITUMINOUS
LIMESTONE
9ABCOCK (  WILCOX
ENERGY CONSUMPTION:   2.3X
STATUS 1      STARTUP   5/79
UNIT 4 AT SOUTHERN  ILLINOIS  POWER  COOP'S  MARION STATION IN MARION. ILLI-
NOIS IS A CYCLONE  FIRED  COAL (3.5X S,  9000 BTU/LB) BOILER WHICH IS SERVED
BY A 89.4X EFFICIENT  (DESIGN)  LIMESTONE  FGD SYSTEM SUPPLIED BY BABCOCK AND
WILCOX. TWO SPRAY  TOWERS  AND A BRICK  LINED STACK ARE DOWNSTREAM OF AN ESP
IN THIS SYSTEM.  THE WATER  LOOP IS  OPEN,  AND THE FLYASH STABILIZED SLUDGE
IS DEWATERED  AND LANDF1LLED. THE SYSTEM  BECAME OPERATIONAL DURING MAY
1979.
SOUTHERN ILLINOIS  POWER  COOP
KARION
5
NEW       300.0 MW  (GROSS)
          300.0 MW  (ESC)
COAL
 3.CO XS
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: ••••X
STATUS 6     STARTUP   0/88
MARION 5 IS A COAL  (3.OX  S.  9000  BTU/LB)  FIRED UNIT PLANNED BY SOUTHERN
ILLNOIS POWER COOP  FOR  LOCATION  IN  MARION, ILLINOIS. THE UTILITY HAS NOT
YET DECIDED ON Ah F60 PROCESS  AS  IT IS  WAITING FOR THE FINALIZATION OF
THE S02 REGULATIONS THE UNIT WILL HAVE  TO MEET. START UP IS EIPECTED IN
1988.
SOUTHERN INDIANA 6AS (  ELEC
A.B. BROWN
1
NEW       265.0 MW (GROSS)
          265.0 MW (ESC)
COAL
 3.35 XS  BITUMINOUS
DUAL ALKALI
FNC
ENERGY CONSUMPTION:    .ex
STATUS 1     STARTUP   3/79
SOUTHERN INDIANA GAS AND ELECTRIC'S  A.6.BROUN 1  IS A DRY BOTTOM PULVERIZED
COAL (3.35X S, 13,010 BTU/LB)  FIRED  UNIT  IN WEST FRANKLIN, INDIANA. FMC
SUPPLIED A DUAL ALKALI FGD SYSTEM  DESIGNED TO REMOVE 85X OF THE FLUE GAS
S02. THE UNIT CONSISTS OF TWO  THREE  STAGE DISC CONTACTORS. A COLD SIDE ESP
PROVIDES PRIMARY PARTICULATE CONTROL, AND ONE CHEVRON HIST ELIMINATOR/MOD*
ULE PRECEDES A 498 FOOT ACID BRICK  LINED  STACK.  THE SYSTEM PRODUCES A
FILTER CAKE WASTE PRODUCT WHICH  IS  DISPOSED IN AN ON SITE LANDFILL. THE
WATER LOOP CAN BE EITHER OPEN  OR CLOSED.  THE SYSTEM HAS BEEN OPERATIONAL
SINCE MARCH 1979.

-------
                                               EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980
                                              SECTION 2
                                        STATUS OF FGD SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS
1
NEW
          720.0 MW (GROSS)
          720.0 My  (ESC)
COAL
  .70 IS  LIGNITE
LIMESTONE
AIR CORRECTION DIVISION,  HOP
ENERGY CONSUMPTION:  «»*«X
STATUS 3     STARTUP   0/86
                               DOLET HILLS 1 OF  SOUTHWESTERN  ELECTRIC POWER IS A PLANNED 720 HU  LIGNITE
                               (P.7XS, 7100BTU/LB)  FIRED  BOILER TO BE LOCATED IN MANSFIELD, LOUISIANA.
                               THE EMISSION  CONTROL  SYSTEM  WILL CONSIST OF AN ESP FOR PARTICULATE  CONTROL
                               AND A WET LIMESTONE  FGD  SYSTEM FOR S02 CONTROL.  THE FLUE GAS WILL  EXIT
                               THROUGH A 525 FOOT  STACK.   A CONTRACT HAS BEEN AWARDED TO UOP FOR THE  FGO
                               SYSTEM.  THE  UNIT IS  SCHEDULED TO STARTUP IN 1986.
SOUTHWESTERN ELECTRIC  POWER
DOLET HILLS
2

COAL
   .80 IS   LIGNITE
LIMESTONE
AIR  CORRECTION  DIVISION,  UOP
ENERGY  CONSUMPTION: •««•!
STATUS  3      STARTUP 12/84
                               HENRY  W.  PIRKEV  1 IS A WET BOTTOM LIGNITE  (0.81  S,  6300 BTU/LB) FIRED UNIT
                               PLANNED  BY  SOUTHWESTERN ELECTRIC POWER FOR LOCATION IN HALLSVILLE, TEXAS.
                               A  CONTRACT  HAS  BEEN AWARDED TO THE AIR CORRECTION  DIVISION OF UOP FOR FOUR
                               LIMESTONE SPRAY  TOWERS (99*1 EFFICIENCY).  MIST ELIMINATION WILL BE PRO-
                               VIDED  BY  TWO  STAGE CHEVRONS, AND THE STACK WILL  BE  ACID BRICK LINED. NO
                               REHEAT IS PLANNED. THE WATER LOOP WILL BE  CLOSED.  AND THE SLUDGE WILL BE
                               POZ-0-TEC STABILIZED. START UP IS EXPECTED BY  DECEMBER 1984.
SPRINGFIELD  CITY UTILITIES
SOUTHWEST
1
MEW        194.0  MW (GROSS)
           194.0  MW (ESC)
COAL
 3.50  IS   BITUMINOUS
LIMESTONE
AIR  CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:  4.6X
STATUS 1      STARTUP  4/77
                                SPRINGFIELD CITY UTILITIES' SOUTHWEST  1  IS  A  PULVERIZED BITUMINOUS COAL
                                (3.5X  S,  12,SCO BTU/LB) FIRED BOILER LOCATED  IN SPRINGFIELD, MISSOURI. THE
                                EMISSION  CONTROL SYSTEM FOR THIS UNIT  CONSISTS  OF A COLD SIDE ESP FOLLOWED
                                BY  TWO UOP LIMESTONE TCA MODULES WHICH WERE DESIGNED TO REMOVE BOX OF THE
                                FLUE  GAS  S02. ONE CHEVRON/NODULE LEADS TO A 384 FOOT CEILCOTE LINED STACK.
                                THE  DRV FLYASH STABILIZED SLUDGE IS DEWATERED BY A ROTARY DRUM VACUUM AND
                                TRUCKED TO A LANDFILL. THE SYSTEM  HAS  BEEN  OPERATIONAL SINCE APRIL 1977.
SPRINGFIELD WATER, LIGHT &  PWR  DALLNAN 3 OF SPRINGFIELD WATER,  LIGHT,  AND POWER IS A PULVERIZED COAL
                                (?.3X S, 10,500 BTU/LB) FIRED BOILER  UNDER CONSTRUCTION IN SPRINGFIELD,
                                ILLINOIS. RESEARCH COTTRELL  IS  SUPPLVING  A LIMESTONE FGD SYSTEM DESIGNED
                                TO REMOVE 95X OF THE S02 FROM 850,000 ACFM OF BOILER FLUE GAS. A HOT SIDE
                                ESP WILL PRECEDE TWO PACKED  TOWER  ABSORBERS,  ONE HORIZONTAL CHEVRON PER
                                MODULE, AND A 500 FOOT ACID  BRICK  LINED STACK. NO REHEAT WILL BE PROVIDED.
                                A  SLUDGE DISPOSAL STRATEGY HAS  NOT BEEN FINALIZED, BUT THE UTILITY IS  CON-
                                SIDERING EITHER PONDING OR LANDFILL.  FGD  OPERATIONS SHOULD BEGIN IN
                                OCTOBER 1980.
3
MEW
           205.0 MW (GROSS)
           205.0 MW (ESC)
COAL
  3.39 XS
LIMESTONE
RESEARCH-COTTRELL
ENERGY CONSUMPTION:  5.9X
STATUS 2      STARTUP 10/80
 ST.  JOE  ZINC
 G.F.  WEATON
 1
 RETROFIT   60.0 MW (GROSS)
            63.0 MW (ESC)
 COAL
  2.00 XS  BITUMINOUS
 CITRATE
 MORRISON 8 KNUDSEN/U.S.B.H.
 ENERGY CONSUMPTION: ••••»
 STATUS 1     STARTUP 11/79
                                G.F. WEATON 1, OWNED BY  ST.  JOE  ZINC,  IS A COAL (2.OX S, 12,500 BTU/LB)
                                FIRED BOILER LOCATED IN  MONACA,  PENNSYLVANIA. THE BUREAU OF MINES  RE-
                                TROFITTED A PROTOTYPE CITRATE  FGD SYSTEM ON THIS UNIT, WHICH PROVIDES
                                POWER FOR THE LOCAL  UTILITY  GRID. ONE  VENTURI SCRUBSER/ABSORBER TRAIN
                                FOLLOWS A COLD SIDE  ESP. TWO CHEVRON MIST ELIMINATORS ARE  FOLLOWED BY
                                A COMBINATION OF  INDIRECT HOT  AIR AND  DIRECT COMBUSTION REHEATERS. AND A
                                102 FOOT FIBERGLASS  LINED SCRUBBER STACK. THE SYSTEM SO2 REMOVAL  EFFICIEN-
                                CY WILL BE OVER 90X. THE WATER LOOP IS CLOSED LOOP MODE. THE  FGD  SYSTEM
                                COMMENCED OPERATION  IN  NOVEMBER  1979.
                                                  37

-------
  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980
                                               SECTION 2
                                         STATUS OF FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                   ABSTRACT
 SUNFLOWER ELECTRIC COOP
 MOLCOMB
 1
 NEW        347.0 MU (GROSS)
           347.0 MU (ESC>
 COAL
   .47 XS  SUBBITUNINOUS
 LINE/SPRAY DRYING
 JOY  MFG/MIRO ATOMIZER
 ENERGY CONSUMPTION:   .9X
 STATUS 3     STARTUP  9/83
 SUNFLOWER  ELECTRIC COOP'S HOLCOMB 1 STATION  IS  A  PLANNED  347  MW UNIT TO 8E
 LOCATED  IN MOLCOMB, KANSAS.  THE PULVERIZED  COAL  (0.47X  S,  8800
 BTU/LB)  FIRED BABCOCK AND UILCOX BOILER  WILL  UTILIZE  A JOY  MANUFACTURING/
 NIRO  ATOMIZER DRV SCRUBBING PROCESS FOR  S02  CONTROL.  A  FABRIC  FILTER
 WILL  BE  UTILI7EO FOR PRIMARY PARTICLE CONTROL.  THE UNIT  IS SCHEDULED
 TO  COMMENCE OPERATIONS IN THE FALL OF 1983.
 TAMPA ELECTRIC
 BIG  BEND
 4
 NEW        475.0 MU (GROSS)
           475.0 MU (ESC)
 COAL
 2.35 XS
 LIME/LIMESTONE
 RESEARCH-COTTRELL
 ENERGY CONSUMPTION:  2.IX
 STATUS 3     STARTUP 12/84
 UNIT  4  AT  TAMPA ELECTRIC'S BIG BEND STATION  IS  A PLANNED  DRY  BOTTOM  PUL-
 VERIZED  COAL (2.35X S. 10.300 BTU/LB) FIRED  UNIT TO  BE  LOCATED  IN  TAMPA,
 FLORIDA.  A CONTRACT HAS BEEN AWARDED TO RESEARCH-COTTRELL  FOR A  WET  LIME/
 LIMESTONE  SCRUBBING PROCESS. AN ESP WILL PROVIDE PRIMARY  PARTICULATE
 CONTROL.  THE FGD SYSTEM, WHICH WILL REMOVE 90X  OF THE FLUE  GAS  S02.  WILL
 INCLUDE  AN INDIRECT HOT AIR REHEATER LEADING TO A 490 FOOT  CONCRETE  LINEC
 STACK.  THE UNIT WILL PRODUCE GYPSUM AS A SALEABLE PRODUCT.
 TENNESSEE  VALLEY AUTHORITY
 JOHNSONVILLE
 1-10
 RETROFIT 1450.0 MU (GROSS)
           600.0 MU (ESC)
 COAL
  3.10  XS
 MAGNESIUM  OXIDE
 EHV1RONEERING.  RILEY STOKER
 ENERGY CONSUMPTION: •»**x
 STATUS 3      STARTUP 12/81
UNITS  1  THROUGH  10 AT JOHNSONVILLE STATION OF TVA ARE COAL  (3.1X  S,  10,750
BTU/LB)  FIRED  BOILERS LOCATED IN NEW JOHNSONVILLEt TENNESSEE.  UNITED EN-
GINEERS  HAS  BEEN  AWARDED A CONTRACT TO PROVIDE ENGINEERING  *SSIST«NCE TO
TVA  FOR  A  90X  EFFICIENT MAGNESIUM OXIDE F6D SYSTEM TO BE  RETROFITTED ON
THESE  UNITS.  SULFURIC ACID WILL BE PRODUCED AS A BYPRODUCT  FROM THIS SYS-
TEM, WHICH WILL  FEATURE FOUR VENTURI SCRUBBER/ABSORBER  TRAINS  (ONE  SPARE),
6CI  BYPASS REHEAT, AND A 600 FOOT STACK. START UP IS EXPECTED  IN  1981.
TENNESSEE  VALLEY AUTHORITY
PARADISE
1
RETROFIT   734.0 MU (GROSS)
           704.0 MU (ESC)
COAL
 4.20 XS
LIMESTONE
CMEMICO DIVISION,  ENVIROTECH
ENERGY CONSUMPTION: ••••*
STATUS 2      STARTUP  3/82
PARADISE  1  OF  TVA  IS  A  4.2X SULFUR COAL FIRED UNIT LOCATED  IN  PARADISE,
KENTUCKY. A  CONTRACT  HAS  BEEN AWARDED TO CHEMICO FOR  AN 84.2X  EFFICIENT
LIMESTONE FGD  SYSTEM  TO BE RETROFITTED ON THIS BOILER. SIX  VENTURI  SCRUB-
BERS AND  VENTURI ABSORBER TRAINS UILL FOLLOW AN ESP.  INLET  FLUE  G«S  WILL
BE USED TO  HEAT WATER,  WHICH IN TURN UILL BE USED TO  REHEAT  THE  OUTLET
FLUE GAS. FORCED OXIDATION WILL 6E USED IN ONE MODULE TO CONTROL  SCALING
THROUGHOUT  THE SYSTEM.  THE UTILITY EKPECTS TO 6ET AN  SOX SOLIDS  LANDFILL*
ABLE GRADE  SLUDGE.  OPERATIONS SHOULD START IN MARCH 1982.
TENNESSEE  VALLEY  AUTHORITY
PARADISE
2
RETROFIT   704.0 MU  (GROSS)
           704.0 MU  (ESC)
COAL
 4.20 XS
LIMESTONE
CHEMICO DIVISION,  ENVIROTECH
ENERGY CONSUMPTION:  **»«x
STATUS 2      STARTUP   6/62
PARADISE 2 OF  TVA  IS  A  4.2X  SULFUR COAL FIRED UNIT LOCATED  IN  PARADISE,
KENTUCKY. A CONTRACT  HAS  BEEN AWARDED TO CHEMICO FOR AN 84.2X  EFFICIENT
LIMESTONE FGD  SYSTEM  TO BE  RETROFITTED ON THIS BOILER. SIX  VENTURI  SCRUB-
BERS AND VENTURI ABSORBER TRAINS UILL FOLLOW AN ESP. INLET  FLUE  GAS  WILL
Bf USED TO HEAT WATER,  WHICH IN TURN UILL BE USED TO REHEAT THE  OUTLET
FLUE GAS. FORCED OXIDATION  WILL BE USED IN ONE MODULE TO CONTROL  SCALING
THROUGHOUT THE SYSTEM.  THE  UTILITY EKPECTS TO GET AN SOX SOLIDS  LANDFILL-
ABLE GRADE SLUDGE. OPERATIONS SHOULD START IN JUNE 1982.
TENNESSEE VALLEY AUTHORITY
SHAUNEE
IDA
RETROFIT   10.o MU  (GROSS)
           10.0 MU  (ESC)
COAL
 2.90 XS  BITUMINOUS
LIME/LIMESTONE
AIR CORRECTION DIVISION,  OOP
ENERGY CONSUMPTION:  *«««X
STATUS 1     STARTUP   4/72
SHAUNEE 10 OF TVA  IS  A  2.9X  SULFUR BITUMINOUS COAL FIRED BOILER LOCATED  IN
PADUCAH, KENTUCKY. MODULE  10A  IS A RETROFIT PROTOTYPE LIME/LIMESTONE  TCA
SYSTEM SUPPLIED BY THE  »IR CORRECTION DIVISION, UOP. THE SYSTEM UTILIZES
A CHEVRON MIST ELIMINATOR  AND  A  DIRECT COMBUSTION REHEATER. AND OPERATES
IN A CLOSED WATER LOOP.  THIS TEST PROGRAM is FUNDED BY THE EPA WITH TVA  AS
THE CONSTRUCTOR AND  FACILITY OPERATOR. THE BECHTEL CORP. OF SAN FRANCISCO
IS THE MAJOR CONTRACTOR,  TEST  DIRECTOR, AND REPORT UR1TER. THE SYSTEM  HAS
BEEN OPERATIONAL SINCE  APRIL 1972.
                                                 38

-------
                                               EPA  UTILITY F60 SURVEY: JULY - SEPTEMBER  1980

                                              SECTION 2
                                        STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
TENNESSEE VALLEY AUTHORITY
SHAWNEE
13B
RETROFIT   10.0 MW  (GROSS)
           10.0 MU  (ESC)
COAL
 2.90 XS  BITUMINOUS
LINE/LIMESTONE
CHEMICO DIVISION,  ENVIROTECH
ENERGY CONSUMPTION: *«**X
STATUS 1      STARTUP   4/72
SNAUNEE 1C OF TVA IS A 2.
PADUCAH, KENTUCKY. MODULE
TURI SCRUflBER/SPRAY TOMER
TIONAL SINCE APRIL 1972,
COMBUSTION REHEATED, AMD
GRAM IS FUNDED BY THE EPA
TOR. THE BECHTEL CORP. OF
RECTOR, AND REPORT WRITER
9X SULFUR BITUMINOUS COAL FIRED BOILER  LOCATED  IN
 108 IS A RETROFIT PROTOTYPE LIME/LIMESTONE  VEN-
 ABSORBER SUPPLIED BY CHENICO. THE SYSTEM,  OPERA-
INCLUDES A CHEVRON MIST ELIMINATOR AND  A  DIRECT
OPERATES IN A CLOSED WATER  LOOP.  THIS  TEST  PRO-
 WITH TVA AS THE CONSTRUCTOR AND  FACILITY OPERA-
 SAN FRANCISCO IS THE MAJOR  CONTRACTOR, TEST DI-
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK
7
RETROFIT  575.0 MM  (GROSS)
          575.0 MW  (ESC)
COAL
 3.70 XS  BITUMINOUS
LIMESTONE
COMBUSTION  ENGINEERING
ENERGY CONSUMPTION: **«*X
STATUS 2      STARTUP  9/81
WIDOWS CREEK 7  IS  A  PULVERIZED  BITUMINOUS COAL (J.7X S, 11,100 BTU/LB)
FIRED BOILER OF  TVA  LOCATED  IN  BRIDGEPORT, ALABAMA. COMBUSTION ENCINEERING
IS PRESENTLY RETROFITTING  A  LIMESTONE  VENTRI ROD SCRUBBER/SPRAY TOWER AB-
SORBER FGD SYSTEM  ON  THIS  UNIT.  AN  ESP WILL PRECEDE THE SCRUBBING TRAIN,
AND A COMBINATION  OF  A  BULK  ENTRAINMENT SEPARATOR, TWO CHEVRON MIST
ELIMINATORS AND  A  FINNED  TUBE  REHEATER FOLLOW THE SYSTEM. THE
SCRUBBER SLUDGE  uILL  BE DISPOSED IN A  SLUDGE POND. CONSTRUCTION BEGAN
IN SEPTEMBER 1978, AND  START UP IS  EXPECTED IN SEPTEMBER 1981.
TENNESSEE  VALLEY  AUTHORITY
WIDOWS  CREEK
8
RETROFIT   550.0 MW  (GROSS)
           550.0 MW  (ESC)
COAL
 3.70 XS
LIMESTONE
TENNESSEE  VALLEY  AUTHORITY
ENERGY  CONSUMPTION:  4.7X
STATUS  1      STARTUP  5/77
WIDOWS CREEK  8  OF  TVA  IS  A  BALANCED frRAFT, T AN6F.NT 1 ALLY  FIRED  COAL  C3.7X
S, 10,000 BTU/LB)  BOILER  IN BRIDGEPORT, ALABAMA. TVA RETROFITTED  THIS  UNIT
WITH A LIMESTONE  FGD  SYSTEM (BOX DESIGN S02 REMOVAL EFFICIENCY) WHICH  BE-
GAN OPERATIONS  IN  MAY  1977. AN ESP PRECEDES FOUR VARIABLE THROAT  VENTURI
SCRUBBER/MULTIGRID TOWER  ABSORBER TRAINS CONE OF THE TOWERS  is PACKED).
ONE VERTICAL  CHEVRON/TRAIN  AND AN INDIRECT HOT AIR REHEATER  ARE INCLUDED
IN THE SYSTEM.  SLUDGE  FROM  THE FGD SYSTEM IS PONDED.
TEXAS  MUNICIPAL  POWER AGENCY
GIBBONS  CREEK
1
UEV        400.0  MW  (GROSS)
           400.0  MW  (ESC)
COAL
  1.06  XS  LIGNITE
LIMESTONE
COMBUSTION ENGINEERING
ENERGY CONSUMPTION: ****X
STATUS 2     STARTUP  1/82
 GIBBONS  CREEK  1  OF THE TEXAS MUNICIPAL POWER AGENCY  IS  A  DRY  BOTTOM PUL-
 VERIZED  LIGNITE  (1.06X S, 4860 BTU/LB) FIRED UNIT  PLANNED FOR LOCATION IN
 CARLOS,  TEXAS. THE EMISSION CONTROL SYSTEM UILL  CONSIST OF A  COLD SIDE ESP
 FOLLOWED  BY  THREE 50X CAPACITY LIMESTONE  SPRAY TOWERS.  A  CONTRACT HAS BEEN
 AWARDED  TO  COMBUSTION ENGINEERING FOR THE F6D SYSTEM, WHICH INCLUDES A
 CHEVRON  MIST ELIMINATOR AND A STEAM COIL  REHEATER. CLEANED FLUE GAS MILL
 BE  DISCHARGED  THROUGH A 465 FOOT ACID BRICK LINED  STACK.  THE  POZ-0-TEC
 STABILIZED  SLUDGE UILL BE USED AS STRIP MINE LANDFILL.  START  UP
 IS  EXPECTED  IN JANUARY 1982.
 TEXAS  POWER 8 LIGHT
 SANDOW
 4
 NEy        545.0 MW (GROSS)
           382.0 MW (ESC>
 COAL
  1.60  XS  LIGNITE
 LIMESTONE
 COMBUSTION ENGINEERING
 ENERGY CONSUMPTION: ****X
 STATUS 2     STARTUP 11/80
 SANDOW  4  IS A PULVERIZED 1.6X SULFUR LIGNITE  FIRED  BOILER OF TEXAS POWER
 AND  LIGHT UNDER CONSTRUCTION IN  ROCKDALE ,  TEXAS.  COMBUSTION ENGINEERING IS
 SUPPLYING THREE LIMESTONE SPRAY  TOWERS  FOR THIS UNIT. A COLD SIDE ESP WILL
 PROVIDE PRIMARY PARTICULATE CONTROL. A  30X BYPASS REHEAT WILL BE USED, AND
 THE  OVERALL S02 REMOVAL EFFICIENCY WILL BE 75X. THE SYSTEM WILL OPERATE IN
 A  CLOSED  WATER LOOP, AND THE SLUDGE WILL BE PONDED. START UP IS EXPECTED
 IN NOVEMBER 1980.
 TEXAS POWER 8 LIGHT
 TWIN OAKS

 NEW       750.0 MW (GROSS)
           750.0 »W (ESC)
 COAL
   .7? XS  LIGMTE
 LIMESTONE
 CHEMICO DIVISION, ENVIROTECH
 ENERGY CONSUMPTION: **«*X
 STATUS 3     STARTUP   8/84
 TWIN OAKS 1 IS A 0.70X SULFUR LIGMTE  FIRED  BOILER PLANNED BY TEXAS POWER
 AND LIGHT AND ALCOA FOR  LOCATION  IN BREMOND. TEXAS. A CONTRACT HAS BEEN
 AWARDED TO CHEMICO FOR A LIMESTONE  FGD SYSTEM ON THIS UNIT. START UP IS
 EXPECTED IN AUGUST 1984.
                                                  39

-------
  EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER 19SC
                                               SECTION 2
                                         STATUS Of FGD SYSTEMS
 UNIT IDENTIFICATION
                                                                    ABSTRACT
 TEXAS POWER K LIGHT
 TWIN OAKS
 Z
 NEW        750.0 MW (GROSS)
           750.0 MW (ESO
 COAL
   .70 XS  LIGNITE
 LIMESTONE
 CHEMICO DIVISION, ENVIROTECH
 ENERGY  CONSUMPTION: **«*X
 STATUS  3     STARTUP  8/85
 TWIN  OAKS 2  IS A 0.70X SULFUR LIGNITE  FIRED  BOILER PLANNED BY TEXAS POWER
 AND  LIGHT AND ALCOA FOR LOCATION  IN  BREMOND,  TEXAS. A CONTRACT HAS PEEN
 AWARDED  TO CHFMICO FOR A LIMESTONE  FGD  SYSTEM ON  THIS UNIT. START UP  IS
 EXPECTED  IN  AUGUST 1985.
 TEXAS  UTILITIES
 FOREST GROVE
 1
 NEW        750.0 M« (GROSS)
           7SQ.C MW 
-------
                                               EPA UTILITY  FED  SURVEY:  JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS OF F6D SYSTEMS
UNIT IDENTIFICATION
                                                                   ABSTRACT
TEXAS UTILITIES
HILL CREEK
1
MEW       750.0 MU  (GROSS)
          750.0 MW  (ESC)
COAL
***** tS  LIGNITE
PROCESS NOT SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION:  *****
STATUS 6      STARTUP   0/85
                                MILL  CREEK  1  OF TEXAS UTILITIES  IS A  PLANNED  LI6NITE FIRED UNIT TO BE
                                LOCATED  IN  HENDERSON, TEXAS. THE UTILITY  WILL INCLUDE AN F6D SYSTEM ON
                                THIS  UNIT,  BUT NO DECISIONS HAVE BEEN MADE  AS TO THE PROCESS TYPE OR
                                VENDOR.  ESP'S WILL PROVIDE PRIMARY PARTICLE CONTROL. START UP IS
                                EXPECTED IN 1985.
TEXAS UTILITIES
MILL CREEK
z
NEW       750.0  My  (GROSS)
          750.0  MW  (ESC)
COAL
***** XS  LIGNITE
PROCESS NOT  SELECTED
VENDOR NOT  SELECTED
ENERGY CONSUMPTION: ****X
STATUS 6      STARTUP   0/86
                                MILL  CREEK 2 OF TEXAS UTILITIES  IS  A  PLANNED LIGNITE FIRED UNIT  TO BE
                                LOCATED IN HENDERSON, TEXAS.  THE  UTILITY WILL INCLUDE AN FGO SYSTEM  ON
                                THIS  UNIT, BUT NO DECISIONS HAVE  BEEN MADE AS TO THE PROCESS TYPE OR
                                VF.NDOR. ESP'S WILL PROVIDE PRIMARY  PARTICLE CONTROL. START UP  IS
                                EXPECTED IN 1986.
                                HONTICELLO  3 OF  TEXAS  UTILITIES IS A LIGNITE  (1.5X  S,  7000 BTU/LB) FIRED
                                UNIT IN MT. PLEASANT,  TEXAS. THIS UNIT'S EMISSION  CONTROL SYSTEM CONSISTS
                                OF TWO COLD SIDE ESP'S FOLLOWED BY THREE CHEMICO  LIMESTONE SPRAY TOWERS
                                (74X DESIGN S02  REMOVAL EFFICIENCY), ONE HORIIONTAL CHEVRON MIST ELIMINA-
                                TOR/MODULE, AND  AN  INDIRECT HOT AIR REHEATER.  THE  WATER  LOOP IS CLOSED.
                                AND THE FLYASH  STABILIZED SLUDGE IS DISPOSED  IN  AN  ON  SITE LANDFILL. THIS
                                SYSTEM HAS  BEEN  OPERATIONAL SINCE MAY  1978.
TEXAS UTILITIES
MONTICELLO
3
NEW       800.0  MW  (GROSS)
          830.0  MW  (ESC>
COAL
 1.50 IS  LIGNITE
LIMESTONE
CHEMICO DIVISION,  ENVIROTECH
ENERGY CONSUMPTION: ****X
STATUS 1      STARTUP  5/78
TUCSON  ELECTRIC POWER
SPRINGERVILLE
1
NEW        370.0 MW (GROSS)
           370.0 MW (ESC)
COAL
   .61 XS  SUBBITUNINOUS
LIME/SPRAY DRYING
JOY  MFG/NIRO ATOMIZER
ENERGY  CONSUMPTION: ****X
STATUS  3     STARTUP  1/85
                                TUCSON ELECTRIC POWER  WILL BE BUILDING TWO NEW UNITS  IN  SPRINGERVILLE,
                                ARIZONA, SPRINGERVILLE 1  AND 2.  THE UNITS WILL  FIRE  PULVERIZED SUBBITU-
                                MINOUS COAL  (0.53-0.69X S AND 8500-6900 BTU/LB).   A  CONTRACT HAS BEEN
                                AWARDED TO JOY MANUFACTURING/NIRO ATOMIZER FOR A  LIME/SPRAY DRYING F6D
                                SYSTEM TO CONTROL  PARTICULATE MATTER AND S02  EMISSIONS.   THE SVSTFM WILL
                                BE DESIGNED  TO ACCOMODATE A REHEATER (SHOULD  ONE  BE  REQUIRED) AND WILL
                                OPERATE IN A  CLOSED  WATER LOOP.  CLEANED FLUE GAS  WILL EXIT THE SYSTEM
                                VIA A 500 FOOT CONCRETE STACK.  STARTUP IS SCHEDULED  FOR JANUARY 1985.
 TUCSON  ELECTRIC POWER
 SPRINGERVILLE

 NEW        370.0 MW (GROSS)
           370.0 MW (ESC)
 COAL
   .61  XS  SUBBITUMINOUS
 LIME/SPRAY DRYING
 JOY  MFG/NIRO ATOMIZER
 ENERGY  CONSUMPTION: ****X
 STATUS  3     STARTUP  3/87
                                TUCSON GAS  AND  ELECTRIC WILL BE BUILDING  TWO  NEW  UNITS IN SPRINGEPVILLE,
                                ARIZONA,  SPRINGERVILLE 1 AND 2.  THE UNITS WILL  FIRE  PULVERIZED SIBB1TU-
                                HINOUS COAL  (0.53-0.69X S AND 8500-8000 BTU/LB).   A  CONTRACT HAS BEEN
                                AWARDED TO  JOY  MANUfACTURING/NIRO ATOMIZER FOR A  LIME/SPRAY DRYING FGD
                                SYSTEM TO CONTROL  PARTICULATE MATTER AND  S02  EMISSIONS.  THE SYSTEM WILL
                                BE DESIGNED  TO  ACCOMODATE A REHEATER (SHOULD  ONE  BE  REQUIRED) AND WILL
                                OPERATE IN  A  CLOSED WATER LOOP.  CLEANED  FLUE GAS WILL EXIT THE SYSTEM
                                VIA A 500 FOOT  CONCRETE STACK.  STARTUP IS SCHEDULED  FOR MARCH 1987.
 UNITED POWER ASSOCIATION
 S1ANTON
 1A
 NEW         50.0 MW (GROSS)
            50.0 MW (ESC)
 COAL
   .77 XS  LIGNITE
 LIME/SPRAY DRYING
 RESEARCH-COTTRELL
 ENERGY CONSUMPTION: ****x
 STATUS 2     STARTUP   6/82
                                STANTON  1A  OF  THE  UNITED POWER ASSOCIATION  IS  A PULVERIZED COAL (C.77X S,
                                7000 BTU/LB)  FIRED UNIT UNDER CONSTRUCTION  IN  STANTON, NORTH DAKOTA.
                                A CONTRACT  HAS BEEN AWARDED TO KOMLINE  AND  SANDERSON FOR A LIME SPRAY
                                DRYER.   A  FABRIC  FILTER SUPPLIED BY  RESEARCH  COTTRELL WILL BE DESIGNED
                                TO REMOVE  99X  OF  THE PARTICULATE.  THE  SYSTEM  WILL OPERATE IN AN  OPEN
                                LOOP MODE  WITH SLUDGE DISPOSAL TO BE  IN A  CLAY LINED SETTLING POND.
                                OPERATIONS  ARE SCHEDULED TO COMMENCE  IN JUNE  1982.

-------
  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
                                              SECTION 2
                                        STATUS Of FGD SYSTEMS
 UNIT  IDENTIFICATION
                                                                  ABSTRACT
 UTAH POWER  I LIGHT
 HUNTER
 1
 NEW        400.0 MH (GROSS)
           360.0 MW (ESC)
 COAL
   .55 XS  BITUMINOUS
 LINE
 CHEMICO  DIVISION,  ENWIROTECH
 ENERGY  CONSUMPTION: **»*X
 STATUS  1     STARTUP  5/79
 HUNTER  1  OF  UTAH  POWER AND LIGHT IS A COAL (0.55X S, 12,500 BTU/LB) FIRED
 UNIT  IN  CASTLEOALE,  UTAH. CHEHICO SUPPLIED A PEBBLE LIME MET SCRUBBING
 SYSTEM  WHICH BECAME  OPERATIONAL IN NAY 1979. THE SCRUBBING SYSTEM IS DE-
 SIGNED  TO OPERATE IN AN OPEN WATER LOOP WITH AN $02 REMOVAL EFFICIENCY OF
 802.  PRIMARY PARTICULATE CONTROL IS PROVIDED BY AN UPSTREAM ESP, AND STACK
 GAS REHEAT IS PROVIDED BY BYPASS. THE SLUDGE IS FLYASH STABILIZED AND DIS-
 POSED ON-SITE.
 UTAH  POWER  (  LIGHT
 HUNTER
 2
 MEW        400.0 MW  (GROSS)
           360.0 MW  (ESC)
 COAL
   .55 XS
 LIME
 CHEMICO DIVISION,  FNVlftOTECH
 ENERGY CONSUMPTION:  ***«X
 STATUS 1      STARTUP  6/80
UTAH POWER  AND  LIGHT'S  HUNTER 2  IS A COAL (0.551 S, 12,500 BTU/LB) FIRED
UNIT LOCATED  IN CASTLEDALE,  UTAH. FOR EMISSION CONTROL, CHEMICO SUPPLIED
A PEBBLE  LIME WET SCRUBBING  SYSTEM DESIGNED TO OPERATE IN AN OP'EN WATER
LOOP WITH AN  S02  REMOVAL EFFICIENCY OF SOX. AN UPSTREAM ESP PROVIDES
PRIMARY PARTICLE  CONTROL, AND A  BYPASS SYSTEM PROVIDES STACK GAS REHEAT.
THE SLUDGE  IS FLYASH  STABILIZED  AND DISPOSED OF ON-SITE. START UP OF BOTH
THE BOILER  AND  FGD  SYSTEM TOOK PLACE IN JUNE 1980.
 UTAH  POWER  t  LIGHT
 HUNTER
 3
 NEW        400.0  NW (GROSS)
           400.0  MW (ESC)
 COAL
   .55 IS   BITUMINOUS
 LIMESTONE
 CHEMICO DIVISION,  ENVIROTECH
 ENERGY CONSUMPTION:  •**•!
 STATUS 3      STARTUP   6/83
UTAH POWER  AND  LIGHT  HAS  PLANS FOR TWO NEW UNITS, HUNTER 3 AND 4, TO BE
CONSTRUCTED  IN  CASTLEDALE,  UTAH.   A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIME,  NONREGENERABLE  FGD UNIT JOR EMISSION CONTROL.  THE PULVERIZED
COAL FIRED  UNIT (o.ssx  s, 12,500  BTU/LB)  is TO BEGIN OPERATIONS in JUNE
1983.
UTAH POWER  t  LIGHT
HUNTER
4
NEW       400.0  MW  (GROSS)
          400.0  MW  (ESC)
COAL
   .55 XS  BITUMINOUS
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION:  **••!
STATUS 3      STARTUP   6/85
UTAH POWER AND LIGHT  HAS  PLANS  FOR  TWO NEW UNITS* HUNTER 3 AND 4, TO BE
CONSTRUCTED IN CASTLEDALE,  UTAH.  A CONTRACT HAS BEEN AWARDED TO CHEMICO
FOR A LIME, NONREGENERABLE  FGD  UNIT /OR EMISSION CONTROL.  THE PULVERIZED
COAL FIRED UNIT  (O.SSX  S, 12,500  BTU/LB)  IS TO BEGIN OPERATIONS IN JUNE
1985.
UTAH POWER (  LIGHT
HUNTINGTON
1
NEW       430.0 MW  (GROSS)
          366.0 MW  (ESC)
COAL
  .55 XS  BITUMINOUS
LIME
CHEMICO DIVISION, ENVIROTECH
ENERGY CONSUMPTION:   1.6X
STATUS 1      STARTUP   5/78
HUNTINGTON 1 OF UTAH  POWER  IS  A  TANGENTIALLY  FIRED PULVERIZED COAL (C.55X
S, 12,500 BTU/LB) BOILER  IN PRICE,  UTAH.  A  COLD SIDE ESP TREATS 1,742,GOD
ACFM OF FLUE GAS AND  IS FOLLOWED BY  A  CHEMICO  LIME FGD SYSTEM CONSISTING
OF FOUR SPRAY TOWERS  (60X DESIGN EFFICIENCY).  ONE  FOUR PASS CHEVRON/MODULE
PROVIDES MIST ELIMINATION,  AND A COMBINATION  OF A  STEAM TUBE AND 10-20X
BYPASS REHEATERS BOOST THE  GAS TEMPERATURE  45-50 DEG F. THE SYSTEM OPER-
ATES IN A CLOSED WATER LOOP, AND THE FLYASH STABILIZED SLUDGE IS TRUCKED
TO AN ON-SITE LANDFILL. THE SYSTEM  INCLUDES A  600  FOOT ACID BRICK LINED
STACK, AND HAS BEEN OPERATIONAL  SINCE  HAY 1978.
UTAH POWER 1 LIGHT
NAU6HTON
3
RETROFIT  330.0 MW (GROSS)
          330.0 MW (ESC)
COAL
  .55 XS  SUBBITUMINOUS
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
ENERGY CONSUMPTION:   1.SX
STATUS 2     STARTUP  6/81
NAUGHTON 3 OF UTAH POWER AND LIGHT  IS  A  PULVERIZED  COAL (.5X S, 9500
BTU/LB) FIRED BOILER LOCATED IN  KEMMERER,  WYOMING.   THE BOILER SUPPLIES
1.500,000 ACFM OF FLUE GAS TO AN ESP FOR PARTICULATE CONTROL.  THE UNIT is
CURRENTLY BEING RETROFITTED WITH A  UOP WET SODA  ASH FGD SYSTEM FOR S02
CONTROL.  THE F6D SYSTEM IS DESIGNED TO  REMOVE 70t  OF THE  S02 BEFORE THE
FLUE GAS EXITS OUT A 475 FOOT STACK.   INITIAL  STARTUP IS SCHEDULED FOR
JUNE 1981.
                                                 42

-------
                                               EPA UTILITY F60 SURVEY: JULY  -  SEPTEMBER 1980
                                              SECTION 2
                                        STATUS Of F6D SYSTEMS
UNIT IDENTIFICATION
                                                                  ABSTRACT
dEST PENN POWER
MITCHELL
33
RETROFIT  300.0 MW  (GROSS)
          300.0 MU  (ESC)
COAL
 2.80 XS  BITUMINOUS
LIME
CHEMICO DIVISION* ENVIROTECH
ENERGY CONSUMPTION:   1.1X
STATUS 3      STARTUP   8/82
                                UNIT  33  AT ALLEGHENY POWER SYSTEM'S MITCHELL  POWER STATION IN COURTNEYt
                                PENNSYLVANIA IS A 2.8* SULFUR COAL  FIRED  BOILER.   A CONTRACT MAS
                                AWARDED  TO CHEMICO FOR A LIME SCRUBBING  PROCESS.   S02 REMOVAL
                                EFFICIENCY UILL BE 95X.  START UP  IS  PLANNED  FOR  AUGUST 1982.
UEST TEXAS UTILITIES
OKLAUNION
1
NEW       720.0  MW  (GROSS)
          720.0  nu  test)
COAL
***** XS
PROCESS NOT  SELECTED
VENDOR NOT SELECTED
ENERGY CONSUMPTION: **••*
STATUS 6      STARTUP  12/86
                                WEST TEXAS UTILITIES HAS  PLANS  FOR  *  PULVERIZED COAL FIRED BOILER TO  BE
                                LOCATED NEAR OKLAUNION, TEXAS.   THE UTILITY HILL INCLUDE AN FGD  SYSTEM
                                FOR EMISSION CONTROL FROM  THE 720 MV  UNIT. THE OKLAUNION 1 PLANT IS
                                SCHEDULED TO COMMENCE OPERATIONS IN 1986.

-------
 EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

                                            SECTION 3
               DESIGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 JN1T <«U
-------
                                              EPA UTILITY FGD SURVEY: JULY -  SEPTEMBER  1960

ALABAMA ELECTRIC COOP: TONBI6BEE 2 (CONT.)
PERIOD

MODULE
a
SYSTEM
AVAILABILITY
100.0
OPERABILITY
86.6
74.0
	 -PERFORMANCE DATA-- 	
RELIABILITY UTILIZATION

86. 5
73.9
X REMOVAL
S02 PART.


PER
HOURS
720
BOILER
HOURS
719
FGD
HOURS
532
CAP.
FACTOR

       *» PROBLEMS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED THAT  FOR  THE  MONTH  OF  APRIL  THE  SYSTEM HAS
                         AVAILABLE  100X OF THE  TIME.

 5/80  A                       34.9                     34.7
       B                       92.8                     92.2
       SYSTEM     100.0        63.9                     63.5                  744   739    472

       ** PROBLEMS/SOLUTIONS/COHMENTS

                         THE FGD SYSTEM WAS  AVAILABLE  100X  DURING NAY.

 6/80  A          100.0        88.0        100.0        11.0
       B             .0          .0           .0          .0
       SYSTEM      50.0        44.0        50.0         5.5                  720    90     40   7.0

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE B  WAS  OUT  OF SERVICE  THE ENTIRE MONTH OF JUNE DUE TO A DAMAGED
                         DAMPER DRIVE  MOTOR.

                         NODULE A  WAS  AVAILABLE FOR OPERATION THE ENTIRE MONTH, BUT HAS NEEDED
                         ONLY  79 HOURS.

 7/80  A          100.0        97.6       100.0        54.5
       B              .0           .0          .0          .0
       SYSTEM      50.0        48.8        50.0        27.3                  744    415     203   26.7

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         THE  B-MODULE  REMAINED  OUT OF SERVICE THROUGH JULY DUE  TO THE DAMAGED
                         DAMPER DRIVE  MOTOR.

                         THE  A-HODULE  OPERATED  ON AN AS NEEDED BASIS WITH NO PROBLEMS.

 S/BO  A           100.0         84.0        84.0        18.3
       B              .0           .0          .0          .0
       SYSTEM       50.0         42.0        42.0         9.2                  744    162      68   14.9

       «• PROBLEMS/SOLUTIONS/COMMENTS

                         DURING  AUGUST MODULE B REMAINED OUT OF  SERVICE DUE TO  DAMAGED  DAMPER
                         OPERATOR  MOTORS.

 »/80  SYSTEM                                                                  720

       *• PROBLEMS/SOLUTIONS/COMMENTS

                          THE  INFORMATION FOR THE MONTH OF  SEPTEMBER  IS  NOT YET  AVAILABLE.

-------
  EPA  UTILITY  FGD  SURVEY:  JULY  - SEPTEMBER  1980

                                            SECTION  3
                DESI6N  AND PERFORMANCE  DATA  FOR OPERATIONAL  DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 CROSS UNIT GENERATING CAPACITY - MU
 NET UNIT 6ENERATIN6 CAPACITY W/F6D - My
 EQUIVALENT SCRUBBED CAPACITY - MU

 •• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE NEAT CONTENT - J/6
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

 •• GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS 1VPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY - X
     A9SORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 *• WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 »* DISPOSAL
     TYPE
                                          ALABAMA ELECTRIC COOP
                                          TOHBIGBEE
                                          3
                                          LEROY
                                          ALABAMA
                                            255.0
                                            235.0
                                            179.0
                                                         I 115.00 BTU/LB)
                                          COAL
                                          BITUMINOUS
                                           267*9.
                                             14.00
                                             7.00
                                             1.15
                                               .04
                                          MET  SCRUBBING
                                          LIMESTONE
                                          PEABODY  PROCESS  SYSTEMS
                                          NEU
                                              3.1
                                           6/79
                                           6/79
                                            59.50
                                            99.30
                                              .0
                                              .0
                                          CLOSED
                                             8.8
                                                LINED POND
                                                         C  140 GPH)
	.	PERFORMANCE DATA	—	—	.......
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  x REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOURS FACTOR
 1/80
A
B
SYSTEM
                               69.2
                               4S.4
                               57.3
                                                30.5
                                                20.0
                                                25.3
           100.0        57.3                    25.3                  744   328

** PROBLEMS/SOLUTIONS/COMMENTS

                  DURING JANUARY UNIT 3 HAS AVAILABLE THE ENTIRE MONTH.
                                                                                          188
 2/80
       A
       B
       SYSTEM
                        33.3
                       100.0
                        66.7
           100.0

•* PROBLEMS/SOLUTIONS/COMMENTS
                                                 1.2
                                                 3.5
                                                 2.4
                                                                      696
                                                                                    16
                         DURING  FEBRUARY  THE  UNIT 3 BOILER AND FGD SYSTEM OPERATED ONLY 24 HOURS.
                         THE  FGD SYSTEM HAS  AVAILABLE  THE ENTIRE MONTH.
3/80   SYSTEM      100.0

       ** PROBLEMS/SOLUTIONS/COMNENTS
                                                  .0
4/80  SYSTEM
                         DURING  MARCH  THE  UNIT  3  GENERATOR  WAS  KEPT  OUT  OF  SERVICE.
                         MAS  AVAILABLE  THE  ENTIRE MONTH.

                                                         .0
                                                                      744     0      0    .0



                                                                              THE FGD SYSTEM


                                                                      720     0      0    .0
                                                46

-------
                                              EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980




ALABA«U ELECTRIC COOP: TONBISBEE 3 (CONT.)
	 PERFORMANCE DATA 	 	 	 — — — — ———————
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER F60 CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*« PROBLEMS/SOLUTIONS/COHMENTS
THE UTILITY REPORTED THAT DURING APRIL THE BOILER DID NOT OPERATE.
5/80 A
B
SYSTEM
95.8
8.3
.0
4.2
.7
.0
.3 744 60 5

** PROBLEMS/SOLUTIONS/COMMENTS
THE F6D SYSTEM WAS AVAILABLE 713 HOURS DURING HAY; HOWEVER* THE BOILER
OPERATED 60 HOURS DUE TO BOILER RELATED PROBLEMS.

i/80 A
B
SYSTEM

100.0
100.0
100.0
THE B MODULE WAS OUT FOR
CAUSING THE DRIVE MOTOR
59.1 100.0
58.6 100.0
58.9 100.0
31 HOURS WHEN THE INLET DAMPER SWITCH FAILED
TO BURN OUT.
52.8
52.4
52.6 720 643 379
ONLY

52.0
• * PROBLEMS/SOLUTIONS/COMMENTS
NO FGD SYSTEM-RELATED PROBLEMS WERE ENCOUNTERED DURING JUNE.
7/80 A
B
SYSTEM
100.0
100.0
100.0
45.5 100.0
90.0 100.0
67.8 100.0
39.7
78.6
59.2 744 650 440
47.8
** PROBLENS/SOLUTIONS/COMMENTS
THE FGD SYSTEM WAS AVAILABLE FOR OPERATION THE ENTIRE MONTH OF JULY.
NODULES ARE UTILIZED ON AN AS NEEDED BASIS.
i/80 A
B
SYSTEM
100.0
100.0
100.0
95.7 100.0
91.6 100.0
93.7 100.0
75.8
72.6
74.2 744 590 552
THE
63.4
        •*  PROBLEflS/SOLUTIONS/COMNENTS



                          NO F60-RELATED PROBLEMS WERE ENCOUNTERED DURING THE MONTH  OF  AUGUST.




  »/80   SYSTEM                                                                 720



        ••  PROBLEMS/SOLUTIONS/COMMENTS




                          THE INFORMATION FOR THE MONTH OF SEPTEHBER  IS  NOT  VET  AVAILABLE.

-------
  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY NAME
  PLANT NAME
  JNIT NUMBER
  CITY
  STATE
  5ROSS UNIT 6ENERATIN6  CAPACITY  - MU
  NET  UNIT  6ENERATIN6  CAPACITY  W/FGD  - MW
  EOUIVALENT SCRUBBED  CAPACITY  -  MU

  •*  FUEL DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE  HEAT  CONTENT  -  J/G
      AVERAGE  ASH CONTENT - X
      AVERAGE  MOISTURE CONTENT  -  X
      AVERAGE  SULFUR CONTENT  -  X
      AVERAGE  CHLORIDE CONTENT  -  X

  •* GENERAL  EMISSION  CONTROL SYSTEM  DATA
      GENERAL  PROCESS  TYPE
      PROCESS  TYPE
      SYSTEM  SUPPLIER
      NEU/RETROFIT
      ENERGY CONSUMPTION -  X
      INITIAL  START-UP DATE
      COMHERCIAL START-UP DATE
      S02 DESIGN REMOVAL EFFICIENCY - X
      PARTICULATE DESIGN REMOVAL  EFFICIENCY
      ABSORBER SPARE CAPACITY INDEX - X
      ABSORBER SPARE COMPONENTS INDEX

 •* HATER LOOP
      TYPE
      FRESH MAKE-UP MATER - LITER/S

 •* DISPOSAL
      TYPE
                                           - X
                                                ARIZONA ELECTRIC POyER COOP
                                                APACHE
                                                2
                                                COCHISE
                                                ARIZONA
                                                  195.0
                                                  175.0
                                                   98.0
                                                COAL
                                                BITUMINOUS
                                                 23260.
                                                   15.00
                                                    9.00
                                                     .55
                                                ********
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
    4.1
 8/78
 1/79
   42.50
   99.50
  100.0
    1.0
               C 10000 BTU/LB)
                                                OPEN
                                                  115.9
                                                POND
               ( 1840 6PM)
...._.._._—— ——————	——PERFORMANCE  DATA	—
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   x  REMOVAL    PER   BOILER   FGD   CAP.
                                                                 S02   PART.  HOURS  HOURS   HOURS FACTOR
                                                                              744    731     426  56.1
1/80  SYSTEM      91.0         58.3        88.8         57.3     97.40

      ** PROBLEMS/SOLUTIONS/COMMENTS

                        DURING JANUARY  SOME  OUTAGE  TIME  WAS  DUE  TO A  PUMP  MALFUNCTION.

                        OUTAGE TIME WAS ALSO CAUSED BY A BROKEN  FEfcD  BELT  TO  THE  LIMESTONE  BALL
                        MILL.

2/80  SYSTEM      92.8         96.7        92.8         92.8     97.40          696    668     646  87.4

      *• PROBLEMS/SOLUTIONS/COMMENTS

                        DURING FEBRUARY OUTAGE TIME RESULTED  FROM AN  ESP FAILURE.

                        FORCED OUTAGE TIME WAS ALSO CAUSED BY  A  PUMP  MALFUNCTION.

3/80  SYSTEM      99.1         99.1        99.0         99.1                   744    744     738  74.1

      ** PROBLEMS/SOLUTIONS/COHNENTS

                        SOME OF THE OUTAGE TIME DURING MARCH  OCCURRED  BECAUSE  OF  PUMP FAILURES.

                        OUTAGE TIME RESULTED FROM STICKING VALVES AND  LIMESTONE FEED-BELT
                        PROBLEMS.
 4/80  SYSTEM
                  67.2
                              65.2
                                           65.2
                                                       61.4
                             720   678    442
                                                48

-------
                                              EPA UTILITY FGD SURVEY:  JULY  -  SEPTEMBER  1980

ARIZONA ELECTRIC POWER COOP: APACHE 2 CCONT.)
	_—...	— — -. ——.	-PERFORMANCE DATA —	—	—	—	—————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   I  REMOVAL    PER   BOILER   FGD   CAP.
                                                                 S02   PART. HOURS  HOURS   HOURS FACTOR


       *• PROBLEMS/SOLUTIONS/COMHENTS

                         DURING APRIL THE  F6D  SYSTEM HAS  FORCED  DOWN  DUE TO PUMP  FAILURES AND A
                         RUPTURE IN THE  SLURRY  RECIRCULATION  LINE.

 S/BO  SYSTEM      90.5        90.5        90.5         V0.5                   7**    744     673

       ** PROBLENS/SQLUTIONS/COMMENTS

                         DURING MAY THE  UNIT HAS  FORCED OFF  LINE WHEN THE LIMESTONE CRUSHER
                         MALFUNCTIONED.

                         THE UNIT WAS ALSO FORCED OUT  DUE TO  PUMP  AND VALVE FAILURES.

 6/80  SYSTEM                                                                 720

       ** PROBLEMS/SOLUTIONS/COMNENTS

                         INFORMATION WAS NOT AVAILABLE  FOR  THE  MONTH OF JUNE.

 7/80  202         100.0          .0                       .0
       203         85.0        85.7        85.7        85.0
       SYSTEM      100.0        85.7        85.7        85.0                  7*4   738    633   77.8

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NODULE  202 HAS  AVAILABLE THE  ENTIRE MONTH. BUT MAS NOT  OPERATED.

                         THE  FED SYSTEM  WAS  DOWN IN  JULY BECAUSE OF A CIRCUIT BREAKER MALFUNCTION.

                         FAILURE OF BOTH THE  BYPASS  DAMPCR AND  THE PACKING  PUMP  ALSO CAUSED  OUTAGE
                         TIME  DURING  THE MONTH.

 8/80  202            .0           .0                       .0
       203          96.8         66.0         95.2        63.3
       SYSTEM       96.8         66.0         95.2        63.3                  744  714     471   61.0

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          TOWER 202  WAS  UNAVAILABLE IN  AUGUST BECAUSE  OF THE LINER  BEING REPLACED.

                          A SAMPLE  LINE  FAILURE CAUSED  TOWER  203 TO GO DOWN  FOR 24  HOURS.

                          THE OPERATION  OF THE F6D SYSTEM WAS REDUCED  BECAUSE OF  LOW  LOAD CAPACITY.

 »/80  SYSTEM                                                                 720

        • *  PROBLEMS/SOLUTIONS/COMKENTS

                          NO INFORMATION WAS AVAILABLE  FOR SEPTEMBER  1980.
                                                  49

-------
  EPA UTILITY FGD SURVEY:  JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  F6D SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  UNIT NUMBER
  CITY
  STATE
  EROSS  UNIT GENERATING  CAPACITY  - NW
  MET  UNIT GENERATING  CAPACITY W/F6D  - MW
  EQUIVALENT SCRUBBED  CAPACITY -  MM

  ••  FUEL  DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE HEAT  CONTENT  -  J/6
      AVERAGE ASH CONTENT - X
      AVERAGE MOISTURE CONTENT -  Z
      AVERAGE SULFUR CONTENT  - Z
      AVERAGE CHLORIDE CONTENT -  X

  •• GENERAL EMISSION  CONTROL SYSTEM  DATA
      GENERAL PROCESS  TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION -  X
      INITIAL START-UP DATE
      COMMERCIAL START-UP DATE
      S02  DESIGN REMOVAL EFFICIENCY - X
      PARTICULATE DESIGN REMOVAL  EFFICIENCY
      ABSORBER SPARE CAPACITY  INDEX - X
      ABSORBER SPARE COMPONENTS INDEX

  •• WATER LOOP
      TYPE
      FRESH MAKE-UP HATER - LITER/S

  •• DISPOSAL
      TYPE
- X
      ARIZONA ELECTRIC POWER COOP
      APACHE
      3
      COCHISE
      ARIZONA
       19S.O
       175.0
        98. 0
     COAL
     BITUMINOUS
      23260.
        15.00
         9.00
          .55
     ********
MET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
    4.1
 6/79
 4/79
   42.50
   99.50
  100.0
    1.0
               < 10000 BTU/LB)
     OPEN
       340.2
     POND
               < 5400 6PH)
............	PERFORMANCE DATA—	——	—————......___
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                S02  PART. HOURS HOURS  HOURS FACTOR
                                  744    744     682   89.7
 1/80  SYSTEM      91.7        91.7        91.7        91.7    97.40

       ** PROBLENS/SOLUTIONS/COHMENTS

                         DURING JANUARY SOME OUTAGE TIME WAS DUE TO A PUMP MALFUNCTION.

                         OUTAGE TIME WAS ALSO CAUSED BY A BROKEN FEED BELT TO THE LIMESTONE BALL
                         MILL.
                                  696    671    497   83.5
 2/80  SYSTEM      95.6        74.1         96.0        71.4    97.40

       **  PROBLEMS/SOLUTIONS/COHMENTS

                         DURING FEBRUARY OUTAGE TIME RESULTED FROM AN ESP FAILURE.

                         FORCED OUTAGE  TIME WAS ALSO CAUSED BY A PUMP MALFUNCTION.

 5/80  SYSTEM      90.9        90.9         90.9        90.9                  744    744    677  91.1

       **  PROBLEMS/SOLUTIONS/COMMENTS

                         SOME  OF  THE  OUTAGE TIME DURING MARCH OCCURRED BECAUSE OF PUMP FAILURE.
                         OUTAGE  TINE  RESULTED  FROM  STICKING  VALVES  AND LIMESTONE  FEED-BELT
                         PROBLEMS.
4/80   SYSTEM
                   99.0
                               96.9
                                           96.9
           30.6
                            720   227    220
                                                SO

-------
                                              EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

ARIZONA ELECTRIC POWER COOP: APACHE 3 CCONT.)
......—....	..-—.--.....-....—._pERFORHANCE DATA———————	——————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  t REMOVAL   PER  BOILER  F60    CAP.
                                                                502  PART. HOURS HOURS   HOURS FACTOR


       •• PROBLEMS/SOLUTIONS/COMNENTS

                         DURING APRIL THE FGD SYSTEM HAS  FORCED DOWN DUE  TO PUMP FAILURES  AND A
                         RUPTURE IN THE SLURRY RECIRCULATION LINE.

 5/80  SYSTEM        .0          .0                       .0                   744    39       0

       •< PROBLEMS/SOLUTIONS/COMHENTS

                         THE BOILER AND F6D  SYSTEM WERE  DOWN FOR A SCHEDULED  OVERHAUL.   THE LINERS
                         IN THE ABSORBER QUENCHER HAD TO  BE REPAIRED.   THE BOILER  RETURNED TO  SER-
                         VICE BEFORE REPAIR  WORK FOR THE  FGD SYSTEM WAS  COMPLETE.   THE  FGD SYSTEM
                         MAS UNAVAILABLE IN  MAY BECAUSE  OF THIS OVERHAUL.

 6/BO  SYSTEM                                                                 720

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION MAS NOT AVAILABLE  FOR THE  MONTH  OF  JUNE.

 7/80  302          29.0         30.0         90.0         29.0
       303           .0          .0                       .0
       SYSTEM       29.0         30.0         90.0         29.0                   744   721     216  49.3

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         BOTH  NODULES  WERE  UNAVAILABLE  BECAUSE  OF  REPLACEMENT OF THE ABSORBER  LINER.
                         NODULE 302  WAS  OUT OF  SERVICE  FOR  22  DAYS,  WHILE MODULE 303 WAS  OUT OF
                         SERVICE DURING  ALL OF  JULY.

                         A PACKING  PUMP  FAILURE  CAUSED  THE  FGD  SYSTEM TO GO DOUN.

 5/80  302          98.5         47.8         96.3         38.4
       303          98.5         19.3         91.3         15.5
       SYSTEM       98.5         67.1         94.8         54.0                  744   599     402  41.5

       •• PROBLEMS/SOLUT10NS/COHNENTS

                          TOWER 302  WAS UNAVAILABLE DURING PART OF AUGUST BECAUSE OF  A QUENCHER
                          PUMP  FAILURE.

                          DUE TO A  SAMPLING LINE FAILURE  IN AUGUST, TOWER 303 WAS SHUT DOWN  FOR
                          PART  OF THE MONTH.

                          THE REDUCED RATE OF FGD OPERATION IN AUGUSZ WAS A RESULT  OF BOILER UNIT
                          PROBLEMS  AND REDUCED LOAD CAPACITY.

  9/80  SYSTEM                                                                 720

        • *  PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION WAS  AVAILABLE FOR SEPTEMBER 1980.
                                                  SI

-------
  EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980
                DESIGN AND PERFORMANCE DATA
                                            SECTION 3
                                            FOR OPERATIONAL DOMESTIC  F6D SYSTEMS
  COMPANY  NAME
  PLANT NAME
  i/NIT NUMBER
  CI1Y
  STATE
  SRCSS UNIT GENERATING CAPACITY - MM
  NET  UNIT GENERATING CAPACITY M/FGD - MW
  EQUIVALENT SCRUBBED CAPACITY - MB
                                          ARIZONA  PUBLIC  SERVICE
                                          CHOLLA
                                          1
                                          JOSEPH CITY
                                          ARIZONA
                                             119.0
                                             115.0
                                             119.0
  **  FUEL  DATA
      FJEL TYPE
      FUEL GRADE
      AVERAGE  HEAT  CONTENT - J/G
      AVERAGE  ASH CONTENT - X
      AVERAGE  MOISTURE  CONTENT - t
      AVERAGE  SULFUR  CONTENT - X
      AVERAGE  CHLORIDE  CONTENT - Z

  •*  GENERAL EMISSION CONTROL SYSTEM DATA
      6ENERAL  PROCESS TYPE
      PROCESS  TYPE
      SYSTEM SUPPLIER
      NEH/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL  START-UP  DATE
      COMMERCIAL START-UP DATE
      532  DESIGN REMOVAL  EFFICIENCY  - X
      PARTICULATE DESIGN  REMOVAL EFFICIENCY
      ABSORBER SPARE  CAPACITY INDEX  - X
      ABSORBER SPARE  COMPONENTS  INDEX

  •*  HATER  LOOP
      TYPE
      FRESH MAKE-UP HATER  - LITER/S

  ••  DISPOSAL
      TYPE
                                     - X
                                          COAL
                                          BITUMINOUS
                                           23609.
                                             13.50
                                             15.00
                                               .50
                                               .02
                   UET SCRUBBING
                   LIMESTONE
                   RESEAfiCH-COTTRELL
                   RETROFIT
                       3.4
                   10/73
                   12/73
                      S8.SO
                      80.00
                        .0
                        .0
                                  ( 10150 BTU/LB)
                                          OPEN
                                              7.6
                                  (  ICO 6PM)
                                          POND
...—...b—	—,—..	——	-—PERFORMANCE  DATA——-
•ERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                                                          X REMOVAL
                                                          S02  PART.
                                                                             PER  BOILER  FGD   CAP.
                                                                            HOURS HOURS  HOURS FACTOR
11/79  A
       B
       SYSTEM

n/79  A
       B
       SYSTEM
 1/80
 5/80
 4/80
       A
       B
       SYSTEM
 2/80  A
       B
       SYSTEM
                  100.0
A
B
SYSTEM
 77.0
 98.5
 87.8

 94.0
 86.7
 90.4

 95.5
 99.1
 97.5

100.0
 99.4
 99.7

 99.1
 93.1
 96.1
          PROBLEMS/SOLUTIONS/COMMENTS
                                    100.0
              77.0
              98.5
              87.8

              94.0
              86.7
              90.4

              95.5
              99.1
              97.3

            100.0
              99.4
              99.7

              99.1
              93.1
              96.1
                                                                       720   720    632
                                                                       744   744    672
                                                                       744   744    724  91.7
                                                                       696   696    694  92.1
                                                                              744    744     715   88.6
                         NO FORCED OUTAGES UERE REPORTED BY THE UTILITY  FOR  THE  FIVE  MONTH  PERIOD
                         OF NOVEMBER 1979 THROUGH MARCH 1980.  SOME SCHEDULED OUTAGE  TIME HAS
                         REQUIRED FOR REPAIR OF THE REHEATER DUCTWORK.
       A
       B
       SYSTEM
           100.0
           100.0
           100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
720   720
                                                                                    720  82.8
                                                52

-------
                                              EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

ARIZONA PUBLIC SERVICE: CMOLLA 1 (CONT.)
——	——	—	—	—	--PERFORMANCE 6ATA—	——-—	—	——~-
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   X  REMOVAL   PER   BOILER  F6D   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR


       »* PR08LEMS/SOLUTIONS/CONMENTS

                         NO  FGD-RELATED PROBLEMS  WERE REPORTED  FOR THE  MONTH OF  APRIL.

 5/80  A          100.0        100.0        100.0       100.0
       B           99.2        99.2         99.2        99.2
       SYSTEM      99.6        99.6         99.6        99.6                  744   744    741  87.6

       ** PROBLENS/SOLUT10NS/CONMENTS

                         THE B-MODULE OUTAGE  TIME IN HAY WAS  CAUSED  BY  PROBLEMS  UITH THE BOOSTER
                         FAN.

 i/80  A          100.0        80.7        100.0        68.7
       B           99.3        87.7         99.1        74.6
       SYSTEM      99.7        84.2         99.6        71.7                  720   613    516  67.5

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         DURING  JUNE  SCHEDULED  MAINTENANCE  MAS  PERFORMED ON THE BOILER.  THE
                         SCHEDULED OUTAGE  TIME  WAS NECESSARY  TO ACID WASH THE CONDENSERS.

                         THE ONLY  FGD-RELATED OUTAGE  OCCURRED WHEN A BLOCK VALVE MALFUNCTIONED.
                         THE B-MODULE HAS  OUT OF  SERVICE FOR  FIVE HOURS.

 7/80  A          100.0        100.0        100.0       100.0
       B          100.0        98.6        100.0        98.6
       SYSTEM     100.0        99.3        100.0        99.3                  744    744     739  95.8

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM  WAS AVAILABLE 1OOZ OF THE TIME  IN JULY.  MODULE  B  WAS  NOT
                         UTILIZED  FOR PART OF THE MONTH  DUE TO  LOU BOILER LOAD.

 S/80  SYSTEM                                                                 744

 9/80  SYSTEM                                                                 720

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          DATA  FOR  THE AUGUST AND SEPTEMBER MONTHS WfcRE  NOT  AVAILABLE  DUE TO
                          PERSONNEL CHANGES.
                                                  53

-------
  EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
 COMPANY NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY - MU
 NET  UNIT  GENERATING  CAPACITY U/F6D - MW
 EQUIVALENT SCRUBBED  CAPACITY - NU

 ••  FUEL DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT -  J/6
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE  CONTENT - X
     AVERAGE SULFUR CONTENT  - X
     AVERAGE CHLORIDE  CONTENT - X

 •• GENERAL EMISSION  CONTROL SYSTEM DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP  DATE
     S02 DESIGN REMOVAL EFFICIENCY  -  X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY  INDEX  -  X-
     ABSORBER SPARE COMPONENTS  INDEX

•* HATER LOOP
     TYPE
     FRESH MAKE-UP WATER  - LITER/S

*• DISPOSAL
    TYPE
                                            - X
                                                 ARIZONA PUBLIC  SERVKE
                                                 CHOLLA
                                                 2
                                                 JOSEPH CITY
                                                 ARIZONA
                                                   264.0
                                                   235.0
                                                   264.0
                                                 COAL
                                                 BITUMINOUS
                                                  23609.
                                                    13.SO
                                                    15.00
                                                      .50
                                                      .02
MET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
*******
 4/78
 6/78
   75.00
   99.70
   33.0
    1.0
                ( 10150 6TU/LB)
                                                 OPEN
                                                     7.6
                                                 UNLINED  POND
               t  1CO GPM)
.	.	_	„__....—.-.-....—-._...._pERfORNANCE  DATA—-———	—-—___.__„_
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X REMOVAL    PER   BOILER   FGD    CAP
                                                                 SO?  PART.  HOURS  HOURS   HOURS  FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                                                            744

                                                                            696

                                                                            744
                         NO INFORMATION IS AVAILABLE AS OF YET WITH RESPECT TO THE CHOLLA 2 FGD
                         OPERATIONS.
 4/80  SYSTEM

 S/BO  SYSTEM

 4/80  SYSTEM

       *•  PROBLEMS/SOLUTIONS/COMNENTS
                                                                            720

                                                                            744

                                                                            720
7/80   SYSTEM

1/80   SYSTEM

J/80   SYSTEM
                        THE  FGD  SYSTEM  PERFORMANCE  DATA FOR THE APRIL-JUNE PERIOD ARE NOT AVAILABLE
                        AT THIS  TIME.                                                             "

                                                                            744

                                                                            744

                                                                            720
                                                54

-------
                                              EPA UTILITY  F6D  SURVEY:  JULY  -  SEPTEMBER  1980

ARIZONA PUBLIC SERVICE: CHOLLA 2 
-------
  EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  F6D  SYSTEMS
  COMPANY WANE
  PLANT NAME
  JNIT NUMBER
  CITY
  STATE
  SROSS UNIT GENERATING CAPACITY - MU
  «ET  UNIT  GENERATING CAPACITY W/FGD - My
  EQUIVALENT SCRUBBED CAPACITY - MU

  •*  FUEL DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE  HEAT  CONTENT - J/G
      AVERAGE  ASH  CONTENT - X
      AVERAGE  MOISTURE  CONTENT - X
      AVERAGE  SULFUR  CONTENT - X
      AVERAGE  CHLORIDE  CONTENT - X

  *• GENERAL  EMISSION CONTROL SYSTEM DATA
      GENERAL  PROCESS TYPE
      PROCESS  TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL  START-UP  DATE
      COMMERCIAL START-UP DATE
      S02 DESIGN REMOVAL  EFFICIENCY  - X
      PARTICULATE DESIGN  REMOVAL EFFICIENCY
      ABSORBER SPARE  CAPACITY INDEX  - X
      ABSORBER SPARE  COMPONENTS  INDEX
                         ARIZONA  PUBLIC  SERVICE
                         FOUR  CORNERS
                         1
                         FARMINGTON
                         NEW MEXICO
                          175.0
                          175.0
                          175.0
                                        (  8600  BTU/L8)
                   - X
COAL
SUBBITUMINOUS
 20004.
   22.00
   12.30
     .75
     .07
UET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
RETROFIT
*******
11/79
**/**
   80.00
   99.00
     .0
     .0
...—.-....——-— —	..	PERFORMANCE DATA	———————————..___._.__
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY  UTILIZATION  X RbflOVAL   PER  BOILER  FGD   CAP
                                                                 302  PART. HOURS HOURS  HOURS FACTOR


11/79  SYSTEM                                                                 720

12/79  SYSTEM                                                                 7**

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         INITIAL OPERATIONS  STARTED  IN  NOVEMBER  1979.

 1/80  SYSTEM                                                                 744

 a/80  SYSTEM                                                                 696

 5/80  SYSTEM                                                                 744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT IS PRESENTLY  IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.

 4/80  SYSTEM                                                                 720

 5/80  SYSTEM                                                                 744

 6/80  SYSTEM                                                                 720

       ** PROBLEMS/SOLUTIONS/COMMENTS
 7/80   SYSTEM

 i/60   SYSTEM

 »/80   SYSTEM
ALTHOUGH THE FGD SYSTEM PERFORMANCE  DATA  ARE  BEING  LOGGED,  THE UTILITY
REPORTED THAT IT IS UNAVAILABLE  FOR  RELEASE  AT  THIS TIME.

                                                     744

                                                     744

                                                     720

-------
                                               EP* UTILITY  FGO  SURVEY:  JULY - SEPTEMBER 1980

ARIZONA PUBLIC SERVICE:  FOUR  CORNERS 1  (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   Z  REMOVAL   PER  BOILER  F6D    CAP.
                                                                  S02   PART. HOURS HOURS  HOURS  FACTOR


       ** PROBLEMS/SOLUTIONS/COMNENTS

                          THE  THIRD QUARTER UPDATE INFORMATION IS NOT YET AVAILABLE.
                                                  57

-------
  EPA UTILITY FGD SURVET:  JULY  -  SEPTEMBER  1980

                                             SECTION  3
                DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL  DOMESTIC  F6D  SYSTEMS
  COMPANY NAME
  PLANT NAME
  UNIT NUMBER
  CITY
  STATE
  CROSS UNIT GENERATING CAPACITY - NW
  HET UNIT GENERATING CAPACITY N/FGD - MU
  EBUIVALENT SCRUBBED CAPACITY - KM

  ••  FUEL DATA
      FUEL TTPE
      FUEL GRADE
      AVERAGE  HEAT CONTENT - J/G
      AVERAGE  ASH CONTENT  - X
      AVERAGE  MOISTURE  CONTENT - Z
      AVERAGE  SULFUR  CONTENT - X
      AVERAGE  CHLORIDE  CONTENT - X

  ••  GENERAL EMISSION CONTROL SYSTEM DATA
      tENERAL  PROCESS TYPE
      PROCESS  TYPE
      SYSTEM SUPPLIER
      HEM/RETROFIT
      ENERGY CONSUMPTION - X
      INITIAL  START-UP  DATE
      COMMERCIAL  START-UP  DATE
      S02  DESIGN  REMOVAL EFFICIENCY - X
      PARTICULATE DESIGN REMOVAL EFFICIENCY
      ABSORBER SPARE  CAPACITY INDEX - X
      ABSORBER SPARE  COMPONENTS  INDEX
                                                  ARIZONA  PUBLIC  SERVICE
                                                  FOUR  CORNERS
                                                  2
                                                  FARMINGTON
                                                  NEW MEXICO
                                                    175.0
                                                    175.0
                                                    175.0
                                                                 <   8600  BTU/LB)
                                            - X
COAL
SUBBITUMINOUS
 20004.
   12.00
   12.30
     .75
     .07
WET SCRUBBING
LIME/ALKALINE FLYASN
CHEMICO DIVISION, EMVIROTECH
RETROFIT
•»••**»
11/79
**/ •*
   80.00
   99.90
     .0
     .0
...........„„....——..---	-PERFORMANCE DATA--	————————.—..___,.____
PERIOD NODULE AVAILABILITY  OPERABIL1TY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS  FACTOR
                                                                              720

                                                                              744
11/79  SYSTEM

1Z/79  SYSTEM

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         INITIAL  OPERATIONS STARTED IN NOVEMBER 1979.

 1/80  SYSTEM                                                                 744

 Z/BO  SYSTEM                                                                 696

 5/80  SYSTEM                                                                 744

       • * PROBLEMS/SOLUTIONS/COMMENTS

                         THE  UNIT  IS PRESENTLY IN THE SHAKEDOWN/DEBUGGING PHASE OF OPERATION.

 4/80  SYSTEM                                                                 720

 5/80  SYSTEM                                                                 744

 i/80  SYSTEM                                                                 720

       ** PROBLEHS/SOLUTIONS/COHMENTS

                         ALTHOUGH  THE  FGD  SYSTEM  PERFORMANCE DATA  ARE BEING LOGGED, THE UTILITY
                         REPORTED  THAT  IT  IS  UNAVAILABLE  FOR RELEASE AT THIS TINE.
 7/80  SYSTEM

 J/BO  SYSTEM

 9/80  SYSTEM
                                                                              744

                                                                              744

                                                                              720
                                                58

-------
                                               EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

ARIZONA PUBLIC SERVICE: FOUR CORNERS 2  (CONT.)
	-PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F6D   CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS FACTOR


       •* PROBLEHS/SOLUTIONS/COMMENTS

                         THE THIRD  QUARTER  UPDATE  INFORMATION IS NOT YET AVAILABLE.

-------
  EPA UTILITY  F60  SURVEY: JULY - SEPTEMBER 198C

                                             SECTION 3
                 DESIGN ANO PERFORMANCE OAT* FOR OPERATIONAL  DOMESTIC  FGD  SYSTEMS
  CONPANY NAME
  PLANT NAME
  JN1T NUM3ER
  CITY
  STATE
  SROSS UNIT GENERATING CAPACITY - Mw
  «ET UNIT GENERATING CAPACITY W/FGD - MW
  EQUIVALENT SCRUBBED CAPACITY - »tf

  •* FUEL  DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE  HEAT CONTENT - J/G
      AVERAGE  ASH CONTENT - X
      AVERAGE  MOISTURE CONTENT - I
      AVERAGE  SULFUR CONTENT - X
      AVERAGE  CHLORIDE CONTENT - X

  •* GENERAL EMISSION  CONTROL SYSTEM  DATA
      GENERAL  PROCESS  TYPE
      PROCESS  TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL  START-UP DATE
      COMMERCIAL  START-UP  DATE
      S02 DESIGN  REMOVAL  EFFICIENCY  - X
      PARTICULATE DESIGN  REMOVAL  EFFICIENCY
      A3SORBER SPARE CAPACITY  INDEX - X
      ABSORBER SPARE COMPONENTS  INDEX
                                                  ARIZONA PUBLIC SERVICE
                                                  FOUR CORNERS
                                                  3
                                                  FARMINGTON
                                                  NEW  MEXICO
                                                    229.0
                                                    229.0
                                                    229.0
                                                                 (   8600  BTU/LB)
COAL
SUBBITUMINOUS
 20004.
   22.00
   12.30
     .75
     .07
                                                 WET SCRUBBING
                                                 LIME/ALKALINE  FLYASH
                                                 CHEMICO  DIVISION,  ENVIROTECH
                                                 RETROFIT
                                                 11/79
                                                 **/ ••
                                                    80.00
                                              X     99.00
                                                      .0
                                                      .0
	.	 — PERFORMANCE DATA	-—._«.
PERIOD MODULE AVAILABILITY  OPERAB1LITY  RELIABILITY UTILIZATION  X RtWOVAL   PER  BOILER   FGD    C*p"~
                                                                 SO?  PART. HOURS HOURS   HOURS  FACTOR
                                                                              720

                                                                              744
                                                                              744

                                                                              696

                                                                              744
11/79  SYSTEM

12/79  SYSTEM
       •* PROBLEMS/SOLUTIONS/COMMENTS

                          INITIAL OPERATIONS STARTED IN NOVEMBER 1979.

 1/80  SYSTEM

 2/80  SYSTEM

 3/BO  SYSTEM
       *• PROBLEMS/SOLUTIONS/COMMENTS

                          THE  UNIT IS PRESENTLY IN THE SHAKEDOWN/BEPUGGING PHASE OF OPERATION.

 t/BO  SYSTEM                                                                 720

 5/80  SYSTEM                                                                 744

 1/80  SYSTEM                                                                 720

       *• PROBLEMS/SOLUTIONS/COMMENTS

                          ALTHOUGH THE FGD  SYSTEM PERFORMANCE DATA ARE BEING LOGGED, THE UTILITY
                          REPORTED THAT  IT  is  UNAVAILABLE FOR RELEASE AT THIS TIME.
 7/80  SYSTEM

 1/80  SYSTEM

 7/80  SYSTEM
                                                                              744

                                                                              744

                                                                              720
                                                 60

-------
                                               EPA  UTILITY  FGB SURVEY: JULY - SEPTEMBER 1980

ARIZONA PUBLIC SERVICE: FOUR CORNERS 3  (CONT.)
..—._	_—._.—...	PERFORMANCE DATA	——«——	——	—-—	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F6D    CAP.
                                                                 302  PART. HOURS HOURS   HOURS FACTOR


       •• PROBLENS/SOLUTIONS/COMNENTS

                         NO INFORMATION HAS  AVAILABLE FOR THE THIRD QUARTER 1980.
                                                  61

-------
  EPA  UTILITY FED SURVEY: JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FCD SYSTEMS
  COMPANY  NAME
  PLANT  NAXE
  JHIT NUMBER
  CITY
  STATE
  REGULATORY CLASSIFICATION
  PARTICULATE EMISSION  LIMITATION - N6/J
  S02 EMISSION.  LIMITATION  -  NG/J
  «ET PLANT 6ENERATTNS  CAPACITY  - KW
  SROSS  UNIT GENERATING  CAPACITY  - My
  »ET UNIT GENERATING CAPACITY U/F6D - My
  VET UNIT GENERATING CAPACITY UO/F6D - MW
  EOUIVALENT SCRUBBED CAPACITY -  MW

  •* BOILER DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL SERVICE DATE
     HAXHUM BOILER FLUE  GAS FLOW - CU.M/S
     FLUE GAS  TEMPERATURE - C
     STACK HEIGHT - H
     STACK TOP DIAMETER - M

 •• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE HEAT CONTENT - 3TU/LB
     AVERAGE ASH CONTENT - X
     RANGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - Z
     RANGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE SULFUR CONTENT - *
     AVERAGE CHLORIDE CONTENT - X
     RANGE CHLORIDE CONTENT - X

 •*  GENERAL  EMISSION CONTROL SYSTEM DATA
     SALEABLE  PRODUCT/THROMAWAY  PRODUCT
     GENERAL PROCESS TYPE
     PROCESS  TYPE
     SYSTEM  SUPPLIER
     A-E FIRM
     CONSTRUCTION  FIRM
     DEVELOPMENT  LEVEL
     NEW/RETROFIT
     PARTICULATE  DFSIGN REMOVAL  EFFICIENCY - X
     S02  DESIGN REMOVAL EFFICIENCY - X
     COMMERCIAL DATE
     INITIAL  START-UP
     CONSTRUCTION  INITIATION
    CONTRACT AWARDED
    LETTER  OF  INTENT  SIGNED

• •  ESP
    NUMBER
    TYPE
    SUPPLIER
    PARTICULATE DESIGN  REMOVAL EFFICIENCY - X
    FLUE GAS CAPACITY  - CU.M/S
    FLUE GAS TEMPERATURE  -  C
    PRESSURE DROP - KPA
    PARTICULATE OUTLET  LOAD - G/CU.M

•• A9SOR3ER
    NUMBER
    TYPE
    INITIAL START UP
    SUPPLIER
    DIMENSIONS - FT
    SHELL MATERIAL
    BOILER LOAD/ABSORBER - I
    SAS  FLOW - CU.M/S
  BASIN  ELECTRIC  POWER  COOP
  LARAMIE  RIVER
  1
  WHEATLAND
  WYOMING
  C
     43.          (
     86.          C
  1500.0
   570.0
   500.0
   500.0
   570.0
 BABCOCK ( WILCOX
 PULVERIZED COAL
 BASE
  4/80
    .tOO LB/MMBTU)
    .COO LB/MMBTU)
  1321.32
    56.1
   183.
     8.7
 COAL
 SUBBITUMINOUS
  18931.

     7.89
 ******
    28.92
 ******
      .81
 .15-.81
      .04
 ******
 THROWAWAY  PRODUCT
 WET  SCRUBBING
 LIMESTONE
 RESEARCH-COTTRELL
 BURNS  K  MCDONNELL
 RESEARCH-COTTRELL
 FULL SCALE
 NEW
   99.60
   90.00
  7/80
  7/80
  1/78
  1/77
 12/76
COLD SIDE
BABCOCK I WILCOX
   59.6
 1085.4
  141.1
*******
     .02
 (2800000 ACFM)
 (  133  F)
 (  600  FT)
 (  28.6  FT)
 (  8139  BTU/LB)
 ******
C2300000 ACFM)
(   286 F)
(***** IN-H20)
(    .01 GR/SCF)
GRID/SPRAY TOWER
 4/80
RESEARCH-COTTRELL
30 X 30 X 88
316L SS CTOP3 UDDEHOLM 904L CBOTTOM]
   25.0
 1085.37       (2300000 ACFM)

-------
                                              EPA UTILITY  F6D  SURVEY:  JULY  - SEPTEMBER  1980
BASIN ELECTRIC POWER COOP: LARAMIE RIVER 1  (CONT.)
     SAS TEMPERATURE - C
     L/6 RATIO - L/CU.M
     SUPERFICAL GAS VELOCITY - M/SEC
     PARTICULATE INLET LOAD - G/CU.M
     PARTICULATE INLET LOAD - NG/J
     PARTICULAR OUTLET LOAD- G/CU.M
     PARTICULATE OUTLET LOAD - NG/J
     PARTICULATE REMOVAL EFFICIENCY - X
     S02 INLET CONCENTRATION - PPM
     S02 INLET CONCENTRATION -NG/J
     S02 OUTLET CONTRATION - PPM
     S02 OUTLET CONCENTRATION- NG/J
     S02 DESIGN REMOVAL EFFICIENCY - X
     A3SORBER SPARE CAPACITY INDEX - X
     A3SORBER SPARE COMPONENT INDEX

    CENTRIFUGE
     INLET SOLIDS - X
     OUTLET SOLIDS - X
                        141.1
                          8.0
                          3.0
                            .0
                          21.
                            .0
                          21.
                            .0
                        800
                       *****
                          80
                       *** **
                          90.0
                          25.0
                          1.0
                          55. 0
                          60.0
(  ?B6 F)
( 60*0 GAL/1000ACF)
C 10.0 FT/S)
(  .015 GR/SCF)
(  .050 LB/MMBTU)
(  .015 GR/SCF)
(  .050 LB/MMBTU)
(****,* LB/MMBTU)

(***«* LB/MMBTU)
 ** PASS
     NUMBER
     TYPE
     SERVICE - WET/DRY

 •* MIST ELIMINATOR
     TYPE
     CONFIGURATION
     NUMBER OF STAGES
     NUMBER OF PASSES

 ** PROCESS CONTROL  CHEMISTRY
     CONTROL VARIABLES
     CONTROL MANNER

 •* THICKENER
     NUMBER
     CONSTRUCTION  MATERIAL
     DIAXETER -  M

 •* WATER LOOP
     TYPE
     FRESH MAKEUP  HATER  ADDITION - LITERS/S

 •* REAGENT PREPARATION  EQUIPMENT
     NUMBER OF BALL  HILLS
     9ALL MILL CAPACITY- N  T/H
     REAGENT PRODUCT -  X SLURRY SOLIDS

 ** BYPRODUCTS
     DISPOSITION

 ** TREATMENT
     TYPE

 •* DISPOSAL
     NATURE
     TYPE
     LOCATION
     TRANSPORTATION
                       INDUCED  DRAFT
                       DRY
                       CHEVRON
                       VERTICAL
                           1
                           1
                       PH.  SOLIDS, $02 INLET, ACFM, S02 OUTLET
                       AUTOMATIC
                       CONCRETE
                          33.5
                       CLOSED
                          16.9
                           2
                          13.6
                         30.0
                       LANDFILL
                       FORCED OXIDATION
                       FINAL
                       LANDFILL
                       ON SITE
                       CONVEYOR BELT
 (110  FT)
 (   269 6PM)
 (  15.0  TPH)
 _	.	—	..—-PERFORMANCE  DATA———-—	.„.——._-—————
 PERIOD  NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   t  REMOVAL   PER  BOILER  F6D   CAP.
                                                                  S02  PART. HOURS HOURS  HOURS FACTOR
  7/80  SYSTEM

        ** PROBLLAS/SOLUTIONS/COMNENTS
                                                     744
  8/80  SYSTEM
THE UNIT BEGAN INITIAL AND  COMMERCIAL  OPERATIONS ON JULY 1, 1980.
PROBLEMS HERE REPORTED DURING  STARTUP.

                                                     744
                                                                                              NO MAJOR
                                                  63

-------
 EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 198C
BASIN ELECTRIC POWER COOP: LARAHIE RIVER 1 CCONT.)
...	.	.	PERFORMANCE DATA	_
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  x REMOVAL   PER  BOILER  FGD   CAP.
                     *                                          SO?  PART. HOURS HOURS  HOURS FACTOR

 >/80  SYSTE"                                                                720

       *•  PROBLEftS/SOLUTIONS/COMWENTS

                         THE UNIT IS STILL IN THE STARTUP PHASE OF OPERATIONS.  NO PERFORMANCE DATA
                         ARE CURRENTLY AVAILABLE.

-------
                                              EPA UTILITY FGD SURVEY: JULY -  SEPTEMBER  1980

                                           SECTION 3
               DESIEN  AND PERFORMANCE  DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 SROSS  UNIT GENERATING  CAPACITY - MW
 «ET UNIT GENERATING  CAPACITY U/FGD - MW
 EQUIVALENT SCRUBBED  CAPACITY - MW

 *•  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X

 »*  GENERAL  EMISSION  CONTROL SYSTEM DATA
    SENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEU/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL START-UP DATE
    S02  DESIGN REMOVAL EFFICIENCY  - X
    PARTICULATE DESIGN REMOVAL EFFICIENCY
    ABSORBER SPARE CAPACITY INDEX  - X
    ABSORBER SPARE COMPONENTS INDEX

 t«  WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 ••  TREATMENT
     TYPE
                             BIG  RIVERS ELECTRIC
                             GREEN
                             1
                             SEBREE
                             KENTUCKY
                               242.0
                               200.0
                        - X
                             COAL
                             BITUMINOUS
                              22678.
                                20.00
                                11.00
                                 3.75
                                  .05
                             WET SCRUBBING
                             LIME
                             AMERICAN AIR FILTER
                             NEW
                                (  9750 BTU/LB)
                 12/79
                 12/79
                    90.00
                    99.00
                    30.0
                      .4
                             CLOSED
                                                 POZ-0-TEC
                                             (..»»*  6PM)
	PERFORMANCE DATA	
(•ERIOD MODULE AVAILABILITY OPERAB1LITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   F6D    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80  SYSTEM

 J/80  SYSTEM
                                                           696

                                                           7*4
 j/80  SYSTEM

       •* PROBLEMS/SOLUTIONS/COMMENTS

                          NO  INFORMATION WAS AVAILABLE FOR THE FIRST OUARTERf  1980.
 t/80  A
       B
       SYSTEM
65.0
65. D
65.0
56.0
56.0
56.0
78.8
79.0
79.0
45.0
45.0
45.0
                                                                               720
                                                                                     576
                                                                                            3Z4
       •* PROBLEMS/SOLUTIONS/COMMENTS
 5/80   A
        B
        SYSTEM
73.7
73.7
73.7
                          THE  FOLLOWING FIVE OUTAGES OCCURRED  IN  APRIL  AND ACCOUNTED FOR THE LOW
                          AVAILABILITY OF THE FGD SYSTEM.
                              1.  LOW ADDITIVE IN TANK
                              2.  INSTRUMENT TROUBLE
                              3.  WATER IN THE PANEL
                              4.  LOW ON LIME IN THE HOLDING  TANKS
                              5.  THE ESPS TRIPPED
76.1
76.0
76.1
79.0
78.9
79.0
73.7
73.5
7J.7
                                                                               744
                                                                                     720
                                                                                            548
                                                 65

-------
 EPA UTILITY FGD SURVEY:  JULY  -  SEPTEMBER  1980

JIB RIVERS ELECTRIC: 6REEN  1  (CONT.)
	PERFORMANCE BATA	
PERIOD MODULE AVAILABILITY OPERABILITV  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  F6D    CAP.
                                                                 $02  PART. HOURS HOURS  HOURS  FACTOR
• •• —» —fc»—•— • ____•__•••_. _•__••_*••«..  •—._••••••• • •«••••••••• ••••• • •••• _•__« _••••_ ••«••  — ••••

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         DURING MAY  THE  FGD  SYSTEM WAS OFF LINE FOR APPROXIMATELY 548 HOURS DUE
                         TO THE FOLLOWING  PROBLEMS.
                             1. SULFUR  OXIDES  TOO  HI6H
                             2. LOU  LEVEL  IN ADDITIVE TANK
                             3. INSTRUMENT TROUBLE
                             It. SCHEDULED  MAINTENANCE OUTAGE
                             5. SOLIDS  ON  CARRY  OVER
                             6. SOLID WASTE  PROBLEM
                             7. UNIT TRIPPED
                             8. CONSTRUCTION WORK

 i/80  SYSTE"                                                                 720

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION WAS NOT AVAILABLE FOR THE MONTH OF  JUNE.

 7/80  SYSTEM                                                                 744

 3/80  SYSTEM                                                                 744

 >/80  SYSTEM                                                                 720

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION WAS  AVAILABLE  FOR  THE  THIRD  QUARTER  1980.

-------
                                              EPA UTILITY FGO SURVEY: JULY -  SEPTEMBER  1980

                                           SECTION 3
               DESIGN  AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  FED  SYSTEMS
COMPANY  NAME
PLANT  MA*E
JM1T NU«3ER
CITY
STATE
5ROSS  UNIT  GENESATIN6 CAPACITY - flu
«ET  UNIT GENERATING CAPACITY W/FCD - MW
EQUIVALENT  SCRUBBED CAPACITY - MW

•*  FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - t
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

• *  GENERAL  EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM  SUPPLIER
     NEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN REMOVAL EFFICIENCY  - X
     PARTICULAR DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARF CAPACITY INDEX  - X
     ABSORBER SPARE COMPONENTS INDEX

 •• WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER - LITER/S

 • * DISPOSAL
     TYPE
                                    - X
                                         CENTRAL  ILLINOIS LIGHT
                                         DUCK  CREEK
                                         1
                                         CANTON
                                         ILLINOIS
                                           416.0
                                           378.0
                                           416.0
                                                        ( 10396 BTU/LB)
                             COAL
                             BITUMINOUS
                              24181.
                                 9.77
                                15.43
                                 3.66
                                  .06
                                         WET SCRUBBING
                                         LIMESTONE
                                         ENVIRONEERING, R1LEY STOKER
                                         NEW
                                             2.9
                                          7/76
                                          8/78
                                            85.00
                                              .0
                                              .0
                                         CLOSED
                                            37.8
                                                 LINED POND
                                                         C  600 GPM>
__	...	- —	PERFORMANCE DATA	—
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                                          X  REMOVAL   PER  BOILER  F6D   CAP.
                                                          S02   PART. HOURS HOURS  HOURS FACTOR
1/80 A
B
C
D
SYSTEM
24.8
58.5
17.1
29.2
32.4
27.0
63.6
18.6
31.8
35.3
29.8
65.9
20.3
35.3
37.8
24.8
58.5
17.1
29.3
32.4




7(4 684 241 81.6
       •• PROBLEMS/SOLUTIONS/COMMENTS
 2/80
A
B
C
D
SYSTEM
11.8
72.7
70.7
41.3
49.1
                          MOST  OF  THE  JANUARY OUTAGE TIME WAS REQUIRED  FOR  RECYCLE  TANK  COVERING
                          WORK.

                          THE  HIST ELIMINATOR SECTION PLUGGED ALONG  WITH  THE  NOZZLES HINDERING
                          SYSTEM OPERATIONS.  THE HIST ELIMINATOR  DRAIN LINE  HAS  MODIFIED ALSO
                          CAUSING  OUTAGE TIME.

                          OTHER PROBLEMS ENCOUNTERED DURING THE MONTH  INCLUDED A  PLUGGED LIMESTONE
                          FEEDER,  INLET DANPER PROBLEMS, SLURRY SUPPLY  HEADER LEAKS AND  STORAGE
                          PUMP  DISCHARGE VALVE REPAIRS.
11.8
72.7
70.7
41.3
49.1
12.5
73.5
71.5
47.9
51.4
11.8
72.7
70.7
41.3
49.1
                                                                               696   696
                                                                                     342   73.5
                                                 67

-------
 EPA UTILITY  fGO SURVEY: JULY  -  SEPTEMBER 1980




CENTPAL ILLINOIS LIGHT: DUCK CREEK  1  (CONT.)
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGO CAP.
SO? PART. HOURS HOURS HOURS FACTOR
•* PROBLE«S/SOLUTIONS/COMMENTS
DURING FEBRUARY SOME OUTAGE TIME VAS DUE TO MODULE D CLEANING AND THE
CLEANING OF THE MODULE D WIST ELIMINATOR SECTION.
THE INLFT DAMPER DRIVE WAS REPLACED DURING THE MONTH.
REPAIR OF THE FIBERGLASS ON THE SLURRY RECYCLE LINE HINDERED OPER-
ATIONS DURING THIS MONTH.
THE MODULES A AND D RECYCLE DISCHARGE VALVE WERE REPLACED CAUSING EXTENSIVE
DOWN TIME.
3/8P
A
B
C
D
SYSTEM
52.9
73.2
51.0
34.0
52.9
6?. 5 64.7 52.9
86.6 86.9 73.2
60.3 60.5 51.0
4T.2 45.9 34.0
6?. 4 65.1 52.8 74* 629 393 68.
6
** PROBLEXS/SOLUTIOSS/COMMENTS




4/80




A
B
C
D
SYSTEM




53.0
54.3
57.2
26.0
47.6
DURING MARCH NEW RECYCLE PUMP DISCHARGE VALVES WERE INSTALLED IN ORDER TO
ELIMINATE RESTRICTED FLOU OF THE OLD VALVES.
CARRIER SEARINGS ON THE INLET DAMPER WERE REPLACED IN ORDER TO MAINTAIN
MODULE ISOLATION CAPABILITY.
THE MIST ELIMINATOR WASH SYSTEM WAS CONVERTED TO RETURN WATER IN ORDER
TO ACHIEVE A HIGHER OUAL1TY ELIMINATION WASH WATER.
FIBERGLASS LINES ON THt RECYCLE PUMP DISCHARGE WERE ALSO REPAIRED DURING
EXTENSIVE
81.7 95.9 5J.9
83.6 87.5 54.2
88.3 95.3 57.2
40.1 71.9 26.0
73.4 89.2 47.6 720 466 342 35.




3
** PROBLEMS/SOLUTIONS/COMMENTS
THE MAJOR PROBLEM HINDERING SYSTEM OPERATIONS DURING APRIL WAS THE REBUILD
OF THE RECYCLE TANK MIXER.

5/80

A
B
C
D
SYSTEM

44.6
45.7
34.7
43.6
42.1
MINOR PROBLEMS DURING THE MONTH WERE CAUSED BY THE INOPERABIL IT V OF THE
LIMESTONE HANDLING SYSTEM.

68.6 72.0 44.6
70.3 73.5 45.7
53.3 59.1 34.7
67.0 73.9 43.6
64.8 69.7 42.1 744 484 314 49.4
** PROBLEMS/SOLUTIONS/COMMENTS



i/80



A
B
C
D
SYSTEM



87.6
86.8
84.5
80.0
84. R
DURING MAY REPAIRS WERE MADE TO THE RECYCLE TANK RUBBER LINER.
EXPANSION JOINT LEAKS WERE ALSO REPAIRED DURING THE MONTH.
OTHER OPERATIONAL PROBLEMS INCLUDED THE REPLACEMENT OF THE LIMESTONE
STORAGE TANK MIXER MOTOR, MODIFICATION OF ROD DECKS TO REDUCE SYSTEM
DIFFERENTIAL PRESSURE AND REPAIR OF THE LIMESTONE FEEDER SYSTEM.
82.3 87.1 82.1
82-6 86.0 82.3
«f«4 84.3 81.1
73.1 75.8 72.9
79'9 84.3 79.6 720 718 573 78.



5
                                                 68

-------
                                              EPA UTILITY  F6D  SURVEY:  JULY - SEPTEMBER 1980
CENTRAL ILLINOIS LIGHT: DUCK CREEK 1 (CONT.)
	.	-PERFORMANCE  DATA	
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F6D   CAP.
                                                                 302  PART. HOURS HOURS  HOURS FACTOR


       • • PROBLEHS/SOLUTIONS/CONMENTS

                         A LEAK HAS  REPAIRED  IN  THE SLURRY  SUPPLY HEADER DURING JUNE.

                         riORK  CONTINUED  ON  THE MODIFICATIONS BEING DONE ON THE ROD DECKS IN THE
                         ABSORBER MODULES.
 7/80  A
       B
       C
       D
       SYSTEM
            91.2
            83.5
            90.5
            87.5
            88.2
            81.0
            70.0
            78.8
            74.9
            76.2
            87.6
            80.0
            86. 4
            85.4
            84.9
            70.1
            60.6
            68.2
            64.8
            65.9
                                                                              744
                                                                                    644
                                   490  67.4
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  JULY FGD SYSTEM OUTAGE TINE RESULTED FROM THE NECESSARY  REPAIR
                          OF  THE  SLURRY  SUPPLY LINE AND REPAIR OF THE MALFUNCTIONING  CLUTCH  IN THE
                          MILL  SYSTEM.

                          ADDITIONAL OUTAGE TIME OCCURRED SO REPAIRS TO THE  1B STORAGE  TANK  PUMP
                          DISCHARGE  VALVES AND THE STORAGE TANK MIXER MOTOR  COULD  BE  COMPLETED.
  3/80
A
B
C
D
SYSTEM
88.6
91.4
91.3
90.6
90.5
85.4
86.3
84.6
85.1
85.4
92.7
90.8
88.9
90.1
90.7
81.9
82.7
81.0
81.6
81.9
                                                                               744   713
                                                                                            609  76.5
        *•  PROBLEMS/SOLUTIONS/COMMENTS
                          THE SLURRY SUPPLY ISOLATION VALVE WAS  REPAIRED  IN  AUGUST.
                          THE POND WATER RETURN LINE WAS  ALSO  REPAIRED  DURING THE MONTH.
                          REPAIRS WERE HADE TO THE ELECTRICAL  SYSTEM  AFTER  A POWER FAILURE IN THE
                          WASTEWATER BUILDING.
  J/80
        A
        B
        C
        D
        SYSTEM
            43.1
            47.8
            45.6
            44.3
            45.6
            39.2
            47.2
            43.2
            46.0
            43.9
            41.5
            48.2
            45.9
            47.6
            45.9
             39.2
             47.2
             43.2
             46.0
             43.9
                                                                               720   720
                                    316  81.3
        ** PROBLEMS/SOLUTIONS/COMMENTS
                          MAJOR PROBLEMS  DURING  SEPTEMBER  INCLUDED REPAIR OF THE LIMESTONE BALL HILL.
                          AFTER IT WAS REPAIRED,  THE  BALL  HILL MOTOR BURNED OUT AND HAD TO BE RE-
                          PLACED.

                          SLURRY CONTAMINATION OF THE HILL BEARING Oil AND REPAIR OF THE RECYCLE PUMP
                          SUCTION SCREEN  CAUSED  THE  FSO  SYSTEM TO BE DOWN FOR SEVERAL HOURS DURING
                          THE MONTH.
                                                  69

-------
  EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FED SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  JN1T  NUMBER
  CITY
  STATE
  KROSS  UNIT GENERATING CAPACITY - HW
  »ET UNIT  GENERATING  CAPACITY U/FGD - MW
  EQUIVALENT SCRUBBED  CAPACITY - MW

  •• FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT -  J/G
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE  CONTENT - X
     AVERAGE SULFUR CONTENT  - X
     AVERAGE CHLORIDE  CONTENT - X

  •• GENERAL EMISSION  CONTROL SYSTEM DATA
     SENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     HEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP  DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     A9SORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS  INDEX

  • • WATER  LOOP
     TYPE
     FRESH MAKE-UP WATER  - LITER/S

  ** TREATMENT
     TYPE
                              CENTRAL ILLINOIS PUBLIC  SERV
                              NEWTON
                              1
                              NEWTON
                              ILLINOIS
                                617.0
                                575.0
                                617.0
                                             ( 10900 BTU/LB)
                  COAL
                  BITUMINOUS
                   25353.
                     12.70
                      9.SO
                      2.25
                       .20
                              WET SCRUBBING
                              DUAL ALKALI
                              BUELL DIVISION. ENViROTECH
                              NEW

                               9/79*
                              13/79
                                 90.00
                           X     99.50
                                   .0
                                   .0
                              CLOSED
                                                 POZ-0-TEC
                                             (««*»» 6PM)
_-_-.__-„_.._-__. — -—	.	..	-PERFORMANCE  DATA	—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
                                                                 X  REMOVAL   PER  BOILER  FGD   CAP
                                                                 S02   PART. HOURS HOURS  HOURS FACTOR
1/80




A
B
C
D
SYSTEM
68.3
66.4
5Z.2
21.0
52.0
57.1
60. 6
48.8
1?.1
46.4
6J.5
64.9
60.5
2«.3
53.8
55.5
58.9
47.4
18.5
45.1




7*4 723 336
       «« PROBLEMS/SOLUTIONS/COMMENTS
                         DURING JANUARY TESTS MERE CONDUCTED TO  CERTIFY  THE  GAS  EMISSIONS  MONITOR
                         AT NEWTON.

                         PRESATURATOR CORROSION AND EXPANSION  JOINT  REPAIRS  AND  A  DEPLETION OF THE
                         FLYASH USED FOR SLUDGE STABILIZATION  ACCOUNTED  FOR  THE  LOU  JANUARY
                         DEPENDABILITY FIGURES.
 2/80
       A
       B
       C
       D
       SYSTEM
61.1
74.4
78.2
  .0
53.4
42.4
55.7
55.5
  .0
39.2
45.0
57.7
59.1
  .0
40.4
42.4
55.7
58.5
  .0
39.2
                                                                              696    696
                                                                                           273
       •*  PROBLEMS/SOLUTIONS/COMMENTS
                         DURING FEBRUARY THE D-MODULE WAS UNAVAILABLE DUE TO  THE COLLAPSE  OF  THE
                         PRECOOLER MIST ELIMINATORS CAUSED BY A TEMPERATURE EXCURSION.

                         REPAIR WORK ON THE PRESATURATOR CORROSION AND EXPANSION JOINTS  AS WELL  AS
                         THE FLYASH DEPLETION PROBLEM CONTINUED TO YIELD LOU  DEPENDABILITY FIGURES
                         FOR FEBRUARY.
                                                70

-------
                                              EPA UTILITY  FGD  SURVEY: JULY - SEPTEMBER 1980
CENTRAL ILLINOIS PUBLIC SERV: NEWTON 1  (CONT.)
. — ...	——	 — PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                                                         X REMOVAL   PER  BOILER  FGD    CAP.
                                                         SO?  PART. HOURS HOURS  HOURS  FACTOR
5/80




A
B
c
ft
SYSTEM
53.4
47.0
44. 5
.0
36.2
53.6
42.3
41.1
.0
34.0
53.1
48.0
46.5
.0
36.9
52.3
42.1
41.0
.0
33.9




744 740 252
       *» PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THE  FIRST QUARTER, 1980. THE FOLLOWING PROBLEMS WERE ENCOUNTERED:
                            THE VALVES  AND PIPING IN THE PRECOOLER LOOP EXPERIENCED  CORROSION.
                            THE WIST  ELIMINATOR OH THE 0 MODULE FAILED.
                            THE  FLY  ASH SUPPLIES DEPLETED.
                            RUBBER  LINING AND DUCTWORK LINING FAILURES OCCURRED.
                            BOOSTER  FAN EXPANSION JOINT FAILURE OCCURRED.
                            THE  THICKENER EXPERIENCED PLUGGING.
                          THESE  COMBINED PROBLEMS ACCOUNTED FOR THE UOW MARCH  PERFORMANCE  FIGURES.
                          FOR THE aUARTER, THE TOTAL SYSTEM HAS AVAILABLE  47.2Z  AND  WAS  UTILIZED
                          39.4X  OF  THE  TIME.
  4/80
A
B
C
D
SYSTEM
33.8
35.4
57.4
26.1
33.2
31.3
25.8
35.6
21.8
28.6
31.4
25.8
35.6
21.8
28.6
31.3
25.8
35.6
21.8
28.6
                                                                               720   720
                                                                                            206
        ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE NEWTON 1 FGD SYSTEM WAS OUT OF  SERVICE  DURING THE FIRST 12 DAYS OF
                          APRIL FOR NECESSARY REPAIRS ON THE  OUTLET  DUCT  LININGS.  THE UTILITY INDI-
                          CATED THAT THE LINING FAILURES MAY  HAVE  RESULTED FROM IMPROPER APPLICATION.

                          DURING THE LAST 18 DAYS OF APRIL  MINOR PROBLEMS WERE EXPERIENCED WITH
                          THE OCCURANCE OF PLUGGING  IN THE  SODIUM  CARBONATE THICKENER AND CORROSION
                          OF THE VALVES IN THE PRESATURATOR CIRCUIT.
  S/80  A
        B
        C
        D
        SYSTEM
               .0
             9.7
             9.7
               .0
             4.8
               .0
             9.6
             9.6
               .0
             4.8
               .0
              9.6
              9.6
               .0
              4.8
               .0
              6.2
              6.2
               .0
              3.1
                       744   477
                                     23  45.5
        ** PROBLEMS/SOLUTIONS/COHMENTS
                          DURING MAY,  THE  FGD  SYSTEM  WAS DOWN BECAUSE THE FLUIDIZING STONES WERE
                          CAKED WITH  FLY ASH.   THIS  WAS CAUSED BY IMPROPER WIRING OF THE HEATER WHICH
                          9LOWS OVER  THE STONES.   THE HEATER WAS REWIRED AND THE FLUIOIZIN6 STONES
                          REPLACED.   FLUIDIZING STONES ARE LOCATED IN THE FLVASH SILO.  HEATED AIR
                          PASSES THROUGH THESE POROUS STONES TO AERATE OR "FLUIDIZE" THE FLYASH SO
                          THAT IT  CAN  BE CONVEYED TO  THE FLVASH/SLUD6E MIXER.  WHEN THE FLYASH
                          SUPPLY IS  DEPLETED OR THE  MATERIAL CANNOT BE DELIVERED TO THE MIXER THE
                          SCRUBBING  SYSTEM IS  SHUT DOWN.  THE SLUDGE MUST BE TREATED WITH  FLYASH
                          BEFORE DISPOSAL.
  S/80  A
        C
        D
        SYSTEM
               .0
             40.3
             40.4
               .0
             20.?
               .0
             40.3
             40.4
               .0
             20.2
               .0
             40.3
             40.4
               .0
             20.2
               .0
             40.3
             40.4
               .0
             20.2
                       720   720
145  63.0
        *» PROBLEMS/SOLUTIONS/COMMENTS
                           DURING JUNE THE A AND D MODULES WERE UNAVAILABLE  FOR  OPERATION BECAUSE
                           THE MIST ELIMINATORS COLLAPSED.

                           THE SYSTEM WAS SHUTDOWN DURING THE  FIRST HALF  OF  THE  MONTH TO REPAIR THE
                           DRY FLVASH COLLECTION SYSTEM WHICH  ACCOUNTED  FOR  THE  LOW B AND C MODULE
                           FIGURES.
                                                  71

-------
 EPA UTILITY  F6D SURVEY:  JULY  - SEPTEMBER 1980

CENTRAL ILLINOIS PUBLIC  SERV:  NEWTON 1  (CONT.)
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
502 PART. HOURS HOURS HOURS FACTOR
7/80 A
B
C
D
SYSTEM
3.5
3.6
.0
.0
1.8
3.7
3.9
.0
.0
1.9
3.7
3.9
.0
.0
1.9
3.5
3.6
.0
.0
1.8
7** 698 13 67.8
•* PROBLEHS/SOLUTIONS/COMMENTS
DURING JULY PROBLEMS WERE
ENCOUNTERED WITH THE MIST ELIMINATORS.
SOME Of THE SYSTEM OUTAGE TIME RESULTED FROM
OCCURRENCE Of CORROSION IN THE PRES ATURATOR .

3/80 A
B
C
D
SYSTEM

.C
64.7
51.2
37.6
53.8
SCRUBBER PLUGGING
AVAILABILITY.
.0
50. 2
3t.1
21.9
36.4
DURING
.0
50.2
36.9
24.0
39.9
JULY CONTRIBUTED TO
.0
49.3
33.5
21.5
35.8
REPAIRS MADE NECESSARY BY THE
THE LOW FCD SYSTEM
744 731 266 68.2
»» PROBLEMS/SOLUTIONS/COMMENTS


PLUGGING PROBLEMS
AUGUST.
WITHIN
THE FGD SYSTEM WERE
BECAUSE OF CHANGES IN SYSTEM OPERATIONS, ONLY
CURRENT S02 REGULATIONS.
9/80 A
B
C
0
SYSTEM
69.0
99.6
96.9
99.6
99.1
20.3
74.6
35.8
80.8
67.8
48.6
80.3
66.8
80.8
82.5
10.0
36.8
17.6
39.9
33.4
THE CAUSE OF DOWN TIME IN
3 MODULES ARE NEEDED TO MEET
720 555 241 33.2
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                         THE BOILER WAS TAKEN OUT OF  SERVICE  ON  SEPTEMBER 16, 1980 FOR A SCHEDULED
                         MAINTENANCE OUTAGE.
                                                72

-------
                                              EP* UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

                                           SECTION 3
               DESIGN  AND  PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FCD SYSTEMS
COMPANY  NAME
PLANT  NAME
UNIT  NUMBER
CITY
STATE
CROSS  UNIT  GENERATING  CAPACITY - HW
NET UNIT GENERATING  CAPACITY W/FGD - MW
EQUIVALENT  SCRUBBED  CAPACITY - MW

*•  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X

»•  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    HEW/RETROFIT
    ENERGY  CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL  START-UP DATE
     S92  DESIGN  REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 »* WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 *• DISPOSAL
     TYPE
                                    - X
                                         COLORADO UTE ELECTRItC ASSN
                                         CRAIG
                                         2
                                         CRAIG
                                         COLORADO
                                           455.0
                                           415.0
                                           400.0
                                                        ( 10000 BTU/LB)
                COAL
                SUBBITUHINOUS
                 23260.
                    8.00
                   16.00
                     .45
                     .00
                WET SCRUBBING
                LIMESTONE
                PEABODY PROCESS  SYSTEMS
                NEW
                    1.5
                12/79
                 5/80
                   85.00
                   99.80
                   33.3
                    1.0
                                         CLOSED
                                             19.9
                                                 MINEFILL
                                                         (   3>6  GPN)
.....	PERFORMANCE DATA"	—	—
PERIOD MODULE AVAILABILITY OPERABILITV  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80

 2/80

 J/BO
SYSTEM

SYSTEM

SYSTEM

*« PROBLEMS/SOLUTIONS/COMMENTS
                                              744

                                              696

                                              744
                          THE  BOILER  WAS DOWN AT THE END OF THE PERIOD DUE TO  TURBINE  RELATED
                          PROBLEMS.

                          WHEN FULL  LOAD OPERATIONS WERE ATTEMPTED CONTROL PROBLEMS  WERE  ENCOUNTERED
                          WITH THE  SCRUBBER.

                          PROBLEMS  WITH OPENING/CLOSIN6 THE BYPASS DAMPER HAVE BEEN  ENCOUNTERED.
                          LARGER OPERATORS ARE BEING TESTED THAT MAY  SOLVE THE PROBLEM.
 4/80
SYSTEM

*• PROBLEMS/SOLUTIONS/COMMENTS
                                                                               720
                          THE FGD SYSTEM IS STILL IN THE STARTUP  PHASE  OF  OPERATIONS.  TESTING IS
                          BEING PERFORMED ON THE SYSTEM, BUT THERE HAS  BEEN  NO OPERATIONAL DATA
                          REPORTED.
  5/80
             38.4
             42.5
             47.0
27.5
32.1
37.2
28.4
33.1
38.4
24.5
28.5
33.1
                                                 73

-------
 EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

COLORADO UTE ELECTRIC ASSN: CRAIG 2  (COMT.)
	—	:	PERFORMANCE DATA	~--..„
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD   CAP.
                                                                S02  PART. HOURS HOURS   HOURS  FACTOR
D
SYSTEM
30.0
52.6
18.0
38.3
18.6
39.5
16.0
34.0
6*. TO,
640
661
253
76.8
       *• PROBLEMS/SOLUTIONS/COHMENTS
                         THE CRAIG 2 UNIT (BOILER AND SCRUBBER) COMMENCED COMMERCIAL OPERATION  ON
                         HAY 4, 1980.

                         NOTE:  THIS SYSTEM EFFECTIVELY HAS ONE SPARE MODULE SO THAT ONLY THREE  ARE
                                CURRENTLY NEEDED AT FULL LOAD TO MAINTAIN COMPLIANCE KITH S02 EMIS-
                                SION REGULATIONS.  WHEN THE CURRENT LOU SULFUR COAL SOURCE IS
                                EXHAUSTED (SEVERAL YEARS FROM NOW) 6REATER SCRUBBING CAPACITY HILL
                                BE REBUIRED SO THAT THERE WILL NO LONGER BE AN ENTIRE MODULE SET
                                ASIDE AS A SPARE DURING FULL LOAD BOILER OPERATIONS.  THE "SYSTEM"
                                DEPENDABILITY FACTORS MILL BE BASED ON THREE MODULES UNTIL THE
                                CURRENT COAL SOURCE IS EXHAUSTED.
 6/80  A
       a
       c
       D
       SYSTEM
            47.6
            53.9
            61.1
            14.6
            65.7
            41.2
            48.0
            55.8
            27.0
            57.3
            42.0
            48.9
            56.9
            27.5
            58.4
            37.9
            44.2
            51.4
            24.9
            52.8
                    65.70
                                                           720   663
                                                380   68.5
       ••  PROBLEMS/SOLUTIONS/COMMENTS
                         DURING MAY AND JUNE, PROBLEMS HERE ENCOUNTERED WITH PLUGGING OF THE
                         ABSORBER SPRAY NOZZLES.

                         A  PROBLEM HAS ALSO ENCOUNTERED DURING INITIATION OF COMMERCIAL OPERATION
                         ylTH  A HIGH PH LEVEL IN THE THICKENER UNDERFLOW.

                         THE SCRUBBING SYSTEM IS STILL UNDERGOING SHAKEDOWN OPERATIONS.
7/80
      A
      B
      C
      D
      SYSTEM
59.1
61.8
37.6
43.7
67.4
                        51.0
                        54.1
                        26.0
                        33.0
                        54.7
                        51.7
                        54.9
                        26.3
                        33.5
                        55.5
                        43.B
                        46.5
                        22.3
                        28.4
                        47.0
                                            65.60
                                  744   640    350  65.8
         PROBLEMS/SOLUTIONS/COMMENTS
                         DURING JULY,  FGD OUTAGE TIME WAS CAUSED BY PLUGGED ABSORBER SPRAY NOZZLES.
a/so
A
B
C
D
SYSTEM
50.0
50. 0
50.0
50.0
66.7
46.7
48.4
47.5
52.3
65.0
48.3
50.0
49.1
54.0
67.1
                                    42.2
                                    43.7
                                    42.9
                                    47.2
                                    58.7
                                                               65.60
744   672
                                                            327   75.6
      ••  PROBLEMS/SOLUTIONS/COMNENTS
                         DURING AUGUST  THE  FGD SYSTEM EXPERIENCED ASSORTED MECHANICAL PROBLEMS.

                         SPRAY  NOZZLE PLUGGING OCCURRED. CAUSING ADDITIONAL OUTAGE TIME WHICH ADDED
                         TO  THE LOW  AVAILABILITY FACTOR DURING THE MONTH.
7/80  A
       C
       D
       SYSTEM
            48.6
            58.2
            61.1
            67.4
            78.4
            47.5
            58.8
            59.6
            66.2
            77.4
            48.4
            59.9
            60.7
            67.4
            78.8
            47.1
            58.2
            59.0
            65.6
            76.6
                                                               65. 70
                                                                             720   713
                                                                                    552  85.2
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE  SPRAY  NOZZLES  IN  THE ABSORBER MODULE CONTINUED TO PLUG UP DURING SEP-
                         TEMBER.
                                                74

-------
                                             EPA UTILITY  F6D  SURVEY:  JULY  -  SEPTEMBER  1980

                                          SECTION 3
              DESIGN  AND PERFORMANCE DATA fOR OPERATIONAL  DOMESTIC FGD  SYSTEMS
COMPANY  NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
SROSS  UNIT 6ENERATIN6  CAPACITY  - NU
MET UNIT GENERATING  CAPACITY  U/FGD - MU
EQUIVALENT SCRUBBED  CAPACITY  -  MU

• *  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  X
    AVERAGE SULFUR CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  X

»*  GENERAL EMISSION  CONTROL SYSTEM DATA
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEU/RETROFIT
    ENERGY CONSUMPTION -  X
    INITIAL START-UP DATE
    COMMERCIAL  START-UP DATE
    $02  DESIGN  REMOVAL EFFICIENCY  -  X
    PARTICULATE  DESIGN REMOVAL  EFFICIENCY
    ABSORBER  SPARE  CAPACITY INDEX  -  X
    ABSORBER  SPARE  COMPONENTS INDEX

 *»  HATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 »•  TREATMENT
     TYPE

 ••  DISPOSAL
     TYPE
                                        COLUMBUS I SOUTHERN OHIO ELEC
                                        CONESVILLE
                                        5
                                        CONESVILLE
                                        OHIO
                                          411.0
                                          375.0
                                          411.0
                                                        (  10850  BTU/LB)
                                    - X
                             COAL
                             BITUMINOUS
                              25237.
                                15.10
                                7.50
                                4.67
                                  .01
                             WET  SCRUBBING
                             LIME
                             AIR  CORRECTION  DIVISION, UOP
                             NEW
                                 3.9
                              1/77
                              2/77
                                89.50
                                  .00
                                  .0
                                  .0
                                         OPEN
                                            31.5
                                         POZ-0-TEC
                                                POND
                                                        (  500 6PM)
....	.	PERFORMANCE DATA	
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
                                                         X REMOVAL
                                                         S02  PART.
                                                         PER  BOILER  F6D   CAP.
                                                        HOURS HOURS  HOURS FACTOR
 1/80
A
B
SYSTEM
89.0
93.0
91.0
38.0
50.0
44.0
45.0
59.0
52.0
13.0
17.0
15.0
                                                                              744    257
                                                                                   113   21.4
       *• PROBLCMS/SOLUTIONS/COMMENTS
                         DURING JANUARY A BOILER OUTAGE OCCURRED  FROM THE  FIRST  OF  THE MONTH  TO
                         JANUARY 20, DURING WHICH TIME MAINTENANCE WAS  PERFORMED ON THE  F6D SYSTEM.
 2/80  *
       B
       SYSTEM
            90.0
            93.0
            92.0
            63.0
            69.0
            66.0
            77.0
            84.0
            81.0
            31.0
            34.0
            33.0
                                                                              696    343
                                                                                    226   31.4
       •» PROBLEMS/SOLUTIONS/CONMENTS
 j/eo
       B
       SYSTEM
            88.0
            88.0
            88.0
                         A BOILER OUTAGE LASTING APPROXIMATELY  17  DAYS  ALSO  OCCURRED  DURING
                         FEBRUARY.

                         IN FEBRUARY. MIST  ELIMINATOR NOZZLE  PLUGGING OCCURRED  CAUSING  SOME F6D
                         SYSTEM  OUTAGE  TINE.
            62.0
            81.0
            82.0
            82.0
            82.0
            82.0
             82.0
             81.0
             82.0
                                                                              744   744
                                                                                    606  75.4
                                                 75

-------
 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

C3LUMSUS l SOUTHERN OHIO ELEC: CONESVILLE s (CONT.)
	-PERFORMANCE DATA	—•	——._._
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  F6D    CAP.
                                                                S02  PART. HOURS HOURS  HOURS  FACTOR


       *• PROBLEMS/SOLUTIONS/COMMENTS

                         DURING MARCH PROBLEMS HERE EXPERIENCED WITH THE IUCS SLUDGE STABILIZATION
                         PROCESS AND SOME OUTAGE TIME RESULTED.  ALSO DURING MARCH SOME GRID RODS
                         REQUIRED REPLACING AND SOME RUBBER LINER FAILURES OCCURRED.

                         THE MAJORITY Of THE MARCH FGO SYSTEM OUTAGE TIME WAS DUE TO CONTINUING
                         PROBLEMS WITH THE MIST ELIMINATOR NOZZLES.

 1/80   A            94.6        8«.4                    78.9
       B            74.9        65.8                    61.5
       SYSTEM      84.7        75.2                    70.3                  720   673    506  63.1

       •* PROBLENS/SOLUTIONS/COMMENTS

                         CONTINUAL PROBLEMS WITH THE DUMPERS, PRESATURATOR HOSES, AND NOZZLES WERE
                         THE CAUSES OF FGD SYSTEM OUTAGE TIME IN APRIL.

 5/80   A            92.1        86.2                    86.2
       8            90.3        84.3                    84.3
       SYSTEM      91.3        85.2                    85.2                  744   744    634  69.5

       •• PROBLERS/SOLUTIONS/COMMENTS

                         IN  MAY, CONTROLS AND INSTRUMENTATION DEVELOPED PROBLEMS THAT CAUSED SOME
                         OUTAGE TIME.

 6/80   A            89.6        71.0                    70.7
       B            94.3        74.8                    74.4
       SYSTEM      86.4        72.9                    72.6                  720   717    523  65.1

       »•  PROBLE1S/SOLUTIONS/COMMENTS

                         EXTERNAL CAUSES  (IUCS  DISPOSAL  FACILITY,  LOW UNIT DEMAND, SERVICE WATER
                         PROBLEMS,  ETC.)  HERE RESPONSIBLE FOR THE  MAJORITY OF THE JUNE OUTAGES.

 7/80   A            90.6        70.7        72.4         43.8
       B            88.8        82.0        84.0         50:8
       SYSTEM       89.7        76.4        78.2         47.3                   744   461    352  36.6

       •»  PROBLEMS/SOLUTIONS/COMMENTS

                         THE  PRESATURATOR HOSES  AND  NOZZLES  PLUGGED  CAUSING  THE  UNIT TO SHUT DOWN
                         FOR  PART OF  JULY.

 J/BO   A            98.0        83.5        84.9         48.5
       B            95.4        88.8        90.4         51.6
       SYSTEM       96.7        86.2        87.6         50.1                   744   432    373  40.0

       ••  PROBLEMS/SOLUTIONS/COHHENTS

                         THE  UTILITY  REPORTED THAT PROBLEMS  WITH THE RECLAIM  WATER SYSTEM OCCURRED
                         IN  AUGUST  CAUSING  SOME  OUTAGE  TIME.

 »/80   *            84.8         73.4        74.4         73.1
       B            85.9         85.1         86.3        82.0
       SYSTEM       88.2         79.2        80.3         78.9                   720   717    568  71.5

       *•  PROBLEMS/SOLUTIONS/COHMENTS

                         DURING  THE JULY-SEPTEMBER PERIOD INLET  DAMPER  SEAL  LEAKING WAS A MAJOR
                         PROBLEM.

                         THE  PRESATURATOR  PROBLEMS CONTINUED IN  SEPTEMBER CAUSING ADDITIONAL OUTAGE
                         TIME FOR THE  F6D  SYSTEM.
                                                76

-------
                                              EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
               DESIGN  AND  PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
6ROSS  UNIT GENERATING  CAPACITY - MU
NET UNIT  GENERATING  CAPACITY H/F60  - MU
EQUIVALENT SCRUBBED  CAPACITY - MU

*•  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT CONTENT - J/G
    AVERAGE ASH CONTENT  - Z
    AVERAGE MOISTURE CONTENT - X
    AVERAGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT - X

*•  GENERAL EMISSION  CONTROL SYSTEM  DATA
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    HEW/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP  DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE DESIGN REMOVAL EFFICIENCY
    ABSORBER  SPARE CAPACITY INDEX - X
    ABSORBER  SPARE COMPONENTS INDEX

 ••  WATER  LOOP
     TYPE
     FRESH MAKE-UP UATER  - LITER/S

 •*  TREATMENT
     TYPE

 •*  DISPOSAL
     TTPE
                                                    SOUTHERN  OHIO ELEC
                                                        C 10850 BTU/LB)
                                    - X
                                         COLUMBUS  «
                                         CONESVILLE
                                         6
                                         CONESVILLE
                                         OHIO
                                           411.0
                                           375.0
                                           411.0
                                         COAL
                                         BITUMINOUS
                                          25237.
                                            15.10
                                             7.50
                                             4.67
                                              .01
                                         UET  SCRUBBING
                                         LIME
                                         AIR  CORRECTION DIVISION, UOP
                                         NEW
                                             3.9
                                          6/78
                                          7/78
                                            89.50
                                              .00
                                              .0
                                              .0
                                         OPEN
                                            31.5
                                         POZ-0-TEC
                                                 POND
                                                         t  500 GPM>
_._.....—...	......—	......	PERFORMANCE  DATA-	......	...—......	....	
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR
1/80 A 88.0 74.0 74.0 74.0
B 89.0 78.0 78.0 78.0
SYSTEM 89.0 76.0 76. C 76.0


744 744 566 73.9
       • * PROBLEMS/SOLUTIONS/COMRENTS

                          NO  MAJOR  FGD  SYSTEM RELATED PROBLEMS UERE REPORTED FOR JANUARY.
 2/80
A
B
SYSTEM
            87.0
            92.0
            90.0
75.0
81.0
78.0
78.D
85.0
82.0
69.0
75.0
72.0
                                                                              696
                                                                                     648
                                                                                            503   70.8
       *• PROBLEMS/SOLUTIONS/COMRENTS
                          IN  FEBRUARY,  MIST ELIMINATOR NOZZLE PLUGGING OCCURRED  CAUSING  SOME  OUTAGE
                          TIME.
 3/80
A
B
SYSTEM
            93.0
            94.0
            94.0
69.0
76.0
73.0
69.0
76.0
73.0
15.0
16.0
16.0
                                                                               744
                                                                                     160
                                                                                            117  17.6
           PROBLENS/SOLUTIONS/COMPENTS
                          THE  BOILER WENT DOUN ON MARCH 9 FOR A BOILER/TURBINE  INSPECTION AND
                          REMAINED OUT OF SERVICE THROUGH THE END OF  THE  MONTH.
                                                 77

-------
 EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980

COLUMBUS I SOUTHERN OHIO ELEC: CONESVILLE 6 (CONT.>
	PERFORMANCE DATA	-—»—..
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD    CAP.
                                                                SO?  PART. HOURS HOURS  HOURS  FACTOR
4/80 A 98.8 25.6
B 98.9 54.2
SYSTEM 98.9 40.1
11.1
23.5
17.4 720 J12 125 1».a
       •• PROBLE4S/SOLUTIONS/COMMENTS

                         CONTINUOUS PROBLEMS WITH DAMPERS, PRESATURATOR HOSES. AND NOZZLES
                         ACCOUNTED FOR MOST OF THE APRIL F6D SYSTEM OUTAGES.

 5/80  A           96.9        58.3                    55.0
       B           96.1        33.8                    31.9
       SYSTEM      96.$        46.1                    43.4                  744   701    323  J9.1

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         CONTROL AND INSTRUMENTATION PROBLEMS THAT DEVELOPED IN HAY WERE RESPONSI-
                         BLE FOR SOME F6D SYSTEM OUTAGE TIME.

 6/80  A           97.1        73.6                    73.1
       SYSTEM      97.1        62.1                    61.7                  720   715    444  S2.5

       »* PROBLEMS/SOLUTIONS/COMMENTS

                         THE MAJORITY OF THE JUNE FGD SYSTEM OUTAGES WERE A RESULT OF EITERNAL
                         CAUSES (IUCS DISPOSAL SYSTEM, LOW UNIT DEMAND, SERVICE WATER, ETC.).

 7/80  A           96.0        85.1        £5.9        82.7
       B           99.1        89.1        89.9        86.6
       SYSTEM      97.5        87.1        87.9        64.6                  744   722    630  61.7

       •* PROBLEMS/SOLUTIONS/COMNENTS

                         THE FGD SYSTEM  EXPERIENCED  PROCESS CONTROL PROBLEMS DURING JULY.

                         PROBLEMS  WITH LEAKING INLET DAMPER SEALS ALSO OCCURRED DURING JULY.

 8/80  A           90.2        65.4        67.3        30.1
       B           97.«        85.5        88.0        39.4
       SYSTEM      93.8        75.5        77.6        34.7                  744   343    259  28.3

       •* PROBLCMS/SOLUTIONS/CONMENTS

                         THE UTILITY  REPORTED  THAT PROBLEMS WERE ENCOUNTERED WITH THE RECLAIM WATER
                         AND THE  RECYCLE  SLURRY SYSTEMS DURING  AUGUST.

 9/80  A            93.6        88.2        88.5        87.8
       B            94.2        90.7        91.0        90.3
       SYSTEM       93.9        89.5        89.8        89.0                  720   716    641  72.6

       ••  PROBLEMS/SOLUTIONS/CONMENTS

                         THE  INLET  DAMPER  SEAL  PROBLEM  CONTINUED THROUGH AUGUST AND SEPTEMBER.

                         EXTERNAL PROBLEMS  WERE EXPERIENCED WITH THE  IUCS SYSTEM.
                                               78

-------
                                             EPA UT1LITT F6D SURVEY: JULY  -  SEPTEMBER  1980
                                          SECTION 3
              DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
COMPANY NAME
PLANT NA1E
JMIT MUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION LIMITATION - N6/J
MET PLANT GENERATING CAPACITY - MM
SROSS UNIT 6ENERATIN6 CAPACITY - MM
MET UNIT GENERATING CAPACITY V/F6D - MU
MET UNIT GENERATING CAPACITY VO/F6D - MW
EBUIVOLENT SCRUBBED CAPACITY - MM
COMMONWEALTH EDISON
POMERTON
51
PEKIN
ILLINOIS
E
4J. ( .tOO
774. ( 1.800
1700.0
450. 0
400.0
425.0
450.0






LB/MMBTU)
LB/MMBTU)





*• BOILER DATA
    SUPPLIER
    TYPE
    SERVICE LOAD
    COMMERCIAL SERVICE DATE
    MAXIKUM BOILER FLUE GAS  FLOW -  CU.M/S
    FLUE GAS TEMPERATURE - C
    STACK HEIGHT - M
    STACK TOP DIAMETER - M

•* FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT CONTENT - J/G
    RANSE HEAT CONTENT - 9TU/LB
    AVERAGE ASH CONTENT - X
    RANGE ASH CONTENT  - X
    AVERAGE MOISTURE CONTENT -  X
    RANEE MOISTURE CONTENT - X
    AVERAGE SULFUR CONTENT - X
    RANGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT -  X
    RANGE CHLORIDE CONTENT - X

** GENERAL  EMISSION  CONTROL  SYSTEM DATA
    SALEABLE  PRODUCT/THROWAWAY  PRODUCT
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    DEVELOPMENT  LEVEL
    NEW/RETROFIT
    SOZ  DESIGN  REMOVAL EFFICIENCY  - X
    COMMERCIAL  DATE
    INITIAL START-UP
    CONSTRUCTION  COMPLETION
    CONSTRUCTION  INITIATION
    CONTRACT  AWARDED

 • *  FABRIC  FILTER
    NUMBER

 »*  ESP
    NUMBER
     TYPE
     SUPPLIER
     PARTICULAR DESIGN REMOVAL EFFICIENCY
     FLUE GAS  TEMPERATURE - C

 *•  MECHANICAL COLLECTOR
     NUMBER

 .*  PARTICLE SCRUBBER
     TYPE

 *• ABSORBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER OF STAGES
     DIMENSIONS - FT
    BABCOCK t WILCOX
    CYCLONE
    BASE
     0/72
      722.18
      157.2
      137.
        6.4
               (1530370 ACFM)
               ( 315  F)
               ( 450  FT)
               C 21.0 FT)
    COAL
    ******
     24516.
               (  10540  BTU/LB)
        9.16
- X
        16.34
    ******
        3.53
    ******
          .20
    ******
    THROUAUAV  PRODUCT
    WET  SCRUBBING
    LIMESTONE
    AIR  CORRECTION DIVISION, UOP
    FULL SCALE
    RETROFIT
        75.50
      6/81
      4/80
      8/80
      3/77
      2/76
 1
COLD SIDE
RESEARCH-COTTRELL
   98.7
  157.2        <  315
     NONE
     MOBILE PACKED  TOWER
     AIR CORRECTION  DIVISION, UOP
         3
     55 X 30  X  18
                                                 79

-------
  EPA  UTILITY  FED SURVEY: JULY - SEPTEMBER  19*0

COMMONWEALTH  EDISON:  POWERTON 51 (CONT.)

      SHELL  MATERIAL
      SHELL  LINER MATERIAL
      INTERNAL  MATERIAL
      33ILER LOAD/APSORBER - X
      GAS  FLOW  -  CU.M/S
      G»S  TEMPERATURE  -  C
      LiauID RECIRCULATION RATE  - LITER/S
      L/G  RATIO - L/CU.M
      PRESSURE  DROP -  KPA
      SUPERFICAL  GAS VELOCITY -  M/SEC
      P»RTICULATE  INLET LOAD - NG/J
      PARTICIPATE  OUTLET  LOAD -  NG/J
      S02  INLET CONCENTRATION -  PPM
      S02  OUTLET  CONTRATION  - PPM
      S02  DESIGN  REMOVAL  EFFICIENCY  - X

 •* CENTRIFUGE
      NUMBER
 CARBON  STEEL
 NEOPRENE RUBBER
 FRP, CARPENTER  20
    33.0
   240.73
   157.2
  1575.
     8.0
     3.0
     3.8
    43.
    43.
  2696
   660
    75.5
( 510123 ACFM)
(  315 F)
(25000 6PH)
( 60.0 GAL/1000ACF)
(12.0 IN-H20)
( 12,5 FT/S)
(  .100 LB/MMBTU)
(  .1-00 LB/MMBTU)
 •• FANS
     TYPE
     SERVICE - MET/DRY

 ** VACUUM FILTER
     NUMBER
     TYPE
     CONSTRUCTION MATERIAL
     CAPACITY - M T/D
     OUTLET SOLIDS - X

 •• MIST ELIMINATOR
     NUMBER
     TYPE
     CONSTRUCTION MATERIAL
     CONFIGURATION
     riASH SYSTEM
     SUPERFICIAL GAS VELOCITY - M/S

 •* PROCESS CONTROL CHEMISTRY
     CONTROL VARIABLES
     CONTROL MANNER
     MODE

 •* TANKS
     SERVICE
     RECYCLE
     SLURRY  MAKE-UP
     4.E.  HASH
     HASTE SLURRY
     LIMESTONE TRANSFER
     RECLAIMED MATER

••  RtHEATER
     TYPE
     HEATING  MEDIUM
     TEMPERATURE  BOOST - C
     ENERGY REQUIRED

••  THICKENER
     NUMBER
     CONSTRUCTION MATERIAL
     DIAMETER  - M
     OUTLET SOLIDS  - I

»*  HATER LOOP
     TYPE
     FRESH MAKEUP HATER  ADDITION - LITERS/S

••  REAGENT PREPARATION  EQUIPMENT
     NUMBER OF BALL MILLS
     BALL MILL CAPACITY- N T/H

•*  TREATMENT
     TYPE
     CONTRACTOR
 CENTRIFUGAL
 DRY
 ROTARY  DRUM
 CARBON  STEEL
  1088.4        ( 1200 T/D)
    55.0
 CHEVRON
 FIBERGLASS REINFORCED PLASTIC
 HORIZONTAL
 WASH  TOP AND BOTTOM LAYERS ONLY
     2.7         (  9.0 FT/S)
 S02,  GAS  FLOW,  PH
 AUTOMATIC
 FEEDBACK/FEED  FORWARD
                                                 NUMBER
HOT AIR  INJECTION
STEAM
   13.9         (    25  F)
71,000.000 BTU/HR
CARBON STEEL
   51.8         <170  FT)
   35.0
CLOSED
   35.3
    2
   20.0
POZ-0-TEC
IUCS
                <  560  GPM)
                ( 22.0 TPH)
                                                80

-------
                                               EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

COMMONWEALTH EDISON: POWERTON  51  (CONT.)

     INLET- KS/S                                    20.6        < 2727 LB/MIN)
     INLET SOLIDS - X                               35.0

 •» DISPOSAL
     NATURE                                      FINAL
     TYPE                                        LANDFILL

 •* DISPOSAL
     NATURE                                      INTERIM
     TYPE                                        LINED POND
     LOCATION                                    ON SITE
     CAPACITY - CU.M                                 122300     (   »OC.O  ACRE-FT)



.--	PERFORMANCE DATA—	
PERIOD NODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIIATION  X RE.MOVAL   PER   BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS  HOURS   HOURS FACTOR


 t/80  SYSTEM                                                                  720

 5/80  SYSTEM                                                                  744

 5/80  SYSTEM                                                                  720

       *•  PROBLEMS/SOLUTIONS/COMMENTS

                          INITIAL FED SYSTEM OPERATIONS  BEGAN  IN APRIL.   THE F6D  SYSTEM IS CURRENTLY
                          OPERATING ON FLUE GAS GENERATED  FROM THE BURNING OF LOU  SULFUR WESTERN
                          COAL.  ONLY TWO OF THE THREE  ABSORBER  MODULES  HAD BEEN  OPERATED AS OF THE
                          END OF JUNE.  THE FGD SYSTEM  IS  NOT  EXPECTE.D TO BE DECLARED COMMERCIAL
                          UNTIL DECEMBER 1980.

                          THE UTILITY REPORTED THAT CURRENT  OPERATING AND MAINTENANCE COST PROJECT-
                          IONS INDICATE THAT MANPOWER REQUIREMENTS  FOR UNIT 51 WILL DOUBLE AND THAT
                          ON A COST BASIS THE  POTENTIAL OPTION OF  BURNING LOU SULFUR COAL AS  A
                          COMPLIANCE STRATEGY  MILL PROVE LESS  EXPENSIVE  THAN FGD.

 7/8C   SYSTEM                                                                  744

 S/80   SYSTEM                                                                  744

        SYSTEM                                                                  720

        *» PROBLEMS/SOLUTIONS/COMMENTS

                          NO DECISION HAS  BEEN MADE  TO  START COMMERCIAL OPERATIONS.  THERE ARE NO  FGD
                          OPERATIONS EXCEPT TESTING  IN  ONE MODULE.  PERFORMANCE DATA UILL BE  AVAIL-
                          ABLE WHEN THE FGD SYSTEM GOES INTO COMMERCIAL OPERATION.
                                                  81

-------
  EPA  UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980
                DESIGN  AND PERFORMANCE DATA
                                            SECTION 3
                                            FOR OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY  NAME
  PLANT NAME
  UNIT NUMBER
  CITY
  STATE
  SROSS UNIT GENERATING  CAPACITY  - MM
  VET UNIT GENERATING  CAPACITY  W/FGD  - MW
  E8UIVALENT SCRUBBED  CAPACITY  -  MU

  •• FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/6
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  -  X

  •• GENERAL EMISSION  CONTROL SYSTEM  DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

  ** MATER LOOP
     TYPE
     FRESH MAKE-UP MATER - LITER/S
- X
     COOPERATIVE  POUER ASSOCIATION
     COAL CREEK
     1
     UNDERWOOD
     NORTH DAKOTA
       545.0
       495.0
       327.0
     COAL
     LIGNITE
      14556.
         7.14
        39.83
          .63
          .02
     WET SCRUBBING
     LIME/ALKALINE FLVASH
     COMBUSTION ENGINEERING
     NEW
              (  6258 BTU/LB)
7/79
8/79
  54.00
  99.50
    .0
    .0
     OPEN
                    (***»•* 6PM)
 •• TREATMENT
     TYPE

 ** DISPOSAL
     TYPE
     FLVASH STABILIZATION
     LINED POND
..._._..._.......—.-..	......—..——PERFORMANCE  DATA——
PERIOD MODULE AVAILABILITY OPERABUITY RELIABILITY  UTILIZATION
                     X REMOVAL   PER  BOILER  FGD    CAP.
                     S02  PART. HOURS HOURS  HOURS  FACTOR
 1/80  SYSTEM                 100.0

       •• PROBLEMS/SOLUTIONS/COMMENTS
            96.1
                            744   715
                                               715
                         DURING JANUARY  TWO  MODULES  AT  A  TIME  HERE  TAKEN OFF-LINE FOR INSPECTION
                         AND CLEANING.   SOME  CRACKED  NOZZLES AND PLUGGING PROBLEMS WERE FOUND
                         DURING THE INSPECTION.   THE  BOILER WAS  OPERATED AT A REDUCED LOAD.

                         SOME OUTAGE TIME DURING  THE  MONTH WAS CAUSbD  BY BOILER-RELATED PROBLEMS.
                         A BOILER TRIP WAS CAUSED BY  A  TURBINE ELECIRICIAL RELAY ON JANUARY 13.

                         AN HOUR OF OUTAGE TIME RESULTED  FROM  A  LOSS  OF  POWER TO THE CONTROL
                         SYSTEM AND AN ABNORMAL BOILER  DRUM LEVEL WAS  ALSO ENCOUNTERED ON JANUARY
                         16 *
                         A THREE TO FOUR HOUR OUTAGE yAS  SCHEDULED  ON  JANUARY 27 TO MAKE REPAIRS ON
                         FGD SYSTEM EQUIPMENT.
 2/60  SYSTEM

       ••  PROBLEMS/SOLUTIOWS/COMMENTS
                                                        99.9
                                                                              696   695
                         WHILE THE BOILER WAS OUT OF SERVICE  DUE  TO  ID  FAN  PROBLEMS CAUSED BY
                         ELECTRICAL GROUNDING, TWO MODULES  WERE TAKEN OUT OF  SERVICE SO CALIBRA-
                         TIONS COULD BE DONE.
 5/80  SYSTE"
                              100.0
            96.1
                                                                              744    715
                                               715
                                                82

-------
                                              EPA UTILITY F60 SURVEY: JULY - SEPTEMBER  1980

COOPERATIVE POWER ASSOCIATION: COAL CREEK 1 (CONT.)
... 	 .- 	 PERFORMANCE KATA 	 	 	 	 — — - — ~ 	 """
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION X REMOVAL PER BOILER F6D CAP.
S02 PART. HOURS HOURS HOURS FACTOR
*• PROBLE1S/SOLUTIOSS/COMMENTS
90ILER TRIPS OCCURRED THREE TIMES DURING THE MONTH.
TO THE CUT DOWN OF TRANSMISSION POWER ON MARCH 12.


4/80 1 1
12
13
14
SYSTE1


96.7
100.0
100.0
100.0
99.2
THE FGD SYSTEM WAS SHUTDOWN
FILTER ON THE BOILER STATOR
DURING MARCH STACK EMISSION
WITH ONE MODULE DOWN DURING
SB. 3 100.0
81.7 100.0
96.1 10C.O
96.9 100.0
83.3 10?. 0
WITH THE BOILER FOR FOUR
COOLING PUMPS.
TESTS WERE UNDERTAKEN.
TESTING.
21.4
30.0
35.3
35.6
30.6
ONE TRIP WAS DUE
HOURS TO CLEAN THE
THE SYSTEM OPERATED
720 264 220 26.2
»» PROBLEMS/SOLUTIONS/COMMENTS

5/80 11
12
1!
14
SYSTEM

88.3
79.3
91.9
91.3
87.7
THE BOILER WAS OFF LINE FOR
AGE. THE SCRUBBING SYSTEM
68.8 1CO.O
18.6 10P.O
79.6 100.0
35.5 100.0
50.6 100.0
APPROXIMATELY 19 DAYS FOR THE ANNUAL UNIT OUT-
WAS AVAILABLE DURING THE BOILER OUTAGE.
34.4
9.3
39.8
17.7
25.3
744 372 188 28.2
«» PROBLEMS/SOLUTIOMS/COMMENTS
THE ANNUAL UNIT OUTAGE WAS COMPLETED IN THE, BEGINNING OF THE MONTH. THERE
HERE PROBLEMS WITH BOILER STARTUP AFTER THIS OUTAGE CAUSING LOW OPERA8ILITY
OF THE FGD SYSTEN.
i/80 11
12
13
SYSTEM
92.9
98.5
74.7
93.5
89.9
49.3 100.0
47.6 100.0
42.2 100.0
73.0 100.0
53.0 10Q.O
49.2
47.5
42.1
72.8
52.9
720 718 381 58.5
  7/80
  S/80

  9/80
        *• PROBLEMS/SOLUTIONS/COMMENTS
                          THERE WERE NO MAJOR PROBLEMS REPORTED  DURING  JUNE.
                          AND REPAIRS WERE DONE THROUGHOUT  THE MONTH.
ROUTINE MAINTENANCE


744   648    648  47.1
SYSTEM     100.0       100.0       100.0        87.1

*• PROBLEMS/SOLUTIONS/COMWENTS

                  IN JULY, NO PROBLEMS WERE  ENCOUNTERED  WITH  THE  F6D SYSTEM.

SYSTEM                                                                 744

SYSTEM                                                                 720

*• PROBLEMS/SOLUT10NS/COMMENTS

                  NO INFORMATION  WAS  AVAILABLE  FOR THE MONTHS OF  AUGUST AND SEPTEMBER.
                                                  83

-------
  EPA  UTILITY  FGO  SURVEY:  JULY  - SEPTEMBER 1980

                                            SECTION J
                DESIGN  AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 BEGULATORY CLASSIFICATION
 PARTICULATE EMISSION LIMITATION -  N6/J
 S02 EMISSION LIMITATION - NG/J
 NET PLANT GENERATING CAPACITY - MW
 SROSS UNIT GENERATING CAPACITY - MW
 NET UNIT GENERATING CAPACITY W/FGD - MW
 NET UNIT GENERATING CAPACITY WO/FGD - MW
 EQUIVALENT SCRUBBED CAPACITY - MU

 •• BOILER DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL SERVICE DATE
     MAXIMUM BOILER FLUE GAS FLOW - CU.M/S
     FLUE GAS TEMPERATURE - C
     STACK  HEIGHT - M
     STACK  TOP  DIAMETER - M

 •*  FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     RANGE  HEAT  CONTENT - BTU/LB
     AVERAGE ASH CONTENT - X
     RANGE  ASH  CONTENT - X
     AVERAGE MOISTURE CONTENT - T
     RANGE  MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE  SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE  CHLORIDE CONTENT - X

 «*  GENERAL  EMISSION CONTROL SYSTEM  DATA
     SALEABLE PftODUCT/THROWAWAY  PRODUCT
     GENERAL PROCESS TYPE
     PROCESS  TYPE
     PROCESS  ADDITIVES
     SYSTEM  SUPPLIER
     A-E  FIRM
     DEVELOPMENT  LEVEL
     NEW/RETROFIT
     PARTICULATE  DESIGN  REMOVAL  EFFICIENCY
     502  DESIGN  REMOVAL  EFFICIENCY  - X
     COMMERCIAL  DATE
     INITIAL  START-UP
     CONSTRUCTION  INITIATION

»•  ESP
     NUMBER
     TYPE
     SUPPLIER
     PARTICULATE  DESIGN  REMOVAL  EFFICIENCY
     FLUE GAS CAPACITY - CU.M/S
     FLUE GAS TEMPERATURE  -  C
    PARTICULATE OUTLET LOAD  - G/CU.M

•* PARTICLE  SCRUBBER
     TYPE

• * ABSORBER
     NUMBER
     TYPE
     INITIAL  START  UP
     SUPPLIER
     NUMBER  OF STAGES
     DIMENSIONS -  FT
     SHELL MATERIAL
     SHELL LINER MATERIAL
      COOPERATIVE POWER ASSOCIATION
      COAL CREEK
      UNDERWOOD
      NORTH DAKOTA
      B
         43.
        516.
       1100.0
        545.0
        495.0
               (  .100 LB/MMBTU)
               ( 1.800 LB/MMBTU)
        327.0
      COMBUSTION  ENGINEERING
      PULVERIZED  LIGNITE
      BASE
      **/ * *
      *»••»***        (•»**.««*  ACFM)
        160.0         (  320 F)
        198.          (  650 FT)
         6.7         <  22.0 FT)
     COAL
     LIGNITE
       14556.

         7.14
     3.69-15.95
        39.83
     27.78-52.55
           .63
     0.18-1.41
           .02
     0.00-0.08
     THROWAWAY PRODUCT
     WET SCRUBBING
     LIME/ALKALINE FLYASH
     NONE
     COMBUSTION ENGINEERING
     BLACK S VEATCH
     FULL SCALE
     NEW
- X     99.50
        54.00
      9/80
      7/80
      8/77
      1
     COLD SIDE
     WHEELABRATOR-FRYE
  X     99.5
               (   6258  BTU/LB)
               3068-7660
                    (2310000 ACFM)
                    (  3C1 F)
                    (   .01 GR/SCF)
1090.1
 160.6
    .02
     NONE
     SPRAY TOWER
     11/79
     COMBUSTION ENGINEERING
         1
     22 X 22 X 20
     316L SS
     NONE
                                                84

-------
                                               EPA UTILITY F60 SURVEY: JULY  -  SEPTEMBER  1980

CJOPERATIVE POWER ASSOCIATION:  COAL  CREEK  2 (CONT.)
     NOZZLE TYPE
     L/6 RATIO - L/CU.M
     S32 INLET CONCENTRATION  -  PPM
     S02 OUTLET CONTRATION  -  PPM
     S02 DESIGN REMOVAL  EFFICIENCY  - X

 »* FANS
     NUMBER
     TYPE

 •• HIST ELIMINATOR
     NUMBER
     TYPE
     CONSTRUCTION  MATERIAL
     NUMBER OF STAGES

 •* MIST ELIMINATOR
     NUMBER
     TYPE
     CONSTRUCTION  MATERIAL

 »* PUMPS
     SERVICE
      BLEED  STREAM
      SLURRY FEED
      REACTION TANK
      *»*•»•
                      PROPRIETARY ATOMIZING
                          8.0         I  60.0  GAL/1000ACF)
                       1000
                        100
                         90.0
                      INDUCED  DRAFT
                      CHEVRON
                      FIBERGLASS  REINFORCED PLASTIC
                           2
                       SLAT  IMPINGEMENT
                       FIBERGLASS REINFORCED PLASTIC
                       NUMBER
                          3
                       *** *
                          6
                       *** *
  **  TANKS
      SERVICE
      REACTION-RECYCLE-THICKENER
      FLY»SH WETTING
      LIME FEED

  ** REHEATER
      TYPE
      TEMPERATURE BOOST - C

  •* WATER LOOP
      TYPE

  •* REAGENT PREPARATION EQUIPMENT
      NUMBER OF SLAKERS

  •* TREATMENT
      TYPE
                       NUMBER

                          2
                       *** *
                       BYPASS
                          47.2         C    85  F)
                       OPEN
                                                  FLYASH STABILIZATION
  ** DISPOSAL
      NATURE
      TYPE
      AREA - ACRES
                       FINAL
                       LINED  POND
                          104.0
 _.	1	PERFORMANCE DATA	
 PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   Jt  REMOVAL   PER  BOILER   F6D    CAP.
                                                                   S02  PART. HOURS HOURS  HOURS  FACTOR
  7/80  SYSTEM

        «• PROBLEMS/SOLUTIONS/COHPENTS
                                                                                744
  5/80  SYSTEM

  j/80  SYSTEM
INITIAL OPERATION  OF  THE  FGD  SYSTEM BEGAN IN JULY  19&0.   NO  MAJOR  STARTUP
PROBLEMS WERE REPORTED.

                                                      744

                                                      720
                                                   85

-------
 EPA UTILITY  F60  SURVEY:  JULY - SEPTEMBER 1980

C30PERATIVE POWER  ASSOCIATION: COAL CREEK 2 CCONT.)
............——.	—-—-—	—	PERFORMANCE DATA——	-—	——-———	—»—..._
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  J REMOVAL   PER  BOILER  F6D    CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR


       *» PROBLE1S/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM  IS  STILL IN  THE  INITIAL PHASE OF OPERATION.  NO PERFORMANCE
                         DATA ARE AVAILABLE  AT  THE PRESENT TIME.
                                                86

-------
                                             EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980
                                          SECTION 3
              DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION - NG/J
S02 EMISSION. LIMITATION - NG/J
MET PLANT GENERATING CAPACITY - MW
SftOSS UNIT GENERATING CAPACITY - MW
MET JNIT GENERATING CAPACITY U/FGD - MW

EQUIVALENT SCRUBBED CAPACITY - MW
DELMARVA POWER
DELAWARE CITY
1
DELAWARE CITY
DELAWARE
E
129.
180.0
60.0

60.0
I LIGHT
( .300 LB/MMBTU)



*• BOILER DATA
    SUPPLIER
    TYPE
    SERVICE LOAD
    COMMERCIAL SERVICE DATE
    MAXIMUM BOILER FLUE GAS FLOW - CUiM/S
    FLUE GAS TEMPERATURE - C
    STACK HEIGHT - M
    STACK TOP DIAMETER - 1

•• FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT CONTENT - J/G
    RANGE HEAT CONTENT - BTU/LB
    AVERAGE ASH CONTENT - X
    RANEE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT - X
    RANGE MOISTURE CONTENT - X
    AVERAGE SULFUR CONTENT - X
    RANGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT - X
    RANGE CHLORIDE CONTENT - X

** GENERAL EMISSION CONTROL SYSTEM DATA
    SALEABLE PRODUCT/THROKAWAY PRODUCT
    GENERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    A-E FIRM
    CONSTRUCTION FIRM
    DEVELOPMENT LEVEL
    NEW/RETROFIT
    PARTICULATE DESIGN  REMOVAL EFFICIENCY
    S02 DESIGN REMOVAL  EFFICIENCY  -  X
    COMMERCIAL DATE
    INITIAL START-UP
    CONSTRUCTION COMPLETION
    CONSTRUCTION INITIATION
    CONTRACT AWARDED
    LETTER OF INTENT SIGNED
    STARTED PREL1MINAY  DESIGN
- X
     RILEV  STOKER
     PULVERIZED  COKE
     BASE
     10/56
       417.63        ( 88SOOO ACFM)
       215.6         ( 420 F>
       152.          ( 500. FT)
        6.1         < 20.0 FT)
     COKE
     FLUID  PETROLEUM COKE
      32564.         ( 1*000 BTU/LB)
                     13500-14500
          .50
     .3-.7
          .70
     .5-1.2
         7.00
     5-8
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
DAVY MCKEE
DAVY MCKEE
FULL SCALE
RETROFIT
   90.00
   90.00
 5/80
 5/80
 4/80
 1/78
 9/77
 8/76
10/77
*•  FA9RIC FILTER
    TYPE


• *  ESP
    NUMBER
    SUPPLIER
    PARTICULATE DESIGN  REMOVAL  EFFICIENCY
    FLUE GAS  CAPACITY - CU.M/S
    FLUE GAS  TEMPERATURE -  C
    PRESSURE  DROP  -  KPA
    PARTICULATE OUTLET  LOAD - G/CU.M


••  MECHANICAL COLLECTOR
    NUMBER
    TYPE
    SUPPLIER
    PARTICULATE DESIGN  REMOVAL  EFFICIENCY
     NONE
     JOY WESTERN
- X     95.0
       104.3
        54.4
     *******
          .69
      3

     TUBULAR
     PRAT-DANIEL
  X     92.0
                (  221000  ACFM)
                (   130  F)
                (***«*  IN-H20)
                (    .30 GR/SCF)
                                                87

-------
 EPA JTUITY  FED  SURVEY:  JULY  -  SEPTEMBER  1980

OELMARVA POWER &  LIGHT:  DELAWARE  CITY  1  (CONT.)
 •« PARTICLE SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUM9ER OF STAGES
     SHELL MATERIAL
     LIMING MATERIAL
     DUMBER OF NOZZLES
     TYPE OF NOZ/LES
     iOlLER LOAD/SCRUBBER - X
     FLUE GAS CAPACITY - CU.M/S
     FLUE GAS TEMPERATURE - C
     LIQUID RECIRCULATION RATE - LITER/S
     PRESSURE DROP - KPA
     P«RTICULATt  INLET LOAD - G/CU.H
     PARTICULATE  OUTLET LOAD - G/CU.M
     PARTICULATE  DESIGN RE10VAL EFFICIENCY
     S32  INLET  CONCENTRATION - PPM
     S02  DESIGN REMOVAL EFFICIENCY - X

 •*  »3SOR8ER
     NUMBER
     TYPE
     INITIAL  START  UP
     SUPPLIER
     NUMBER OF  STAGES
     DIMENSIONS -  FT
     SHELL  MATERIAL
     SHELL  LINER MATERIAL
     INTERNAL MATERIAL
     30ILER LOAD/ABSORBER  - X
     GAS FLOW - CU.M/S
     GAS TEMPERATURE -  C
    LI8UID RECIRCULATION  RATE  -  LITER/S
    PARTICULATE INLET  LOAD  -  G/CU.M
    PHRTICULATE OUTLET  LOAD-  G/CU.M
    PARTICULATE REMOVAL EFFICIENCY  - X
    S02 INLET  CONCENTRATION  - PPM
    S92 OUTLET CONTRATION  -  PPM

•* CENTRIFUGE
    TYPE

•* FANS
    NUMBER
    CONSTRUCTION MATERIALS
    SERVICE -  WET/DRY
    CAPACITY - CU.M/S
     VENTURI
     AIRPOL
         1
     CARBON STEEL
     GLASS FLAKE, ACID BRICK, CAROBRAX BRICK
         1
     OPEN PIPE WITH REFRAX TIP
       100.0
       139.2          295000 ACFM)
       215.6           
   400 6PM)
   .100 GR/SCF)
   .tOO 6R/SCF)
     NONE
     CARBON STEEL
     DRY
       139.21
                    ( 295000 ACFM)
•• VACUUM FILTER
    TYPE

•• MIST ELIMINATOR
    NUMBER
    TYPE
    CONSTRUCTION MATERIAL
    CONFIGURATION
    NUMBER OF STAGES
    NUMBER OF PASSES
    FREEBOARD DISTANCE  - M
    BEPTH - m
    4ASH SYSTEM
    PRESSURE DROP - KPA

•• PROCESS CONTROL CHEMISTRY
    CONTROL VARIABLES
    CONTROL MANNER
    MODE
    SENSOR LOCATION

t* PUMPS
    SERVICE
     NONE
      3
     CHEVRON
     NORtL  PLASTIC
     HORIZONTAL
         1
         1
         1.83
         2.29
< 6.0 FT)
< 7.5 FT)
     INTERMITTANT  SPRAYS
          .1
                       .3 IN-H20)
     PH,  SOLIDS.  SP.G.. CONC.
     AUTOMATIC
     FEEDBACK
     CAS  OUTLET,  SOLUTION OUTLET
                                                NUMBER
                                                88

-------
                                               EPA UTILITV F60 SURVEY: JULY  -  SEPTEMBER  1980

PELNARVA POWER & LIGHT:  DELAWARE  CITY  1  (CONT.)
 *• REHEATER
     TYPE
     HEATING MEDIUM
     TEMPERATURE BOOST  -  C

 »* THICKENER
     TYPE

 *• WATER LOOP
     TYPE

 •* BYPRODUCTS
     BYPRODUCT  NATURE
     BYPRODUCT  flUANTITY - M  T/H
     BYPRODUCT  dUALITV  -  X
     DISPOSITION

 •* TREATMENT
     TYPE

 •* DISPOSAL
     NATURE
     TYPE
                                               HOT AIR INJECTION
                                               FLUE GAS
                                                  27.8         (    SO  F)
                                               NONE
                                               CLOSED
                                               SULFURIC ACID
                                                  11.3*        (  12,50 TPH>
                                                  93.0
                                               MARKETED
                                               NEUTRALIZATION
                                                FINAL
                                                LINED  POND
	PERFORMANCE  DATA	
PERIOD  MODULE  AVAILABILITY OPtRABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER   FGO    CAP.
                                                                  S02  PART. HOURS HOURS   HOURS  FACTOR
  5/BD  SYSTEM     100.C       100.0

        •* PROBLEMS/SOLUTIONS/COMMENTS
                                          100.3
                                                       32.3
744   240    240
                          THE FGD SYSTEM  REGAN  INITIAL AND COMMERCIAL OPERATIONS  ON  MAY  22i  19BC.
                          NO MAJOR PROBLEMS  HERE  ENCOUNTERED FROM STARTUP THROUGH THE  END OF
                          THE HONTH.

     0  SYSTE"      98.9        9«.9         98.9         98.9                   720   720     712

        «* PROBLE1S/SOLUTIOSS/COM»ENTS

                          NO MAJOR PROBLEMS  WERE  ENCOUNTERED DURING JUNE.

  7/61  SYSTEM      97.2        97.0         97.C         90.7                   744   696     675

        ** PROBLE*S/SOLUTION$/COM-«ENTS

                          THE  FGD SYSTEM  WAS DOWN FOR PART  OF THE MONTH  IN  JULY TO REPAIR A LEAK  IN
                          THE  MIST ELIMINATOR.
                                             99.9
                                                         99.9
3/6"  SYSTEM      99.9         99.9

      «• PROBLEMS/SOLUTIONS/COMMENTS

                         NO  FGD-RELATED PROBLEMS WERE REPORTED  CURING AUGUST.

J/8"  SYSTEM                                                                  720

      •• PROBLEMS/SOLUTIONS/COMMENTS

                         NO  INFORMATION WAS AVAILABLE FOR  SEPTEMBER 198C.
                                                                                744   744    743
                                                   89

-------
 EPA UTILITY FGD SURVEY:  JULY  -  SEPTEMBER  1980

                                            SECTION  3
               DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL  DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 REGULATORY CLASSIFICATION
 PARTICIPATE EMISSION LIMITATION - NG/ J
 S02 EMISSION LIMITATION - NG/j
 NET PLANT GENERATING CAPACITY - MW
 • ROSS UNIT GENERATING CAPACITY - MW
 NET JNIT GENERATING CAPACITY U/FSD - MW
 SET UNIT GENERATING CAPACITY WO/FGD - MW
 EQUIVALENT SCRUBBED CAPACITY - MU

 ••  BOILER DATA
     SUPPLIER
     TYPE
     SERVICE  LOAD
     COMMERCIAL  SERVICE  DATE
     4.AXHUM  BOILER  FLUE  GAS  FLOW - CU.M/S
     FLUE  GAS  TEMPERATURE -  C
     STACK  HEIGHT  -  M
     STACK  TOP DIAMETER  - M

 *•  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT - J/G
     RANGE  HEAT  CONTENT  - BTU/LB
     AVERAGE ASH CONTENT  - X
     RANGE  ASH CONTENT -  X
     AVERAGE MOISTURE  CONTENT - X
     RANGE  MOISTURE  CONTEHT - X
     AVERAGE SULFUR  CONTENT - X
     RANGE  SULFUR  CONTENT • X
     AVERAGE CHLORIDE  CONTENT - X
     RANGE  CHLORIDE  CONTENT - X

•• GENERAL EMISSION CONTROL  SYSTEM DATA
     SALEABLE PRODUCT/THftOHAWAY PRODUCT
    GENERAL PROCESS TYPE
    PROCESS TYPE
     SYSTEM SUPPLIER
    A-E FIRM
    CONSTRUCTION  FIRM
    DEVELOPMENT LEVEL
    NEW/RETROFIT
    P»RTICULATE DESIGN  REMOVAL EFFICIENCY
    S02 DESIGN REMOVAL  EFFICIENCY  -  X
    COMMERCIAL DATE
    INITIAL START-UP
    CONSTRUCTION  COMPLETION
    CONSTRUCTION  INITIATION
    CONTRACT AWARDED
    LETTER OF INTENT  SIGNED
     STARTED PPELIMINAY  DESIGN

•* FABRIC  FILTER
     TYPE
- X
      DELMARVA POWER & LIGHT
      DELAWARE CITY
      2
      DELAWARE CITY
      DELAWARE
      E
        129.

        180.0
         60.0
                   .300 LB/MMBTU)
                  ..*•* LB/MMBTU)
         60.0
     RILEY  STOKER
     PULVERIZED  COKE
     BASE
     10/S6
       417.63        <  885000  ACFM)
       215.6         (  420  f)
       152.          (  500  FT)
         6.1         <  20.0 FT)
     COKE
     FLUID PETROLEUM  COKE
      32564.

           .50
     .3-. 7
           .70
     .5-1.2
         7.00
     5-B
SALEABLE PRODUCT
UET SCRUBBING
WELLMAN LORD
DAVY HCKEE
DAVY HCKEE
DAVY HCKEE
FULL SCALE
RETROFIT
   90.00
   90.00
 5/80
 5/80
 4/80
 1/7S
 9/77
 8/76
10/77
                                                NONE
                (  UOOO  BTU/LB)
                135QO-14500
• • ESP
    NUMBER
    SUPPLIER
    PARTICULATE DESIGN  REMOVAL  EFFICIENCY
    FUUE GAS CAPACITY - CU.M/S
    FLUE GAS TEMPERATURE  -  C
    PRESSURE DROP - *PA
    PARTICULATE OUTLET  LOAD  - G/CU.M

•• MECHANICAL COLLECTOR
    NUMBER
    TYPE
    SUPPLIER
    PARTICULATE DESIGN  REMOVAL  EFFICIENCY
- X
JOY WESTERN
   95.0
  104.3
   54.4
          .69
     TUBULAR
     PRAT-DANIEL
  X     92.0
                    ( 33*000 ACFM)
                    C  130 M
                    (..*«» JM-H20)
                    C   .30 GR/SCF)
                                                90

-------
                                               EPA  UTILITY  F6D SURVEY: JULY - SEPTEMBER 1980

DELMARVA POWER & LIGHT: DELAWARE CITY 2  (CONT.)
 ** PARTICLE SCRUBBER
     NUMBER
     TYPE
     SUPPLIER
     NUMBER OF STAGES
     SHELL MATERIAL
     LINING MATERIAL
     NUMBER OF NOZZLES
     TYPE OF NOZZLES
     BOILER LOAD/SCRUBBER - X
     FLUE GAS CAPACITY - CU.M/S
     FLUE GAS TEMPERATURE - C
     LIQUID RECIRCULATION RATE - LITER/S
     PRESSURE DROP - KPA
     PARTICULATE INLET LOAD - G/CU.M
     PARTICULATE OUTLET LOAD - G/CU.M
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     S02 INLET CONCENTRATION - PPM
     S02 DESIGN REMOVAL EFFICIENCY  - X

 *• A3SOD3ER
     NUMBER
     TYPE
     INITIAL START UP
     SUPPLIER
     NUMBER OF STAGES
     DIMENSIONS -  FT
     SHELL MATERIAL
     SHELL LINER MATERIAL
     INTERNAL MATERIAL
     BOILER LOAD/ABSORBER - X
     SAS FLOW - CU.M/S
     6»S TEMPERATURE - C
     LI8UID RECIRCULATION RATE - LITER/S
     PARTICULATE INLET LOAD - G/CU.M
     PARTICULATE OUTLET LOAD- G/CU.M
     PARTICULATE REMOVAL EFFICIENCY -  X
     S02 INLET CONCENTRATION - PPM
     SOt OUTLET CONTRATION  - PPM

 •• CENTRIFUGE
     TYPE

 • • FANS
     NUMBER
     CONSTRUCTION  MATERIALS
     SERVICE  - WET/DRV
     CAPACITY - CU.M/S

 ** VACUUM  FILTER
     TYPE

 *• MIST ELIMINATOR
     NUMBER
     TYPE
     CONSTRUCTION  MATERIAL
     CONFIGURATION
     NUMBER  OF STAGES
     NUMBER  OF PASSES
     FREEBOARD DISTANCE  -  M
     DEPTH  -  M
     rfASH  SYSTEM
     PRESSURE DROP - KPA

 ** PROCESS  CONTROL  CHEMISTRY
     CONTROL  VARIABLES
     CONTROL  MANNER
     NODE
     SENSOR  LOCATION

 »* PUMPS
     SERVICE
     VENTURI
     AIRPOL
         1
     CARBON STEEL
     GLASS FLAKE, ACID BRICK, CAROBRAX BRICK
         1
     OPEN PIPE M1TH REFPAX TIP
       100.0
       139.2        i 295000 ACFMJ
       215.6        (  *CO F)
       315.0        ( 5000 GPM)
     *******        (***** IN-M20)
         3.2        C  1.39 6R/SCF)
          .6        C  .250 GR/SCM
- X     81.5
      3500.000
          .0
     TRAY TOWER
      4/80
     DAVY MCKEE
         4
     20 X 20
     REINFORCED CONCRETE
     TILE
     316L SS
       100.0
       103.82
        54.4
        25.
           .2
           .2
           .0
      3500
       390
     NONE
     CARBON  STEEL
     DRY
        139.21
      NONE
      CHEVRON
      NORYL  PLASTIC
      HORIZONTAL
          1
          1
          1.83
          2.29
               ( 220000 ACFB)
               (  130 F)
               (  400 6P«>
               (  .100 GR/SCF)
               (  .>OC 6R/SCF)
                     I 29SOOO ACFH)
               ( 6.0 FT)
               I 7.5 FT>
INTERHITTANT SPRAYS
     .1        (  .3 IN-H20)
      PH,  SOLIDS,  SP.fc.t tONC.
      AUTOMATIC
      FEEDBACK
      GAS  OUTLET,  SOLUTION OUTLET
                                                 NUMBER

                                                 *•* •
                                                 91

-------
  EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  19SO

 &ELKARYA POWER i LIGHT: DELAWARE CITY  2  (CONT.)
  •*  REHEATER
      TYPE
      HEATING MEDIU"
      TEMPERATURE BOOST - C

  ••  THICKENER
      TYPE

  ••  WATER  LOOP
      TYPE

  **  BYPRODUCTS
      BYPRODUCT  NATURE
      BYPRODUCT  (1UANTITY  - M  T/H
      3YPSODUCT  BUALITY - *
      DISPOSITION
     TYPE

 *• DISPOSAL
     NATURE
     TYPE
      HOT AIR  INJECTION
      FLUE GAS
         27.8         <
      NONE
      CLOSED
            SO  F)
      SULFURIC ACID
         11.34
         93.0
      MARKETED
                                                 NEUTRALIZATION
      FINAL
      LINED POND
        ( 12.SC TPH)
	PERFORMANCE DATA	— — .....	
PERIOD MODULE AVAILABILITY  OPERABUITY RELIABILITY UTILIZATION  I REMOVAL    PER   BOILER   FGD   CAP.
                                                                 S02   PART.  HOURS  HOURS   HOURS FACTOR
 5/80  SYSTEM     100.0        100.0

       *« PROBLEMS/SOLUTIONS/COMMENTS
100.0
3?.3
                                    744
                                          240
                                                 240
                          THE  FGD  SYSTEM BEGAN INITIAL AND COMMERCIAL OPERATIONS  ON  MAY  22,  1980.
                          NO MAJOR  PROBLEMS  WERE ENCOUNTERED DURING STARTUP  OR  THROUGH THE  REST OF
                          THE  MONTH.
 5/8P  SYSTEM      B0.«         60.4

       •• PROBLEMS/SOLUTlONS/COMHENTS
                                            80.4
                                                        80.4
                                                                               720    720
                                                                                            579
                          THE  CHEVRON  PACKING IN THE MIST ELIMINATOR FAILED  CAUSING  SOME  FGD SYSTEM
                          OUTAGE  TIME  DURING JUNE.

                          FAILURE  OF THE  CIRCULATION PUMPS ALSO CAUSED OUTAGE  TIME DURING  THE MONTH.

 7/80  SYSTEM      50.1         50.1         50.1        50.1                   744    744     373

       •• PROBLEMS/SOLUTIONS/COMMENTS

                          THE  FGD  SYSTEM  WAS DOWN FOR PART OF THE MONTH TO REPAIR  A  LEAK  IN THE  HIST
                          ELIMINATOR.   IT WAS ALSO DOWN TO REBUILD THE CHEVRON PACKING.
 S/60  SYSTEM      92.9         92.9         92.9        92.9                   744

       •• PROBLEMS/SOLDIlONS/COMPENTS

                         REPAIRS WERE  MADE  TO  THE  ESP DURING AUGUST.

 9/80  SYSTEM                                                                  720

       • * PROBLEMS/SOLUTIONS/COMMENTS

                         NO  INFORMATION  WAS  AVAILABLE FOR SEPTEMBER 19SO.
                                          744
                                                 691
                                                 92

-------
                                              EPA UTILITY FGO SURVEY: JULY -  SEPTEMBER  1980

                                           SECTION  3
              DESIGN  AND  PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICULATE EMISSION  LIMITATION - NG/J
SD2 EMISSION LIMITATION  -  NG/J
ATE
    INITIAL START-UP
    CONSTRUCTION  COMPLETION
    CONSTRUCTION  INITIATION
    CONTRACT  I.ARDED
    LETTER Of  1NTFNT SIGNED
    STARTED PRE.LIWINAY DESIGN

*•  FA3RIC  FILTER
    TYPE

»•  ESP
    SJM?ER
    SUPPLIER
    PARTICULATE DFSIGN REMOVAL EFFICIENCY
    FLUE  GAS  CAPACITY - CU.M/S
    FLUE  GAS  TEMPERATURE  -  C
    PRESSURE  DROP - KPA
    PARTICULATE OUTLET LOAD  -  G/CU."

•*  MECHANICAL COLLECTOR
    •4UM9ER
     TYPE
     SUPPLIER
     PARTICULATE DESIGN  REMOVAL  EFFICIENCY
- X
     DELMARVA POWER I LIGHT
     DELAWARE CITY
     3
     DELAWARE CITY
     DELAWARE
     E
- X
       180.0
        60.0
        60.0
     RILEY STOKER
     PULVERIZED COKE
     BASE
     10/56
       417.63
       215.6
       15?.
         6.1
                       .300 LB/MMRTU)
                      •««•* LB/MMBTU)
               ( 8850CO  ACFM)
               ( 420  F)
               < 500  FT)
               ( 20.C  FT)
     COKE
     FLUID PETROLEUM COKE
      32564.         ( 140CC  BTU/LB)
                     13500-14500
          .50
     .3-. 7
          .70
     5-8
         7.0C
SALEABLE PRODUCT
WET SCRUBBING
WELLMAN LORD
DAVY MCKEE
DAVY MCKEE
DAVY MCKEE
FULL SCALE
RETROFIT
   90.00
   90.00
 5/fcO
 5/80
 4/eo
 1/78
 9/77
 8/76
10/77
     NONE
JOY WESTERN
   95.0
  104.3
   54.4
           .69
     TUBULAR
     PRAT-DANIEL
  X      92.0
(  221000 ACFM)
<   130 F)
(«••»• IN-H20)
(    .30 6R/SCF)

-------
 EPA UTILITY  FGD SURVEY:  JULY  - SEPTEMBER 1980

DELNARVA POWER t LI6HT:  DELAWARE CITY 3 (CONT.)
 ** PARTICLE SCRUBBER
     DUMBER
     TYPE
     SUPPLIER
     NUMBER OF STAGES
     SHELL MATERIAL
     LINING MATERIAL
     NUM9ER OF N027LES
     TYPE OF NOZZLES
     33ILER LOAD/SCRUBBtR - X
     FLUE GAS CAPACITY - CU.M/S
     FLUE 6AS TEMPERATURE - C
     LIQUID RECIRCULATION RATE - LITER/S
     PRESSURE DROP - KPA
     PARTICULATE INLET LOAD - G/CU.M
     P«RTICULATE OUTLET LOAD - G/CU.M
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     502 INLET CONCENTRATION - PPM
     502 DESIGN REMOVAL EFFICIENCY  - X

 *• A3SOP3ER
     NUMBER
     TYPE
     INITIAL START UP
     SUPPLIER
     SUM3ER OF STAGES
     DIMENSIONS - FT
     SHELL MATERIAL
     SHELL LINER MITERIAL
     INTERNAL "IATEPIAL
     33ILER LOAD/APSORBER - X
     GAS FLOW - CU.M/S
     GAS TEMPERATURE - C
     LiauiD PECIRCULATION RATE - LITER/S
     PARTICULATE INLET LOAD - G/CU.H
     PARTICULATE OUTLET LOAD- G/CU.M
     PARTICULATE REMOVAL EFFICIENCY - X
     S02 INLET  CONCENTRATION - PPM
     S32 OUTLET CONTRATION  - PPM

 ••  CENTRIFUGE
     TYPE

 »•  FANS
     NUMBER
     CONSTRUCTION  MATERIALS
     SERVICE  -  rfET/DRY
     CAPACITY  - CU.M/S
     VENTURI
     AIRPOL
          1
     CARBON STEEL
     GLASS FLAKE,  AC 1C  BRICK,  CAROBRAX  BRICK
          1
     OPEN PIPE WITH  REFRAX  TIP
       100.0
       139.2         ( 295000 ACFH)
       215.6         (   460  F)
       315.0         < 5000  GPf)
     .......         <«**.«  IH-H20)
          3.2         (   1.39 GR/SCF)
          .6         <   .250 GR/SCF)
- X     81.5
      3503.000
          .0
     TRAY TOWER
      5/80
     DAVY MCKEE
         4
     20 X 20
     REINFORCED CONCRETE
     TILE
     316L SS
       100.0
       103.82
        54.4
        25.
          .2
          .2
          .0
      3500
       390
     NONE
         ( 220000 ACFM)
         <  130 F>
         (  400 6PM)
         (  .100 6R/SCF)
         (  .100 GR/SCF)
      3
     CARBON
     DRY
       139.21
STEEL
                                                                (  295000 ACFK)
•• VACUUM  FILTER
    TYPE

•* WIST ELIMINATOR
    NUMBER
    TYPE
    CONSTRUCTION  MATERIAL
    CONFIGURATION
    NUMBER OF STAGES
    NUMBER OF PASSES
    FREEBOARD DISTANCE  - M
    DEPTH - M
    riASH SYSTEM
    PRESSURE DROP - KPA

•• PROCESS CONTROL CHEMISTRY
    CONTROL VARIABLES
    CONTROL MANNER
    MODE
    SENSOR LOCATION
     NONE
     CHEVRON
     NORYL  PLASTIC
     HORIZONTAL
         1
         1
         1.83
         2.29
        < 6.0 FT)
        { 7.5 FT)
     INTERMITTENT  SPRAYS
          .1
                    (   .3 IN-M20)
    PH,  SOLIDS,  SP.G.,  CONC.
    AUTOMATIC
    FEEDBACK
    6AS  OUTLET,  SOLUTION  OUTLET
•* PUMPS
    SERVICE
                                                NUMBER
                                                94

-------
                                               EPA UTILITY FGO SURVEY: JULY - SEPTEMBER 1980

9ELM«RVA POWER & LIGHT:  DELAWARE  CITY  3  (CONT.)
 »• REHE'TER
     YUM9ER
     TYPE
     HEATING
     TEMPERATURE  BOOST  -  C

 »* THICKENER
     TYPE

 • • WATER  LOOP
     TYPE

 »* BYPRODUCTS
     BYPRODUCT  KATURE
     BYPRODUCT  8UANTITY - N  T/H
     BYPRODUCT  QUALITY  -  X
     DISPOSITION

 •• TREATMENT
     TYPE

 «• DISPOSAL
     NATURE
     TYPE
     HOT AIR  INJECTION
     FLUE GAS
         27.8         (
     NONE
      CLOSED
      SULFURIC  ACID
         11.3*
         93.0
      MARKETED
    50  F)
{  12.50 TPH)
      NEUTRALIZATION
      FINAL
      LINED POND
 .._	...	PERFORMANCE  DATA	 —	
 PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X R6.MOVAL   PER  BOILER  FGD   CAP.
                                                                  SO?  PART. HOURS HOURS  HOURS FACTOR
  5/bO  SYSTEM     100.0       100.0

        •• PROBLEMS/SOLUTIOVS/COMMENTS
100.0
             32.3
                                                                               7*4   240    240
                          THE FGD SYSTEM BEGAN  INITIAL AND  COMMERCIAL OPERATIONS ON MAY 22,  1980.
                          NO MAJOR PROBLEMS  WERE  ENCOUNTERED DURING STARTUP OR THROUGH THE REST  OF
                          THE MONTH.
        SYSTEM      86.4        86.4

        ** PROBLEMS/SOLUTIONS/COMMENTS
 86.4
             86.4
               720    720    622
                          REPAIRS WERE  MADE  TO  A  LEAK AND DAMAGED CHEVRON PACKING  IN  THE  MIST  ELIM-
                          INATOR DURING JUNE.
  7/80  SYSTEM      95.3         95.3

        •• PROBLEMS/SOLUTIONS/COMMENTS
 95.3
             95.3
               744   744    709
                           SOME  FGD  SYSTEM OUTAGE TIME DURING THE MONTH WAS  CAUSED  BY  LEAKS IN THE
                           MIST  ELIMINATOR THAT NEEDED REPAIR.

                           AN  ELECTRICAL FAILURE IN THE SHUTDOWN  INSTRUMENTATION  CAUSED THE FGD SYSTEM
                           TO  BE  OUT OF SERVICE PART OF THE MONTH.
  J/80  SYSTEM       73.3         7J.3

        ** PROBLEMS/SOLUTIONS/COMMENTS
 73.3
              73.3
               744   744    545
                           THE  FGD SYSTEM HAS OUT OF SERVICE  FOR  PART  OF  THE  MONTH TO REPAIR THE
                           PRESCRUBBER MIST ELIMINATOR.
  J/80   SYSTEM

         •*  PROBLEMS/SOLUTIONS/COMMENTS

                           NO INFORMATION WAS AVAILABLE  FOR  SEPTEMBER  1980.
                                    720
                                                   95

-------
  EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER
                                             SECTION 3
                DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
  COMPANY NAME
  PLANT  NME
  JNIT NUMBER
  CITY
  STATE
  3ROSS  UNIT  GENERATING CAPACITY - Mw
  1ET  UNIT  GENERATING CAPACITY W/FGD - M*
  EQUIVALENT  SCRUBBED CAPACITY - *H

  •*  FUEL DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE HEAT CONTENT - J/G
      AVERAGE ASH CONTENT - X
      AVERAGE MOISTURE CONTENT - X
      AVERAGE SULFUR CONTENT - X
      AVERAGE CHLORIDE CONTENT - X

  »*  GENERAL  EMISSION CONTROL SYSTEM DATA
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM  SUPPLIER
      NEW/RETROFIT
      ENERGY  CONSUMPTION - X
      INITIAL START-UP DATE
      COMMERCIAL  START-UP DATE
      S02 DESIGN  REMOVAL EFFICIENCY - X
      PARTICULATE  DESIGN REMOVAL EFFICIENCY
      ABSORBER SPARE CAPACITY INDEX - X
      A3SORBER SPARF COMPONENTS  INDEX

  •• WATER  LOOP
      TYPE
      FRESH MAKE-UP  WATER -  LITER/S

  »• TREATMENT
      TYPE

  •• DISPOSAL
      TYPE
                                           OUOUESNE LIGHT
                                           ELRAMA
                                           1-4
                                           ELRAMA
                                           PENNSYLVANIA
                                             510.C
                                             475.0
                                             510.0
                                                          ( 11350 BTU/LB)
                                COAL

                                 2640J.
                                   21.00

                                   2.2C
                                           WET  SCRUBBING
                                           LIME
                                           CHEMICO  DIVISION,  ENVIROTECH
                                           RETROFIT
                                               1.5
                                           10/75
                                           10/75
                                             83.00
                                             99.00
                                             25.0
                                               1.0
                                          OPEN
                                                                 CPU)
                                          POZ-0-TEC
                                                 LANDFILL
	..	_—PERFORMANCE DATA — —
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                                                 t REMOVAL   PER   BOILER   F60    CAP
                                                                 502  PART. HOURS  HOURS   HOURS FACTOR
12J79





101
201
301
401
501
SYSTEM
103.0
100.0
100.0
88.1
100.0
100.0
51.6
90.9
100.0
6?. 6
100.0
100,0
1C?.0
100.0
96.1
86.4
100.0
10P.O
48.5
85.5
100.0
64.5
100.0
98.7





744 700 734
 1/8"
 2/80
          PROBLEMS/SOLUTIONS/COMMENTS
101
201
301
401
sm
SYSTEM
       201
 95. B
 87.1
 84.6
 86.4
100.0
100.0

100.0
100.0
                         THERE  WERE  NO  SCRUBBER-RELATED OUTAGES DURING THE SEPTEMBER THROUGH
                         DECEMBER PERIOD.

                         A NEW  S02 MONITOR,  WHICH  WAS INSTALLED IN OCTOBER,  HAS PLUGGED ONLY  OUCE
                         SINCE  INSTALLATION  AND  HAS  REQUIRED ONLY FOUR HOURS OF MAINTENANCE PER
                         WEEK.
 91.2
100.0
10P.O
 55.6
100.0
130.0

 85.4
100.0
 94.8
 87.1
 84.6
 77.1
100.0
100.0

100.0
105.0
 75.2
 87.1
 84.6
 45.8
100.0
 98.2

 6C.5
 96.6
                                                                              744   613
                                                                                            528
                                                96

-------
                                               EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER  1980
DJQUESKE LIGHT: ELRANA 1-4  (CONT.)
...	.	PERFORMANCE DATA	
PERIOD NODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   F60    CAP.
                                                                 SO?  PART. HOURS HOURS   HOURS  FACTOR
301
(.01
501
SYSTEM
100.0
100.0
77.6
100.0
100.0
100. 0
56.8
100.0
100.0
100.0
64.0
100.0
10C.O
70.7
40.2
92.0


696


493


427
          PROBLEMS/SOLUTIONS/COMMENTS
                          THE  NEW  S02 MONITOR IS STILL OPERATING WELL  AND  HAS  LOGGED  SIX MONTHS OF
                          OPERATION.

                          THE  HIGH AVAILABILITIES ARE DUE TO THE 5TH MODULE  BEING  A  TRUE SPARE.
                          AS  OF  FEBRUARY 1980 AND ARE STILL OPERATING  WITHOUT  ANY  MAJOR PROBLEMS.

                          THE  TWO  RUBBER LINED UORMEN RECYCLE PUMPS HAVE  NOW LOGGED  14,000 HOURS
 S/bO
101
201
331
431
501
SYSTE"
103.3

 73.7
100.0
 78.1
103.0
100.0
100.0
 73.7
 48.4
 7P.1
100.0
103.0
100.C
 73.7
100.0

100.0
100.0
100.0
 73.7
 48.4
 78.1
100.0
                                                                               744
                                                                                     744
                                                                                            595
           PROBLE*S/SOLUTIONS/COMMENTS
                          THE FGD SYSTEM WAS AVAILABLE  FOR  OPERATION  THE  ENTIRE MONTH OF MARCH.
131

301
431
501
SYSTEM
                    40.3
                    72.3
                    87.3
                   100.0
                   100.0
                    99.4
             72.3
             67.3
            130.D
            100.0
             99.4
             40.0
             72.3
             87.3
             100.0
             100.0
             100.0
             40.0
             72.3
             87.3
            100.0
            100.0
             99.4
                                                                               720    720
                                                                                             572
        ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING APRIL THF  1C1  AND  201  RECYCLE PUMP IMPELLERS HAD TO BE  REPLACED.
                          THIS CAUSED 8 HOURS  OF  OUTAGE TIME FOR THESE TWO MODULES.  NO  OTHER  FGD
                          SYSTEM OUTAGES OCCURRED.
  5/6r
101
2P1
        501
        SYSTEM
103.0
 40.1
 94.1
 90.3
 96.8
103. n
1CT.C
 37.1
 89.0
 71.2
 96.8
 9R.5
100.0
 3P.2
 93.8
 88.0
 9f .8
100.0
100.0
  37.1
  89.0
  71.2
  96.8
  98.5
                                                                               744
                                                                                      744
                                                                                             586
        •» PROaLEMS/SOLUTIOSS/COWENTS
                          CURHG "AY  THE  FGD  SYSTEM WAS AVAILABLE FOR OPERATION  THE  ENTIRE  MONTH.
 101

 JD1

 501
 SYSTEM
100.3
103."
100.0
    .0
100.0
100.0
  97.8
  96.7

 100.0
  98.6
 100.0
 100.0
 100.0
    .0
 100.0
  99.7
 100.0
  97.8
  96.7
    .0
 100.0
  98.6
                                                                                720
                                                                                      720
                                                                                             710  61.6
        *• PR08LEMS/SOLUTIONS/CCMMENTS
  7/80
 201
 301
 401
 501
 SYSTEM
 100.0
 100.0
  98.?
  75.8
  35.5
 10D.C
                          DURING  JUNE  MODULE  401 WAS CLEANED AND THE  CEILCOTE  LINER  WAS REPLACED.
                          THIS  IS THE  FIRST  TIME SINCE START UP  (APPROXIMATELY 17,000 OPERATING
                          HOURS)  THAT  ANY MODULE NEEDED RELINED.
  64.9
  91.1
  85.6
  75.8
  12.9
  82.6
 100.0
 100.0
  9".?
  75.8
  14.7
  97.7
  64.9
  91.1
  85.6
  75.8
  12.9
  82.6
                                                                                744   744
                                                                                             615  66.0
                                                  97

-------
 EPA UTILITY FSD SURVEY:  JULY  - SEPTEMBER  1980

BJ8UESNE LIGHT: ELR»1A  1-4  (CONT.)
.	. — .	.	._	.—..	PERFORMANCE DATA—	—	-—	——...
PERIOD MODULF AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILED  FED    CAP ~
                                                                 S03  PART. HOURS HOURS  HOURS FACTOR

       *• PROSLEMS/SOLUTIONS/COMMENTS
                         THE RELININ6  OF  MODULE  401  CONTINUED INTO PART OF JULY.
 3/80
101
201
351
401
531
SYSTEM
30.9
103.0
103.0
99.1
83.9
100.0
21.2
94.8
93.3
99.1
£2.5
97.7
23.5
100. C
100. 0
99.1
E3.7
1CO.O
21.2
94.8
93.3
99.1
82. 5
97.7
                                                                              744
                                                                                    744
                                                                                           727  65.0
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE RELINING WITH  CEILCOTE  OK  MODULE  501  COMMENCED IN JULY AND CONTINUED
                         FOR APPROXIMATELY  120  HOURS IN  AUGUST.

                         THE RELININ6 OF MODULF  101  WITH CEILCOTE  STARTED IN AUGUST ACCOUNTING
                         FOR THE LOW AVAILABILITY  DURING THE MONTH.

 »/8f»  SYSTEM                                                                 720

       *•  PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION FOR THE MONTH OF SEPTEMBER  IS  NOT  AVAILABLE AT THIS TIME.
                                                98

-------
                                              EPA UTILITY  FGO  SURVEY: JULY - SEPTEMBER 1980

                                           SECTION  3
               DESIGN  AND PERFORMANCE DATA fOR OPERATIONAL  DOMESTIC  FGO SYSTEMS
COMPANY  NAME
PLANT  NAME
J1JT
CITY
STATE
SRGSS  UNIT  GENERATING CAPACITY - Mw
HET UNIT GENERATING CAPACITY U/FGD - My
EQUIVALENT  SCRUBBED CAPACITY - My

**  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT CONTENT - J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT - X
    AVERAGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT » Z

• *  GENERAL  EMISSION CONTROL SYSTEM DATA
    GENERAL PROCESS TYPE
    PROCESS TYPE
     SYSTEM  SUPPLIER
    NEH/RETROF1T
     ENERGY  CONSUMPTION  - X
     IVIT1AL START-UP DATE
     COMMERCIAL STIRT-UP DATE
     S32  DESIGN REMOVAL  EFFICIENCY  - X
     PART1CULATE DESIGN  REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX  - X
     ABSORBER SPARF COMPONENTS  INDEX

 •*  WATER LOOP
     TYPE
     FRESH MAKE-UP  HATER - LITER/S

 ••  TREATMENT
     TYPE

 • •  DISPOSAL
     TYPE
                         -  X
                                             ( 11535 BTU/LB)
                             DUQUESNE  LIGHT
                             PHILLIPS
                             1-6
                             SOUTH  HEIGHT
                             PENNSYLVANIA
                               408.0
                               373.0
                               4G8.0
                COAL
                BITUMINOUS
                 26830.
                    16.?7
                    5.02
                    1.92
                UET  SCRUBBING
                LIME
                CHEMICO  DIVISION, ENVIROTECH
                RETROFIT
                     3.4
                  7/73
                  6/74
                    83.00
                    99.00
                      .0
                      .0
                              OPEN
                                              (*•*»*  GPM)
                              POZ-0-TEC


                              LANDFILL
..	...	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION   t  REMOVAL   PER  BOILER  F6D   CAP.
                                                                  SO?   PART. HOURS HOURS  HOURS FACTOR
12/79




101
201
301
401
SYSTEM
.0
100. P
90.7
77.7
67.1
.0
99.6
89.6
72.9
65.3
.0
100.0
9T.6
76.6
66.8
.0
98.6
89.6
72.9
65.3




744 744 486
           PROBLEMS/SOLUTIONS/COMMENTS
 1/80   101
        201
        J01
        431
        SYSTEM
 2/80   101
        201
   .0
 95.1
100.0
 97.6
 73.9

 13.7
 91.6
                          PRESENTLY THE UTILITY HAS BEEN  ADDING SODIUM THIOSULfATE TO THE LIKE  TO
                          PREVENT SCALE FORMATION.  THIS  PROCESS HAS IMPROVED S02 COLLECTION  AS
                          WELL.

                          THE SCRUBBER FAN HOUSING LINERS ARE  BEING REPLACED.

                          THE MECHANICAL COLLECTORS ARE BEING  UPGRADED TO IMPROVE THE 8UAL1TY OF
                          THE WET SLUDGE.
  .0
93.3
99.0
95.8
72.0

13.7
91.6
   .0
 9P.O
10P.O
 97.5
 73.9

 13.7
 91.7
  .0
93.3
99.0
95.8
72.0

13.7
91.6
                                                                                744
                                                                                      744
                                                                                             536
                                                  99

-------
 EPA UTILITY  FGD SURVEY:  JULY  -  SEPTEMBER  1980

ttJQUFSNE LIGHT: PHILLIPS  1-6  (CONT.)
	PERFORMANCE DATA	
PERIOD MO&ULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                                              r REMOVAL   PER  BOILER   FGD    CAP.
                                              SO?  PART. HOURS HOURS  HOURS  FACTOR
       351
       O1
       SYSTEM
86.3
94.2
71.4
£4.6
90.5
70.1
86.0
94.C
71.4
84.6
90.5
70.1
696   696
                                                                                            468
       *• PROBLEMS/SOLUTIONS/COMMENTS
 5/B?
      SODIUM THIOSULFATE  ADDITION CONTINUED THROUGH THE FIRST QUARTER RESULTING
      IN A INCIDENCE  OF  SIGNIFICANTLY REDUCED HIST ELIMINATOR SCALING.  2000-
      5000 HOURS OF OPERATION  HAVE BEEN LOGGED WITHOUT MIST ELIMINATOR SCALE
      ACCUMULATION.   THE  UTILITY  REPORTED THAT S02 REMOVAL EFFICIENCY HAS
      IMPROVED 3X DUE  TO  THE  SODIUM THIOSULFATE ADDITION.  THE UTILITY IS  LOOKING
      INTO SODIUM THIOSULFATE  ADDITION AT ELR»MA.

      THE FAN RUBBER  LINERS  HAVE  BEEN A CONTINUAL PROBLEM.  TWO FANS WILL  BE
      REPLACED WITH INCONEL  THE  NEXT TIME THE RUBBER LINERS FAIL.

      THE PHILLIPS  FGD  SYSTEM  HAD A SYSTEM AVAILABILITY OF 71.81  FOR THE YEAR
      1979.

                                     84.0
                                     53.9
                                     4C.3
                                     95.3
                                     54.7                  744   744    407
101
2D1
301
401
SYSTEM
94.7
59. 0
4S.4
95.4
60.3
84.3
5T.9
4C.3
95.3
54.7
94.?
56.8
47.8
99.8
73.6
       «*  PROBLEMS/SOLUTIOSS/COWENTS
                         PROBLEMS WERE  ENCOUNTERED  WITH THE MODULE 101 ID FAN.
                         TAKEN OFF LINE  SO  THE  ID  FAN COULD BE BALANCED.
                                                              THE MODULE WAS
                         PROBLEMS WERE  ENCOUNTERED  WITH  THE  HUB BOLTS ON THE ID FAN OF MODULE  201,
                         CAUSING THE MODULE  TO  COME  OFF  LINE FOR 11 DAYS.

                         THE RUBBER LINING ON  THE  1C FAN HOUSING OF MODULE 301 NEEDED REPAIR  DURING
                         MARCH.

                         MODULE 401 WAS  TAKEN  OFF  LINE  FOR  APPROXIMATELY 2 HOURS SO REPAIRS COULD
                         BE MADE ON THE  SCRUBBER MAKE-UP VALVES.
 4/80  101
       201
       J01
       401
       SYSTEM
92.6
14.2
99.2
95. R
96.9
89.4
1P.O
99.0
94.6
73.3
92.4
10.5
99.f
98.6
75.6
89.4
10.0
99.0
94.6
73.3
                                                           720   720
                                                                        527
          PROBLEMS/SOLUTIONS/COMMENTS
                         ON APRIL 5 MODULE  101  WAS  TAKEN  OFF  LINE  DUE TO ID FAN BEARING PROBLEMS.
                         LATER IN THE "ONTH  THE  MODULE  WAS  SHUTDOWN DUE TO AN IB FAN INSTRUMENTATION
                         PRESSURE SWITCH PROBLEM.

                         TOWARDS THE LATTER  PART OF  APRILt  MODULE  2u1 WAS SHUTDOWN DUE TO ID  FAN
                         SEARING PROBLEMS.   THIS PROBLEM  WAS  CORRECTED BY BALANCING THE FAN.

                         MODULE 301 WAS REMOVED  FROM  OPERATION  ON  APRIL 11 DUE TO AN ID FAN MOTOP
                         MALFUNCTION.

                         THE RECYCLE PUMP PACKING ON  MODULE 401  NEEDED TO 8E REPLACED OUR1N6  THE
                         MONTH.
101
201
301
401
SYSTEM
67.5
81.6
91.7
92.2
83.2
53.9
69.0
77.1
75.9
6?.0
6?. 3
78.9
89.?
9^.6
60.2
                                                        53.9
                                                        69.0
                                                        7?.1
                                                        75.9
                                                        68.0
                                                           744   744
                                                                                           506
                                               100

-------
                                               EPA UTILITY  F6D  SURVEY: JULY - SEPTEMBER  1980
JUQUESNE LIGHT: PHILLIPS  1-6  (CONT.)
— _ — .	.	„___-	PERFORMANCE  OAT*	
PERIOD MODULE  AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER   FGD   CAP.
                                                                  S02  PART. HOURS HOURS   HOURS FACTOR


       »• PROBLEMS/SOLUTIONS/COMMENTS

                          NODULE 101 CAME OFF  LINE  IN MAY SO REPAIRS COULD BE MADE  ON  THE CONTROL
                          DAMPER AND TO INSTRUMENTATION.

                          DURING MAY MODULE  201  EXPERIENCED  PROBLEMS WITH THE MIST  ELIMINATOR AND
                          THE 10 FAN.  THE MODULE  WAS TAKEN  OFF LINE FOR  APPROXIMATELY TWO OAYS TO
                          WASH THE MISTELIMINATOR  INTERNALS  AND ONE DAY TO REPAIR THE  ID  FAN BEARING.

                          MODULE 301 EXPERIENCED  ID  FAN PROBLEMS AND WAS  TAKEN  OFF  LINE  WHILE THE
                          ID FAN WAS BALANCED.

                          MODULE 401 MAS  SHUTBOWN  APPROXIMATELY 58 HOURS  SO THAT  THE  10  FAN CONTROL
                          DAMPERS COULD BE INSPECTED.
  6/6"
101
201
3D1
401
SYSTEM
 97.1
100.0
 75.5
100.0
 93.2
8C.5
76.2
64.8
71.4
7?.2
 96.5
100.0
 72.6
100.0
 91.5
80.5
76. 2
64.8
71.4
73.2
                                                                                720   720
                                                                                             527  55.3
        •*  PROBLEMS/SOLUTIOtS/COMMENTS
                          THE MODULE  101  MIST ELIMINATOR WAS CLEANED  DURING JUNE.
  7/80
1C1
231
331
431
SYSTEM
 94.0
100.0
 94.7
 91.1
 94.9
86.3
94.7
84.1
85.5
87.1
 93.5
100.0
 94.0
 90.?
 94.5
86.2
94.7
84.1
83.5
87.1
                                                                                744
                                                                                      744
                                                                                              648   71.4
        •* PROBLEMS/SOLUTIONS/COMMENTS
                           DURING  JULY THE RECYCLE PUMP  IMPELLERS  WERE REPLACED ON ALL THE  NODULES
                           EXCEPT  FOR  MODULE 2"1.
  J/B;
1D1
251
301
401
SYSTE"
 91.1
 96.9
 87.6
 92.3
 92. C
 72.9
 85.8
 85.J
 86.1
 82.5
 90.6
 96.5
 89.6
 91.8
 91.5
72.9
85.8
85.5
86.1
82.5
                                                                                744
                                                                                       744
                                                                                              614   58.5
        *• PROBLEMS/SOLUTIONS/COMMENTS
                           DURING AUGUST MODULE 401  EXPERIENCED PACKING PROBLEMS WITH  THE  RECYCLE
                           PUMP.

                           DURING THE PERIOD OF JUNE  THROUGH AUGUST THE RUBBER  LININGS ON  THE FAN
                           HOUSINGS WERE REPAIRED.

  9/60   SYSTEM                                                                   720

         *•  PROBLEMS/SOLUTIONS/COMMENTS

                           INFORMATION  FOR  THE  MONTH OF SEPTEMBER IS NOT  AVAILABLE  AT  THIS TIME.
                                                  101

-------
  EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  F6D  SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  JNJT  NUM3ER
  CITY
  STATE
  SROSS  UNIT  GENERATING CAPACITY - MW
  tET JN1T  GENERATING CAPACITY U/FGD - MW
  EBUIVALENT  SCRUBBED CAPACITY - MW

  *• FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE  CONTENT - X
     AVERAGE SULFUP  CONTENT - X
     AVERAGE CHLORIDE  CONTENT - X

  • « GENERAL  EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM  SUPPLIER
     SEW/RETROFIT
     ENERGY  CONSUMPTION  - X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP DATE
     502 DESIGN RE"OVAL  EFFICIENCY - X
     PARTICULATE DFSIGN  REMOVAL EFFICIENCY
     A9SORBER SPARE  CAPACITY INDEX - X
     ABSORBER SPARE  COMPONENTS  INDEX

  •• WATER  LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

  •• TREATMENT
     TYPE
                   -  X
                        INDIANAPOLIS POKER & LIGHT
                        PETERSBURG
                        3
                        PETERSBURG
                        INDIANA
                          532.3
                          515.0
                          532.3
                                       ( 10750 BTU/LB)
COAL
BITUMINOUS
 25004.
                            3.25
WET SCRUBBING
LIMESTONE
AIR CORRECTION DIVISION, UOP
NEW
    2.4
12/77
12/77
   85.00
   99.30
     .0
     .0
                        CLOSED
                           55.6
                                                 POZ-0-TEC
                                       (  682 GPM)
    DISPOSAL
     TYPE
                                                 LANDFILL
..	_.	.	.	PERFORMANCE DATA-	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION
                                                                 X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR
 1/8C'  SYSTEM

 2/80  SYSTEM

 S/bO  SYSTEM

       •• PROBLEMS/SOLUTIONS/COMMENTS
                                                     744

                                                     696

                                                     744
 t/80  SYSTE"

 5/80  SYSTEM

 i/80  SYSTEM
DURING THE FIRST QUARTER OF  1980,  THE  ENTIRE  SCRUBBER PACKING BED WAS LOST
DUE TO EXCESSIVE WEAR OF THE  NEOPRENE  FOAM  PACKING BALLS.  THE UNIT
WILL BE TAKEN OFF LINE IN  APRIL  TO ACCOMOOATE NECESSARY REPAIRS AND
REPLACEMENT OF THE HALLS.

BYPASS DAMPER FAILURES ALSO  OCCURRED  AND  ARE  REPORTED TO BE A CONTINUAL
PROBLEM.  MODIFICATIONS WERE  MADE  TO  THE  GULLOTINE TYPE DAMPERS DURING
THE PERIOD.

                                                     7?0

                                                     744

                                                     730
                                                102

-------
                                               EPA UTILITY F6D SURVEY:  JULY  - SEPTEMBER 1980

IVD1ANIPOLIS POWER K LIGHT:  PETERSBURG  3 (CONT.)
....	PERFORMANCE DATA	- ————
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   1  REMOVAL    PER  BOILER  F6t>   CAP.
                                                                  502   PART.  HOURS HOURS  HOURS FACTOR


       •* PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION UAS AVAILABLE FOR THE  PERI06  APRIL  1980 THROUGH JUNE
                          1980.

 7/80  SYSTEM                                                                  744

 3/80  SYSTEM                                                                  744

 9/80  SYSTEM                                                                  7ZO

       •• PROBLfcMS/SOLUTIONS/CONMENTS

                          THE OPERATIONAL DATA FOR THE THIRD  QUARTER  19SC MERE NOT AVAILABLE  FOR
                          PUBLICATION.
                                                  103

-------
  EPA  JTUITY FGO SURVEY: JULY - SEPTEMBER  1980

                                             SECTION  3
                DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC FGO SYSTEMS
  COMPANY  NAME
  PLANT  NAUE
  JN1T  NUM3ER
  CITY
  STATE
  SROSS  UNIT  GENERATING CAPACITY - MW
  YET UNIT  GENERATING CAPACITY W/FGD - MW
  EQUIVALENT  SCRUBBED CAPACITY - r*l
     KANSAS  CITY  POWER  R  LIGHT
     HAWTHORN
     3
     KANSAS  CITY
     MISSOURI
        90.0
        E5.0
        90.0
  »•  FUEL  DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE HEAT  CONTENT - J/G
      AVERAGE ASH  CONTENT - X
      AVERAGE MOISTURE  CONTENT - X
      AVERAGE SULFUR  CONTENT - I
      AVERAGE CHLORIDE  CONTENT - X

  «*  GENERAL EMISSION CONTROL SYSTEM DATA
      SENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      ...	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION  * REMOVAL    PER   BOILER  FGO   CAP.
                                                                 S02   PART.  HOURS  HOURS  HOURS FACTOR
ID/79
11/79
12/79
1 /bO
2/80
5/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.
100.
100.
10P.
ior.
100.
0
0
0
0
0
0
91
38
91
93
100
100
.0
.1
.9
.0
.0
.0
74*
720
744
744
696
744
677
274
684
692
696
744
677
274
684
692
696
744
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE  FGD  SYSTEM  WAS  AVAILABLE 1 COX OF THE TIKE THE BOILER  OPERATED.   NO
                         PROBLEMS  WERE ENCOUNTERED.
 4/80  SYSTE"

 5/60  SYSTEM

 4/80  SYSTEM
            68.0

            60.0

            66.0
                             720

                             744

                             720
490

446

475
                                                104

-------
                                               EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

KANSAS CITY POWER * LIGHT:  HAWTHORN  3  (CONT.)
	PERFORMANCE DATA	
PERIOD NODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION   X  REMOVAL    PER  BOILER  F6D   CAP.
                                                                  SO?   PART.  HOURS HOURS  HOURS FACTOR


       *• PROBLEIS/SOLUTICm/CONMENTS

                          THE  UNIT 3 BOILER EXPERIENCED SUPERHEATER AND  ECONOMIZER LEAKS DURIN6 THE
                          APRIL-JUNE PERIOD ACCOUNTING FOR THE LOW  SCRUBBER  UTILIZATION FIGURES.

 7/80  SYSTEM                  100.0                    65.0                   744   484    484  45.0

       ** PROBLENS/SOLUTIONS/COMWENTS

                          THE  OUTAGE TIME DURING JULY HAS  CAUSED  BY BOILER  TUBE LEAKS.  NO FGD-
                          RELATED PROBLEMS WERE ENCOUNTERED.

 3/80  SYSTEM                                                                  744   64Z         49.4

       •• PROBLEIS/SOLUTIONS/COM^ENTS

                          THE  UTILITY REPORTED THAT THE  F6D  SYSTEM  IS NOW CERTIFIED, THEREFORE  THE
                          SCRUBBER OPERATING HOURS ARE NO  LONGER  RECORDED.

                          THE  FGD SYSTEM WAS SHUT  DOWN FOR 10 HOURS DURING  AUGUST TO REPAIR  REHEATER
                          TUBE LEAKS.

 ?/bC  SYSTEM                                                                  720   248          13.9

       ••  PKOBLEMS/SOLUTIONS/COMMENTS

                          DURING  SEPTEMBER BOILER  OPERATION  WAS  LIMITED DUE  TO  A  SCHEDULED  OVERHAUL.

                          DURING  THE  MONTH 67  HOURS OF SCRUBBER  OUTAGE TIME  WERE  DUE  TO  REQUIRED
                          CLEANING  OF THE  SCRUBBER MODULES.
                                                  105

-------
  EPA  UTILITY FED SURVEY: JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FED  SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  UNIT  NUMBER
  CITY
  STATE
  SROSS  UNIT GENERATING CAPACITY - MU
  NET UNIT  GENERATING CAPACITY W/FGD - MU
  EQUIVALENT SCRUBBED CAPACITY - MU
KANSAS CITY POWER  (  LIGHT
HAWTHORN
4
KANSAS CITY
MISSOURI
   90.0
   65.0
   90.0
  *•  FUEL  DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE HEAT  CONTENT - J/G
      AVERAGE ASH CONTENT  - X
      AVERAGE MOISTURE  CONTENT - X
      AVERAGE SULFUR  CONTENT - X
      AVERAGE CHLORIDE  CONTENT - X

  ••  GENERAL EMISSION CONTROL SYSTEM DATA
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - X
      INITIAL START-UP  DATE
      COMMERCIAL START-UP  DATE
      S02  DESIGN REMOVAL  EFFICIENCY  - X
      PARTICULATE DESIGN  REMOVAL EFFICIENCY
      ABSORBER SPARE  CAPACITY INDEX  - X
      ABSORBER SPARE  COMPONENTS  INDEX
               (  9800 BTU/LB)
COAL
BITUMINOUS
 22795.
   11.00

     .60
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
    2.2
 8/7?
** / **
   70.00
   99.00
     .0
     .0
 •• WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER  -  LITER/S
CLOSED
                                                                (**•»• GPM)
 •* TREATMENT
     TYPE
                                                 FLYASH STABILIZATION
 •• DISPOSAL
     TYPE
                                                 POND
	..	PERFORMANCE DATA	—	——-——	____
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  x REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR
13/79
11/79
12/79
1/80
2/60
3/80
SYSTEM 100.0
SYSTEM 10C.O
SYSTEM 100.0
SYSTEM
SYSTEM
SYSTEM
91.0
38.1
91.9
.0
.0
.0
744
720
744
744
696
744
677
274
684
0
0
0
677
274
684
0
0
0



.0
.0
.0
       *• PROBLEMS/SOLUTIONS/COMMENTS
                         THE UNIT REMAINED OFF  LINE  THROUGH  THE  FIRST QUARTER OF 1980 BECAUSE OF A
                         TURBINE GENERATOR OVERHAUL.
 4/80  SYSTEM

       *• PROBLEMS/SOLUTIONS/CONMENTS
       65.0
                             720
                                          468
                         LOW APRIL SCRUBBER UTILIZATION  FIGURES  OCCURRED BECAUSE  THE BOILER WAS OUT
                         OF SERVICE FOR SCHEDULED MAINTENANCE  DURING  PART OF THE  MONTH.
 S/80  SYSTEM

 4/80  SYSTEM
       90.1

       98.1
                             744

                             720
670

706
                                                106

-------
                                               EPA UTILITY  F6D  SURVEY:  JULT - SEPTEMBER 1980

KANSAS CITY POWER « LIGHT:  HAWTHORN  4 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE  AVAILABILITY  OPERABILITY RFLIAPILITY UTILIZATION   X  REMOVAL   PER  BOILER  F6D    CAP.
                                                                  503   PART. HOURS HOURS  HOURS  FACTOR


       •*  PR03LE1S/SOLUTIONS/COHMENTS

                          THE UTILITY REPORTED THAT NO  UNUSUAL FGB  SYSTEM PROBLEMS OCCURRED  DURIN6
                          MAY AND JUNE.

 7/BO  SYSTEM                  10r.O                     78.C                   744   580     580   55.0

       **  PROBLEMS/SOLUTIONS/COMMENTS

                          NECESSARY REPAIRS TO THE GENERATOR  COLLECTOR RING CAUSED SYSTEM OUTA6E
                          TIME DURING JULY.

                          A  53 HOUR OUTAGF WAS DUE TO  THE  REPLACIN6 OF THE UNDER BED  SPRAY  HEADERS
                          ON THE 4A MODULE.   THIS  UAS  THE  ONLY FGD-RELATED PROBLEM DURING  JULY.

 3/80  SYSTEM                                                                  744    569          47.4

       •*  PROBLEMS/SOLUTIONS/COMMENTS

                          THE UTILITY REPORTED THAT  THE FGD  SYSTEW IS SOW  CERTIFIED.  THEREFORE  THE
                          SCRUBBER OPERATING  HOURS ARE NO  LONGER RECORDED.

                          DURING AUGUST  APPROXIMATELY  66 HOURS WERE NECESSARY TO PERFORM GENERAL
                          MAINTENANCE ON  THE  SYSTEM.

 J/B"   SYSTEM                                                                  720    111           9.4

        **  PROBLE»S/SOLUTIONS/COHMENTS

                          LOW BOILER  UTILIZATION  DURING SEPTEMBER WAS DUE  TO  A  LACK  OF DEMAND.

                          NO  FGD SYSTEM  PROBLEMS  WERE  REPORTED FOR THE MONTH  OF SEPTEMBER.
                                                  107

-------
  EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  198C

                                             SECTION  3
                DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL  DOMESTIC  FGD SYSTEMS
  COMPANY  NAMF
  PLANT  NAME
  JN1T  NUMBER
  CITY
  STATE
  SROSS  UNIT  GENERATING CAPACITY - MW
  »ET UNIT  GENERATING CAPACITY W/FGD -
  EQUIVALENT  SCRUBBED CAPACITY - MW
                              KANSAS CITY POWER 8  LIGHT
                              LA CYGNE
                              1
                              LA CYGNE
                              KANSAS
                                820.0
                                820.0
                                sza.o
  »*  FUEL  DATA
      FUEL  TYPE
      FUEL  GRADE
      AVERAGE HEAT  CONTENT - J/G
      AVERAGE ASH CONTENT  - X
      AVERAGE MOISTURE  CONTENT - X
      AVERAGE SULFUR  CONTENT - X
      AVERAGE CHLORIDE  CONTENT - X

  **  GENERAL EMISSION CONTROL SYSTEM DATA
      GENERAL PROCESS TYPE
      PROCESS TYPE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION  - i
      INITIAL START-UP  DATE
      COMMERCIAL START-UP  DATE
      S02 DESIGN REMOVAL  EFFICIENCY - X
      PARTICULAR DESIGN  REMOVAL EFFICIENCY
      ABSORBER SPARF  CAPACITY INDEX - X
      ABSORBER SPARE  COMPONENTS INDEX
                         - X
                              COAL
                              SUBDITUMINOUS
                               2191}.
                                 24.36
                                  ?.60
                                  5.39
                                   .03
                  WET SCRUBBING
                  LIMESTONE
                  BABCOCK K WILCOX
                  NEW
                      2.9
                   2/73
                   6/73
                     80.00
                     99.50
                       .0
                                 <  9*21 BTU/LB)
 •• WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER  -  LITER/S
                              CLOSED
                                 72.3
                                             ( 1148 EPPO
    DISPOSAL
     TYPE
                              UNLINED POND
	PERFORMANCE DATA	
»ERIO» MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                              X REMOVAL   PER  BOILER   F6D    CAP.
                                              S02  PART. HOURS HOURS   HOURS  FACTOR
12/79  SYSTEM         -0

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                       .0
                                                           744
                                                                                .0
                          THE  BOILER  WENT  DOWN FOR AN OVERHAUL ON OCTOBER  19  AND  WAS  OUT  OF  SERVICE
                          THROUGH  DECEMBER.
                          EXTENSIVE  MAINTENANCE  WORK BEGAN ON THE FGD SYSTEM  LATE  IN  OCTOBER  CAUSING
                          THE  SYSTEM  TO  BE  UNAVAILABLE DURING NOVEMPI.R AND DECEMBER.   SOME  ITEMS
                          INCLUDED  IN THE MAINTENANCE bERE:
                              THE  INSTALLATION OF TWO NEW SPRAY HEADERS  IN SIX OF  THE  MODULES,  RE-
                              PLACEMENT  OF  THE ABSORBER SIOEWALLS, R&PLACEMENT OF  THE  MODULE  OUTLET
                              DUCTS  AND  DAMPERS,  AND VARIOUS DUCTWORK PATCHING.
 1/80  SYSTEM         .0

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                       .0
                                                           744
                                                                                .0
                         THE BOILER  AND  FGD  SYSTEM REMAINED UNAVAILABLE DURING JANUARY  DUE  TO  THE
                         ON-GOING GENERATOR/TURBINE OVERHAUL AND THE EXTENSIVE FGD  SYSTEM MOD-
                         IFICATIONS  BEING  PERFORMED.
 2/60  A
       B
       C
       D
       E
       F
98.2
98.2
97.4
99.1
98.2
99.1
84.1
58.3
66.2
45.9
93.0
91.7
95.7
92.9
89.7
92.3
97.3
97.3
2P.O
13.2
14.9
10.3
21.0
20.7
                                                108

-------
                                               EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980
KANSAS CITY POWER *  LIGHT:  LA  CYCNE  1  (CONT.)
	.	PERFORMANCE DATA	—	—	—-——— — —
PERIOD MODULE  AVAILABILITY  OPERABlLITt RELIABILITY UTILIZATION   *  REMOVAL   PER  BOILER  F6D   CAP.
                                                                  S02  PART. HOURS HOURS  HOURS  FACTOR
6 99.1 91.7 97.3 20.7
H 99.6 92.4 97.J 20.8
SYSTEM 98.6 77.7 95.3 17.5


696


157


122


10.9
        **  PROBLEMS/SOLUTIONS/COMMENTS
 3/80
THE TURBINE/GENERATOR  OVERHAUL  WAS COMPLETED IN FEBRUARY AND  THE  BOILER
AND F6D SYSTEM RETURNED  TO  SERVICE ON FEBRUARY 20.  THE FGD SYSTEM  VAS
AVAILABLE FOR OPERATION  MOST  OF THE MONTH.

                                4.3
                                4.3
                                4.3
                                4.3
                                4.0
                                2.3
                                1.3
                                 .0
                                3.1                  744     32     23
A
B
C
D
f.
f
G
H
SYSTE"
94.6
96.2
96.1
96.1
95.8
94.7
93.3
95.7
95.3
100.0
100.0
10C.O
100.0
9?. 8
53.1
31.3
.0
72.3
100.0
100.0
100.0
100.0
100.0
100.0
100.0

100.0
                                                                                                   1.7
        • *  PROBLEMS/SOLUTIONS/COMMENTS
                          THE FGD SYSTEM  HAS  OPERATED FOR ONLY 23 HOURS IN MARCH  AS  A  RESULT OF
                          GENERATOR/TURBINE PROBLEMS.  SOME ROUTINE CLEANING  AND  INSPECTIONS OF THE
                          FGD SYSTEM WERE  PERFORMED DURING THE OUTAGE TIME.
4/80








5/80








i/80








A
B
C
D
e
F
G
H
SYSTEM
A
B
C
D
E
F
G
H
SYSTEM
A
B
C
D
E
F
G
H
SYSTEM
96.3
95.1
95.0
96.7
95.3
92.5
97.0
97.0
95.6
96.4
94.6
95.7
95.9
96.1
96.5
96.1
96.8
96.0
98.2
9S.1
97.4
98.1
98.1
98.3
98.8
99.3
98.1
** PROBLEMS/SOLUT

7/80









A
a
c
D
E
F
G
H
SYSTEM

89.7
97.8
97.3
98.1
98.2
96.6
98.1
97.7
96.9
94.1
78.4
97.5
93.6
86.0
76.3
68.4
62.9
82.2
89.4
87.9
88.3
83.9
84.4
89.3
96.0
82.3
87.7
69.5
9C.3
96.8
92.5
87.6
91.1
88.2
87.3
90.4
IONS/COMMENTS
MO MAJOR FGD
86.9
97.6
96.9
98. 0
97.6
9?. 6
97.9
96.9
96.3
94.5
91.4
92.9
94.8
92.3
87.2
93.9
93.4
92.6
96.0
93.9
95.2
95.1
95.3
96.2
94.Q
96.2
95.5
97.2
96.8
96.7
9P.C
97.9
98.5
97.3
98.6
98.9

RELATED PROBLEMS
87.1
97.3
96.6
97.7
97.8
98.3
97.6
97.1
96.2
61.7
51.4
63.9
61.4
56.4
5C.O
44.9
41.3
53.9
84.1
82.7
83.1
78.9
79.4
84.0
90.3
77.4
82.5
46.0
46.4
49.7
47.5
45.0
46.8
45.3
44.9
4t.4

WERE
69.9
7R.5
77.9
7F.8
7P.4
79.3
78.7
77.9
77.4
                                                                                720
                                                                                      472
                                                                                             388  37.6
                                                                                744
                                                                                      700
                                                                                             614   49.9
                                                                                720   37C
                                                                                              334   35.5
                                                               REPORTED FOR THE SECOND  QUARTER  OF  1980,
                                                                                 744
                                                                                       598
                                                                                              576  60.9
                                                  109

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

KANSAS CITY POWER t LIGHT: LA CYGNE 1 (CONT.)
.	».——	....	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
                                              X  REMOVAL   PER   BOILER  FGD   CAP.
                                              S02   PART.  HOURS  HOURS   HOURS FACTOR
 9/80
       •• PROBLEMS/SOLUTIONS/COMMENTS

                         NO MAJOR FGD-RELATED PROBLEMS HERE  REPORTED  FOR  JULY.
 S/80  A
       C
       D
       E
       F
       e
       H
       SYSTEM
94.6
97.9
98.1
97.7
97.2
98.7
97.6
97.3
97.4
92.7
97.3
97.3
96.8
96.2
97.2
96.9
96.4
96.4
93.9
97.2
97.3
97.4
96.7
98.1
96.7
96.3
96.7
66.9
70.3
70.3
69.9
69. 5
70.2
69.9
69.6
69.6
                                                                              744    537
                                                                                           518   54.7
       ••  PROBLEMS/SOLUTIONS/COMMENTS
                         THE UTILITY REPORTED THAT NO MAJOR PROBLEMS HERE ENCOUNTERED DURING  THE
                         MONTH OF AUGUST.
       A
       B
       C
       D
       E
       F
       6
       H
       SYSTEM
98.9
98.6
97.8
94.9
98.6
99.2
99.2
98.8
98.2
90.4
91.1
90.7
84.8
91.1
93.0
93.0
90.2
90.7
98.0
97.5
96.0
90.8
97.5
98.5
98.5
97.7
97.0
53.9
54.3
54.0
50.6
54.3
55.4
55.4
53.8
54.0
                                                                             720   429    389   43.3
          PROBLEKS/SOLUTIONS/COMMENTS
                         THE  FGD SYSTEM UAS TAKEN OFF LINE SEVERAL TIMES FOR A TOTAL OF 118 HOURS
                         BECAUSE OF BOILER  TUBE LEAKS.

                         THE  BOILER WENT DOUN ON SEPTEMBER 27, 1980 FOR A SCHEDULED MAINTENANCE
                         OVERHAUL.   THE FGD SYSTEM VAS AVAILABLE DURING THIS TINE.
                                               110

-------
                                              EPA  UTILITY FGO SURVEY: JULY - SEPTEMBER 19&0

                                           SECTION J
              DESIGN AND PERFORMANCE  DAT*  FOR  OPERATIONAL DOMESTIC F6D  SYSTEMS
         NAME
 PLANT  NAME
 JNIT NUM3ER
 CITY
 STATE
 SROSS  UNIT GENERATING  CAPACITY  -  MW
 »ET UNIT GENERATING  CAPACITY  W/FGD  - MW
 EQUIVALENT SCRUBBED  CAPACITY  -  My

 • •  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT -  J/6
    AVERAGE ASH CONTENT  - X
    AVERAGE MOISTURE CONTENT  -  I
    AVERAGE SULFUR CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  t

 »•  GENERAL  EMISSION  CONTROL SYSTEM  DATA
    6ENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    IHITIAL START-UP DATE
    COMMERCIAL  START-UP  DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE  DESIGN REMOVAL  EFFICIENCY
    A9SORBER  SPARE CAPACITY INDEX - X
    ABSORBER  SPARE COMPONENTS INDEX

 ..  WATER LOOP
     TYPE
     FRESH MAKE-UP WATER  - LITER/&

 •*  DISPOSAL
     TYPE
            - X
                 KANSAS PO*ER t LIGHT
                 JEFFREY
                 1
                 MANEGO
                 KANSAS
                   720.0
                   660.0
                   540.0
                                (  8125 BTU/LB)
COAL

 18899.
    5.80
   28.00
     .32
     .01
                 WET SCRUBBING
                 LIMESTONE
                 COMBUSTION ENGINEERING
                 NEW
 8/78
**/ **
   80.00
   99.00
   20.0
    1.0
                 CLOSED
                     35.1
                                                POND
                                    S&7  GPMJ
	—	PERFORMANCE DATA	—	-——_———.	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   X  REMOVAL    PER  BOILER  fGD   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 Z/80  SYSTEM

 5/gO  SYSTEM     100.0       100.0

       •* PROBLEMS/SOLUTIONS/COMMENTS
            100.0
                         67.7
                              744

                              696

                              744
504
                                                            504
                         THE BOILER  WENT  OFF  LINE  FOR TEN DAYS IN MARCH FOR A SCHEDULED INSPECTION.
                         DURING THE  BOILER  OUTAGE  GENERAL MAINTENANCE HAS PERFORMED ON THE FGD
                         SYSTEM.  OTHER THAN  THIS  OUTAGE, THE FGD UMIT OPERATED 100X OF THE TIME
                         IN MARCH.
k/80 SYSTEM
5/80 SYSTEM
6/80 SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
                                                                              720

                                                                              744

                                                                              720
                                                     720

                                                     744

                                                     720
                                           720

                                           744

                                           720
        • * PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THE  APRIL  THROUGH JUNE PERIOD THE F6» SYSTEM OPERATED 100X OF THE
                          TIME.
 7/80   SYSTEM
                   100.0
100.0
            100.0
                                                        69.1
                                                                              744
                                                      S14
                                            514   49.3
                                                111

-------
 EPA UTILITY FGO SURVEY:  JULY  - SEPTEMBER 19?0

   CAP.
                                                                 SOZ   PART.  HOURS  HOURS   HOURS FACTOR


       ** PRDBLEMS/SOLUTIONS/COMHENTS

                         DURING  JULY A  230 HOUR OUTAGE OCCURRED DUE TO A REHEATER  TUBE LEAK  IN
                         THE BOILER.  NO FGD-RELATED PROBLEMS OCCURRED DURING  THE  MONTH.

 S/89  SYSTE1     100.0        1CP.O        100.0        84.8                  711    631     631  42.8

       *» PROBLE"S/SOLUTIONS/COMMENTS

                         THE F6D  SYSTEM  WAS TAKEN OUT OF SERVICE FOR  PART OF AUGUST  SO REPAIRS
                         COULD BE  CONDUCTED ON A BOILER REHEAT TUBE.

 9/80  SYSTE*     100.0        10P.O        100.0       100.0                  720    720     720  67.7

       •* PROBLEflS/SOLUTIONS/COMHENTS

                         NO PROBLEMS WITH  THE  BOILER OR THE FGD SYSTEM WERE  ENCOUNTERED  DURING
                         SEPTEMBER.
                                               11?

-------
                                              EPA UTILITY  F60 SURVEY: JUtY -  SEPTEMBER  1980

                                           SECTION  3
              DESIGN  AND  PERFORMANCE DATA FOR OPERATIONAL DOMESTIC fGO SYSTEMS
COMPANY NAME
PLANT N»ME
JN1T NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION  LIMITATION - N6/J
S02 EMISSION LIMITATION  -  N6/J
NET PLANT GENERATING  CAPACITY - MM
SROSS UNIT GENERATING CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MU
NET UNIT GENERATING CAPACITY WO/FGO - MU
EQUIVALENT SCRUBBED CAPACITY - MU

• * BOILER DATA
    SUPPLIER
    TYPE
    SERVICE LOAD
    COMMERCIAL  SERVICE DATE
    HAXIMUN BOILER  FLUE  GAS FLOW - CU.M/S
    FLUE GAS TEMPERATURE - C
    STACK HEIGHT  -  M
    STACK TOP  DIAMETER - «

** FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT - J/G
    RANGE HEAT  CONTENT - 9TU/LB
    AVERAGE ASH CONTENT  - X
    RANGE ASH  CONTENT -  X
    AVERAGE MOISTURE  CONTENT - X
    RANGE MOISTURE  CONTENT - X
    AVERAGE SULFUR  CONTENT - X
    RANGE SULFUR  CONTENT - X
    AVERAGE CHLORIDE  CONTENT - X
    RANGE CHLORIDE  CONTENT - X

•* GENERAL  EMISSION CONTROL SYSTEM DATA
    SALEABLE P ROD UC M THROWAUA Y PRODUCT
    SESERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    A-E FIRM
    DEVELOPMENT LFVEL
    NE./RETROFIT
    502 DESIGN  RE»OVAL EFFICIENCY  -  X
    COHMERCIAL  DATE
    INITIAL START-UP
    CONTRACT  A*»RDED
    KANSAS  POUER fc LIGHT
    JEFFREY
    2
    UAMEGO
    KANSAS
    0
                    (*
                            LB/MMBTU)
                            LB/MMBTU)
       700.0
       680.0
     *** **.*
       490.0
     COMBUSTION ENGINEERING
     PULVERIZED COAL
     BASE
      6/80
     ********       (.......  ACFM)
     *******        (*•**  F)
       183.         I 600  FT)
     ***.**•        (....*  FT)
     COAL
     *** **•
      18841.
                     <  8100  BTU/LB)
         5.80
     7-8
          .30
     THROUAUAY PRODUCT
     WET SCRUBBING
     LIMESTONE
     COMBUSTION ENGINEERING
     BLACK R VEATCH
     FULL SCALE
     NEW
        60.00
      1/80
      4/bo
      7/73
     NUMBER
     TYPE
     SUPPLIER
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     FLUE  GAS  CAPACITY - CU.M/S
     FLUE  GAS  TtXPFRATURE -  C
     PARTICULATE OUTLET LOAD - G/CU.M

 • *  PARTICLE SCRUBBER
     TYPE

 • *  A3SOR3ER
     TYPE
     INITIAL START UP
     SUPPLIER
     BOILER  LOAD/ABSORBER -  X
     L/G RATIO - L/CU.M
     SOZ DESIGN REMOVAL EFFICIENCY - X

 •*  MIST ELIMINATOR
     TYPE
     COLD SIDE
     COMBUSTION  ENGINEERING
- X     98.6
      13Z7.9         (?8140CO ACFM)
       139.4         (   ?S3 F)
          .07        (    .03 GR/SCF)
     NONE
     SPRAY  TOWER
      6/60
     COMBUSTION  ENGINEERING
         11.7
          4.1         ( 30.4 GAL/1000ACF)
         60.3
                                                  CHEVRON
                                                 113

-------
 EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980

KANSAS POWER t LIGHT: JEFFREY  2  (CONT.)
    SERVICE

    •»**»»

** REHEATER
    TYPE
    TEMPERATURE BOOST - C

•* WATER LOOP
    TYPE

»• TREATMENT
    TYPE

»• DISPOSAL
    MATURE
    TYPE
    LOCATION
    TRANSPORTATION
                                                 NUMBER

                                                 »»•*
                                                 BYPASS
                                                    zs.o
                                                 CLOSED
                                                             45 F>
                                                 BOTTOM ASH STABILIZATION
                                                 FINAL
                                                 LINED POND
                                                 ON SITE
                                                 PUMPED
	...	..........—.—PERFORMANCE DATA	—	-—.—...._
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 5/BO  SYSTE"

       •* PROBLEMS/SOLUTIONS/COMMENTS
                                                                       744

                                                                       696

                                                                       744
                         INITIAL OPERATIONS  AT  JEFFREY Z BEGAN IN JANUARY 1980.  NO MAJOR PROBLEMS
                         HAVE BEEN  ENCOUNTERED  SINCE  STARTUP.

 t/80  SYSTEM                                                                 720

       •* PROBLENS/SOLUTIONS/COMNENTS

                         DURING APRIL  THE  SYSTEM  WAS  STILL IN THE SHAKEDOUN/DEBUGGIN6 PHASE.

 S/8P  SYSTEM     100.0       100.0        100.0       100.0                  744   744    744

 S/80  SYSTEM     100.0       100.0        100.0       10C.O                  720   720    720

       •• PROBLEMS/SOLUTIOtS/COMPENTS

                         COMMERCIAL  OPERATIONS  BEGAN  ON MAY 1, 1980.  SINCE THEN THERE HAVE BEEN
                         NO PROBLEMS ENCOUNTERED  WITH THE FGD SYSTEM.  THE UNIT HAS OPERATED 100*
                         OF THE TIME.
 7/8P  SYSTEM     100.0       100.0

       »* PROBLEMS/SOLUTIONS/COMMENTS
                                    100.0
                                                       95.3
                                                                       744
                                                                             709
                                                                                     709   81.0
                         DURING JULY  A  35  HOUR  OUTAGE OCCURRED DUE TO A REHEATER TUBE LEAK  IN  THE
                         BOILER.  NO  FGD-RELATE6  OUTAGES OCCURRED DURING THE MONTH.
 8/80  SYSTEM

 »/80  SYSTEM
           100.0       100.0        100.0        100.0

           100. •)       100.0        100.0        100.0

•• PROBLENS/SOLUTIOMS/COMMENTS
                                                                             744

                                                                             720
744

720
744  80.1

720  73.5
                         NO PROBLEMS WERE  ENCOUNTERED  WITH THE BOILER OR THE FGD SYSTEM DURING  THE
                         AUGUST AND SEPTEMBER  PERIOD.
                                                114

-------
                                              FP* UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980

                                           SECTION 3
               DESIGN  «NO  PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FCD  SYSTEMS
COMPANY  NAME
PLANT  NAME
J*IT NUMBER
CITY
STATE
• ROSS  UNIT  GENERATING CAPACITY - MM
«ET UNIT GENERATING CAPACITY M/FGD - MM
EQUIVALENT  SCRUBBED CAPACITY - My

• *  FUEL  DATA
    fUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - I
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X

**  GENERAL  EMISSION CONTROL SYSTEM DATA
    GENERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION  - X
    INITIAL START-UP DATE
    COMMERCIAL START-UP DATE
    S02  DESIGN REMOVAL  EFFICIENCY  - X
    PARTICULATE DESIGN  REMOVAL EFFICIENCY
    ABSORBER SPARE CAPACITY INDEX  - X
    ABSORBER SPARE COMPONENTS INDEX

 • *  WATER LOOP
     TYPE
     FRESH MAKE-UP  MATER - LITER/S

 .*  TREATMENT
     TYPE

 •*  DISPOSAL
     TYPE
                             KANSAS  POWER
                             LAMRENCE
                             4
                             LAMRENCE
                             KANSAS
                                U5.0
                                115.0
                                125.0
                              COAL
                                                              &  LIGHT
                                             ( 10000 BTU/LB)
                  23260.
                     9.80
                     12.00
                       .55
                       .03
                              MET  SCRUBBING
                              LIMESTONE
                              COMBUSTION ENGINEERING
                              RETROFIT
                               1/76
                              ** / **
                                 73.00
                           X      98.90
                                   .0
                                   .0
                              CLOSED
                                              (****•*  6PM)
                              FORCED OXIDATION
                                                 POND
_...— ——— —	—	———.—pERFORMANCE DATA	—	———	——
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION   X  REMOVAL   PER  BOILER  FGD    CAP.
                                                                  S02   PART. HOURS HOURS  HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
3/80 SYSTE"
100.0
10C.O
100.0
100.0
100.0
100.0
7*4 744
696 696
744 744
744
696
744
       «. PROBLEMS/SOLUTIONS/COMMENTS
                          NO MAJOR PROBLEMS MERE REPORTED  FOR  THE LAWRENCE 4 SCRUBBER DURING
                          THE FIRST QUARTER 1980.
 4/80   SYSTEM      100.0       100.0

        *•  PROBLEMS/SOLUTIONS/COMMENTS
                        100.0
                                      80.0
                                                720   576
                                                                          576
                          THE BOILER WAS OFF LINE  FOR  SIX DAYS IN APRIL FOR A SCHEDULED  INSPECTION.
                          DURING THE BOILER OUTAGE  GENERAL MAINTENANCE MAS PERFORMED  ON  THE  FGD
                          SYSTEM.
 5/80   SYSTEM

 4/&0   SYSTEM
100.0

100.0
100.0

100.0
100.0

100.0
10C.O

100.0
744   744

720   720
744

720
                                                 115

-------
 EP» UTILITY  FGD  SURVEY: JULY - SEPTEMBER  19*0

	_
'ER10D MODULE  AVAILABILITY OPERAfULlTY  RELIABILITY UTILIZATION   X  REMOVAL   PER  BOILER  F66    C*P.
                                                                   S02   PART. HOURS HOURS   HOURS  FACTOR


       •• PROBLE1S/SOLUTIOYS/COMMENTS

                          THE UTILITY REPORTED THAT THE FGD SYSTEM  OPERATED 100* OF THE TIHE  IN
                          NAY AND JUNE.

 7/&1  SYSTEM       96.8         96.8         96.P         96.8                   74*   744     720   54.8

       ** PROBLtMS/SOLUTlONS/COMMENTS

                          A STORAGE TANK  ERODED  COMPLETELY THROUGH  CAUSING A Tl>0 DAY OUTAGE IN
                          JULY.

 3/80  SYSTE"      100.0        100.0        10^.0        100.0                   744   744     744   SP.e

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          NO PROBLEMS WERE  ENCOUNTERED WITH THE  F6D SYSTEM 01) THE BOILER  DURING
                          AUGUST.

 ?/8?  SYSTEM       96.9        100.0        100.C         40.3                   720   290     290   16.4

       •• PROBLEXS/SOLUTIOYS/CONMENTS

                          THE BOILER WAS  OUT  OF  SERVICE FOR APPROXIMATELY  17 DAYS FOR A BOILER
                          INSPECTION.

                          ECONOMIZER WELD REPAIRS  CAUSED THE SYSTEM TO  REMAIN OUT OF SERVICE  FOR
                          22 HOURS.
                                                 116

-------
                                             EPA UTILITY  FGO  SURVEY: JULY - SEPTEMBER  1980
                                          SECTION 3
             DESIGN AND  PERFORMANCE  DATA FOR OPERATIONAL  DOMESTIC  FGO SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
SROSS UNIT GENERATING CAPACITY - My
SET UNIT GENERATING CAPACITY H/FGD - MW
EQUIVALENT SCRUBBED CAPACITY - MH
.• FUEL DATA
FUEL TYPE
FUEL GRADE
AVERAGE HEAT CONTENT - J/&
AVERAGE ASH CONTENT - I
AVERAGE MOISTURE CONTENT - *
AVERAGE SULFUR CONTENT - X
AVERAGE CHLORIDE CONTENT - X
•* GENERAL EMISSION CONTROL SYSTEM DATA
GENERAL PROCESS TYPE
PROCESS TYPE
SYSTEM SUPPLIER
NEK/RETROFIT
cucDfv rnu^iiMPTirtM — ' y
t"t"OT tUPloUnr*lll)r
-------
 EPA UTILITY FED SURVEY: JULY  - SEPTEMBER  1980

KANSAS POtfER I LIGHT: LAURENCE 5  (CONT.)
.	..	.......	— PERFORMANCE  DATA	—	—	
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F6D   CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS FACTOR


       •* PROBLEHS/SOLUTIONS/COMMENTS

                         A 29 HOUR OUTAGE OCCURRED  AS  A  RESULT OF A REHEATER TUBE LEAK IN THE
                         BOILER.  NO FED SYSTEM-RELATED  PROBLEMS OCCURRED DURING JULY.

 3/80  SYSTEM     100.0       100.0       100.0        81.5                   744   606    606  43.3

       •* PROBLENS/SOLUTIONS/COMMENTS

                         THE OUTAGE TIME IN  AUGUST  yAS DUE TO NECESSARY  REPAIR OF A BOILER REHEAT
                         TUBE.

 »/80  SYSTEM     100.0       100.0       100.0        95.7                   7ZO   689    689  38.7

       •• PROBLEMS/SOLUTIONS/COHMENTS

                         THE BOILER HAS OUT  OF SERVICE FOR APPROXIMATELY 31  HOURS FOR A SCHEDULED
                         INSPECTION.
                                               118

-------
                                              EPA UTILITY  FGO  SURVEY:  JULY  - SEPTEMBER 1980

                                           SECTION 3
               DESIGN  AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FGD  SYSTEMS
COMPANY  NAME
PLANT  NAUE
JHIT NUMBER
CITY
STATE
SROSS  UNIT  GENERATING CAPACITY - Mb
YET UNIT GENERATING  CAPACITY W/FGD - My
E8UIVALENT  SCRUBBED  CAPACITY - »M

••  FUEL  DATA
    fUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X

••  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
     INITIAL START-UP DATE
    COMMERCIAL  START-UP DATE
     S02  DESIGN  REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 t*  WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 »«  DISPOSAL
     TYPE
                              KENTUCKY UTILITIES
                              GREEN RIVER
                              1-3
                              CENTRAL  CITY
                              KENTUCKY
                                 64.0
                                 60.0
                                 64.0
COAL
BITUMINOUS
 35586.
   13.40
   12.10
    4.00
                              WET SCRUBBING
                              LIME
                              AMERICAN AIR FILTER
                              RETROFIT
                                  3.1
                               9/75
                               6/76
                                 80.00
                                 99.50
                                   .0
                                   .0
                                             ( 11000 8TU/LB)
CLOSED
    4.7
                                                 LINED POND
                                              (    75  GPM)
	 — —	——	—~ — PERFORMANCE DATA	.....	— — ...—
•ERIOO MODULE AVAILABILITY  OPERABIL1TY  RELIABILITY UTILIZATION  t REMOVAL    PER   BOILER  FGO   CAP.
                                                                 502   PART.  HOURS HOURS  HOURS FACTOR
1/80 SYSTEM
2/80 SYSTEM
J/BO SYSTEM
100.0
100.0
100.0
.0
.0
.0
744
696
744
0
0
0
0
0
0
.0
.0
.0
       *• PROBLEMS/SOLUTIONS/COMMENTS
                          THE  BOILER REMAINED OUT OF SERVICE  DUE  TO  BOILER REPAIRS.
                          EXPECTED TO BE OPERATING IN MAY.
                                                                    THE  UNIT  IS
 k/80  SYSTEM

 5/80  SYSTEM

 S/8P  SYSTE*
100.0

100.0

100.0
          .0

          .0

          .0
720

744

720
.0

.0

.0
       • *  PROBLEMS/SOLUTIONS/COMMENTS
 7/80   SYSTEM
                   100.0
       THE FGD SYSTEM  REMAINED OFF LINE DURING THE SECOND QUARTER  Of  1980 AS A
       RESULT OF  THE ON-GOING  BOILER REPAIRS.  COMPLETION OF  THE BOILER REPAIRS
       HAS BEEN DELAYED  BY THE UNAVAILABILITY OF SOME NEEDED  PARTS.

                                        .0                   744      0       0    .0
                                                 119

-------
 EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER  19PC


-------
                                               EPA UTILITY FGD SURVEY:  JULY  - SEPTEMBER 1980

                                            SECTION 3
               DESI6N AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
COMPANY  NAME
PLANT  NME
UNIT NUMBER
CITY
STATE
SROSS  UNIT GENERATING CAPACITY  - MM
YET  UNIT GENERATING CAPACITY W/FGD -  My
EQUIVALENT SCRUBBED CAPACITY -  MM

.•  FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT -  *
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT -  X

*•  GENERAL EMISSION CONTROL SYSTEM  DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     SDZ DESIGN REMOVAL  EFFICIENCY  - X
     PARTICULATE DESIGN  REMOVAL  fFFIClENCY
     ABSORBER SPARE CAPACITY INDEX  - X
     ABSORBER SPARE COMPONENTS  INDEX

 •*  WATER LOOP
     TYPE
     fHESH  MAKE-UP  yATER -  LITER/S

 •»  DISPOSAL
     TYPE
             - X
                  LOUISVILLE GAS & ELECTRIC
                  CANE RUN
                  4
                  LOUISVILLE
                  KENTUCKY
                    188.0
                    175.0
                    188.0
                  COAL
                  BITUMINOUS
                   26749.
                     17.10
                      9.00
                      J.75
                       .04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
RETROFIT
    1.6
 8/76
 8/77
   85.00
   99.00
     .0
     .0
                (  11500  BTU/LB)
                  OPEN
                      6.3
                                                 LINED  POND
                                  (  10,0 6PM)
	PERFORMANCE  DATA	
PERIOD NODULE  AVAILABILITY  OPERA9IL1TY RELIABILITY  UTILIZATION  X REMOVAL    PER   BOILER  FGO   CAP.
                                                                  SO?  PART.  HOURS  HOURS  HOURS FACTOR
 1/80  SYSTEM

 Z/80  SYSTEM

 $/80  SYSTEM
10C.O

 99.8

 80.5
        95.6

        66.7

        74.3
744   711

696   465

744   687
711

464

553
        •*  PROBLEMS/SOLUTIONS/COMMENTS
                          NO MAJOR OPERATIONAL  PROBLEMS yERE REPORTED  FOR  THE  FIRST QUARTER OF  19PO
                          rflTH EITHER THE  BOILER  OR THE FGD SYSTEM.

 4/60   SYSTEM       99.0        98.8         9S.8         79.9                   7?0   5P2    575

        **  PROBLcMS/SOLUTlONS/COMMENTS

                          DURING APRIL  SPRAY PUMP PROBLEMS CAUSED  SEVEN  HOURS  OF OUTAGE TIME.

 5/80   SYSTEM       96.8       100.0        100.0          7.0                   744    52     52

        •*  PROBLEMS/SOLUTIONS/COMMENTS

                          THE BOILER  WAS  NOT NEEDED MOST Of MAY, THIS  ACCOUNTS FOR THE LOW
                          UTILIZATION OF  THE FGD  SYSTEM.

                          ONE DAY  OF  OUTAGE  TIME  IN MAY yAS CAUSED BY  A  LEAK IN A  SPRAY PUMP
                          SEAL.
        SYSTE"
                                   .0
                                                            .0
                                                                                720    350
                                                 121

-------
 EPA UTILITY FGO SURVEY: JULY  -  SEPTEMBER  1980

LOUISVILLE 6AS I ELECTRIC: CANE  RUN  I  (CONT.)
...	...	.	.	.	PERFORMANCE DATA	-—————«_..__
PERIOD NODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F6D   CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/CONMENTS

                         DURING PART OF  JUNE  THE  BOILER  WAS ON RESERVE, IN WHICH TIME THE SCRUBBER
                         DUCTWORK AND LININGS  WERE  REPAIRED.

                         REPAIRS WERE WADE  TO  MODULE  LININGS AND DUCTWORK.  DUCTWORK REPAIRS/
                         REPLACEMENTS WERE  MADE WITH  316 SS.

                         ALSO DURING THE DOWN  TIME  THE EXPANSION JOINT LOCATED AT THE DISCHARGE
                         OF THE BOOSTER  PUMP WAS  REPLACED.
 7/80  A
       a
       SYSTEM
 85.7
 85.7
 85.7
 92.8
 92.8
 92.8
 92.8
 92.8
 92.8
85.7
85.7
85.7
                                                         87.CO 99.00   74*   687    638

** PROBLEfS/SOLUTIONS/COMMENTS

                  PROBLEMS WERE ENCOUNTERED  WITH  THE  OIL REHEAT SYSTEM DURING JULY.
                         SPRAY PUMP AND VALVE FAILURES  ENCOUNTERED  DURING THE MONTH ACCOUNTED FOR
                         SOME OF THE FGD SYSTEM  DOWN  TIME.
 S/80  SYSTEM

 7/80  SYSTEM
100.0

100.0
 99.3

100.0
 99.3

100.0
76.9

35.7
                                                                       744

                                                                       720
576

257
572  5C.O

257  50.0
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE UTILITY REPORTED THAT NO MAJOR  OUTAGES  OCCURRED  DURING AUGUST AND
                         SEPTEMBER.
                                               122

-------
                                              EPA UTILITY FGD SURVEY: JULY -  SEPTEMBER  1980

                                           SECTION 3
               DESIGN  AND  PERFOR»ANCE  DATA fOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY  NAME
PLANT  NAME
UNIT  NUMBER
CITY
STATE
SROSS  UNIT GENERATING CAPACITY - MM
«ET  UNIT GENERATING CAPACITY W/FGD - MM
EBUIVALENT SCRUBBED CAPACITY - MW

••  FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE  HEAT CONTENT - J/G
     AVERAGE  ASH CONTENT - X
     AVERAGE  MOISTURE CONTENT - 5!
     AVERAGE  SULFUR CONTENT - X
     AVERAGE  CHLORIDE CONTENT - X

• •  GENERAL  EMISSION CONTROL SYSTEM DATA
     GENERAL  PROCESS TYPE
     PROCESS  TYPE
     SYSTEM  SUPPLIER
     SEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL  START-UP DATE
     COMMERCIAL START-UP BATE
     S02 DESIGN REMOVAL EFFICIENCY  - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX  - X
     ABSORBER SPARE COMPONENTS INDEX

 **  WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 »*  TREATMENT
     TYPE

 *«  DISPOSAL
     TYPE
                                    - X
                                         LOUISVILLE GAS fc ELECTRIC
                                         CANE RUN
                                         5
                                         LOUISVILLE
                                         KENTUCKY
                                           200.0
                                           192.0
                                                        ( 11500 BTU/LB)
COAL
BITUMINOUS
 26749.
   17.10
    9.00
    3.75
WET SCRUBBING
LIME
COMBUSTION ENGINEERING
RETROFIT
    1.5
12/77
 7/78
   85.00
   99.00
     .0
     .0
                                         OPEN
                                         ttt•«*•
                                         POZ-0-TEC
                                                 LINED POND
                                                         (*****  6PM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 $02  PART. HOURS HOURS   HOURS  FACTOR
 1/80
 2/80
SYSTEM                  92.1                     72.2                   7*4   583    5S7

*• PROBLEMS/SOLUTIONS/COMMENTS

                  DURING JANUARY  NO  OPERATIONAL PROBLEMS WERE ENCOUNTERED.

SYSTEM                  71.9                     49.7                   696   481    3*6

•• PROBLEMS/SOLUTIONS/COMMENTS

                  IN  FEBRUARY THE UTILITY  RAN OUT OF  CARBIDE LIME CAUSING INTERRUPTION  OF
                  THE FGD  SYSTEM  OPERATION.  THE UNAVAILABILITY OF LIME HAS CAUSED BT  FREEZE
                  UPS ENCOUNTERED BY AIRCO, THE LIME  SUPPLIER.
 5/80
SYSTEM                   44.5

«• PROBLEMS/SOLUTIONS/COMMENTS
        27.2
                                                                               744
                                                                                     454
                                                                                            202
  fc/80   SYSTEM
                      .0
                  REHEATER  TUBE  PROBLEMS WERE ENCOUNTERED IN FEBRUARY  AND  CONTINUED
                  THROUGH MARCH.   THE UTILITY HOPES TO REPLACE THE TUBE BUNDLES  IN  THE
                  SUMMER.

                                                   .0                   720      0       0
                                                   .0
                                                 123

-------
 EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER  1980

L3U1SVILLE GAS fc  ELECTRIC:  C»NE RUN 5 (CONT.)
	PERFORMANCE  DATA	—- —
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION  I REMOVAL   PER   BOILER   F6D   CAP.
                                                                  S02  PART. HOURS  HOURS   HOURS FACTOR


       •* PROBLE1S/SOLUTIONS/COMMENTS

                          THE FGD SYSTEM WAS OFF  LINE THE ENTIRE MONTH OF APRIL TO  INSTALL
                          STAINLESS STEEL (316  SS)  IN THE DUCTWORK AND IN THE MODULES.
 5/60  SYSTEM       95.3         94.5

       *• PROBLEMS/SOLUTIONS/COMWENTS
 3/80

 J/80
                                            94.5
                                                         80.2
                                                                               744
                                                                                      597
                          DURING "AY ONE DAY OF  OUTAGE  TIME  WAS NECESSARY TO COMPLETE  THE  INSTALLA-
                          TION OF THE STAINLESS  STEEL  IN  THE  DUCTWORK AND MODULES.

                          A  PUMP SEAL ON THE RECIRCULATION  PUMP FMLED CAUSING APPROXIMATELY 10
                          HOURS OF OUTAGE TIME.
 S/60  SYSTEM
                    78.8
                                74.4
                                            74.4
                                                         61.8
                                                                               720
                                                                                      598
                                                                                             44S
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING JUNE THE SYSTEM HAD  TO  BE  TAKEN OFF LINE FOR 153 HOURS  DUE  TO THE
                          POOR  WELDS ON THE TUBE BUNDLES  IN THE  REHEATER.  THE TUBE  BUNDLES  HAVE
                          BEEN  A CONSTANT PROBLEM AND  THE MANUFACTURER IS SCHEDULED  TO REPLACE
                          THEM  IN THE FALL.
 7/80  SYSTEM      78.7         87.6

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                            87.6
                                                  78.7
                                                          85.00 99.00   744
                                                                               669
                                                                                      586
                          DURING JULY THE REHEAT TUBE  EXCHANGERS  FAILED.  TWO NEW EXCHANGERS ARE
                          NOW  ON SITE AND ARE SCHEDULED  TO  BE  INSTALLED IN NOVEMBER OR  DECEMBER 1980.

                          A  THREE DAY OUTAGE OCCURRED  IN  JULY  DUE TO A LIMESTONE ROCK DISABLING
                          THE  THICKENER.
SYSTEM

SYSTEM
49.6

87.2
5R.4

97.5
58.4

97.5
49.6

87.2
744

720
632

644
369  50.0

628  SO.O
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                          THE  OUTAGE  TIME DURING AUGUST AND  SEPTEMBER WAS CAUSED BY A REHEAT  TUBE
                          BUNDLE  FAILURE.  THE BUNDLES ARE PRESENTLY BEING REPLACED IN BOTH MODULES.
                                                124

-------
                                               EPA  UTILITY FGD SURVEY: JULY  - SEPTEMBER 1980

                                            SECTION 5
               DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC  FGD  SYSTEMS
         NAME
PLANT  NAME
JN1T  NUMBER
CITY
STATE
SROSS  UNIT  GENERATING CAPACITY - MW
«ET  UNIT GENERATING CAPACITY W/FGD -  My
E8UIVALENT  SCRUBBED CAPACITY - MW

**  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

• *  GENERAL  EMISSION CONTROL SYSTEM  DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM  SUPPLIER
     SEW/RETROFIT
     ENERGY  CONSUMPTION  - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL  EFFICIENCY  - X
     PtRTICULATE DESIGN  REMOVAL  EFFICIENCY
     ABSORBED SPARE CAPACITY  INDEX  - X
     ABSORBER SPARE COMPONENTS  INDEX

 •• WATER LOOP
     TYPE
     FRESH  MAKE-UP  WATER -  LIUH/S

 •* DISPOSAL
     TYPE
                                                         I  ELECTRIC
                                    - X
                                                         ( 11000 BTU/LBI
                                         LOUISVILLE GAS
                                         CANE RUN
                                         6
                                         LOUISVILLE
                                         KENTUCKY
                                           299.0
                                           277.0
                                           299.0
COAL
BITUMINOUS
 25586.
   17.10
    9.00
    4.80
     .04
WET SCRUBBING
DUAL ALKALI
COMBUSTION  EQUIP ASSOCIATES
RETROFIT
    1.0
 4/79
*«/«*
   95.00
   99.00
   20.0
      .3
                                          CLOSED
                                                 LANDFILL
                                                         (****» 6PM)
	.	PERFORMANCE  DATA	
PERIOD MODULE  AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL    PER   BOILER  FGO   CAP.
                                                                  502  PART.  HOURS  HOURS  HOURS FACTOR
 1/80  SYSTEM                   49.D

       »*  PROBLEMS/SOLU1IOSS/COMMENTS
                                                 13.8
                                                                        744
                                     210
             103
                          FGD SYSTEM OUTAGE  TIME  IN JANUARY HAS CAUSED BY  A  THICKENER FAILURE.
                          THE RAKF BECAME  INOPERABLE  BECAUSE OF HIGH  SOLIDS  AND THE THICKENER HAD
                          TO BE CLEANED OUT.
 2/80

 5/80
SYSTEM                   64.7

SYSTE"                   7C..3

*» PROBLEMS/SOLUTIONS/COMMENTS
        47.0

        64. 5
696

744
386

686
327

480
                          IN FEBRUARY  AND  MARCH OUTAGE TIME WAS  CAUSED  BY  PROBLEMS WITH THE RECYCLE
                          PUMPS.
 4/80
SYSTEM      93.8         91.5

*• PROBLEMS/SOLUTIONS/COMMENTS
                                             97.7
                                                         73.9
                 95.00 99.CO   720   581
                                                                                              531
                          THE BOILER  OUTAGES IN APRIL WERE  A  RESULT  OF  THE LOSS OF ONE OF THE  BOILER
                          FEED PU«PS  ASD  BECAUSE THE LOAD WAS  NOT  NEEDED.

                          THE FGD  OUTAGES WERE A RESULT OF  HIGH  BOOSTER FAN SUCTION TRIPS,  REPAIRS
                          TO  THE  IUCS SYSTEM, REPAIRS TO THE  THICKENER  UNDERFLOW LINE  AND A PLANNED
                          INSPECTION  OF  THE TRAYS.  THE TRAY  PLUGGING PROBLEM «AS SOLVED  BY A
                          SLIGHT  PH  ADJUSTMENT IN THE REACTORS.
  5/&C  SYSTE"
                    99.
                                 99.9
                                             99.9
                                                  99.5
                                                                         744
                                                                               741
                                                                                              740
                                                 125

-------
 EPA UTILITY F6D SURVEY:  JULY  -  SEPTEMBER  1980

L3UISVILLE GAS I ELECTRIC: CANE  RUN  A  (CONT.)
...	_	PERFORMANCE DATA	——	—-——.-.._
PERIOD NODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS  FACTOR


       • * PROBLEKS/SOLUTIONS/COMMENTS

                         DURING  MAY  THE  PRESSURE RELIEF VALVE ON THE BOOSTER  FAN MALFUNCTIONED
                         FORCING  THE FGD SYSTEM OUT OF SERVICE.

 4/80  SYSTEM      99.9        99.8         99.9        88.9                   720    642     640

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         A SPRAY  PUMP MALFUNCTION CAUSED THE SYSTEM TO SHUTDOVN.  APPROXIMATELY
                         ONE HOUR WAS NEEDED  TO PUT THE SPARE INTO SERVICE.

                         THE BOILER WAS  OFF  FOR REPAIRS TO THE CLINKER GRINDER AND  TO REPAIR A
                         BOILER  TUBE LEAK.

                         IMPROVEMENTS TO T»E  PH CONTROL CIRCUITRY HAVE LEAD TO IMPROVED CARBIDE
                         LIME UTILIZATION.

                         EXPERIMENTATION WITH A NEW FILTER CLOTH HAS SHOWN AN IMPROVEMENT  IN SODA
                         ASH CONSUMPTION.

                         SULFUR  DIOXIDE  EMISSIONS AVERAGED LESS THAN 200 PPM  FOR JUNE.

 7/80  SYSTEM      99.9        99.9         99.7        82.9                   744    618     617

       •• PROBLEMS/SOLUTIO*S/COM»ENTS

                         DURING  THE PERIOD  FROM JULY 17 THROUGH JULY 28 AN ACCEPTANCE TEST  WAS RUN.
                         DURING  THE TEST THE  FGD SYSTEM EXPERIENCED NO MAJOR  PROBLEMS OR OUTAGE
                         TIME.   THE AVERAGE  SO? REMOVAL EFFICIENCY DURING THE TEST  UAS 95.IX.

                         DURIKG  NORMAL OPERATION IN JULY NO MAJOR FGD RELATED PROBLEMS WERE
                         ENCOUNTERED.

 S/80  SYSTEM      99.5        94.6        94.6        84.5                   744    665     628   50.0

 »/80  SYSTEM      99.0        98.6        9».8        86.9                   720    635     626   50.0

       • • PROBLENS/SOLUTIONS/COMMENTS

                         THE UTILITY REPORTED  THAT  NO MAJOR PROBLEMS OCCURRED DURING THE MONTHS  OF
                         AUGUST AND SEPTEMBER.
                                               126

-------
                                              EPA  UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
              DESIGN  AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
oROSS UNIT GENERATING  CAPACITY  -  Mtt
YET UNIT  GENERATING  CAPACITY  W/FGD  - Mb
EQUIVALENT SCRUBBED  CAPACITY  -  HW

••  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE  HEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT  - X
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR CONTENT -  X
    AVERAGE  CHLORIDE CONTENT  -  X

••  GENERAL  EMISSION  CONTROL SYSTEM  DATA
    GENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE DESIGN REMOVAL  EFFICIENCY
    ABSORBER SPARE CAPACITY INDEX - X
    ABSORBER SPARE COMPONENTS INDEX

 «*  WATER  LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 »*  TREATMENT
     TYPE

 ••  DISPOSAL
     TYPE
                                    - X
                                         LOUISVILLE  GAS  t  ELE.CTR1C
                                         MILL  CREEK
                                         3
                                         LOUISVILLE
                                         KENTUCKY
                                           442.0
                                           420.0
                                         COAL
                                         BITUMINOUS
                                          26749.
                                            11.50

                                             3.75
                                              .04
WET SCRUBBING
LIME
AMERICAN AIR FILTER
NEW
    1.6
 8/78
 5/79
   85.00
   99.00
     .0
     .0
               ( 11500 BTU/LB)
                                         OPEN
                                             9.4
                                                         (  150 6PM)
                                         FLYASH/LIME STABILIZATION
                                                 POND
..	PERFORMANCE  DATA	———	———	
»ERIOD MODULE AVAILABILITY OPERABILIT1 RELIABILITY  UTILIZATION   X REMOVAL   PER  BOILER  FGD   CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS FACTOR
 1/60
 2/80
 3/80
SYSTEM

** PROBLEMS/SOLUTIONS/COMMENTS
                                                                              744
                         DURING  THE  OVERHAUL  GENERAL SCRUBBER MAINTENANCE WAS DONE BUT NO MAJOR
                         MODIFICATIONS  MERE MADE.
SYSTEM                  36.1

• * PROBLEMS/SOLUTIONS/COMMENTS
        26.6
                              696
                                    512
                                                                                            185
                          THE  UNIT  CAME  BACK  ON LINE ON FEBRUARY 10 AFTER THE TURBINE OVERHAUL
                          WORK  WAS  COMPLETED.
SYSTEM                  36.9

•• PROBLEMS/SOLUTIONS/COMMENTS
        30.6
                                                                              744
                                    618
228
                          PROBLEMS  ENCOUNTERED DURING FEBRUARY AND MARCH WITH THE F6D SYSTEM
                          OPERATION INCLUDED FROZEN WATER LINES AND WORN GASKETS BLOWING  IN THE
                          REHEATER  FLANGES.
  4/80   SYSTEM
                  THE UTILITY  IS  IN  THE  PROCESS OF REPLACING THE REHEATER TUBES.

            *2«*         42.5         42.5         42.2    85.00 99.40   720   715
                                            304
                                                  .0
                                                127

-------
 EPA UTILITY fGD SURVEY:  JULY  - SEPTEMBER 1980

LDUISVILLE G»S & ELECTRIC:  WILL CREEK  3  (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AV«ILABILIT₯  OPERAPILITY  RELIABILITY UTILIZATION  I  REMOVAL    PER   BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS  HOURS   HOURS FACTOR


       «* PRQ,BLE«IS/SOLUTIONS/CON«ENTS

                          THE  REHFATER  TUBE REPLACEMENT CONTINUED INTO APRIL.

                          THE  OTHER  OUTAGE  TIME ENCOUNTERED DURING  APRIL  WAS  CAUSED  BY A BLOWN
                          GASKET  IN  THE  CONDENSATE PUMP.

 5/80  SYSTEM      67.5         51.4        51.4        34.4                   744    498     256

       ** PROBLE»S/SOLUTIONS/COMMENTS

                          DURING  MAY THE  PLASTIC MIST ELIMINATOR COMPONENTS  WERE  REPLACED WITH
                          STAINLESS  STEEL.   THIS KEPT THE SYSTEM OFF LINE FOR  APPROXIRATELY  10 DAYS.

                          REHEATER  TUBE  LEAKS  WERE ALSO ENCOUNTERED IN MAY.

 4/80  SYSTEM      88.2           .0          .0          .0                   720     85       0

       ** PROBLEHS/SOLUTIONS/COHMENTS

                          IN LATE MAY THE  TURBINE  LOST TWO BLADES CAUSING THE  SYSTEM  TO  SHUTDOWN
                          UNTIL  THE  LATTER  PART OF JUNE.  DURING THE OUTAGE  THE UTILITY  DECIDED
                          TO REPLACE THE  LIME  STORAGE TANK LINES WITH  LARGER  ONES  TO  SERVICE THE
                          NEW  UNITS. THE  WORK WAS NOT COMPLETED WHEN  THE BOILER  WAS  RETURNED
                          TO SERVICE; THUS, THE FGD UNIT DID NOT OPERATE  DURING THE  MONTH.

 7/80  SYSTEM      92.0         91.3        91.3        83.9                   744    684     625

       •» PROBLEMS/SOLUTIOMS/COMMENTS

                          RECYCLE PUMP  FAILURES CAUSED THE FGD SYSTEM TO  SHUTDOWN  FOR  PART OF JULY.

 J/80  SYSTEM      58.7        81.7        81.7        58.7                   744    535     437  60.0

 J/80  SYSTEM      57.2        60.4        60.4        57.2                   720    682     412  60.0

       *• PR03LEMS/SOLUT10NS/COMMENTS

                          DURING  THE AUGUST THROUGH SEPTEMBER PERIOD THE  PUMP  HOUSE  WAS  FLOODED
                          DUE  TO  THE FAILURE OF THE BLEED PUMP FRP PIPE LINE.  BECAUSE OF THIS
                          FAILURE, 23 PUMPS AND 23 PUMP MOTORS WERE DAMAGED.
                                                128

-------
                                               EPA UTILITY FGD  SURVEI:  JULY - SEPTEMBER 1980

                                            SECTION 3
               DESIGN AND PERFORMANCE  DATA FOR OPERATIONAL  DOMESTIC  FGD SYSTEMS
COHPMt  NAME
PLANT  NAME
UNIT  MUM3ER
CITY
STATE
6ROSS  UNIT  GENERATING CAPACITY  -  My
til  UNIT GENERATING CAPACITY  W/FGD  - My
EQUIVALENT  SCRUBBED CAPACITY  -  MW

••  FUEL  DATA
     FUEL TYPE
     FJEL GRADE
     AVERAGE HEAT CONTENT -  J/G
     AVERAGE ASH CONTENT -  X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  -  X

..  GENERAL  EMISSION CONTROL  SYSTEM  DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM  SUPPLIER
     NEd/RETROFIT
     ENER6Y  CONSUMPTION  - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S92 DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE DESIGN  REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARF COMPONENTS INDEX

 ••  WATER LOOP
     TYPE
     FRESH  MAKE-UP  WATER -  LITER/S

 «•  TREATMENT
     TYPE

 •*  DISPOSAL
     TYPE
- X
     LOUISVILLE GAS & ELECTRIC
     PADDY'S RUN
     6
     LOUISVILLE
     KENTUCKY
        72.0
        67.0
        72.0
                     t  11500 BTU/LB)
COAL
BITUMINOUS
 26749.
   11.50

    2.50
WET SCRUBBING
LIKE
COMBUSTION  ENGINEERING
RETROFIT
    2.8
 4/73
* * / **
    90.00
    99.10
      .0
      .0
     CLOSED
         3.1         (   SO GPM>
     LIME  STABILIZATION
                                                  POND
.	«.	PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X  REMOVAL    PER  BOILER  FGD    CAP.
                                                                  S02   PART. HOURS HOURS  HOURS  FACTOR
1/80 SYSTEM
2/6" SYSTE"
3/80 SYSTEM
.0
.0
.0
744
696
744
0
0
0
0
0
0
.0
.0
.0
         *  PROBLE*S/SOLUTIONS/CO«>"ENTS
                          THIS UNIT DID  NOT  OPERATE DURING THE  FOURTH  QUARTER OF 1979 OR  THE  FIRST
                          SUARTER OF  19FO  DUE  TO A LACK OF DEMAND.   THIS UNIT IS USED AS  A  PEAKING
                          UNIT ANt> WILL  BE RETIRED SOMETIME  IN  1987.
 4/8C   SYSTE"      100.?

        **  PROBLi*S/SOLUTIONS/COM»ENTS
               .0
                                    720
                                                         .0
                          DURING  APRIL  THE  FGD SYSTEM WAS AVAILABLE  10CX OF THE TIME  BUT  WAS  NOT
                          OPERATED  DUE  TO  A  BOILER RELATE6  PROBLEM.
 5/8C   SYSTE1     100.3         86.6

        • *  PROBLfcMS/50LUTIONS/COM«lENTS
 66.6
              7.8
                                    744
                                           67
                          DURING  MAY,  NINF HOURS OF OUTAGE  TIME  RESULTED FROM  THE  UNAVAILABL1TY OF
                          THE  LIME  SLURRY.
  i/8'
        SYSTEM
                   '00.0
                                 94.1
                                             94.1
              6.7
                                    720
                                                                                        51
                                                                                               48

-------
 EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980

L9UISVILLE GAS I ELECTRIC:  PADDY'S  RUN  6  (CONT.)
                  _ ----- .. --------------- -PERFORMANCE DATA --------- - — — — — — - — ...... — ._._.__ __ _
       MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGft    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR
 7/80
 3/80

 9/60
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE  THREE  HOURS  THE  SCRUBBERS DID NOT OPERATE IN JUNE WAS  DUE  TO  THE  FACT
                         THAT  THE BOILER  WAS  BROUGHT ON LINE BEFORE THE SCRUBBER OPERATORS  WERE
                         ON DUTY.
       A
       B
       SYSTEM
           100.0
           100.0
           100.0
.0
.0
.0
                                                                              744
       •* PROBLEMS/SOLUTIONS/COHMENTS
                         THE BOILER  AND  FGD  SYSTEM DID NOT OPERATE DURING THE MONTH OF JULY  DUE  TO
                         A LACK  OF  DEMAND.
SYSTEM     100.0

SYSTEM     100.0

** PROBLEMS/SOLUTIONS/COMMENTS
.0

.0
744

720
0

0
                         THE BOILER DID WOT  OPERATE  DURIN6 AUGUST AND SEPTEMBER.  THE FGO  SYSTEM
                         dAS AVAILABLE  100X  OF  THE  TIME.
                                               130

-------
                                              EPA UTILITY  FGO  SURVEY:  JULY - SEPTEMBER 1980

                                           SECTION 3
              DESIGN  AN6  PERFORMANCE  DATA FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
COMPANY NAME
PLANT NAME
JN1T NUM3ER
CITY
STATE
REGULATORY CLASSIFICATION
PART1CULATE EMISSION  LIMITATION  - NG/J
S02 MISSION LIMITATION  -  NG/J
NET PLANT GENERATING  CAPACITY  -  Mw
SRCSS UNIT GENERATING  CAPACITY - My
MET JNIT GENERATING CAPACITY  W/FGD - MM
YET UNIT GENERATING CAPACITY  WO/FGD  - MW
EQUIVALENT SCRUBBED CAPACITY  - »y

** BOILER DATA
    SUPPLIER
    TYPE
    SERVICE LOAD
    COMMERCIAL  SERVICE  DATE
    HAHIIUM BOILER  FLUE  GAS  FLOW - Cu.M/S
    FLUE GAS TEMPERATURE - C
    STACK HEIGHT  -  M
    STACK TOP DIAMETER  - M

• * FJEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT - J/G
    RANGE HEAT  CONTENT  - 3TU/LD
    AVERAGE ASH CONTENT  -  X
    RANGE ASH CONTENT  -  X
    AVERAGE MOISTURE  CONTENT  -  X
    RANGE MOISTURE  CONTENT -  X
    AVERAGE SULFUR  CONTENT -  X
    R«NGE SULFUR  CONTENT - X
    AVERAGE CHLORIDE  CONTENT  -  X
    RANGE CHLOKIDE  CONTENT -  X

»• GENERAL EMISSION CONTROL  SYSTEM DATA
    SALEABLE PRODUCT/THROiiAUAY  PRODUCT
    GENERAL PROCESS TYPE
    PROCESS TYPE
    PROCESS ADDITIVES
    SYSTEM SUPPLIER
    A-E FIR"
    CONSTRUCTION  FIRM
    DEVELOPMENT LFVEL
    NEW/RETROFIT
    PART1CULATE DESIGN REMOVAL  EFFICIENCY
    so2 DESIGN  REMOVAL EFFICIENCY - x
    INITIAL START-UP
    CINSTRUCT I ON  COMPLETION
    CONSTRUCTION  INITIATION
    LETTER OF INTENT  SIGNED
    STARTED REQUESTING BIDS
    STARTED PBELI»INAV DESIGN

** ESP
    NUMBER
    TYPE
    SUPPLIER
    PARTICULATE DESIGN REMOVAL EFFICIENCY
    FLUE GAS  CAPACITY - CU.M/S
    FLUE GAS  TEMPERATURE - C
    PRESSURE.  DROP - KPA
    PARTICULATE OUTLET LOAD - G/CU.M

•• PARTICLE SCRUBBER
    NUMBER
    TYPE
    SUPPLIER
    NUMBER OF STAGES
    SHELL  MATERIAL
    LINING MATERIAL
     MINNESOTA POWER I LIGHT
     CLAY BOSWtLL
COHASSET
MINNESOTA
B
   43.
  516.
 10CO.O
  554.0
  504.0
  511.0
                    t  .1CC LB/MMPTU)
                    ( 1.COO LP/MMPTU)
     COMBUSTION ENGINEERING
     PULVERIZED COAL
     BASE
      2/60
      1086.40
       148.9
       163.
        11.3
                         ACFM)
                (  3PCj  F)
                <  6PO  FT)
                (  37.0 FT)
                     <  8887  BTU/LB)
                     7509  -  9923
COAL
SU8BITUMINOUS
 19276.

    9.4C
4.81 - 15.99
   21.50
20.3D - 26.31
     .94
0 - 4.55
     .01
0 - O.C7
     THROWAWAV PRODUCT
     WET SCRUBBING
     LIME/ALKALINE FLYASH
     NONE
     PEABODY PROCESS  SYSTEMS
     EBASCO
     PEABOOY PROCESS  SYSTEMS
     FULL SCALE
     NEW
- X     99.7J
        £4.55
      4/8?
      2/60
      5/78
      2/77
      4/76
      6/75
      1
     HOT SIDE
     JOY
  X     99.7
        94.4
       398.9
           .07
                ( 200000 ACFM)
                (  750 F)
                (••«.» IN-H20)
                (   .02 GR/SCF)
     RADIAL  VENTURI  VARIABLE THROAT
     PEABODY  PROCESS  SYSTEMS
          1
     STAINLESS  STEEL
     RUBBER
                                                131

-------
 EPA  JT1LITY  FGO SURVEY: JULY  -  SEPTEMBER 1980
"UNNESOTA  POWER  S LIGHT: CLAY BOSWELL  4  (COM.)

     I ETERNAL  "ATE RIAL
     NUMBER  OF NOZ7LES
     TYPF  OF  NOZZLES
     30ILER  LOAD/SCRUBBEP - X
     FLUE  GAS  CAPACITY - CU.M/S
     FLUE  GAS  TEMPERATURE - C
     LI3UID  9ECIRCULATION RATf - LITEfi/S
     L/G RATIO -  LITER/CU.1
     PRESSURE DROP  - KPA
     PARTICULATE  INLET LOAD - N&/J
     PARTICULATfc  OUTLET  LOAD - NG/J
     PARTICULATE  DFSIGN  REMOVAL  EFFICIENCY - X
     S02 INLET CONCENTRATION - NG/J
     S02 DESIGN RE«OVAL  EFFICIENCY - X
 ••  A3SOR3ER
     N U ,1 8 E R
     TYPF
     INITIAL START UP
     SUPPL IER
     NUMBER OF STARES
     DIMENSIONS - FT
     SHELL MATERIAL
     SHELL LINER MATERIAL
     INTERNAL MATERIAL
     NUMBER OF NOZZLES
     NOZZLE TYPt
     3DILER LOAD/ABSORBER - X
     iAS  FLOW - CU.M/S
     3»S  TEMPERATURE - C
     LIQUID RECIRCULATION RATE - UTER/S
     L/G  RATIO - L/CU.M
     PRESSURE  DROP  - KPA
     SUPERFICAL  GAS  VELOCITY - M/SEC
     PARTICULATE  INLET LOAD - G/CU.M
     PARTICULATE;  INLET LOAD - NG/J
     PARTICULATE.  OUTLET LOAD- G/CU.M
     PARTICULATE  OUTLET LOAD - NG/J
     502  OUTLET  CONTRATION - PPM
     Sit  OUTLET  CONCENTRATION- NG/J
     SOI  DESIGN  REMOVAL EFFICIENCY - X
     A3SORBER  SPARF  CAPACITY INDF.X - X
              SPARF  COMPONENT INDEX
•• FANS
    NUM9E R
    TYPF
    CONSTRUCTION  "ATERIALS
    SERVICE -  uET/DRY
    CAPACITY -  CU.M/S

•• VIST ELIMINATOR
    TYPE

•* ^IST ELIMINATOR
    NUMBER
    TYPE
    CONSTRUCTION  "ATE»1AL
    CONFIGURATION
    NUMBER OF  STAGES
    NUMBER OF  PASSES
    FREEBOARD  DISTANCE  - M
    DEPTH - M
         SPACING  -  CM
         ANGLES
    rfASH SYSTEM
    SUPERFICIAL GAS  VELOCITY - «/S
    PRESSURE DROP -  KPA

•• PROCESS CONTROL  CHEMISTRY
    CONTROL VARIABLES
    CONTROL RANGE
    CONTROL MANNER
    MODE
    SENSOR LOCATION
 STAINLESS STEEL
    13
 TANGENTIAL AND BULL  NOZZLES
    33.3
   394.4        (  835840  ACFM)
   148.9        (   }CO  F)
   841.7        (1336C  GPM)
     2.7        (20.il GAL/100CACF>
 *******        (***»*  IN-H20)
                dZ.iOO LB/MMPTU)
                (   .IOC LB/MMBTU)
51 59.
  43.
  99.7
2752.
  89.0
                 ( 6.401  LB/MMBTU)
 VENTUKI/SPRAY TOWER
  5/e?
 PEAeODY  PROCESS SYSTEMS
     4
 DIA  35'  HT 60'
 CARbON  STEEL
 RUBBER  LINED
 STAINLESS STEEL, CARBON STEEL  R  RUBBER  LINED
    24
 REFRAX  NOZZLES
    33.3
   302.08
    53.3
  21C4.
     6.7
     5.
               < 64C13C  ACFM)
               (  1C8 F)
               (334CO GPM)
               ( 50.0 GAL/1000ACF)
               (20.0 IN-H20)
                ( 12.0 FT/S)
                (  .030 GR/SCF)
                (  .IOC1 LB/MMBTU)
                (  .Q3C GR/SCF)
                (  .IOC
                <*•*»« LB/MMBTU)
     .0
    3.7
     .1
   43.
     .1
   43.
  345
*****
   89.0
   33.C
    1.0
CENTRIFUGAL  RADIAL TIP
INCONEL  6^5  R  INCOLY 825
WET
  JtO.33        (  6788CO ACFM)
SIEVE TRAY
CHEVRON
NORYL PLASTIC
HORIZONTAL
    1
    3
    1.52
     .30
    3.5
90
              ( 5.0 FT)
              ( 1.0 FT)
              ( 1.3.8 IN)
HOSE CONNECTION  TO  HEADER FOR MANUAL WASH
    3.4         (11.0  FT/S)
     .0         (   ,J  1N-H20)
PH-DENSITY IN  RECYCLE  TANKS
3-6 PH; 7-9X DENSITY
AUTOMATIC
FEE DBACK
RECYCLE TANKS
                                                132

-------
                                              EPA UTILITY  F60  SURVEY:  JULY - SEPTEMBER 1980

          POUER  S  LIGHT:  CLAY  B05UELL 4 (CONT.)
    PUMPS
     SERVICE

     ALKALI  FEED
     FLY  ASH  SLURRY  FEED
     VENTURI  RECYCLE
     ABSORBER RECYCLE
     rfASH  WATER
NUMBER

   2
   2
   6
  12
   2
*** *
    SERVICE

    RECYCLE
    ALKALI STORAGE
    J«SH WATER
    FLY ASH STORAGE

.* REHEATER
    DUMBER
    TYPE
    HEATING MEDIUM
    TEMPERATURE BOOST  -  C

• * WATER LOOP
    TYPE
    EVAPORATOR WATER LOSS  -  LITER/S
    RECOVERED WATFR RETURN - LITER/S
    FRESH MAKEUP  WATER  ADDITION  -  LITERS/S

•* REAGENT PREPARATION  EQUIPMENT
    NUMBER OF STORAGE  HOPPERS
    NUMBER OF SLAKERS
    SLAKER CAPACITY -  H  T/H
    REAGENT PRODUCT -  t  SLURRY SOLIDS
    POINT OF  ADDITION

•* DISPOSAL
    MATURE
    TYPE
    LOCATION
    TRANSPORTATION
    DIMENSIONS
    AREA  - ACRES
    CAPACITY  -  CU.M
                                                NUMBER

                                                    4
                                                    1
                                                    1
                                                    1
                                                  4
                                                 BYPASS
                                                 FLUE  GAS
                                                    14.4
                                                 CLOSED
                                                    23.9
                                                   188.1
                                                    56.4
                                                     5
                                                     4
                                                      .4
                                                   20.0
                                                 RECYCLE TANKS
                                                                    26 F>
                (   380 6PM)
                <  298S GPM)
                (   895 6PM)
                    .4 TPH)
                                                 FINAL
                                                 LINED POND
                                                 1  MILE WNW OF UNIT
                                                 PIPE
                                                 4000 X 3000 FT
                                                   300.0
                                                    9556522      <  7814.0  ACRE-FT)
.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                 x REMOVAL   PER   BOILER   FGD   CAP.
                 SO?  PART.  HOURS  HOURS   HOURS FACTOR
 4/BO  SYSTEM
                               7?0
       •* PROBLEMS/SOLUTIONS/COMMENTS
                          THE  BOILER  BEGAN OPERATIONS ON  FEBRUARY  26s  1980 AND FIRED OIL THROUGH THE
                          MONTH  OF  MARCH.  INITIAL FGD SYSTEM  OPERATIONS  BEGAN IN EARLY APRIL KITH
                          THE  BOILER  FIRING COAL FOR TESTING PURPOSES.   THE UNIT WAS SHUTDOWN IN
                          MID-APRIL TO RECTIFY MINOR SHAKEDOWN PROBLCMS.   A TRIAL RUN OF THE FGD
                          SYSTEM IN AN INTEGRATED MODE OCCURRED  IN LATE  APRIL.
 5/80   SYSTE"

 5/80   SYSTEM

        **  PROBLEMS/SOLUTIONS/COMMENTS
                               744

                               7ZO
                          SHAKEDOWN OPERATIONS CONTINUED  THROUGH THE SECOND CUARTER OF 1980.   THE
                          FGD SYSTEM WILL BE FINE  TUNED  TO  MEET  DESIGN CRITERIA THROUGH JULY.   TO
                          DATE THE UTILITY REPORTED  THAT, ALTHOUGH MANY TYPICAL STARTUP PROBLEMS
                          ATTRIBUTABLE TO OPERATOR ERROR  AS WELL AS MECHANICAL MALFUNCTIONS HAVE
                          OCCURRED, NO UNUSUAL PROBLEMS  HAVE  OCCURRED.  THE COMPLIANCE TEST IS
                          SCHEDULED FOR EARLY SEPTEMBER.
                                                 13J

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980


MINNESOTA POWER t LIGHT: CLAY BOSWELL 4  (CONT.)
....	...	.-	—	PERFORMANCE 6ATA	
PERIOft MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                         X REMOVAL   PER  BOILER   F6D    CAP.
                                                         S02  PART. HOURS HOURS   HOURS  FACTOR
7/80




1
Z
3
4
SYSTEM
87.8
97.8
100.0
.0
96.1
100.0
100.0
100.0

100.0
86.8
96.7
10C.O
.0
95.0




720 712 684 79.0
 S/8P  1
       2
       3
       4
       SYSTEM
 7/80
1
2
3
t,
SYSTEM
71.8
75.5
29.*
49.7
75.5

71.6
89.6
14.7
65.1
80.5
100.0
10P.O
100.0
100.0
100.0

100.0
100.0
100.0
100.0
10P.O
62.9
66.1
25.8
45.5
66.1

n.o
88.7
14.5
64.5
79.6
                                                                       744    652
                                                                              744    737
                                                                                    *»2   61.7
                                                                                           592   73.7
       •* PROBLEMS/SOLUTIONS/COMMENTS
                         THE FGO SYSTEM IS STILL IN THE DEBUGGING PHASE OF OPERATION.   MUCH  OF  THE
                         EQUIPMENT IS STILL BEING WORKED ON AND TESTED.
                                                134

-------
                                              EPA UTILITY FGD SURVEY: JULY - SEPTEMBER i?80

                                           SECTION 3
               DESISN  AND  PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY  NAME
PLANT  NAME
JHlT  NUMBER
CITY
STATE
CROSS  UNIT  GENERATING  CAPACITY - MW
NET UNIT GENERATING CAPACITY W/FGD - MW
            SCRUBBED CAPACITY - MW
•*  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HFAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

•»  GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     HEM/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     $02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESISN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 »*  HATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 **  DISPOSAL
     TYPE
- X
    MINNKOTA  POWER  COOPERATIVE
    MILTON  R. YOUNG
    2
    CENTER
    NORTH DAKOTA
       440.0
       402.0
       185.0
                    (  6500 BTU/LB)
COAL
LIGNITE
 15119.
    6.50
   38.00
     .70
     .01
WET SCRUBBING
LINE/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
NEW
    1.6
 9/77
 6/78
   36.13
   99.60
  100.0
    1.0
     CLOSED
        44.1
     MINEFILL
                    (  700 6PM)
„__	—	- — - —	——-PERFORMANCE  DATA-	~—	......_..._.._..._.._..-.
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
1/gO A 7.1 10.5 7.1
B .0 .0 .0
SYSTEM 7.1 10.5 10.5 7.1


744 504 53 58.5
       **  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  JANUARY A COLD yEATHER CAUSED SOME PIPE LINES AND A BOOSTER
                          FAN  ICE UP.

                          A  HUH  PERCENTAGE OF COARSE SOLIDS IN THE IHICKENER CAUSED SOME OUTAGE
                          TIME.   THE  WORM GEAR ON THE THICKENER FAILED ADDING TO THE OUTAGE TIME.

                          CLEANING AND  REPAIR OF THE THICKENER HAS COMPLICATED BY SUB-ZERO AMBIENT
                          TEMPERATURES.
 2/80   SYSTEM         .0          .0

        • »  PROBLE1S/SQLUTIONS/COMMENTS
               .0
                                   696   696
                                                  0  97.1
                          PROBLEMS RELATED TO THE COLD HEATHER CONTINUED  THROUGH  FEBRUARY.   ICE
                          ON THE BOOSTER FAN HAD TO BE MELTED BEFORE  IT COULD BE  OPERATED.

                          SHAFT SLEEVES ON SEVERAL SPRAY RECYCLE PUMPS WERE  REPLACED  DURING
                          FEBRUARY.

                          THE GEAR REDUCER FAILED ON THE B-SIDE ABSORBER  AGITATOR PREVENTING SCRUB-
                          BER OPERATION.

                          THE ISOLATION DAMPER CHAINS BROKE DURING  THE MONTH.
                                                135

-------
 EPA UTILITY  fGO  SURVEY:  JULY - SEPTEMBER  198C

*INNK3TA POWER  COOPERATIVE:  "111 TON R. YOUNG 2 (CONT.)
	.	PERFORMANCE  DATA	.	.
ȣRIOD MODULE AVAILABILITY  OPERABILITY RELIAP1L1TY  UTILIZATION   I REMOVAL   PER  BOILER   FGO    CAP.
                                                                  S02  PART. HOURS HOURS   HOURS  FACTOR
5/80 A 22.6 22. 6 22.6
B 6.2 6.2 6.2
SYSTEM 28.9 28.8 28. B 28.8


744 743 214 89.1
 t/80
5/80
          PROBLE'S/SOLUTIONS/COMMENTS

                          DURING  MARCH COLD HEATHER  CONTINUED  TO  BE  A PROBLEM.

                          THE  TORQUE SWITCHES ON THE  ISOLATION DAMPERS WERE REPLACED.  THE  DAMPER
                          PROBLEMS  CAUSED THE BOOSTER  FAN  TO  TRIP.   THE OUTA6E TIME WAS  EXTENDED
                          BECAUSE THE UTILITY HAD TO  WAIT  FOR  THE SWITCHES TO BE DELIVERED.

                          AN  EXCESSIVE AMOUNT OF COARSE  PARTICLES IN THE THICrENER CONTINUED  TO  BE
                          A PROBLEM.  PLUGGED BLEED  LINES  FROP THE  ABSORBER TO THE THICKENER  WERE
                          ALSO ENCOUNTERED.

                          THE  A-SIDE ABSORBER AGITATOR ANCHOR  BOLTS  SHEARED DURING MARCH CAUSING
                          MODULE  COWN TIME.

                          THE  SHAFT SLEEVES ON THE SPRAY RECYCLE  PUMPS WOULD NOT MOLD THE PUMP GLAND
                          PACKING.   THE SHAFT SLEEVES  ARE  CURRENTLY  BEING REPLACED.
       A
       B
       SYSTEM
100.0
   .0
100.P
  .0
  .G
  .3
  .0
  .c
  .0
  .0
  .0
                                                             720    154
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE  UNIT  WAS DOWN FOR APPROXIMATELY  3  WEEKS  FOR THE ANNUAL UNIT OUTAGE
                          DURING  APRIL.

                          PLUGGED BLEED  LINES AND THE REPLACEMENT  OF  THE  SHAFT SLEEVES ON THE
                          RECYCLE PUMPS  CAUSED THE F6D SYSTEM  TO REMAIN  OFF  LINE DURING THE TIME
                          THE  BOILER  OPERATED.
       A
       B
       SYSTEM
   .0
 47.2
 47.2
  .0
48.4
48.4
50.6
50.6
  .0
45.6
45.6
                                                                               744
                                                                                     700
                                                                                            339
       •• PROBLEMS/SOLUTIONS/COMMENTS
                         MODULE  B  WAS  OPERATED DURING MAY WHILE  REPAIR  WORK  WAS BEING DONE ON MODULE
                         A .

                         THE  REPAIRS  ON  MODULE A INCLUDED WORK  ON  THE  SPRAY  RECYCLE NOZZLE PIPING,
                         AND  THE RECYCLE HEADER.

                         THE  VALVES ON  BOTH THE SPRAY RECYCLE PUMP  AND  THE  DISCHARGE SPRAY CYCLE
                         PUMP WERE  REPAIRED.

                         THE  ABSORBER  LINING HAS STARTED TO WEAR AND  IS  NOW  BEING REPAIRED.

                         HIGH SOLIDS  RESULTED IN THICKNER LINE  PLUGGING.  HIGH SOLIDS ALSO CAUSED
                         PROBLEMS  WITH  THE  RAKE AND CONE.  BOTH  THE THICKNER AND THE CLARIFIER  HAD
                         TO BE DRAINED  AND  CLEANED.

                         THE  ABSORBER  AGITATOR TUNNEL WAS ALSO  CLEANED  DURING THE MONTH.
       A
       B
       SYSTEM
   .0
 41.B
 41.8
  .0
40.4
40.4
41.4
41.4
  .0
39.3
39.3
                                                                               720
                                                                                     701
                                                                                            283
       .*  PROBLEMS/SOLUTIONS/COMMENTS

                         MODULE B CONTINUED  TO OPERATE THROUGH JUNE.

                         PROBLEMS WITH  THE  THICKNER CONTINUED THROUGH  THE  MONTH.   HIGH SOLIDS CAUSED
                         PROBLEMS WITH  THE  RAKE  MECHANISM AND THE LIMIT  SWITCH.
                                                136

-------
                                                EPA  UTILITY FGD SURVEY: JULY  - SEPTEMBER 1980

4JNNKOTA POWER  COOPERATIVE: MILTON R. YOUNG  2  CCONT.)
__	PERFORMANCE DATA	
PERIOD  NODULE  AVAILABILITY OPERABIL1TY  RELIABILITY UTILIZATION  t  REMOVAL   PER  BOILER  F6D    CAP.
                                                                  SO?   PART. HOURS HOURS  HOURS  FACTOR


                          TROUBLE WAS  ENCOUNTERED DURING JUNE WITH  THE VACUUM FILTER.

                          THE REPAIR UORK  CONTINUED ON THE ABSORBER FLAKE  LININGS.

                          NODULE A  REPAIR  WORK CONTINUED DURING  JUNE.

 r/eo   A              >o          .0                       .0
        B            65.3        64.5         65.8        52.0
        SYSTEM       65.3        64.5         65.8        52.0                   7*4   600     387   60.0

        *• PROBLEMS/SOLUTIONS/CONMENTS

                          PROBLEMS  WITH  THE  RAKE MECHANISM AND  UNDERFLOW PUMPS  IN THE  THICKENER CON-
                          TINUED  IN JULY.   HIGH  SOLIDS IN THE  THICKENER ARE CAUSED  WHEN  FLY ASH IS
                          ADDED  TO  THE LIME  IN THE ABSORBER  TOWER.   THE ABSORBER  REAGENT IS CHANGED
                          TO  STRAIGHT  LIME WHEN  THIS  OCCURS.

                          PROBLEMS  WERE  ENCOUNTERED WITH  THE  TWO VACUUM FILTER  PUMPS.   ONE  WAS  BEING
                          REBUILT  WHILE  THE  OTHER  FUNCTIONED  POORLY.

                          REPAIRS  WERE MADE  TO THE LEAK  IN THE  ABSORBER TOWER.

                          PROBLEMS  WERE  REPORTED WITH THE MOTOR AND DISCHARGE VALVE ON THE  TRAY
                          RECYCLE  PUMPS.

                           THE FGD  SYSTEM WAS  NOT PLACED  IN  SERVICE WHEN THE  BOILER  WAS RUN AT REDUCED
                           LOAD  DURING THE MONTH.

  «/60  A            90.7         54.3        98.8         53.9
        B            56.9         44.2        99.4         44.0
        SYSTE"       99.2         9P.6        99.2         98.0                   744   739    729  92.8

        «•  PROBLEMS/SOLUTIONS/COMMENTS

                           30TH  MODULES  WERE OPERATED  DURING  AUGUST.

                           DURING THE  MONTH, MAINTENANCE  UORK WAS DONE OH  THE TEFLON PACKING  OF  THE
                           SPRAY RfCYCLE PUNPS.   THE  VACUUM  FILTER  DRUM,  SPRAY NOZZLES,  THE ABSORBER
                           AGITATOR, THE CLARIFJER  CONE,  AND  THE THICKNER  RAKE MECHANISM.

  9/80  A            70.1         72.6        11-0.0        66.9
        B            66.7         25.1        100.P        2'.2
        SYSTEM      100.0         97.9        1G*.0        90.3                    720   664    650  7P.5

        • *  PROBL£MS/SOLUT10NS/COM»ENTS

                           THE FGD  SYSTE"  WAS  AVAILABLE DURING  ALL  OF  SEPTEMBER.

                           BOTH MODULES  WERE  OPERATED DURING THE  MONTH.
                                                   137

-------
 EPA  UTILITY  F6D  SURVEY:  JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIGN  AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 SROSS UNIT GENERATING  CAPACITY - MM
 «ET UNIT  6ENERATIN6  CAPACITY  W/F6D  - MW
 EQUIVALENT SCRUBBED  CAPACITY  - My

 »* FUEL DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  - X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  - X

 •• GENERAL EMISSION  CONTROL SYSTEM  DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     502 DESIGN REMOVAL  EFFICIENCY - I
     PARTICIPATE DESIGN  REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDFX - X
     A3SORBER SPARE COMPONENTS  INDEX

 •• HATER  LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S
NONONGAHELA POWER
PLEASANTS
1
8ELMONT
WEST VIRGINIA
  618.0
  580.0
  618.0
COAL
BITUMINOUS
 27912.

   15.00
    3.70
***•*•*»
WET SCRUBBING
LIME
BABCOCK t W1LCOX
NEW
( 12000 BTU/LB)
 3/79
 3/79
   90.00
   99.55
     .0
     .0
CLOSED
               (.*.*• GPM)
.	PERFORMANCE DATA —	" ——— ———.__.	
»E»IOO MODULE AVAILABILITY  OPERABILIT*  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR
 1/60  SYSTEM

 2/80  SYSTE"

 3/80  SYSTE"

       ** PROBLEMS/SOLUTIONS/COMMENTS
                             74*

                             690

                             7*4
                         NO  INFORMATION  WAS  AVAILABLE ON THE OPERATIONS AT PLEASANTS  1  FOR  THE
                         FIRST  QUARTER OF  198C.

       SYSTE*                                                                 720

 5/80  SYSTEM                                                                 7*4

 S/6?  SYSTEM                                                                 720

       t* PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION WAS UNAVAILABLE  FOR THE SECOND QUARTER 1980 REPORT  PERIOD.

 7/80  SYSTEM                                                                 7*4

 S/80  SYSTEM                                                                 7*4

 J/8P  SYSTEM                                                                 720

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION FOR THE  MONTHS  OF  AUGUST AND SEPTEMBER IS NOT AVAILABLE  AT
                         THIS TIME.
                                                138

-------
                                                EPA  UTILITY FGO SURVEY: JULY -  SEPTEMBER  1980

*ONONG»HELA POWER:  PLEASANTS 1 (CONT.)
...	PERFORMANCE DATA	
ȣRIOO NODULE AVAILABILITY OPERAB1LITY RELIABILITY  UTILIZATION  * RtKOVAL    PER   BOILER  FGO   CAP.
                                                                  S02  PART.  HOURS  HOURS  HOURS FACTOR


                          AN EIGHT WEEK BOILER  AND FGD SYSTEM SCHEDULED  OUTAGE  BEGAN DURING THE WEEK
                          OF AUGUST 11.  THE  FGD  SVSTEH MAS EXPECTED TO  BE  DOWN FOR 8-12 WEEKS.
                                                  139

-------
  £PA  JTHITY  fGO SURVEY: JULY -  SEPTEMBER  19RC

                                             SECTION 3
                DESIGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
        NAME
PLANT NAME
JNIT XU»3ER
CITY
STATE
3HOSS IWT GENERATING  CAPACITY - MW
NET JNIT GENERATING  CAPACITY W/FGD -
EOUIVALENT SCRUBBED  CAPACITY - "fc

•* FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT CONTENT  -  J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT - T
    AVERAGE SULFUR CONTENT  - X
    AVERAGE CHLORIDE CONTENT - X
                                                  MONTANA POWER
                                                  COLSTRIP
                                                  1
                                                  COLSTRIP
                                                  "ION TANA
                                                    360.0
                                                    332.0
                                                    I6P.D
                                                  COAL
                                                  SUB6ITUMINOUS
                                                   20569.
                                                      9.60
                                                     2*.90
                                                       .77
                                                       .01
                                        <   ?843 BTU/LB)
 •• GENERAL  EMISSION CONTROL SYSTEM DATA
     4ENERAL  PROCESS TYPE
     PROCESS  TYPE
     SYSTEM  SUPPLIER
     MEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL  START-UP DATE
     COM»ERCIAL  START-UP DATE
     S02 DESIGN  REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER  SPARE  CAPACITY INDEX - X
     A9SORBER  SPARE  COMPONENTS INDEX
                   - X
                                                WET  SCRUBBING
                                                LIME/ALKALINE FLYASH
                                                COMBUSTION  EBUIP ASSOCIATES
                                                NEW
                                                     3.3
                                                 9/75
                                                11/75
                                                   60.00
                                                   99.50
                                                   20.0
                                                     .5
 •* WATER LOOP
     TYPF
     FRtSH MAKE-UP  WATER - LITER/S
                        CLOSED
                           23.3
                                                                 (  370 6PH)
 •• DISPOSAL
     TYPE
                                                  POND
	PERFORMANCE  DATA	
»ERIOD MODULE AVAILABILITY OPERAPILITY RELIABILITY  UTILIZATION  I REMOVAL   PER   BOILER  FED   CAP
                                                                  S02  PART. HOURS  HOURS   HOURS FACTOR
12/79 SYSTEM
1/80 SYSTEM
Z/80 SYSTEM
3/SO SYSTEM
95.9
96.5
97.4
95.4
744
744
696
744
          PROBLEMS/SOLUTIONS/COMMENTS
                          TOTAL  SYSTEM AVAILABILITY  CONTINUES  TO BE HIGH WITH NO MAJOR  F&D  SYSTEM
                          PROBLEMS REPORTED DURING THE  FIRST  QUARTER OF 1980.
 W6C  SYSTEM       99.8

       •» PROBLEMS/SOLUTIONS/COMMENTS
                                                      720
                          MO  MAJOR PROBLEMS WITH THE  F6D  SYSTEM WERE REPORTED BY THE  UTILITY  DURING
                          APRIL.
 5/80  SYSTEM

       •» PROBLEMS/SOLUTIONS/COMMENTS
                                                                               744
 6/80  SYSTEM
NO AVAILABILITY DATA  HERE  REPORTED BY THE UTILITY  BECAUSE OF A SCHEDULED
BOILER AND FGO SYSTEM OUTAGE FOR ROUTINE MAINTENANCE.

                                                      720
                                                140

-------
                                               EPA  UTILITY  F60 SURVEY: JULY - SEPTEMBER 1980

ONTANA POWER: COLSTRIP 1 (CONT.)
	.	-PERFORMANCE  OAT*	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  I REMOVAL   PER  BOILER  F6D   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         PERFORMANCE  INFORMATION  FOR THE MONTH OF JUNE HAS NOT AVAILABLE.

 7/80  SYSTEM                                                                 74*

 S/80  SYSTEM                                                                 7*4

 9/60  SYSTEM                                                                 720

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         INFORMATION  FOR THE THIRD QUARTER OF 1980 HAS NOT AVAILABLE.

-------
 EPA UTILITY  FED  SURVEY:  JULY - SEPTEMBER 1980

                                            SECTION 3
               DESIGN  AND PERFORMANCE  DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 SROSS UNIT GENERATING  CAPACITY  - MW
 YET UNIT GENERATING  CAPACITY  W/FGD  -  MU
 EBUIVALENT SCRUBBED  CAPACITY  -  MW
     MONTANA POWER
     COLSTRIP
     2
     COLSTRIP
     MONTANA
       360.0
       332.0
       360.0
 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE  CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE  CONTENT  -  X

 •* GENERAL EMISSION CONTROL SYSTEM  DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION -  *
     INITIAL START-UP  DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     A3SORBER SPARE COMPONENTS INDEX
- X
     COAL
     SUBBITUMINOUS
      20569.         (  8843  BTU/LB)
         a.60
        23.90
          .77
          .01
WET SCRUBBING
LINE/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
NEW
    3.3
 5/76
10/76
   60.00
   99.50
   20.0
     .5
 •• WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S
     CLOSED
        23.3
               (  370 6PM
 •* DISPOSAL
     TYPE
                                                 POND
..	fc	PERFORMANCE  DATA	———>-..-._..	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  x REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
12/79
1/80
2/6P
5/60
SYSTEM
SYSTEM
SYSTEM
SYSTEM
95.8
92.7
98. 1
9B.2
744
744
696
744
          PROBLEMS/SOLUTIONS/COMMENTS
                         TOTAL FGD SYSTEM AVAILABILITY  CONTINUES TO  BE  HI6H WITH NO MAJOR PROBLEMS
                         REPORTED FOR THE FIRST QUARTER  OF  1980.
 t/80  SYSTEM

       *•  PROBLEMS/SOLUTIONS/COMMENTS
                                  720
                         NO AVAILABILITY DATA WERE REPORTED  BY  THE  UTILITY BECAMSE OF A BOILER AND
                         FGD SYSTEM OUTAGE THAT WAS  SCHEDULED  FOR ROUTINE MAINTENANCE.
 5/80  SYSTEM      93.5

       «•  PROBLEMS/SOLUTIONS/COMMENTS
                                  744
                         NO MAJOR PROBLEMS WITH THE  F6D  SYSTEM  WERE  REPORTED BY THE UTILITY DURING
                         MAY.
 S/8C1  SYSTEM
                                                                              720
                                               142

-------
                                                EPA  UTILITY F6D SURVEY: JULY -  SEPTEMBER  1980

ONTANA POWER:  COLSTRIP  2 (COM.)
	1.	PERFORMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERABIL1TY RELIABILITY  UTILIZATION  X REMOVAL    PER   BOILER  FGD   CAP.
                                                                  SO?  PART.  HOURS  HOURS  HOURS FACTOR


       *•  PROBLEWSfSOlUTIONS/COMMENTS

                          PERFORMANCE INFORMATION FOR THE MONTH OF JUNE  WAS  NOT AVAILABLE.

 7/80  SYSTEM                                                                   744

 3/80  SYSTEM                                                                   744

 j/80  SYSTEM                                                                   720

       •*  PROBLEMS/SOLUTIONS/COMMENTS

                          INFORMATION FOR  THE  THIRD QUARTER OF  1980  WAS  NOT  AVAILABLE.
                                                  143

-------
  EPA  JTILITY FGD SURVEY: JULY  -  SEPTEMBER  19?C

                                             SECTION 3
                DESIGN »N£> PERFOR"ANCE  CATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
          NAME
  PLANT
  JIIJT
  CITY
  STATE
  SROSS  UNIT  GENERATING CAPACITY - MH
  NET U1IT  GENERATING CAPACITY y/FGD - M*
  EQUIVALENT  SCRUBBED CAPACITY - »W

  ••  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE MEAT  CONTENT - J/G
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE  CONTENT - X
     AVERAGE SULFU"  CONTENT - X
     AVERAGE CHLORIDE  CONTENT - T

  •• GENERAL  EMISSION CONTROL SYSTEM CATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM  SUPPLIER
     NEW/RETROFIT
     ENERGY  CONSUMPTION  - X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP  DATE
     S02 DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE DESIGN  REMOVAL EFFICIENCY
     A9SORBE* SPARE  CAPACITY INDEX - X
     ABSORBER SPARE  COMPONENTS INDEX

 ** HATER LOOP
     TYPE
     FRESH MAKE-UP HATER  - LITER/S

 •• DISPOSAL
     TYPE
     NEVADA POyER
     REID GARDNER
     1
     MOAPA
     NEVADA,
       125.0
       110.0
       125.0
     COAL
     BITUMINOUS
      28959.
         8.00
         5.50
          .50
          .05
     WET SCRUBBING
     SODIUM CARBONATE
     COMBUSTION EfiUIP  ASSOCIATES
     RETROFIT
(  12*50 BTU/LB)
      3/74
      4/74
        90.00
  X     97.00
          .0
          .0
     CLOSED
         9.8
     LINED POND
                     (   155  6PM)
                  	PERFORMANCE  DATA	—	_——.	_
PERIorMoi)iJLF~AVAILABILITY QPERABILITY RELIABILITY  UTILIZATION  t REMOVAL   PER  BOILER   FGD   CAP.
                                                                  S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80  SYSTEM      100.0        100.0

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                            10C.O
                                                        100.0
                                   744   744    744
                          THE BOILER AND  FGD  SYSTEM  OPERATED THE ENTIRE MONTH WITH NO  OUTAGES.

 2/BO  SYSTEM      100.0       1QO.O        100.C        100.0                  696    696     696

       •• PROBLEMS/SOLUTIONS/COMMENTS

                          DURING FEBRUARY,  NO OUTAGES  OCCURRED.

 i/80  SYSTEM       93.8        83.3        84.4         33.6                  744    300     250

       «• PROBLEMS/SOLUTICm/COMMENTS

                          DURING THE FIRST  OF MARCH  THE  F6D  SYSTEM WAS OFF LINE FOR  A  SCHEDULED
                          OVERHAUL.

                          THE fGD UNIT WAS  FORCED  OUT  OF SERVICE ONCE 10 REPAIR THE  VENTURI  PUMP
                          AND SIX OTHER TIMES DUE  TO LOW VENTURI FLOW.
 4/80   SYSTEM       97.3        96.4

        ••  PROBLEMS/SOLUTIONS/COMMENTS
96.8
            82.7
                                   720   618    596
                          LEAKS IN THE VENTURI LINE  FORCED  THE  FGD SYSTEM OUT OF SERICE  TWICE
                          DURING APRIL.
                                                 144

-------
                                               EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980

HEVAOA POWER: REID 6ARDNER  1  (CONT.)
.	_	—	PERFORMANCE  6ATA	.——	
PERIOD MODULE AVAILABILITY  OPtRABILITY RELIABILITY UTILIZATION   *  REMOVAL   PER  BOILER  FG6    CAP.
                                                                  SO?  PART. HOURS HOURS  HOURS  FACTOR


                          A  THERMOCOUPLE SHORTED OUT  DUE  TO  HIGH VENTURI GAS OUTLET TEMPERATURES.
                          THIS FORCED THE FGD SYSTEM  OUT  OF  SERVICE FOR SEVERAL HOURS.

                          THE BOILER WAS OUT OF SERVICE FOR  11?  HOURS DUE TO BOILER TUBE LEAKS.

 5/80  SYSTEM       97.7        93.9        97.4        84.7                  7*4   672     630

       •• PROBLEMS/SOLUTIONS/COMKENTS

                          THE FGD SYSTEM WAS DOUN  THREE TIMES  IN MAY BECAUSE OF LOU FLOW THROUGH THE
                          VENTURI.

                          A  BOILER TRIP CAUSED THE  FGD  SYSTEM  TO BE OUT APPROXIMATELY 97 HOURS.

 6/80  SYSTEM       92.1        92.7        92.7        88.3                  720   686     636

       *» PROBLEMS/SOLUTIONS/COMMENTS

                          THE NOZZLES  IN THE VENTURI  RACE TRACK  HAD TO BE  CLEANED  SEVERAL  TIMES THIS
                          MONTH.  TOTAL OUTAGE FOR  THIS WAS  APPROXIMATELY  48 HOURS.

                          THE FGD SYSTEM WAS FORCED OUT OF SERVICE WHEN THE EMERGENCY  SPRAY SYSTEM
                          FAILED.

                          THE FGD SYSTEM WAS OUT  OF SERVICE  TWICE  DURING  JUNE DUE  TO  BOILER OUTAGES.

 7/80   SYSTEM       87.1        94.9        86.7         84.0                  744    658     625

        *•  PROBLtMS/SOLUTlONS/COMMENTS

                          THE FGD SYSTEM WAS RETURNED TO  SERVICE ON JULY  3, 1980  AFTER  THE BOILER
                          TRIPPED THE  SYSTEM OFF  LINE.   THE GUILLOTINE  DAMPER HAD  TO  BE  REPAIRED
                          BEFORE  THE  FGD SYSTEM  COULD RETURN TO  SERVICE.

                          THE FGO SYSTEM WAS OFF  LINE FOR SEVERAL  HOURS  TO UNPLUG  THE VENTURI TRAY
                          AND RACETRACK.   MAINTENANCE MORK WAS  ALSO DONE  ON THE VENTURI  LINE.

                          A  SCHEDULED  BOILER  OUTAGE CAUSED THE  FGD SYSTEM TO BE OFF LINE FOR ONE
                          DAY.

                          THE FGD SYSTEM WAS  FORCED OUT OF SERVICE WHEN  THE EMERGENCY SPRAY SYSTEM
                          FAILED.   THE ASH SLUICE PUMP SHAFT WAS REPAIRED DURING  THIS TIME.

  8/80  SYSTEM      86.1         85.5         83.7         71.5                   744    622    532

        *» PR08LEMS/SOLUTIONS/COMMENTS

                          THE FGD SYSTEM HAS  OUT  OF SERVICE FOR  ALMOST  60 HOURS FOR ROUTINE CLEANING
                          AND MAINTENANCE.

                          LOSS  OF EMERGENCY SPRAY KEPT THE  FGD  SYSTEM OFF LINE  FOR SEVERAL HOURS.

                          BOILER  RELATED OUTAGES CAUSED  THE FGD SYSTEM  NOT TO  OPERATE FOR OVER  10C
                          HOURS.

                          THE  TRAY  SPRAY PUMP BELTS  WERE  REPAIRED.

                          A DAMPER  THAT FAILED TO  CLOSE  TRIPPED THE FGD SYSTEM OFF LINE DURING  THE
                          MONTH.

  >/80  SYSTEM      91.3         91.0        91.1         89.6                    72C   709     645

        ** PROBLEMS/SOLUTIONS/COMMENTS

                          THE FGO SYSTEM WENT OFf  LINE SEVERAL  TIMES IN  SEPTEMBER  FOR ROUTINE  CLEAN-
                          ING AND MAINTENANCE.   THIS ROUTINE  WORK INCLUDED CLEANING  THE  TRAYS  AND
                          REPAIRING VENTURI, ASH.  AND  EFFLUENT  LINES.
                                                  U5

-------
 EPA JTUITT  F60  SURVET:  JUL» - SEPTEMBER 1980

NEVADA POKER:  REID  GARDNER  1  (CONT.)
...———-—__————.——.	——.-PERFORMANCE  DATA———	———	-.————.—_.__._
PERIOD MODULE AVAILABILITY  OPERABILITr  RELIABILITY  UTILIZATION   X  REMOVAL   PER  BOILER  FGO   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR


                         A  BOILER OUTA6E KEPT  THE FGD  SYSTEM  OFF LINE FOR SEVERAL HOURS.
                                               1*6

-------
                                              cru uiiLlTY FGD SURVEY:  JULY  -  SEPTEMBER  1980

                                           SECTION 5
               DESIGN  AND  PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  F60  SYSTEMS
 COMPANY  NAME
 PLANT  NANE
 JNIT  NUK3ER
 CITY
 STATE
 5ROSS  UNIT 6ENERAT1N6 CAPACITY - MW
 »ET UNIT GENERATING CAPACITY W/F6D - MU
 EQUIVALENT SCRUBBED CAPACITY - MU

 **  FUEL  DAT*
    FUEL TYPE
    FUtL GfUOE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - I
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTEXT - X

 ••  GENERAL  EMISSION CONTROL SYSTEM DATA
    GENERAL  PROCESS TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEW/RETKOFIT
    ENERGY  CONSUMPTION - X
     1HIT1AL  START-UP DATE
     COMMERCIAL  START-UP DATE
     S32  DESIGN  REMOVAL EFFICIENCY - X
    PJRTICULATE DESIGN REMOVAL EFFICIENCY
     A3SORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX
   NEVADA POWER
   REID GARDNER
   2
   MOAPA
   NEVADA
     125.0
     110.0
     125.0
   COAL
   BITUMINOUS
    28S59.
       8.00
       5.50
        .50
        .05
   WET SCRUBBING
   SODIUM CARBONATE
   COMBUSTION EQUIP ASSOCIATES
   RETROFIT
(  12450 6TU/LB)
    4/74
   **/ **
      90.00
X     97.00
        .3
        .0
 •• WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER'S
   CLOSED
       9.8
                   C  155 GPM)
  * DISPOSAL
     TYPE
                                                 LINED  POND
.,_-— — — —	—	—— —	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABIL1TY  RELIABILITY  UTILIZATION  T REMOVAL   PER  BOILER   FGC    CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR
 1/80  SYSTEM      97.4        9*.5

       *• PROBLEMS/SOLUTIONS/COHMENTS
                                            96.9
                                                        81.6
                                                                              744
                                       642
                            607
                          DURING  JANUARY  THE  SCRUBBER WENT OFF LINE WITH THE BOILER TO  REPLACE  THE
                          REBUILT BOILER  HIGH PRESSURE HEATER.  THIS OUTAGE LASTED APPROXIMATELY
                          112  HOURS.

                          REPAIRS MERE  NEEDED ON THE LEFT HAND INTERCEPT VALVE ON THE TURBINE CAUSING
                          THE  SCRUBBER  TO COME OFF  LINE WITH THE BOILER.

                          THE  CLEANING  OF THE VENTURI RACE TRACK NOZZLES CAUSED TWO SCRUBBER OUTAGES.

                          THE  SCRUBBER  WENT OFF LINE SO MAINTENANCE COULD BE PERFORMED  ON  THE ID
                          FAN  DAMPER  CONTROLS.
 Z/80  SYSTEM       96.9         96.9

       ••  PROBLEMS/SOLUTIONS/COMMENTS
                                            96.9
           96.9
                                                                              696    696
                                                                                            675
                          THE SCRUBBER WAS TAKEN OFF-LINE TWICE  6URIN6  FEBRUARY  DUE  TO  A MALFUNCTION
                          OF  THE ID FAN CONTROLS.  THE PRESSURE  SENSING LINES  WERE  ALSO CLEANED
                          DURING THE OUTAGE.

                          THE SCRUBBER RACE TRACK NOZZLES HAD TO BE  CLEANED  TWICEt  CAUSING APPROX-
                          IMATELY 4 HOURS OUTAGE TIME.

                          THE DISCHARGE VALVE ON THE VENTURI  RECYCLE PUMP WAS REPLACED DURING
                          FEBRUARY.
                                                 147

-------
 EPA t/MLITy  fGt>  SURVEY:  JULY - SEP7EHPEP

NEVADA POrfER: REID  GARDNER  2  (CONT.)
	PERFORMANCE DATA	—_
»E9IOD MODULE AVAILABILITY  OPERAPILITY  RELIABILITY UTILIZATION  X  REMOVAL    PER  BOILER  FGO   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR


                         REPAIRS  MERE  «IAD£ ON THE SCRUBBER EMERGENCY  SPRAY  LINE CAUSING ABOUT 4
                         HOURS  OUTAGE  TIME.

                         THE  SCRUBBER  HAD TO BE SHUT DOWN SO REPAIRS  ON  THE  ID  FAN DAMPER CONTROLS
                         COULD  BE  1ADE.

 3/80  SYSTE*      98.4         97.5         97.5        97.5                   7*4   74*    725

       ** PROBLEMS/SOLUT IONS/COMMENTS

                         DURING MARCH  THE SCRUBBER WAS TAKEN OFF LINE  DUE TO  THE UNAVAILABILITY OF
                         THE  EMERGENCY  SPRAY SYSTEM.  DURING THIS  TIME MAINTENANCE WAS DONE ON THE
                         A  AND  B  ASH  SLUICE PUMPS.

                         LATER  IN  THE  MONTH AN OUTAGE WAS CAUSED BY A  LEAK  IN THE EMERGENCY SPRAY
                         LINE.

                         LOW  VENTURI  FLOW ALSO WAS A PROBLEM DURING MARCH.

 4/80  SYSTEM      99.0         99.0         99.0        93.5                   720   680    673

       *•  PROBLEMS/SOLUTIONS/COMMENTS

                         THE  FGD  SYSTEM  WAS UNAVAILABLE FOR 7 HOURS TO UNPLUG THE VENTURI RACE
                         TRACK.

                         THE  BOILER WAS  OUT OF SERVICE FOR *0 HOURS DUE  TO BOILER TUBE LEAKS.

 5/80  SYSTE*     100.0         8*.3           .0        14.3                   7*4   124    107

       «*  PROBLEMS/SOLUTIONS/COMMENTS

                         THE  FGD OVERHAUL WAS COMPLETED EARLY IN MAY.

                         A BOILER  OVERHAUL WAS STARTED AND COMPLETED DURING MAY.  THIS OUTAGE LASTFtt
                         ALMOST 23 DAYS.                                                            '"

 S/80   SYSTE-      99.6         97.5         9'-5        ".*                   '20   5*1    5Z8

       ••  PR08LEMS/SOLUTIOYS/COMMENTS

                         THE BOILER WAS  OUT OF SERVICE SEVERAL TIMES. DURING JUNE.  THIS CAUSED THE
                         FGD  SYSTEM TO BE OUT APPROXIMATELY 80 HOURS.

                         VENTURI RACE TRACK NOZZLES  NEEDED TO BE UNPLUGGED CAUSING THE FGD SYSTEM
                         OUT OF SERVICE  FOR SEVERAL  HOURS.

 7/80   SYSTEM      88.1         77.2         86.2        74.5                   7*4   718    55*

       **  PROBLEMS/SOLUTIONS/COMMENTS

                         BOILER RELATED  OUTAGES KEPT THE FGD SYSTEM OUT  OF SERVICE FOR OVER 100
                         HOURS  DURING JUNE.  OVER  HALF  OF THIS OUTAGE TIME WAS  A RESULT OF CONTROL
                         PROBLEMS  WITH THE  BOILER  AND FGD SYSTEM.  THE BOILER WAS RUN WITHOUT THE
                         FGO SYSTEM IN ORDER  TO DETERMINE IF THE CONTROL PROBLEMS HERE FGD OR BOILER
                         RELATED.  PROBLEMS WERE  REPAIRED IN BOTH CONTROL SYSTEMS.  THIS ALSO CAUSED
                         OVER 60 HOURS OF FGD SYSTEM RELATED DOWN TIME.

                         PROBLEMS  WITH THE  BOTTOM  HOPPER SEALS CAUSED THE FGD SYSTEM TO GO DOWN.

                         THE FGD SYSTEM  NEEDED TO  BE OFF LINE FOR 1} HOURS FOR  INSTRUMENT CHECKS
                         AND MAINTENANCE.

                         THE FGD SYSTEM  WAS FORCED OUT  OF SERVICE WHEN THE EMERGENCY SPRAY SYSTEM
                         FAILED.   THE ASH SLUICE  PUMP SHAFT WAS REPAIRED DURING  THIS TIME.

 S/80  SYSTEM      97.0         96.S         96.4        79.7                   744   613    591
                                                U8

-------
                                                EPA  UTILITY FGO SURVEY:  JULY - SEPTEMBER 1980

1EVADA POJER: REID  GARDNER 2 (CONT.)
	PERFORMANCE DATA	
•ER10D MODULE  AVULAB1L1TY OPERABILITV RELIABILITY UTILIZATION  X  R&KOVAL   PER  BOILER   FSB    CAP.
                                                                  S02   PART. HOURS HOURS  HOURS  FACTOR


       ** PROBLE«tS/SOLUTIONS/COni"ENTS

                          LOSS OF EMERGENCY  SPRAY KEPT THE F6D  SYSTEM  OFF LINE FOR ALMOST  20  HOURS.

                          BOILER RELATED  OUTAGES  CAUSED THE  FGD  SYSTEM NOT TO OPERATE  FOR  OVER  130
                          HOURS.

 9/EO  SYSTEM      100.0                                    .0                   720      D       0

       •* PROBLEIS/SOLUTIONS/CCmWENTS

                          THE FGD SYSTE*  WAS 1COX AVAILABLE  DURING  A  SCHEDULED BOILER  OVERHAUL  IN
                          SEPTEMBER.
                                                  149

-------
  EPA  UTILITY  FGD  SURVEY: JULY - SEPTEMBER  19«0

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FGD SYSTEMS
 COMPANY  MAKE
 PLANT  NAME
 U«IT NUMBER
 CITY
 STATE
 SUOSS  UNIT GENERATING  CAPACITY - My
 «ET UNIT GENERATING  CAPACITY W/FGD - Mw
 EflUIVALENT SCRUBBED  CAPACITY - MW

 •» FUEL  DATA
     fUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  - J/G
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

 *» GENERAL EMISSION  CONTROL SYSTEM DATA
     SENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     MEM/RETROFIT
     ENERGY CONSUMPTION  -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE DESIGN  REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ASSOR8ER SPARE COMPONENTS INDEX

 »• WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 *• DISPOSAL
     TYPE
                                     - X
                                                          (  12450  BTU/LB)
                                          NEVADA  PQyER
                                          REID GARDNER
                                          3
                                          MOAPA
                                          NEVADA
                                            125.0
                                            110. 3
                                            125.0
COAL
BITUMINOUS
 28959.
    8.90
    9.00
     .SO
     .05
WET SCRUBBING
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
NEW
*******
 6/76
 7/76
   85.00
   99.00
     .0
     .0
                                          CLOSED
                                              9.8
                                                 LINED POND
                                                          (   155  6PM)
..	 — PERFORMANCE DATA	
»ERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER  BOILER  FG»   CAP.
                                                                 502   PART.  HOURS  HOURS  HOURS FACTOR
 1/BO
SYSTEM     1DO.O         99.8

*• PROBLEMS/SOLUTIONS/COHMENTS
                                           100.0
                                                        91.4
                                                                               744
                                                                                     681
                                                                                            680
                          DURING  JANUARY  THE SCRUBBER AND BOILER WERE OFF  LINE  FOR  APPROXIMATELY
                          64  HOURS  TO  REPAIR AND BALANCE THE BOILER  ID  FAN.
 2/6?
SYSTEM     1CO.O         9P.1

•* PROBLEMS/SOLUTIONS/COMMENTS
                                           10C.C
       77.9
                                                                               696
                                    552
                                                                                            542
                         DURING  FEBRUARY TWO OUTAGES WERE NECESSARY SO  THE  ID  FAN COULD BE BALANCED.

                         THE  SCRUBBER  AND BOILER WENT OFF LINE SO THAT  THE  COAL  LEAKS  ON THE
                         BURNER  LINES  COULD BE REPAIRED.

                         HIGH  FURNACE  PRESSURE CAUSED THE SCRUBBER AND  BOILER  TO  TRIP  OFF.

 S/8P  SYSTE"     100.0        99.6        10".0        60.3                  744    450    448

       ••  PROBLE1S/SOLUTIONS/COHMENTS

                         THE  UNIT  AND  SCRUBBER WENT DOWN TWICE DURING MARCH.   THE FIRST OUTAGE WAS
                         TO BALANCE  THE  ID  FAN.  LATER IN THE MONTH THE ID  FANS  AND  THE
                         PRECIPITATORS  HAD  TO  BE REPAIRED.
 4/8C  SYSTEM
                  100. il
                                                          .0
                                                                               720
                                                150

-------
                                               EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

       POrfER: REID GARDNER  3  (COM.)
......	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERARILITY RELIABILITY UTILIZATION  *  REMOVAL    PER  BOILER  EGO   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR


       ** PROBLEIS/SOLUTIONS/COMNENTS

                          THE  FGD SYSTEI" WAS AVAILABLE 10CX  DURING  APRIL,  HOWEVER, DID NOT OPERATE
                          DUE  TO THE OVERHAUL OF BOTH THE DUST  COLLECTOR  AND THE ID FAN.

 5/80  SYSTEM         .0           .0          .0          .0                  74*   462      0

       *• PROBLEHS/SOLUTIOHS/COHHENTS

                          THE  FGD SYSTEM WAS DOWN THE ENTIRE MONTH  FOR THE  OVERHAUL OF THE FGD ID
                          FANS.  BECAUSE OF THIS, THE SYSTEM AVAILABILITY WAS ZERO FOR MAY.

 i/80  SYSTEM       75.2         81.4        81.4        72.2                  720   639    520

       *• PR03LE1S/SOLUTIONS/COM-ENTS

                          THE  ID FAN OVERHAUL WAS COMPLETED  EARLY  IN JUNE.

                          THE  BOILER WAS OUT OF  SERVICE  FOR  21  HOURS.

 7/80  SYSTEM       95.7         96.4        95.7        95.2                  744   735    721

       ** PROBLE^S/SOLUTIONS/COMHENTS

                          BOILER RELATED OUTAGES KEPT  THE  FGD SYSTEM OFF LINE FOR  SEVERAL  HOURS.

                          A HIGH VENTURl OUTLET  TEMPERATURE  FORCED THE FGD  SYSTEM  OFF  LINE DURING
                          PART OF JULT.

                          A HIGH VENTURI OUTLET  TEMPERATURE  FORCED THE FGD  SYSTEM  OFF  LINE DURING

 3/80   SYSTEM      103.0       10P.O        101.0       100.0                  744    744    744

        *•  PROBLEMS/SOLUTIONS/COMMENTS

                          THE  FGD SYSTEM WAS  AVAILABLE  DURING ALL  OF  AUGUST.

 9/gO   SYSTEM       96.S         96.8         96.8        96.8                  720   720    697

        «*  PROBLEMS/SOLUTIONS/COMMENTS

                          THE  FGD SYSTEM WAS  OUT OF SERVICE IN SEPTEMBER BECAUSE OF  ROUTINE  CLEANING
                          AND  MAINTENANCE.
                                                  151

-------
  EPA  JT1LITY FGO SURVEY: JULY  -  SEPTEMBER 1VC

                                             SECTION 3
                DESIGN AND PERFORMANCE  DATA  TOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
  COMPANY  NAWE
  PLANT  NAIE
  JNIT  NU"3ER
  CITY
  STATE
  JROSS  UNIT  GENERATING CAPACITY - Mw
  
-------
                                               EPA UTILITY  FGD SURVEY: JULY - SEPTEMBER  1980

ORTHERN INDIANA PUB  SFRVICE:  DEAN  H. MITCHELL 11 (CONT.)
..	PERFORMANCE  DATA	
»ERIOO MODULE  AVAILABILITY  OPERABILITY RELIABILITY  UTILIZATION  J REMOVAL   PER  BOILER   f6tt   CAP.
                                                                  SO?  PART. HOURS HOURS   HOURS FACTOR


 3/8^  SYSTEM       75.4        20.4        24.9         U.5                  744    529     108

       •*  PROBLEMS/SOLUTIONS/COMMENTS

                          THE BOILER WAS OPERATIONAL ON MARCH 1 AFTER THE HYDROGEN  LEAKS  WERE
                          REPAIRED.  THE BOILER  WAS  DOHN FROM MARCH 18 TO 23 SO  THAT THE  TURBINE
                          STOP VALVES COULD BE PULLED AND THE HYDROGE.N SEALS COULD  BE INSPECTED.

                          THE FGD SYSTEM WAS  FORCED  OUT OF SERVICE WHEN  A COMPRESSOR FAILED AND
                          AGAIN LATER AFTER AN INSTRUMENT MALFUNCTION.   THERE WAS  A COMPLETE POWER
                          IN THE FGD AREA  WHICH  FORCED THE SYSTEM DOHN FROM MARCH  26 THROUGH 27.

 4/8?  SYSTEM       63.3        52.6        53.4         50.3                  720    702     362

       «*  PROBLEMS/SOLUTIONS/CONMENTS

                          FGD SYSTEM OPERATIONS  DURING APRIL WERE INTERRUPTED BY SULFUR  ACCUMULA-
                          TION AND BLOCKAGE IN THE CLAUS CONVERTER UNIT.

 5/80  SYSTEM       62.B        23.5        26.4         15.5                   744    490    115

        «*  PR08LEMS/SOLUTIONS/COMMENTS

                          THE FGO  SYSTtM  REGENERATION FACILITY  EXPERIENCED  A  DRIVE MOTOR  FAILURE  ON
                          THE EVAPORATOR  CIRCULATING PUMP DURING  MAY.

  <>/80   SYSTEM       53.7           .0           .0          .0                   720    211       0

        **  PRD3LE*S/SOLUTIOKS/COMMENTS

                          THE BOILER  WAS  OFF  LINE MOST OF JUNE  DUE  TO  LOW SYSTEM POWER DEMAND.

                          THE AVAILABILITY OF THE FGD SYSTEM  WAS  LIMITED BY PROBLEMS  WITH THE
                          BOOSTER  BLOWER  DRIVE  AND LOOSENING  OF A SUPPORT BEAM  IN  THE ABSORBER.

  7/3°  SYSTEM       103.C           .0                        .0                   744    331       0

        **  PH09LtMS/SOLUTIONS/COM«EHTS

                          THE BOILER  OPERATED ON  LOW  SULFUR  COAL DURING JULY.   THE BOILER WAS OFF
                          LINE  FOR APPROXIMATELY  17  DAYS  DUE  TO LOW SYSTEM POWER DEMAND.

  J/6T  SYSTEM      83.9         65.6         65.6         31.0                   744    352     251

        *• PROBLEMS/SOLUIIONS/COM«ENTS

                          FROM  AUGUST 1 TO AUGUST 13  THE  BOILER FIRED LOW SULFUR COAL OR WAS
                          OPERATED AT LOW LOAD.   FGD  SYSTEM OPERATION W«S NOT NECESSARY  DURING  THIS
                          TIME.

                          FROM  AUGUST 14  TO  AUGUST  31,  HIGH SULFUR COAL WAS FIRED  MAKING FGD
                          SYSTE* OPERATION NECESSARY.  PROBLEMS WITH THE BOOSTER BLOWER  WERE
                           ENCOUNTERED »HEN THE  UTILITY ATTEMPTED TO BRING THE SYSTEM ON  LINE.  THE
                          BLOWER EXPERIENCED LOW  OIL PRESSURE  CAUSING THE SYSTEM NOT TO  BE OPERABLE
                          UNTIL AUGUST 19.

  >/80  SYSTEM      68.6        5?.1         55.1         45.1                  720    612     325

        •• PROBLE«S/SOLUTIONS/COMMENTS

                           THE BOOSTER BLOWER REARING AND GOVERNOR REPAIRS  ACCOUNTED FOR   SOME OUTAGE
                           TIME DURING SEPTEMBER.

                           THE SULFUR CONDFNSERS  IN  THE S02 REDUCTION UNIT  WERE  AN  ADDITIONAL PROBLEM
                           DURING SEPTEMBER.
                                                  153

-------
 EPA  UTILITY  FGD  SURVEY: JULY - SEPTEMBER 198C

                                            SECTION 3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUM3ER
 CITY
 STATE
 GROSS UNIT GENERATING  CAPACITY - *W
 VET UNIT GENERATING  CAPACITY  W/FGD  - MW
 EOUIVALENT SCRUBBED  CAPACITY  - MW
                              NORTHERN  STATES POWER
                              SHERBURNE
                              1
                              BECKER
                              MINNESOTA
                                740.0
                                700.0
                                740.0
 •*  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE  CONTENT  -  X
     AVERAGE SULFUR  CONTENT  -  X
     AVERAGE CHLORIDE  CONTENT  -  X

 •*  GENERAL EMISSION CONTROL SYSTEM  DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION -  X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY  - X
     P*RTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE  CAPACITY INDEX  - X
     ABSORBER SPARE  COMPONENTS INDEX
                        - X
                              COAL
                              SUBBITUMINOUS
                               19771.         <  8500 BTU/Ld)
                                 9.00
                                 25.00
                                   .80
                                   .03
UET SCRUBBING
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
NEW
    2.7
 3/76
 5/76
   50.00
   99.00
    9.0
    1.0
 *• HATER LOOP
     TYPE
     FRESH MAKE-UP HATER  - LITER/S
                              CLOSED
                              *******
                                             (****.* GPM)
 •• TREATMENT
     TYPE
                              FORCED  OXIDATION
 •• DISPOSAL
     TYPE
                              LINED  POND
		PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                              X  REMOVAL
                                              SO?  PART.
                             PER   BOILER   FGD   CAP.
                            HOURS  HOURS   HOURS FACTOR
 1/80  SYSTEM

 2/81  SYSTEM

 3/80  SYSTEM
97.0

97.0

98.0
                              74*

                              696

                              744
793

687

688
       ** PROBLEMS/SOLUTIONS/CONMENTS
9C.8

66.2

84.1
                          DURING  THE  FIRST QUARTER OF 1980 NO MAJOR PROBLEMS  HERE  ENCOUNTERED  WITH
                          THE  FGD SYSTEM.
 WBO  SYSTEM

 S/BO  SYSTEM

 6/80  SYSTEM
97.0

96.0

96.0
                          FROM  MID-SEPTEMBER TO MID-OCTOBER THE UTILITY HAS SCHEDULED  A  BOILER
                          OUTAGE  AT  WHICH TIME THE MARBLE BEDS WILL BE INSPECTED.

                          THE UTILITY  HAS DECIDED TO CONVERT THE ENTIRE MARBLE BED  SCRUBBING  SYSTEM
                          TO  A  SPRAY TOWER SYSTEM BY REMOVING THE MARBLE BEDS AND MODIFYING  THE  SPRAY
                          ARRANGEMENT.  TESTS CONDUCTED IN 1978 AND 1979 SHOW THAT  MOST  OF THE  S02
                          IS  COLLECTED IN THE VENTURI SECTION OF THE SCRUBBING TRAINS  AND THAT
                          ALTHOUGH  THE HARBLE BEDS IN THE ABSORBER SECTIONS IMPROVE  INTIMATE  S02/
                          SLURRY  MIXING S02  REMOVAL EFFICIENCY OF THE SCRUBBING TRAINS IS NOT
                          MARKEDLY  DIFFERENT WHEN MARBLE BEDS ARE REMOVED.
                              720

                              744

                              720
720

720

697
79.4

78.1

74.7
                                                154

-------
                                               EPA UTILITY F6D SURVEY:  JULY  - SEPTEMBER 1980

*JRTH£RN STATES POWER: SHERBURNE  1  (CONT.)
...	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITT RELIABILITY UTILIZATION  X  REMOVAL    PER  BOILER  FGO   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR


       «• PROBLEMS/SOLUTIONS/COMMENTS

                          NO MAJOR  OPERATIONAL PROBLEMS WERE  REPORTED  DURING THE SECOND ftUARTER
                          OF 1980.

 7/81  SYSTE"      100.0        1CP.O       100.0       100.0                   744   744    744  8?.1

       ** PROBLEMS/SOLUTIONS/COM-ENTS

                          NO OPERATIONAL PROBLEMS WERE ENCOUNTERED  IN  JULY.

 3/80  SYSTEM      100.0        1CO.O       100.0        99.2                   744   738    738  69.1

       «* PROBLEMS/SOLUTIONS/COMMENTS

                          THERE WERE TWO SHORT TERM OUTAGES  IN JULY DUE TO BOILER RELATED TRIPS.

 J/bC  SYSTE"      100.0        100.0       100.0        99.6                   720   717    717  76.8

       »* PROBLEMS/SOLUTIONS/COMMENTS

                          A BOILER RELATED PROBLEM CAUSED  THE ONLY  OUTAGE TIME  IN SEPTEMBER.
                                                 155

-------
  E»A  JTILITY FGD SURVEY: JULY - SEPTEMBER  198C

                                            SECTION  3
                DESIGN AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FGO  SYSTEMS
  CONPANY  NAME
  PLANT  NAME
  J1IT  YLH3ER
  CITY
  STATE
  SROSS  UNIT GENERATING CAPACITY - MW
  »ET UNIT  GENERATING CAPACITY W/FGD -
  EBUIW«LF.WT SCRUBBED CAPACITY - PW
                              NORTHERN STATES POWER
                              SHERBURNE
                              2
                              BECKER
                              MINNESOTA
                                7*0.0
                                700.0
                                740.0
 ••  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT - J/G
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE  CONTENT  - *
     AVERAGE SULFUR  CONTENT -  X
     AVERAGE CHLORIDE  CONTENT  - X
 ••  GENERAL EMISSION CONTROL  SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     ENERGY CONSUMPTION  -  X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL  EFFICIENCY  - X
     PARTICULATE DFSIGN  REMOVAL  EFFICIENCY
     A9SORBEP SPARE  CAPACITY  INDEX  - X
     ABSORBER SPARE  COMPONENTS  INDEX

 •* WATER LOOP
     TYPE
     FRESH MAKE-UP UATER - LITER/S
                         -  X
                              COAL
                              SUBBITUMINOUS
                               19771.         <  85CC BTU/LB)
                                  9.00
                                 as.oo
                                   .80
                                   .03
WET SCRUBBING
LIMESTONE/ALKALINE flYASH
COMBUSTION ENGINEERING
NEW
    2.7
 3/77
 4/77
   50.00
   99.00
    9.0
    1.0
                              OPEN
                                             (*•**• GPM)
 •• TREATMENT
     TYPE

 »• DISPOSAL
     TYPE
                              FORCED OXIDATION
                              LINED POND
	..	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERAB1L1TY RELIABILITY UTILIZATION
                                              X REMOVAL   PER  BOILER
                                              S02  PART. HOURS HOURS
                                          FGO   CAP.
                                         HOURS FACTOR
 1/80  SYSTEM

 2/8C  SYSTE"

 J/80  SYSTE"
97.0

96.0

98.0
                              7*4    744

                              696    696

                              744    744
       ** PROBLEMS/SOLUTI01S/COMMENTS
91.8

91.9
                          DURING THE FIRST QUARTER OF 1980 THE  FGO  SYSTEM  EXPERIENCED NO MAJOR
                          PROBLEMS.

                          A  FOUR WEEK BOILER OUTAGE IS SCHEDULED  FOR MAY AT  WHICH  TIME THE MARBLE
                          BEDS WILL BE REMOVED FROM THE FGD  SYSTEM.
 4/80  SYSTEM
                    96.0
                          THE  UTILITY HAS DECIDED TO CONVERT THE  ENTIRE  MARBLE  BED SCRUBBING SYSTEM
                          TO  A SPPAY TOWER SYSTEM BY REMOVING THE MARBLE  BEDS  AND MODIFYING THE SPRAY
                          ARRANGEMENT.  TESTS CONDUCTED AT UNIT  1 IN  1978 AND  1979 SHOW THAT HOST OF
                          THE  SOZ IS COLLECTED IN THE VENTURI SECTION  OF  THE  SCRUBBING TRAINS AND
                          THAT ALTHOUGH THE MARBLE BEDS IN THE ABSORBER  SECTIONS IMPROVE INTIMATE
                          SD2/SLURRY MIXING S02 REMOVAL EFFICIENCY  OF  THE SCRUBBING TRAINS IS N01
                          MARKEDLY DIFFERENT WHCN MARBLE REDS ARE REMOVED.
                                                                               720   704
                                                                                                 6P.6
                                                156

-------
                                              EPA UTILITY rGO SURVEY: JULY - SEPTEMBER  1980

NORTHERN STATES POWER: SHERBURNE 2 CCONT.)
	...	PERFORMANCE DATA	~————	——————
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  S REMOVAL   PER  BOILER   FGD    CAP.
                                                                S02  PART.  HOURS HOURS   HOURS  FACTOR


       •* PROBLENS/SOLUTIONS/COMMENTS

                         NO MAJOR OPERATIONAL PROBLEMS HERE  ENCOUNTERED  IN  APRIL.

 5/80  SYSTEM      96.0                                                       744    214          2*.2

 6/80  SYSTEM     100.0                                                       720     SI           2.8

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         THE  FGD SYSTEM HAS  OUT  OF  SERIVE HOST  OF HAY  AND  JUNE BECAUSE  OF THE ANNUAL
                         BOILER AND TURBINE  INSPECTION.

 7/80  SYSTEM     100.0        100.0        100.0        82.7                   744    615     615  63.8

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         BOILER TUBE LEAKS CAUSED  THE BOILER NOT  TO  OPERATE FOR 73 HOURS IN JULY.

                         BOTTOM ASH PLUGGING ALSO  FORCED THE BOILER  DOWN FOR 56 HOURS.

 8/80  SYSTEM     100.0        100.0        100.0       100.0                   744    744    744  70.7

 7/80  SYSTEM     100.0        100.0        100.0       100.0                   720   720    720 100.0

       ** PROBLEMS/SOLUTIONS/COMttENTS

                         THE  BOILER AND  FGD SYSTEM RAN  CONTINUOUSLY  THROUGH AUGUST AND  SEPTEMBER
                         WITHOUT  ANY  PROBLEMS.
                                                 157

-------
 EPA UTILITY  FED  SURVEY:  JULY  - SEPTEMBER 1980

                                            SECTION 3
                DESIGN  AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FED SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 CROSS UNIT GENERATING CAPACITY  -  MH
 NET UNIT GENERATING CAPACITY W/F6D -  MW
 EQUIVALENT SCRUBBED CAPACITY -  MM

 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT -  X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT -  X

 *• GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - I
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     SD2 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - .«
     ABSORBER SPARE COMPONENTS INDEX

 *• HATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 *• DISPOSAL
     TYPE
                                          PACIFIC POWER f
                                          JIM BRIDGER
                                          4
                                          ROCK SPRINGS
                                          WYOMING
                                            550.0
                                            507.8
                                            550.0
                                                                 LIGHT
                                                         (  9300 BTU/LB)
                              COAL
                              SUBBITUMINOUS
                               21632.
                                  9.00
                                 18.00
                                   .56
                                   .01
                                          WET SCRUBBING
                                          SODIUM CARBONATE
                                          AIR CORRECTION DIVISION, UOP
                                          NEW
                                               .2
                                           9/79
                                           2/80
                                             91.00
                                             99.00
                                               .0
                                               .0
                                          CLOSED
                                          *******
                                                LINED POND
                                                         (•**** 6PM)
...._.__,._—___-_._—	.....—......	—PERFORMANCE DATA——
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION
                                                          X REMOVAL   PER  BOILER  F6D   CAP.
                                                          S02  PART. HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 5/80  SYSTEM

       •• PROBLEMS/SOLUTIONS/COMMENTS
 1/80
                                                                       744

                                                                       696

                                                                       744
                         THE UNIT IS STILL IN THE SHAKEDOWN PHASE OF OPERATIONS.   A  NUMBER  OF
                         MECHANICAL PROBLEMS AND SOME CONTROL PROBLEMS  HAVE BEEN  ENCOUNTERED.
                         NO PROCESS-RELATED PROBLEMS HAVE OCCURRED.
41
42
45
SYSTEM
27.5
24.0
26.6
26.0
18.4
23.9
34.0
25.4
22.3
26.3
34.2
27.6
14.2
18.4
26.1
19.6
                                                                              720    553
                                                                                           141
          PROBLEMS/SOLUTIONS/COMMENTS
                         ALL THREE MODULES WERE OUT OF SERVICE THE FIRST 21 DAYS OF  APRIL  WHILE  THE
                         UTILITY WAITED FOR DELIVERY OF NEW .SPRAY NOZZLES.  SOME PLUGGING  HAD  OCCUR-
                         RED IN THE ORIGINAL NOZZLES.  THE NEW NOZZLES HERE INSTALLED  FOR  TESTING
                         PURPOSES.
 5/80   41
       42
       43
       SYSTEM
            95.2
            72.4
           100.0
            89.2
            46.0
            75.1
            81.6
            67.6
            9?.6
            71.7
           100.0
            88.1
            42.9
            70.1
            76.1
            63.0
                                                                       744    694
                                                                                           469
                                               158

-------
                                              EPA UTILITY FGD SURVEY: JULY -  SEPTEMBER  1980

PACIFIC POWER K LIGHT: JIM BRIDGER 4 (CONT.)
_„___„_„--_-——_—-- — —------—----PERFORMANCE  DATA——~————.-_.—————	
PERIOD MODULE AVAILABILITY OPERABIL1TV RELIABILITY UTILIZATION   X  REMOVAL    PER   BOILER   FGD    CAP.
                                                                 S02  PART.  HOURS  HOURS   HOURS  FACTOR


       *• PROBLEMS/SOLUTIONS/COMNENTS

                         NODULE 42 WAS FORCED OUT OF SERVICE FOR EIGHT DAYS IN MAY  WHILE A VORTEX
                         BREAKER WAS INSTALLED  IN THE  ABSORBER VESSEL.   THE VESSEL  HAS  DRAINING
                         BEFORE REACHING DESIGN  FLUID  LEVELS.

                         VORTEX BREAKERS WERE INSTALLED  IN MODULES 41  AND  43 AS  WELL BUT INSTALLA-
                         TION IN THESE MODULES  WAS NOT UNDERTAKEN  DURING PERIODS  WHEN MODULE  SERVICE
                         WAS REQUIRED.

       41           81.2         77.7         66.5         30.9
       42           89.2       100.0         85.1         43.2
       41           86.0         75.0         73.6        29.8
       SYSTEM       85.5         87.1         75.4         34.6                  744   296    258

       **  PROBLENS/SOLUUONS/COMMENTS

                          THE FGD  SYSTEM  WAS DOWN FOR 5 DAYS TO REPAIR  A  RECIRCULATION PUMP BREAKER
                          ON  MODULE  41.

                          MODULES  41  AND  42 WERE UNAVAILABLE FOR  A  COMBINED TOTAL OF 6 DAYS DUE TO
                          THE REPLACING  OF  THE PH CONTROL PIPING.

  7/80  41           97.3         67.2         96.0        64.8
        42           97.4         91.2         97.1        87.8
        4!           99.4         90.2         99.3        86.9
        SYSTEM      98.0         82.9         97.6        79.8                  744    717     594

        *•  PflOBLEHS/SOLUTIONS/COMMEMTS

                          NO MAJOR F6D-RELATED PROBLEMS WERE ENCOUNTERED IN JULY.

  j/80  41           99.7         92.8        99.7        86.1
        42           94.1         92.3        93.6        85.6
        43           94.7         68.4        92.4        63.5
        SYSTEM      96.2         84.5        95.2        78.4                  744    690     583

        •*  PROBLtMS/SOLUTIONS/COMMENTS

                          NO FGD RELATED PROBLEMS HERE REPORTED  FOR  THE  MONTH OF  AUGUST.

  J/80  SYSTEM                                                                720

        •* PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION WAS  AVAILABLE FOR SEPTEMBER 1980.
                                                 159

-------
  EPA  UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980

                                            SECTION 3
                DESIEN  AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC F6D SYSTEMS
  COMPANY  NAME
  PLANT  NAME
  J1IT NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING  CAPACITY  -  MU
  MET UNIT GENERATING  CAPACITY  W/FGD -  MU
  EQUIVALENT SCRUBBED  CAPACITY  -  MW

  •• FUEL  DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  -  Z

  •• GENERAL EMISSION  CONTROL SYSTEM DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     MEM/RETROFIT
     ENERCY CONSUMPTION -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN REMOVAL EFFICIENCY - I
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 • * WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 •• TREATMENT
     TYPE

 ** DISPOSAL
     TYPE
PENNSYLVANIA POWER
BRUCE MANSFIELD
1
SHIPPINGPORT
PENNSYLVANIA
  917.0
  825.0
  917.0
COAL
BITUMINOUS
 26749.
   12.90
    7.00
    3.00
< 11500 BTU/LB)
WET SCRUBBING
LIME
CHEMICO DIVISION, ENVIROTECH
NEW
    6.0
12/75
 6/76
   92.10
   99.80
     .0
     .0
OPEN
CALCILOX
LANDFILL
               (***«* 6PM)
————————————	———PERFORMANCE DATA	——___
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   FGD    CAP
                                                                S02   PART.  HOURS  HOURS   HOURS  FACTOR


 1/80  SYSTEM      98.6       100.0                    90.4                   744    672     672

 2/80  SYSTEM      9S.1       100.0                    93.7                   696    652     652

       •* PROBLEMS/SOLUTIONS/COHMENTS

                         NO MAJOR F6D-RELATED PROBLEMS OCCURRED DURING  JANUARY AND  FEBRUARY.

 3/80  SYSTEM      98.8       100.0                    83.7                   744    623     623

       • * PftOBLEMS/SOLUTIONS/COHHENTS

                         THE BOILER HAS OUT OF SERVICE ONE WEEK IN MARCH DUE  TO A PLUGGED  AIR
                         PREHEATER.  NO MAJOR F6D-RELATED PROBLEMS WERE REPORTED  FOR MARCH.

 4/80  SYSTEM                                                                 720

 5/80  SYSTEM                                                                 744

 4/80  SYSTEM                                                                 720

       *• PROBLEHS/SOLUTIONS/COMMENTS

                         INFORMATION FOR THE APRIL THROUGH JUNE PERIOD  HAS  NOT AVAILABLE.

 7/80  SYSTEM                                                                 744
                                               160

-------
                                              EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

PENNSYLVANIA POWER: BRUCE MANSFIELD 1 CCONT.)
...	.	... PERFORMANCE DATA	—	
PERIOD NOtULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION   t  RHOVAL    PER   BOILER   F6»   CAP.
                                                                 S02   PART.  HOURS  HOURS   HOURS  FACTOR


 J/80  SYSTEM                                                                 7**

 J/80  SYSTEM                                                                 720

       • * PROBLEMS/SOLUTIONS/COHMENTS

                         THE THIRD QUARTER UPDATE  INFORMATION IS NO* YET  AVAILABLE.
                                                 161

-------
  EPA  UTILITY  f6D  SURVEY:  JULY  -  SEPTEMBER  1980

                                            SECTION  3
               DESIGN  AND PERFORMANCE  DATA  FOR OPERATIONAL  DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 CROSS UNIT GENERATING CAPACITY - MU
 NET UNIT GENERATING CAPACITY U/FGD - NU
 EQUIVALENT SCRUBBED CAPACITY - HW

 •• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - I
     AVERAGE CHLORIDE CONTENT - X

 ** GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - t
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 •* WATER LOOP
     TYPE
     FRESH MAKE-UP HATER - LITER/S

 •* TREATMENT
     TYPE

 »» DISPOSAL
     TYPE
- X
     PENNSYLVANIA POWER
     BRUCE MANSFIELD
     2
     SNIPPINGPORT
     PENNSYLVANIA
       917.0
       825.0
       917.0
                    < 11500 8TU/L8)
COAL
BITUMINOUS
 26749.
   12.90
    7.00
    3.00
UET SCRUBBING
LIME
CNEHICO DIVISION, EMVIROTECH
NEU
    6.0
 7/77
10/77
   92.10
   99.80
     .0
     .0
     OPEN
     *******
     CALCILOX


     LANDFILL
                    (***•* GPM)
	.......	...	..	—PERFORMANCE DATA	———— —...—————...____..
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD    CAP
                                                                S02  PART. HOURS HOURS  HOURS FACTOR


 1/80  SYSTEM      97.1       100.0                    90.6                  744   674    674

 2/80  SYSTEM      94.7       100.0                    99.8                  696   694    694

       *• PROBLEMS/SOLUTIONS/COHMENTS

                         THE FGD SYSTEM EXPERIENCED NO MAJOR PROBLEMS DURING JANUARY AND FEBRUARY.

 5/80  SYSTEM      98.4       100.0                    51.1                  744   380    380

       •» PROBLEMS/SOLUTIONS/COHMENTS

                         THE BOILER HAS OUT OF SERVICE 16 DAYS IN MARCH FOR A SCHEDULED BOILER
                         INSPECTION.  NO MAJOR FGD-RELATED PROBLEMS HERE REPORTED.

 4/80  SYSTEM                                                                720

 5/80  SYSTEM                                                                744

 6/80  SYSTEM                                                                720

       *• PROBLEMS/SOLUTIONS/CONHENTS

                         INFORMATION FOR THE APRIL THROUGH JUNE PERIOD HAS NOT AVAILABLE.

 7/80  SYSTEM                                                                744
                                               162

-------
                                               EPA UTILITY F60 SURVEY: JULY  -  SEPTEMBER  1980

PENNSYLVANIA POWER: BRUCE MANSFIELD  2  CCONT.)
       ................	...—PERFORMANCE DATA—	——	___.__._.__.-.—————
       NODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER   BOILER  FCO   CAP.
                                                                 S02  PART.  HOURS  HOURS   HOURS FACTOR


 S/BO  SYSTEM                                                                  7«4

 7/80  SYSTEM                                                                  730

       •* PROBLEMS/SOLUTIONS/COHNENTS

                          THE  THIRD QUARTER UPDATE INFORMATION  IS NOT YET  AVAILABLE.
                                                 163

-------
 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
               DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 REGULATORY CLASSIFICATION
 'ARTICULATE EMISSION  LIMITATION - N6/J
 SO!  EMISSION.  LIMITATION -  NG/J
 MET  PLANT  GENERATING  CAPACITY  - MM
 SROSS  UNIT GENERATING CAPACITY  - MU
 NET  UNIT GENERATING CAPACITY W/FGD - MW
 NET  UNIT GENERATING CAPACITY WO/FGD  - MU
 EQUIVALENT SCRUBBED CAPACITY -  MW

 •* BOILER  DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL  SERVICE  DATE
     MAXIMUM BOILER FLUE  GAS  FLOW - CU.H/S
     FLUE GAS  TEMPERATURE - C
     STACK  HEIGHT  - M
     STACK  TOP DIAMETER  - M

 •• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT - J/G
     RANGE  HEAT  CONTENT  - BTU/LB
     AVERAGE ASH CONTENT  -  X
     RANGE  ASH CONTENT -  X
     AVERAGE MOISTURE  CONTENT -  X
     RANGE  MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     RANGE  SULFUR  CONTENT - X
     AVERAGE CHLORIDE  CONTENT -  X
     RANGE  CHLORIDE CONTENT - X

• • 6ENERAL  EMISSION CONTROL  SYSTEM DATA
     SALEABLE PRODUCT/THROWAWAY  PRODUCT
     GENERAL PROCESS TYPE
     PROCESS TYPE
     PROCESS ADDITIVES
     SYSTEM  SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEK/RETROFIT
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     S02 DESIGN  REMOVAL EFFICIENCY  -  X
     COMMERCIAL  DATE
     INITIAL START-UP

• • ESP
     NUMBER
     TYPE

»* PARTICLE SCRUBBER
     TYPE

• * ABSORBER
    NUMBER
    TYPE
    INITIAL START UP
    SUPPLIER
    NUMBER  OF STA6ES
    NUMBER  OF NOZ7LES
    PRESSURE DROP - KPA
    SUPERFICAL GAS VELOCITY  - H/SEC
    ABSORBER SPARE CAPACITY  INDEX - X
    ABSORBER SPARE COMPONENT INDEX

• • FANS
    NUMBER
    TYPE
- X
     PENNSYLVANIA POWER
     BRUCE MANSFIELD
     3
     SHIPP1NGPORT
     PENNSYLVANIA
     D
         32.         (
       258.         (
      2751.0
       917.0
       825.0
                   .075  LB/MMBTU)
                   .600  LB/MMBTU)
       917.0
     FOSTER WHEELER
     PULVERIZED COAL
     BASE
     **/ **
      1561.05
       140.6
       183.
                (3308000 ACFM)
                ( 285 F>
                ( 600 FT)
                (***** FT)
     COAL

      26749.        ( 11500 BTU/LB)
                     11.500-11t950
        12.50
     11.5-13.5
         7.00
     5.5-8.5
         3.00
     1.75-3.75
     ********
     ******
THROUAUAY PRODUCT
WET SCRUBBING
LIME
MG PROMOTED
PULLMAN KELLOGG
GILBERT/COMMONWEALTH ASSOCIATES
FULL SCALE
NEW
   95.00
   92.20
 6/80
 6/80
     COLD SIDE
     NONE
     SPRAY TOWER
      4/80
     PULLMAN KELLOGG
         6
       300
         7.0        (28.0 IN-H20)
         6.7        ( 22.0 FT/S)
         2.5
         1.0
                                               CENTRIFUGAL RADIAL TIP
                                              164

-------
                                              EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980

PENNSYLVANIA POWER: BRUCE MANSFIELD 3 CCONT.)

     SERVICE - MET/DRY                          DRV

 *• HIST ELIMINATOR
     TYPE                                       CHEVRON

 •* PUMPS
     SERVICE                                    NUMBER
     SLURRY RECIRCULATION                       •*•*
     ******                                     •***

 •* TANKS
     SERVICE                                    NUMBER
     REACTION                                   •»•»
     LIME SLURRY                                ****

 **  REHEATER
     TVPE                                       NONE

 **  THICKENER
     NUMBER                                       1

 *•  TREATMENT
     TYPE                                       FLVASM  STABILIZATION



__. ----- - — —————— ---------- _ ----- PERFORMANCE OAT* ------- — — — • -- --- - — — ---- -~ — — -- -
PERIOD  NODULE AVAILABILITY OPERABIL1TV  RELIABILITY  UTILIZATION   X REMOVAL   PER  BOILER  F6D   CAP.
                                                                      PART.  HOURS HOURS  HOURS FACTOR
  4/80   SYSTEM                                                                 720

        •*  PROBLEMS/SOLUTIONS/CONMENTS

                          INITIAL OPERATION OF THE F6D SYSTEM COMMENCED ON JUNE 9, 1980.  THE
                          UTILITY REPORTED THAT IT IS PRESENTLY IN THE PROCESS OF DEBUGGING THE
                          SYSTEM.

  7/80   SYSTEM                                                                 744

  3/80   SYSTEM                                                                 744

  9/80   SYSTEM                                                                 7ZO

        •*  PROBLEMS/SOLUTIONS/COHPENTS

                          THE THIRD QUARTER UPDATE INFORMATION IS NOC YET AVAILABLE.
                                                 165

-------
 EPA UTILITY FGD SURVEY:  JULY  -  SEPTEMBER  1980

                                            SECTION  3
               DESIGN AND PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 CROSS UNIT GENERATING CAPACITY - MM
 NET UNIT GENERATING CAPACITY U/F6D - MU
 EQUIVALENT SCRUBBED CAPACITY - MU
                               PUBLIC  SERVICE
                               SAN  JUAN
                               1
                               UATERFLOU
                               NEU  MEXICO
                                361.0
                                314.0
                                361.0
                                                                OF NEU MEXICO
 ** FUEL »ATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - I
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

 • * GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     STSTEM SUPPLIER
     NEU/RETIOFIT
     ENERGY CONSUMPTION - Z
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX
                              COAL
                              SUBBITUAINOUS
                               22795.
                                  18.00
                                  14.82
                                    .80
                                    .03
                              UET SCRUBBING
                              UELLHAN  LORD
                              DAVY MCKEE
                              RETROFIT
                                  4.4
                               4/78
                               4/78
                                 90.00
                                 99.80
                                100.0
                                  2.0
                                 (  9800  BTU/LB)
 •• HATER LOOP
     TYPE
     FRESH MAKE-UP UATER - LITER/S

 •• BYPRODUCT
     3VPRODUCT NATURE
     DISPOSITION
                              CLOSED
                                 30.2
                                              (  480 6PM)
                              ELEMENTAL SULFUR
                              MARKETED
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERAB1LITY RELIABILITY UTILIZATION
                                                                X REMOVAL   PER  BOILER   FGD    CAP.
                                                                S02  PART.  HOURS HOURS   HOURS  FACTOR
1/80




2/80




3/80




A
a
c
D
SYSTEM
A
B
C
D
SYSTEM
A
B
C
D
SYSTEM
81.0
96.0
.0
83.0
100.0
.0
99.0
3.0
99.0
67.0
.0
100.0
58.1
97.5
100.0
51.0
42.3
.0
79.3
86.3
.0
94.3
2.5
97.6
97.2
.0
50.4
82.8
85.5
100.0 100.0
41.8
34.7
.0
65.1
70.8 744 610 527
.0
85.9
2.3
88.9
88.6 696 634 616
.0
17.6
29.2
30.1
38.5 744 262 286 11. 0
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                         SCRUBBER OPERATIONS AT UNIT ONE ARE STILL LIMITED TO TUO MODULES BECAUSE
                         OF THE CURRENT LACK OF REHEATER CAPACITY.
 4/80  A
       B
       C
       D
       SYSTEM
   .0
 98.2
 50.0
 91.7
100.0
  .0
71.5
 7.2
71.5
75.1
                        100.0
  .0
48.2
 4.9
48.2
50.7
                                              720
                                                    485
                                                                        365  SS.8
                                               166

-------
                                              Cr« wTILITY F60 SURVEY: JULY - SEPTEMBER 1980

PUBLIC SERVICE OF NEW MEXICO: SAN JUAN 1 CCONT.i
...	.—	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY QPERABILITV RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD    CAP.
                                                                SO?  PART.  HOURS HOURS   HOURS  FACTOR


       ** PROBLEMS/SOLUT10NS/COMMENTS

                         ONLY TWO MODULES ARE NEEDED AT  THE  PRESENT  TIME TO MEET CURRENT SOZ
                         EMISSION REGULATIONS CSEE COMMENTS  FOR 00/78).

                         A TUBE WALL LEAK FORCED THE BOILER  OUT OF SERVICE  DURIN6  APRIL.

                         HIGH VIBRATIONS IN THE BOOSTER  BLOWER  IN MODULE D  FOLLOWED  AFTER  THE  UNIT
                         OUTAGE.

                         HIGH VIBRATIONS IN THE BOOSTER  BLOWER  CAUSED  MODULE  A TO  BE UNAVAILABLE
                         THE ENTIRE MONTH.

                         REPAIR AND MAINTENANCE OF  THE  BOOSTER  BLOU6R  AND  ISOLATION  DAMPERS IN
                         MODULE C WERE  PERFORMED  DURING  APRIL.

 5/80 A            73.1         62.1                     55.9
       B            99.7         37.2                     33.5
       C            75.5         71.8                     64.7
       D            80.2         19.9                     17.9
       SYSTEM     100.0         95.5        100.0         86.0                   7*4   670    640  87.4

       •* PROBLEMS/SOLUTIONS/COMMENTS

                          BOOSTER  BLOWER VIBRATIONS  ARE  CONTINUING IN ALL THE MODULES.

                          THERE  WAS  A  UNIT  OUTAGE  SO THAT REPAIR WORK COULD BE UNDERTAKEN ON THE ESP.

 A/BO
A
B
C
D
SYSTEM
2.8
96.9
82.5
.1
91.2
2.5
92.0
79.2
.2
87.0
2.1
75.6
65.0
.1
79.8 71.4
                                                                              720   591     514  65.4

        • • PROBLEMS/SOLUTIONS/COMMENTS

                          A BOILER TUBE LEAK FORCED THE UNIT OUT OF SERVICE  IN  JUNE.

                          REPAIR WORK WAS DONE ON THE ISOLATION DAMPBRS  DURING  JUNE.

  7/80
A
B
C
D
SYSTEM
.0
30.4
89.2
82. 8
100. 0
.0
16.0
87.9
79.6
91.7
.0
16.0
87.9
79.6
91.7
                                                                               744    744    683  91.7

        *• PROBLEMS/SOLUTIONS/COMMENTS

                          NODULE A WAS UNAVAILABLE  IN  JULY  BECAUSE  OF  REPAIRS MADE TO THE ISOLATION
                          DAMPER AND THE  LOWER  CHIMNEY SEAL.

                          MODULE B WAS FORCED OUT BECAUSE OF  HIGH VIBRATIONS IN THE BOOSTER BLOWER.
                          VIBRATIONAL PROBLEMS  ALSO KEPT MODULE D OFF  LINE UNTIL JULY 4, WHEN THE
                          BOOSTER BLOWER  WAS BALANCED.
  8/80
A
B
C
D
SYSTEM
.0
21.5
91.1
94.4
100.0
.0
21.5
77.8
90.1
94.7
.0
21.5
77.8
90.1
93.2 94.7
                                                                               744   744    704  82.0

         *•  PROBLEMS/SOLUTIONS/CONMENTS

                           NODULE A DID NOT OPERATE IN AUGUST BECAUSE OF REPAIRS HADE TO THE LOWER
                           CHIMNEY SEAL.

                           MODULE B WAS OUT OF SERVICE FOR OVER 3 WEEKS TO CLEAN, PAINT, AND BALANCE
                           THE BOOSTER BLOWER ROTOR.
                                                 167

-------
 EPA UTILITY FED SURVEY: JULY  -  SEPTEMBER  1980

PUBLIC SERVICE OF NEW MEXICO:  SAN JUAN  1  CCONT.)
	....—__._	_	.	PERFORMANCE DATA—	——	——————_.__.
PERIOD NODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FGO   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR


                         CRACKED VELDS  ON THE  WATER  INLET NOZZLES W6RE REPAIRED ON MODULE C.

                                                          .0
                                                        31.4
                                                        30.7
                                                        39.3
                                            94.8         50.7                  720   394    365  43.5

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         HI6H VIBRATIONS IN  THE  BOOSTER  BLOWER CAUSED MODULE C TO SHUT DOWN FOR
                         PART OF SEPTEMBER.

                         THE F6D SYSTEM WAS  DOWN FOR SEVERAL DAYS BECAUSE OF BOILER RELATED
                         PROBLEMS.

                         THE BOILER AND FGD  SYSTEM  WENT  DOWN ON SEPTEMBER 18. 1980 FOR SCHEDULED
                         MAINTENANCE AND WERE  UNAVAILABLE THE REST OF THE MONTH.
9/80




A
B
C
D
SYSTEM
.0
37.2
39.4
45.1
60.9
.0
57.4
56.1
71.8
92.7
                                               168

-------
                                              EPA  UTILITY  FED  SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
              DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC  F6D SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING  CAPACITY  -  MU
NET UNIT GENERATING  CAPACITY  U/F6D -  MU
EDUIVALENT SCRUBBED  CAPACITY  -  MU

• •  FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT  -  J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR  CONTENT  -  X
    AVERAGE  CHLORIDE CONTENT  -  X

•*  GENERAL EMISSION CONTROL SYSTEM  DATA
    GENERAL  PROCESS TYPE
    PROCESS  TYPE
    SYSTEM SUPPLIER
    HEU/RETROFIT
    ENERGY CONSUMPTION -  X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE  DESIGN REMOVAL  EFFICIENCY
    ABSORBER SPARE  CAPACITY INDEX - X
    ABSORBER SPARE  COMPONENTS INDEX

 «•  WATER  LOOP
     TYPE
    FRESH  MAKE-UP WATER  - LITER/S

 »*  BYPRODUCT
     1YPRODUCT NATURE
     DISPOSITION
                                    - X
                                        PUBLIC  SERVICE  OF  NEU  MEXICO
                                        SAN JUAN
                                        2
                                        UATERFLOU
                                        NEU MEXICO
                                           350.0
                                           306.0
                                           350.0
                                         COAL
                                         SUBBITUMINOUS
                                          22795.
                                            18.00
                                            U.82
                                              .SO
                                              .05
                              UET  SCRUBBING
                              UELLMAN  LORD
                              DAVY NCKEE
                              RETROFIT
                                  4.6
                               8/78
                               8/78
                                 90.00
                                 99.SO
                                 33.0
                                  1.0
                                         CLOSED
                                            30.2
                                             <   9800  BTU/LB)
                                             (  480 GPM)
                                         ELEMENTAL SULFUR
                                         MARKETED
........	....-.-.._....	.	_	-PERFORMANCE  DATA——
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
                                                         X REMOVAL
                                                         502  PART.
                                                          PER  BOILER   F6D    CAP.
                                                         HOURS HOURS   HOURS  FACTOR
 1/80
E
F
G
H
SYSTEM
 92.0
100.0
   .0
   .0
 96.0
63.0
  .0
  .0
  .0
31.5
62.4
  .0
  .0
  .0
31.2
                                                                              744   737
                                                                                           232
       • * PROBLEMS/SOLUTIONS/COMMENTS
                         THE  F-NODULE  UAS  AVAILABLE.  HOWEVER, FGD SERVICE UAS NOT REQUIRED BECAUSE
                         A  BOILER-RELATED  POKER  FAILURE FORCED THE BOILER TO OPERATE AT LOU LOAD.
 2/60
 3/80
E
f
G
H
SYSTEM

E
F
G
H
SYSTEM
 97.0
 22.0
   .0
   .0
 59.5

 87.0
 8S.O
   .0
   .0
 86.0
65.7
12.3
  .0
  .0
39.0

  .0
93.6
  .0
  .0
46.8
64.5
12.1
  .0
  .0
38.3

  .0
59.4
  .0
  .0
29.7
                                                                              696   683
                                                                              744    472
267
                                                                                            221   33.0
        •*  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING THE FIRST QUARTER ONLY ONE ABSORBER COULD BE  OPERATED  DUE  TO AN
                          ELECTRICAL PROBLEM.  CURRENTLY, OPERATIONS ARE LIMITED  TO  TUO ABSORBERS
                          UNTIL NEU REHEATERS ARE INSTALLED.  REHEATEJt INSTALLATION  IS  EXPECTED TO
                                                169

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980



PUBLIC SERVICE OF NEW MEXICO: SAN JUAN  l  (CONT.)
PERIOD

4/80
MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION X REMOVAL PER BOILER FGD CAP.
$02 PART. HOURS HOURS HOURS FACTOR

E
F
G
H
SYSTEM
BE COMPLETED IN APRIL.
99.3 91.3 68.5
99.9 71.1 53.3
.0 .0 .0
44.2 58.5 43.9
100.0 90. 8 98.8 68.1

720 540 490 66.

3
•• PROBLEMS/SOLUTIONS/COMMENTS


MODULE G IS DOWN FOR MAJOR REPAIRS WHICH WERE
EARLIER IN THE YEAR.
A RESULT OF AN INTERNAL FIRE
A REGULATION CHANGE EFFECTIVE APRIL 18, NOW REQUIRES THAT THREE MODULES
OPERATE TO MEET S02 REGULATIONS (SEE COMMENTS FOR 00/76).
MODULE H WAS UNAVAILABLE IN THE BEGINNING OF THE MONTH.
5/80
E
F
&
H
SYSTEM
99.1 97.3 86.7
98.9 95.2 84.8
.0 .0 .0
98.9 91.9 81.9
99.0 94.8 100.0 84. 5
744 663 628 79.
1
*» PROBLEMS/SOLUTIONS/COMMENTS
THE BOILER WAS DOWN FOR SEVERAL HOURS FOR MINOR MAINTENANCE AND BOILER TUBE
REPAIRS.
i/80
E
F
G
H
SYSTEM
89.2 72.4 56.0
89.6 74.1 57.4
.0 .0 .0
88.8 83.8 64.9
89.2 76.7 98.3 59.4
720 557 428 69.
6
•* PROBLEMS/SOLUTIONS/COMMENTS

7/80

E
F
G
H
SYSTEM
AN ELECTRICAL CABLE FAILURE PREVENTED MODULES
SIMULTANEOUSLY. AUXILIARY POWER COULD ONLY BE
97.6 55.4 49.1
96.9 85.0 75.3
.0 .0 .0
98. 9 91.0 80.6
97.8 77.1 68.3
E AND F FROM OPERATING
PROVIDED TO ONE MODULE.
744 659 508 79.

8
** PROBLEMS/SOLUTIONS/CONMENTS
THE BOILER WAS DOWN FOR SEVERAL DAYS IN JULY TO REPAIR TUBE LEAKS.
THE POWER CABLE WHICH FAILED IN JUNE WAS REPAIRED THIS MONTH. THIS CABLE
PERMITS OPERATION OF THE E AND F MODULES WITH THE H MODULE.
J/80
E
F
G
H
SYSTEM
98.4 90.2 85.8
97.8 72.7 69.1
.0 .0 .0
98.3 92.6 88.0
98.2 85.2 100.0 81.0
744 707 602 88.
7
•* PROBLEMS/SOLUTIONS/COHMENTS

»/80

E
F
G
H
SYSTEM
TUBE LEAK REPAIRS IN THE BOILER CAUSED THE FGD
TWO DAYS.
99.0 56.1 51.9
99.3 56.1 51.9
•0 .0 .0
97.6 56.2 52.1
98.6 56.1 62.5 51.9
SYSTEM NO TO OPERATE FOR
720 667 374 85.

5
                                               170

-------
                                              EPA UTILITY  F60  SURVEY:  JULY  - SEPTEMBER  1980

PUBLIC SERVICE OF NEV MEXICO: SAN JUAN Z (CONT.)
.	.	PERFORMANCE  DATA	——
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   t  REMOVAL   PER  BOILER  F60   CAP.
                                                                 $02  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         ESP PROBLEMS  CAUSED  ERRATIC OPERATION  OF  THE F6D SYSTEM FOR SEVERAL DAYS
                         IN SEPTEMBER.

                         THE F6D SYSTEM  WAS NOT  OPERATED  DURING A  SCHEDULED OUTAGE OF THE CHEMICAL
                         PLANT.  THE SYSTEM MAS  AVAILABLE DURING THIS TIME.

                         NODULE 6  HAS  UNAVAILABLE  IN  SEPTENBER  BECAUSE OF ONGOING REPAIR OF FIRE
                         DAMAGE.
                                                 171

-------
  EPA  UTILITY  FGD  SURVEY:  JULY  - SEPTEMBER  1980
               OESI6N  AND  PERFORMANCE  DATA
                                            SECTION 3
                                            FOR OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 SROSS UNIT GENERATING  CAPACITY  -  MM
 NET UNIT GENERATING CAPACITY  U/FGD -  MW
 EQUIVALENT SCRUBBED CAPACITY  -  My
                                          PUBLIC SERVICE OF NEW MEXICO
                                          SAN JUAN
                                          3
                                          WATERFLOW
                                          NEW MEXICO
                                            534.0
                                            468.0
                                            534.0
 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE  CONTENT  -  S
     AVERAGE SULFUR  CONTENT  -  X
     AVERAGE CHLORIDE  CONTENT  -  X

 •* GENERAL EMISSION CONTROL SYSTEM  DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     MEW/RETROFIT
     ENERGY CONSUMPTION -  X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX
                                     -  X
                                          COAL
                                          SUBBITUMINOUS
                                           18641.
                                             22.45
                                             14.82
                                               .80
                                               .07
                              WET  SCRUBBING
                              WELLMAN  LORD
                              DAVY NCKEE
                              NEW
                                  3.6
                              12/79
                              **/ **
                                 90.00
                                 99.50
                                  .0
                                  .0
                                             <  8>00 BTU/LB)
 »• BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
                                          SULFURIC  ACID
                                          MARKETED
	PERFORMANCE  DATA	——.—.	-•.._
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X  REMOVAL    PER  BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR
 1/80
       M
       SYSTEM
            86.0
            86.0
            54.4
            54.4
                        41.5
                        41.5
                                                                              744
                                                                                    568
                                                                                           309
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE FGD SYSTEM FIGURES REFLECT  THE  OPERATION  OF  A  SINGLE MODULE.  ONLY ONE
                         MODULE WILL BE NEEDED UNTIL MAY  1982  TO  MEET  CURRENT 502 EMISSION
                         REGULATIONS.
 2/80


 3/80
M
SYSTEM

M
SYSTEM
98.0
98.0

85.5
85.5
13.6
13.6

78.3
78.3
                                           79.6
                                           79.6
 1.0
 1.0

56.7
56.7
696
       44
                                                           744    539
                                                                                           *22  53.0
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                         THE ONE NODULE CURRENTLY OPERATIONAL  AT  SAN  JUAN  3  OPERATED WITHOUT ANY
                         MAJOR PROBLEMS DURING THE FIRST QUARTER  OF 1980.   THE  BOILER HAS OFF LINE
                         FOR APPROXIMATELY 24 DAYS IN FEBRUARY  DUE ffO  AN ELECTRICAL  PROBLEM.
 4/80
       N
       SYSTEM
            92.1
            92.1
            82.7
            82.7
            90.1
            90.1
71.8
71.8
                                                                       720   625
                                                                                           517  77.0
       *• PROBLEMS/SOLUTIONS/COMMENTS
                         MINOR REPAIR WORK WAS DONE TO  THE BOILER  THIS  MONTH.   FGD SYSTEM AVAILABIL-
                         ITY WAS OVER 90S.
 5/80
       N
       SYSTEM
           100.0
           100.0
            78.1
            78.1
           100.0
           100.0
32.7
32.7
                                                                       744
                                                                             311
                                                                                           243  35.0
                                               172

-------
                                              EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980

PUBLIC SERVICE OF NEW MEXICO: SAN JUAN 3 (CONT.)
_._...—	........	PERFORMANCE 6ATA	—	
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   X  REMOVAL    PER   BOILER   F6»   CAP.
                                                                 $02  PART.  HOURS  HOURS   HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER HAS OUT  OF  SERVICE FOR  A  SCHEDULED MAINTENANCE OUTAGE.

 j/80  M           49.0         43.3        39.2       27.6
       SYSTEM      49.0         43.3        39.2       27.6                  720    460    127  $5.0

       •* PROBLEMS/SOLUTIONS/COMHENTS

                         MINOR  REPAIR  AND  MAINTENANCE  OF THE  BOILER  CAUSED SYSTEM OUTA6E TIME.

                         THE  F6D  SYSTEM DID  NOT OPERATE  AFTER JUNE *9  DUE TO FAILURE OF THE HIST
                         ELIMINATOR MESH PADS  AND BOTTOM BALLAST TRAY.

 7/80  *           75.5         89.B         89.8        74.5
       SYSTEM      75.5         89.8         89.8        74.5                  744   617    544  66.0

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE  FGD  SYSTEM WAS  RETURNED TO  SERVICE ON JULY STH AFTER BOILER AND  FGD
                         SYSTEM REPAIRS HERE MADE.

 1/80  H           83.2         81.6         82.7        80.2
        SYSTEM       83.2         81.6         82.7        80.2                  744    732     597 81.9

        •»  PROBLENS/SOLUTIONS/COMNENTS

                          BEARINGS ON  THE  CIRCULATING PUMP MERE  REPLACED DURING AUGUST.

                          A PUMP DISCHARGE VALVE WAS REPLACED DUE  TO LEAKAGE.

  9/80  N           96.7        59.4         59.1        45.7
        SYSTEM      96.7        59.4         59.1        45.7                  720   549     329  61.6

        **  PROBLEMS/SOLUTIONS/CONMENTS

                          THE FGD SYSTEM HAS DOWN  FOR SEVERAL DAYS IN  SEPTEMBER BECAUSE  OF BOILER
                          TUBE  LEAKS.

                          THE FGD SYSTEM WAS NOT  OPERATED DURING A SCHEDULED OUTAGE OF THE CHEMICAL
                          PLANT.  THE  SYSTEM WAS  AVAILABLE  DURING THIS TIME.
                                                  173

-------
  EPA  UTILITY  F6D  SURVEY:  JULY  -  SEPTEMBER  1980

                                            SECTION  3
                DESIGN  AMD PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 CROSS UNIT GENERATING CAPACITY - MM
 NET UNIT GENERATING CAPACITY W/F6D - MW
 EBUIVALENT SCRUBBED CAPACITY - MU

 »• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/B
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - t
     AVERAGE CHLORIDE CONTENT - X

 •» GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     MEM/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - t
     ABSORBER SPARE COMPONENTS INDEX

 ** WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 •• DISPOSAL
     TYPE
                                     -  X
                                          SALT RIVER PROJECT
                                          CORONADO
                                          1
                                          ST.  JOHNS
                                          ARIZONA
                                            350.0
                                            350.0
                                            280.0
                                          COAL
                                          SUBBITUMINOUS
                                           19306.
                                             25.00
                                             16.00
                                              1.00
                                       (   8300 BTU/LB)
                        UET  SCRUBBING
                        LIMESTONE
                        PULLMAN  KELLOGG
                        NEW
                            4.3
                        11/79
                        13/79
                          66.00
                          99.87
                            .0
                            .0
                                         OPEN
                                             17.0
                                                LINED POND
                                       (  270 GPM)
....	....	.	PERFORMANCE DATA	————————.._.	.	
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP
                                                                SO?  PART. HOURS HOURS  HOURS  FACTOR
 1/BO

 2/BO

 3/80
 4/80

 5/80

 6/80
SYSTEM

SYSTEM

SYSTEM

*• PROBLEMS/SOLUTIONS/COMMENTS
                                                    744

                                                    696

                                                    744
                         DURING THE PERIOD STACK EMISSION TESTS WERE COMPLETED.
                         INFORMATION HAS AVAILABLE.
                                                                          NO OPERATIONAL
SYSTEM

SYSTEM

SYSTEM

• • PROBLEMS/SOLUTIONS/COMMENTS
                                                    720

                                                    744

                                                    720
 7/80

 J/80

 9/60
SYSTEM

SYSTEM

SYSTEM
ALTHOUGH FGD SYSTEM PERFORMANCE DATA ARE BEING LOGGED. THE UTILITY REPORTED
THAT THE INFORMATION IS UNAVAILABLE FOR RELEASE AT THIS TIME.

                                                    744

                                                    744

                                                    720
                                               174

-------
                                               EPA  UTILITY F60 SURVEY: JULY - SEPTEMBER 1980

SILT RIVER PROJECT: CORONAOO 1  (CONT.)
...	.	f	PERFORMANCE DATA—	—	
PERIOD NODULE AVAILABILITY OPERA8ILITV  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FG0    CAP.
                                                                 SOZ  PART. HOURS HOURS  HOURS  FACTOR
«_.._ — — — ^• — •— • "•••••—••• • *«*«••__._•.  .»•.•*___«»•«« »—*«»*»• — — -. ••	••••» »••» •••««•• •••••  •••»••

       •» PROBLEHS/SOLUTIONS/COHMENTS

                         THE  UTILITY WILL HOT AUTHORIZE THE RELEASE OF F«D PERFORMANCE DATA AT
                         THIS TIME, BUT NOTED THAT THE SYSTEM IS TO SHUT BOHN ON NOVEMBER  1, 19SO
                         FOR  A MAJOR OVERHAUL.
                                                 175

-------
 EPA UTILITY f60 SURVEY: JULY - SEPTEMBER  1980

                                           SECTION 3
               DESI6N AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 REGULATORY CLASSIFICATION
 PARTICULATE EMISSION LIMITATION - NG/J
 S02  EMISSION LIMITATION - NG/J
 NET  PLANT GENERATING CAPACITY - MW
 CROSS UNIT GENERATING CAPACITY - My
 NET  UNIT  GENERATIN6 CAPACITY W/FGD - MW
 MET  UNIT  GENERATING CAPACITY WO/FGD - MW
 EQUIVALENT SCRUBBED CAPACITY - MW

 »* BOILER DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL  SERVICE  DATE
     MAXIMUM BOILER  FLUE  GAS  FLOW - CU.H/S
     FLUE  6AS  TEMPERATURE - C
     STACK  HEIGHT  -  M
     STACK  TOP DIAMETER  - N

 ** FUEL DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE  HEAT  CONTENT - J/G
     RANGE  HEAT  CONTENT  - BTU/LB
     AVERAGE  ASH CONTENT  - X
     RANGE  ASH CONTENT -  Z
     AVERAGE  MOISTURE  CONTENT -  X
     RANGE  MOISTURE  CONTENT - X
     AVERAGE  SULFUR  CONTENT - X
     RANGE  SULFUR  CONTENT - X
     AVERAGE  CHLORIDE  CONTENT -  X
     RANGE  CHLORIDE  CONTENT - X

 ** GENERAL EMISSION CONTROL  SYSTEM 6ATA
     SALEABLE  PRODUCT/THROUAUAV  PRODUCT
     GENERAL  PROCESS TYPE
     PROCESS  TYPE
     PROCESS  ADDITIVES
     SYSTEM SUPPLIER
     A-E FIRM
     CONSTRUCTION  FIRM
     DEVELOPMENT LEVEL
     NEW/RETROFIT
     PARTICULATE DESIGN  REMOVAL  EFFICIENCY
     S02 BESX6N  REMOVAL  EFFICIENCY  - X
     COMMERCIAL  DATE
     INITIAL  START-UP
     CONSTRUCTION  COMPLETION
     CONSTRUCTION  INITIATION
     CONTRACT  AWARDED

• • ESP
     NUMBER
     TfPE
     SUPPLIER
    PARTICULATE DESIGN  REMOVAL  EFFICIENCY
    FLUE GAS CAPACITY -  CU.M/S
    FLUE GAS TEMPERATURE  - C
    PRESSURE DROP - KPA
    PARTICULATE OUTLET LOAD  - G/CU.M

•• PARTICLE SCRUBBER
    TYPE

•* ABSORBER
    NUMBER
    TYPE
     INITIAL START UP
    SUPPLIER
- X
      SALT  RIVER  PROJECT
      CORONADO
      2
      ST. JOHNS
      ARIZONA
      D
        43.          C
       700.0
       350.0
       350.0
       365.0
       260.0
RILEY STOKER
PULVERIZED COAL
BASE
 4/80
 1226.94
  404.4
  152.
    5.8
                        .,100  LB/MHBTU)
                        .800  LB/MMBTU)
                    C2600000 ACFB)
                    ( 760 F)
                    < 500 FT>
                    ( 19.0 FT)
     COAL
     SUBBITUMINOUS
      19306.

        25.00
     19-35
        16.00
     12-20
         1.00
     0.4-1.0
     ********
                I  8300 BTU/LB)
                t,000-11,000
THROWAWAY PRODUCT
WET SCRUBBING
LIMESTONE
NONE
PULLMAN KELLOGG
BECHTEL
BECHTEL
FULL SCALE
NEW
   99.87
   66.00
10/80
 7/80
11/79
 5/77
 6/76
     HOT SIDE
     WESTERN PRECIPITATION
  X     99.8
      1321.3        (2800000' ACFH)
       404.4        (  760 F)
     *******        <**•*.* 1N-H20)
          .00       (   .00 GR/SCF)
     NONE
     SPRAY TOWER
      1/80
     PULLMAN KELLOGG
                                               176

-------
                                               EPA UTILITY  F6D SURVEY.: JULY - SEPTEMBER 1980
SALT RIVER PROJECT: CORONADO 2 (CONT.)

     NUMBER OF STAGES
     DIMENSIONS - FT
     SHELL MATERIAL
     INTERNAL MATERIAL
     NUMBER OF NOZZLES
     BOILER LOAD/ABSORBER - X
     SIS FLOW - CU.K/S
     GAS TEMPERATURE - C
     LIQUID RECIRCULATION RATE - LITER/S
     L/E RATIO - L/CU.N
     PRESSURE DROP - KPA
     S02 INLET CONCENTRATION - PPM
     S92 OUTLET CONTRATION - PPM
     S02 OUTLET CONCENTRATION- N6/J
     502 DESIGN REMOVAL EFFICIENCY - X
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENT INDEX

 •* FANS
     NUMBER
     TYPE
     SERVICE - WET/DRY
     CAPACITY - CU.M/S

 ** MIST ELIMINATOR
     NUMBER
     TYPE
     CONSTRUCTION MATERIAL
     CONFIGURATION
     NUMBER OF STAGES
     NUMBER OF PASSES
     FREEBOARD DISTANCE - M
     DEPTH - M
     VANE SPACING - CM
     riASH SYSTEM
     SUPERFICIAL GAS VELOCITY - M/S

 *• PROCESS CONTROL CHEMISTRY
     CONTROL VARIABLES
     CONTROL RANGE
     CONTROL MANNER
     HOOF.
     SENSOR LOCATION

 •* PU1PS
     SERVICE
     SLURRY RECIRCULATION
     SLUDGE DISPOSAL
     SLURRY PURGE
     ALKALI MAKEUP
     PROCESS MATER
     SEAL UATER
     HI6H PRESSURE  SEAL  UATER
     MIST ELIMINATOR WASH
     ******

 ** TANKS
     SERVICE
     REACTION MIX
     PROCESS UATER
     MIST  ELIMINATOR
     SEAL  UATER
     LIMESTONE  SLURRY  STORAGE
     SLUDGE STORAGE

 **  REHEATER
     TYPE
     TEMPERATURE BOOST - C

 •»  THICKENER
     NUMBER
     TYPE
     DIAHETER - M
     OUTLET SOLIDS  -  X
120 L X 28 U X 17 H
CARBON STEEL
POLYESTER RESIN
  14*
   40.0
   25.48
   46.1
  630.
    3.3
 1000
  180
     .4
t  54000 ACFIO
t  115 F)
(10000 GPM>
( 25.0 6AL/1000ACF)
C 1.5 IN-H20)
   82.0
     .0
     .0
SCRUBBER Fc
DRV
  304.52
                (***«* LB/MMBTU)
                C 644880  ACFM)
CHEVRON
HEIL NORVL E-265
VERTICAL
    1
    3
    8.84
     .21
    3.2
MAKEUP UATER  SPRAY
(29.0 FT}
(  .7 FT)
( 1.25 IN)
    4.6
                (  15.0  FT/S)
S02  INLET CONCENTRATION  GAS FLOU, PH
0-1000 PPM S02,  0-500,000 SCFM,  4-8 PH
AUTOMATIC AND  MANUAL
FEED FORUARD
INLET DUCT,  FIRST  AND  FOURTH STAGES (PH)
                                                 NUMBER
  10
   4
   4
   1
   2
   1
   2
   2
*** *
NUMBER

*•**
    2
    2
    1
    1
    1
 BYPASS
    27.8         (   50 F)
  1
 CENTER  FEED UELL
    32.0        (105 FT)
    30.0
                                                177

-------
 EPA UTILITY FGO SURVEY:  JULY  -  SEPTEMBER  1980

SALT RIVER PROJECT: CORONADO 2  CCONT.)
 •» WATER LOOP
     TYPE
     EVAPORATOR HATER LOSS - LITER/S
     SLUDGE VATER LOSS - LITER/S
     POND WATER LOSS - LITER/S
     PURGE WATER LOSS - LITER/S
     OTHER HATER LOSSES - LITER/S
     RECOVERED WATER RETURN - LITER/S
     FRESH MAKEUP WATER ADDITION - LITERS/S

 ** REAGENT PREPARATION EQUIPMENT
     NUMBER OF STORAGE HOPPERS
     NUMBER OF BALL MILLS
     NUMBER OF SLAKERS
     BALL MILL CAPACITY- M T/N
     REAGENT PRODUCT - X SLURRY SOLIDS
     POINT OF ADDITION

 •» DISPOSAL
     NATURE
     TYPE
     LOCATION
     TRANSPORTATION
     AREA - ACRES
     OPACITY - CU.H
OPEN
   13.2
    3.8
     .0
     .0
     .0
     .0
   17.0
210 GPM)
 60 GPM)
  0 GPM)
  0 6PM)
  0 GPM)
  0 6PM)
270 6PM)
    1
    2
    0
   11.8        ( 13.0 TPH)
  20.0
REACTION MIX TANK BENEATH EACH ABSORBER TRAIN
FINAL
LINED POND
ON SITE
PIPE
   28.0
   4525100     C  3700.0 ACRE-FT)
...	.__	_—....	PERFORMANCE  DATA	———....-._.__
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   X  REMOVAL    PER   BOILER  F6D   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR
 7/80  SYSTEM

 S/80  SYSTEM

 9/80  SYSTEM

       •• PROBLEMS/SOLUTIONS/COMMENTS
                             744

                             744

                             720
                         INITIAL OPERATION OF THE F6D SYSTEM AT  THE  CORONADO  2  STATION  COMMENCED
                         IN JULY, 1980.

                         DURING THE THIRD QUARTER 1980 A BEARING INSPECTION HAS CONDUCTED.   THE UNIT
                         IS PRESENTLY IN THE PROCESS OF BEGINNING  COMMERCIAL  OPERATION.
                                               178

-------
                                              EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
               DESIGN  AND  PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC F6D SYSTEMS
COMPANY  NAME
PLANT  NAME
JN1T NUMBER
CITY
STATE
CROSS  UNIT GENERATING  CAPACITY  - MU
MET UNIT GENERATING  CAPACITY  W/F6D  - MW
EQUIVALENT SCRUBBED  CAPACITY  -  MW

**  FUEL  OATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT  - I
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR CONTENT -  X
    AVERAGE  CHLORIDE CONTENT  -  X

**  GENERAL EMISSION  CONTROL SYSTEM  DATA
    SENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP  DATE
     S02  DESIGN  REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 *»  WATER LOOP
     TYPE
     FRESH MAKE-UP HATER  - LITER/S

 it  DISPOSAL
     TYPE
                                    - X
                                         SOUTH  CAROLINA  PUBLIC  SERVICE
                                         UINVAH
                                         2
                                         GEORGETOWN
                                         SOUTH  CAROLINA
                                           280.0
                                           258.0
                                           140.0
                                         COAL
                                         BITUMINOUS
                                          26749.
                                            13.50

                                             1.70
                                         ********
                 WET SCRUBBING
                 LIMESTONE
                 BABCOCK I WILCOX
                 NEW
                     1.1
                  7/77
                 **/ *»
                    45.00
                    99.40
                      .0
                      .0
                                ( 11500 BTU/LB)
                                         OPEN
                                             6.3
                                                        <  100 6PM)
                                                POND
...—————————————	-PERFORMANCE DATA—————-——	——	—__	
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION   X  REMOVAL   PER  BOILER  F6D   CAP.
                                                                 SO?   PART. HOURS HOURS  HOURS FACTOR
 1/80

 2/80

 5/80
 4/8C

 5/80
 6/80
SYSTEM

SYSTEM

SYSTEM

*• PROBLEMS/SOLUTIONS/CONMENTS
                                               744

                                               696

                                               744
                         DURING  THE  FIRST  QUARTER  Of  1980 NO MAJOR FGD RELATED PROBLEMS WERE
                         REPORTED.
SYSTEM     100.0       100.0       100.0

SYSTEM      95.8        94.9        94.9

** PROBLEMS/SOLUTIONS/COMMENTS
                         85.3

                         77.7
720

744
614

609
614  60.2

578  61.9
                          THE  FGD  SYSTEM  WAS  OFF  LINE THROUGH PART OF MAY TO HASH DOWN THE ABSORBER
                          MODULES.
SYSTEM     100.0       100.0

•* PROBLENS/SDLUTIONS/COMMENTS
            100.0
                         99.6
720   718
       718  76.6
                          NUMEROUS  LEAKS IN THE FGD SYSTEM WERE REPAIRED THROUGHOUT THE PERIOD  WHILE
                          THE BOILER  AND SCRUBBER WERE IN SERVICE.  NO MAJOR OPERATIONAL PROBLEMS
                          WERE REPORTED FOR APRILt MAY, OR JUNE.
  7/80  SYSTEM
            100.0
100.0
                                           100.0
                                                100.0
                                                                              744
                                                                                     744
                                                                                    744  75.3
                                                179

-------
 EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

SOUTH CAROLINA PUBLIC SERVICE: WINYAH  2  (CONT.)
	...	__.—.—.	—PERFORMANCE DATA	—————————..____„
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD    CAP.
                                                                 $02  PART. HOURS HOURS  HOURS  FACTOR


       *• PROBLEMS/SOLUTIONS/COMMENTS

                         NO OPERATIONAL PROBLEMS WERE REPORTED DURING JULY.

 B/80  SYSTEM      99.7         99.7         99.7         88.3                  7*4   659    657   74.0

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE GRIT SEPARATOR  PLUGGED  CAUSING A TWO HOUR OUTAGE.  THE FGD SYSTEM
                         MAS AVAILABLE  THROUGH ALL OF AUGUST EXCEPT FOR THIS SHORT OUTA6E.

 »/8P  SYSTEM      94.5       100.0        100.0         87.2                  720   629    629   73.4

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER  AND FGD  SYSTEM WENT DOWN FOR A SCHEDULED MAINTENANCE OVERHAUL
                         OH SEPTEMBER 30,  1980.   WORK SCHEDULED TO BE DONE INCLUDED INSTALLING  A
                         SECOND TRAY IN THE  ABSORBER  MODULE, RENEWING DEMISTER WASH SYSTEM WITH
                         ALLOY  20 PIPING,  AND CLEANING SCALE DEPOSITS FROM SUENCHER THROAT.
                                               180

-------
                                             EPA UTILITY  FGO  SURVEY:  JULY - SEPTEMBER 1980

                                          SECTION  3
              DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
REGULATORY CLASSIFICATION
PARTICIPATE EMISSION LIMITATION -  NG/J
SOZ EMISSION LIMITATION - NG/J
NET PLANT GENERATING CAPACITY  - MW
CROSS UNIT GENERATING  CAPACITY - MU
«ET UNIT GENERATING CAPACITY W/FGD -  NU
NET UNIT GENERATING CAPACITY UO/FGO - HV
EQUIVALENT SCRUBBED CAPACITY - MW

*• BDILER DATA
    SUPPLIER
    TYPE
    SERVICE LOAD
    COMMERCIAL  SERVICE DATE
    NAX1NUM BOILER  FLUE GAS  FLOW - CU.H/S
    FLUE GAS TEMPERATURE  -  C
    STACK HEIGHT  -  N
    STACK TOP  DIAMETER -  M

»*  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    RANGE HEAT  CONTENT -  BTU/LB
    AVERAGE ASH CONTENT - X
    RANGE ASH  CONTENT  - X
    AVERAGE MOISTURE  CONTENT - X
    RANGE MOISTURE  CONTENT  - X
    AVERAGE SULFUR  CONTENT  - X
    RANGE  SULFUR  CONTENT  - I
    AVERAGE CHLORIDE  CONTENT - X
    RANGE CHLORIDE  CONTENT  - X

 • *  GENERAL  EMISSION CONTROL SYSTEM DATA
     SALEABLE  PRODUCT/THROUAHAV PRODUCT
     GENERAL  PROCESS TYPE
     PROCESS  TYPE
     SYSTEM  SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     MEM/RETROFIT
     SOZ DESIGN REMOVAL EFFICIENCY -  X
     COMMERCIAL DATE
     INITIAL START-UP
     CONSTRUCTION  INITIATION

 • *  ESP
     NUMBER
     SUPPLIER

 •*  PARTICLE SCRUBBER
     TYPE

 **  ABSORBER
     NUMBER
     TYPE
     INITIAL START  UP
     SUPPLIER
     $02 DESIGN REMOVAL EFFICIENCY -  X

 »* MIST ELIMINATOR
     TYPE

 •* PU1PS
     SERVICE
SOUTH CAROLINA PUBLIC SERVICE
UINYAH
3
GEORGETOWN
SOUTH CAROLINA
B
******         (•*»»** LB/MHBTU)
******         (•***** LB/MMBTU)
*******
  280.0
  252.0
  2S8.0
  280.0
RILEY STOKER
PULVERIZED COAL
BASE
**/**
********
*******
******
*******
 COAL
 ******
  26749.

 ********
(•**•*** ACFN)
<•*** M
(***•* ft)
C***«* FT>
< 11500 BTU/LB)
 *•«*.*•
 ******
     1.70
 THROWAWAY PRODUCT
 UET SCRUBBING
 LIMESTONE
 BABCOCK I WILCOX
 BURNS I ROE
 FULL SCALE
 NEW
    90.00
  6/80
  5/80
  3/79
 RESEARCH-COTTRELL
 NONE
 SPRAY TOWER
  5/80
 BABCOCK t WILCOX
    90.0
 CHEVRON


 NUMBER

 ****
                                                181

-------
 EPA UTILITY F60 SURVEY: JULY - SEPTEMBER  1980

SOUTH CAROLINA PUBLIC SERVICE: WIN-YAH 3  (CONT.)


 ** REHEATER
     TYPE                                       HOT  AIR  INJECTION
     HEATING MEDIUM                             STEAM

 • • WATER LOOP
     TYPE                                       CLOSED



..	.	.	PERFORMANCE DATA	—	_
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION   X  REMOVAL    PER   BOILER   F6D   CAP.
                                                                 S02   PART.  HOURS  HOURS   HOURS FACTOR


 6/80  SYSTEM      60.0        60.0        60.0        46.6                   720    559     336  59.5

       •• PROBLEMS/SOLUTIONS/CONMENTS

                         INITIAL FGD OPERATIONS BEGAN JUNE 3, 1980.

                         THE INLET DAMPER  LOCKED UP  FORCING  THE  FGD  SYSTEM  OUT OF SERVICE FOR PART
                         OF JUNE.

                         THERE HAVE BEEN CONTINUING  PROBLEMS WITH  THE  THICKENER  SUMP RESULTING FROM
                         IT'S LOCATION.  THESE PROBLEMS  FORCED THE FGD  SYSTEM OUT OF SERVICE FOR
                         APPROXIMATELY 7 DAYS.

 7/80  A           12.8        12.8        12.8        12.8
       B           12.8        12.8        12.8        12.8
       SYSTEM      12.8        12.8        12.8        12.8                   744    744      95  79.8

       •* PROBLENS/SOLUTIONS/COMMENTS

                         THE THICKNER RAKE DRIVE MECHANISM HAS REPAIRED  DURING JULY.

                         THE LARGE BELT  DRIVEN PUMP  HAS  BEGUN TO SHOW  SIGNS  OF RAPID WEAR.

                         THE F6C SYSTEM  WAS OUT OF SERVICE BECAUSE OF  COMPUTER LOGIC PROBLEMS CAUSED
                         BY A BAD CABLE.

                         THE THICKNER SUMP PUMP AND  MIXER MOTORS WERE  FLOODED OUT CAUSIN6 THE FGD
                         SYSTEM TO GO DOWN.

 3/80  A           18.0        20.4        20.4        18.0
       B           18.0        20.4        20.4        18.0
       SYSTEM      18.0        20.4        20.4        18.0                   744    658     134  79.4

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         THE THICKNER SUMP PUMP AND  MIXER MOTORS CONTINUED  TO HAVE PROBLEMS BECAUSE
                         OF THE FLOODING LAST MONTH.

                         THE SCRUBBER OUTLET DAMPER  WOULD NOT CLOSE  PROPERLY  WHICH REQUIRED WORK
                         DURING AUGUST.

                         THE ABSORBER TRAY STRAP WAS BROKEN  IN SEVERAL  AREAS  AND  REQUIRED REPAIR
                         WORK DURING THE MONTH.

 9/80  A             .0          .0          .0          .0
       B             »0          .0          .0          .0
       SYSTEM        .0          .0          .0          .0                   720    647       0  84.6

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM WAS OUT OF SERVICE THROUGH ALL  OF SEPTEMBER  BECAUSE OF
                         REPAIRS BEING MADE ON THE THICKNER.
                                               182

-------
                                              EPA  UTILITY  F60  SURVEY:  JULT - SEPTEMBER 1980

                                           SECTION 3
              DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC  FGD  SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT 6EMERATING  CAPACITY  -  MW
WET UNIT  GENERATING  CAPACITY  W/FGD -  MW
EQUIVALENT SCRUBBED  CAPACITY  -  MW

•• FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  X
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  X

• * GENERAL EMISSION CONTROL SYSTEM  DATA
    GENERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION -  X
    INITIAL START-UP DATE
    COMMERCIAL  START-UP  DATE
    SD2  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE DESIGN REMOVAL  EFFICIENCY
    ABSORBER  SPARE  CAPACITY INDEX - X
    ABSORBER  SPARE  COMPONENTS INDEX

 »•  WATER  LOOP
     TYPE
     FRESH MAKE-UP WATER  - LITER/S

 .*  TREATMENT
     TYPE

 »*  DISPOSAL
     TYPE
                                               SOUTH MISSISSIPPI  ELEC
                                               R.D. MORROW,  SR.
                                               1
                                               HATTISBUR6
                                               MISSISSIPPI
                                                 200.0
                                                 180.0
                                                 124.0
                                                                       PWR
                                                              ( 12000 BTU/LB)
                                          - X
                            COAL
                            BITUMINOUS
                             27912.
                               15.00
                                6.50
                                1.30
                                 .01
                            WET SCRUBBING
                            LIMESTONE
                            ENVIRONEERING, RILEV  STOKER
                            NEW
                                5.5
                             8/78
                             8/78
                                52.70
                                99.60
                                 .0
                                 .0
                                               CLOSED
                                               *******
                                                               {**••* 6PM>
                                               FLVASH STABILIZATION
                                                LANDFILL
____—.—..	............—.....	.......PERFORMANCE
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F66   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
1/80
       SYSTEM        .0

       «• PROBLEMS/SOLUTIONS/COMMENTS
                                             .0
                                                                             7*0
                                                                                                 .0
                          THE  UNIT  REMAINED  OFF LINE DURING JANUARY AS RELINING OF THE SCRUBBERS
                          WAS  COMING  TO  COMPLETION.

                          THE  PRESATURATOR AREAS, BYPASS DUCTS, AND THE SECTIONS OF DUCT FROM
                          ABSORBER  EXITS AT  POINTS WHERE BYPASSED GAS MIXES WITH WET GAS ALL THE
                          WAY  TO  THE  STACK ARE BEING LINED WITH HASTtLLOY G (A I/ft INCH LINING IS
                          BEING  WELDED  TO THE EXISTING CARBON STEEL).
                          THE  MAIN  BODY  OF THE ABSORBER MODULES IMMEDIATELY ABOVE THE PRESATURATOR
                          SECTIONS  ALL  THE WAV TO THE ABSORBER EXIT LS BEING LINED WITH CHLOROBUTVL
                          RUBBER  CON  THE EXISTING CARBON STEEL).
Z/80

J/80
  k/80
        SYSTEM

        SYSTEM
  .0

41.5
            95.1
   .0

100.0
  .0

39.5
696

744
  0

309
  0

294
       • •  PROBLEMS/SOLUTIONS/COMNENTS

                         DURING MARCH THE UNIT 1 FGD SYSTEM RETURNED TO SERVICE OPERATING  294  HOURS.

       SYSTEM      100.0        99.0       100.0        99.0    80.00          720    720     713
                                                183

-------
 EPA UTILITY FSO SURVEY: JULY - SEPTEMBER  1980

S3UTH H1SSISSIPPI ELEC PUR: R.D. MORROW, SR.  1  (CONT.)
------------------------------------------ PERFORMANCE  DATA ----------------- - — -- — - ------------
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION   X R6.MOVAL   PER  BOILER  FGO   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THERE WERE NO  OPERATIONAL  PROBLEMS  RELATED TO THE FGD SYSTEM DURING APRIL.
                         FOUR INSPECTIONS WERE  PERFORMED  WHICH  REOUIREO  THE FGD SYSTEM TO BE OUT
                         OF SERVICE FOR SEVEN HOURS.
5/80  SYSTEM      99.7         99. B

      *• PROBLEMS/SOLUTIONS/COMMENTS
                                           100.0
                                                        88.7
                                                                80.00
                                                                              744
                                                                                    660
                                                                                           658
                         THE BOILER WAS SCHEDULED  TO  BE  OUT  OF  SERVICE  FOR 84 HOURS TO CLEAN THE
                         AIR PREHEATERS.  THE  BOILER  OPERATED  THE  REMAINING HOURS IN MAY.

                         THE FGD SYSTEM WAS  SCHEDULED TO BE  OUT OF SERVICE FOR 1.5 HOURS FOR ROU-
                         TINE MODULE INSPECTION.   THE FGD SYSTEM WAS AVAILABLE 99. 7X DURING HAY.
6/80  SYSTEM
                  99.?
97.0
            99.0
                                                       93.0
                                                               90. 00
                                                                              720   690
                                                                                           668  68.9
          PROBLEMS/SOLUTIONS/COMMENTS
                         DURING JUNE OPERATIONS  CAME  TO  A  HAULT  FOR  APPROXIMATELY SIX HOURS TO CLEAN
                         THE MIST ELIMIMTORS.   OTHER  OUTAGE  TIME  DURING THE MONTH HAS CAUSED
                         BY BOILER-RELATED PROBLEMS.
7/60  SYSTEM      94.1        99.3

      «• PROBLEfS/SOLUTIONS/COMMENTS
                                           99.3
                                                        94.1
                                                               90.00
                                                                              744
                                                                                    705
                                                                                           700  67.3
                         DURING JULY THE SCRUBBER WAS  INSPECTED  FOR  SCALE  ACCUMULATION AND A TRIP
                         TEST WAS CONDUCTED ON THE  SCRUBBER  CONTROLS TO  CHECK  ON EARLIER MODIFICA-
                         TIONS.

                         THE MAJORITY OF OUTAGE TIME WAS  CAUSED  BY  A MALFUNCTION OF THE BALL HILL.
                         THIS RESULTED IN A LOSS OF LIMESTONE  SUPPLY IN  THE  STORAGE TANK.

                         A LEAK IN THE FEED WATER LINE  CAUSED  ADDITIONAL OUTAGE TINE DURING THE
                         MONTH.
3/80  SYSTEM     100.0        100.0        100.0        100.0    80.00

      ** PROBLEMS/SOLUTIONS/COMMENTS

                        NO PROBLEMS WERE  ENCOUNTERED DURING THE MONTH OF AUGUST.

>/80  SYSTEM      99.2        99.6         99.6         99.2                  720

      • * PROBLEMS/SOLUTIONS/COMMENTS
                                                                              744   744
                                                                                    717
                                                                                           744  77.7
                                                                                           714  70.3
                         DURING SEPTEMBER THE SCRUBBER WAS  INSPECTED  CAUSING TWO HOURS OF
                         OUTAGE TIME.

                         A BRIEF FGD OUTAGE OF 12 MINUTES WAS  CAUSED  BY  AN ELECTRICAL SHORT.

                         THE UNIT AND FGD SYSTEM WERE OUT OF SERVICE  FOR APPROXIMATELY 3 1/2 HOURS
                         DUE TO ESP PROBLEMS.
                                               184

-------
                                              EPA UTILITY  FCD  SURVEY:  JULY  - SEPTEMBER  1980

                                           SECTION  3
              DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL DOMESTIC  F6D  SYSTEMS
COMPANY NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
(ROSS  UNIT EENERATING  CAPACITY  -  MU
NET UNIT  GENERATING  CAPACITY  U/FGD -  MU
EQUIVALENT SCRUBBED  CAPACITY  -  MU

•*  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT  -  J/6
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  X
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  X

•*  GENERAL EMISSION  CONTROL SYSTEM DATA
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION -  X
    INITIAL START-UP DATE
    COMMERCIAL  START-UP DATE
    S02  DESIGN  REMOVAL EFFICIENCY -  X
    PARTICULATE DESIGN REMOVAL  EFFICIENCY
    ABSORBER  SPARE  CAPACITY INDEX -  X
     ABSORBER  SPARE  COMPONENTS INDEX

 ••  WATER  LOOP
     TYPE
     FRESH MAKE-UP WATER  - LITER/S

 .*  TREATMENT
     TYPE

 .*  DISPOSAL
     TYPE
                                        SOUTH MISSISSIPPI ELlEC  PUR
                                        R.D. MORROW, SR.
                                        2
                                        HATTISBURG
                                        MISSISSIPPI
                                          200.0
                                          180.0
                                          124.0
                                                        ( 12000 BTU/LB)
                                    - X
                          COAL
                          BITUMINOUS
                           27912.
                             IS.00
                              6.50
                              1.30
                               .01
                          UET SCRUBBING
                          LIMESTONE
                          ENVIRONEERINGt  RILEV  STOKER
                          NEU
                              5.5
                           6/79
                           6/79
                             52.70
                             99.60
                               .0
                               .0
                                         CLOSED
                                         *******
                                                        (**».* 6PK>
                                         FLVASH STABILIZATION
                                                LANDFILL
„_	.	PERFORMANCE DATA	—-	
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER   FGD   CAP.
                                                                S02   PART.  HOURS  HOURS   HOURS FACTOR
 1/80
SYSTEM        .0

** PROBLEMS/SOLUTIONS/COMMENTS
                        .0
                                    .0
                                                        744   743
                                                           0  75.4
 2/80

 3/80

 4/80
SYSTEM

SYSTEM

SYSTEM
                         THE UNIT REMAINED  OFF  LINE  DURING  JANUARY UHILE SCRUBBER LINER REPAIRS
                         CONTINUED.

                         THE PRESATURATOR AREAS,  BYPASS  DUCTS,  AND THE  SECTIONS OF DUCT FROM
                         ABSORBER EXITS  AT  POINTS WHERE  BYPASSED GAS MIXES UITH WET GAS ALL THE
                         HAY TO  THE  STACK ARE BEING  LINED UITH  HASTBLLOV G CA 1/8 INCH LINING IS
                         BEING WELDED  TO THE EXISTING CARBON STEEL).
                         THE MAIN BODY OF THE ABSORBER MODULES  IMMEDIATELY ABOVE THE PRESATURATOR
                         SECTIONS ALL  THE WAY TO  THE ABSORBER EXIT IS BEING LINED UITH CHLOROBUTYL
                         RUBBER  (ON  THE  EXISTING  CARBON STEEL).
.0

.0

.0
.0

.0
.0

.0
.0

.0

.0
                                .00

                                .00
696

744

720
698

486

  0
                                      75.0
        *•  PROBLENS/SOLUTIONS/COMNENTS
                          THE  FGD SYSTEM REMAINED OFF LINE THROUGH APRIL AS SCRUBBER LINER REPAIRS
                          CONTINUED.   THE UNIT IS EXPECTED BACK ON LINE AT THE END OF MAY.
  5/80   SYSTEM
                     2.4
                         14.2
                                            14.2
                                                         2.4
                                                                85.00
                                                                              744
                                                                             127
                                                                                             18
                                                185

-------
 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

SDUTH MISSISSIPPI ELEC PUR: R.O. MORROW, SR. 2  (CONT.)
..........—___.....-......-.—	———PERFORMANCE DAT*-———	——	...	——_._.._
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   X  RBHOVAL    PER   BOILER   F6D    CAP.
                                                                 S02   PART.  HOURS  HOURS   HOURS  FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE UNIT REMAINED OFF  LINE  DURING MOST  OF HAT TO COMPLETE SCRUBBER AND
                         STACK LINING MODIFICATIONS.

                         THE BOILER OPERATED 127 HOURS IN NAY; HOWEVER, THE  F6D SYSTEM OPERATED
                         ONLY 18 HOURS BECAUSE  OF COMPUTER CONTROL PROBLEMS.

 6/80  SYSTEM      99.3        90.0        99.1        78.0    90.00         720   625     561   68.9

       *« PROBLEMS/SOLUTIONS/COHHENTS

                         THE FED SYSTEM COMPUTER LOST POWER  DURING JUNE CAUSING THE  UNIT TO
                         BE SHUT DOWN FOR 25 MINUTES.

                         DURING JUNE OPERATIONS CANE TO A HAULT  FOR APPROXIMATELY FIVE HOURS TO
                         CLEAN THE HIST ELIMINATORS.  OTHER  OUTAGE MHE DURING THE MONTH HAS CAUSED
                         BY BOILER RELATED PROBLEMS.

 7/80  SYSTEM      79.8        80.7        80.7        79.8    85.0ft         7*4   736     594   73.8

       »* PR08LEHS/SOLUTIONS/COMHENTS

                         DURING JULY BALL HILL  REPAIRS ACCOUNTED FOR  THE MAJOR PORTION OF THE  FGD-
                         RELATED OUTAGE TIME.

                         THE SCRUBBER WAS INSPECTED  FOR SCALE ACCUMULATION  AND A  TRIP TEST WAS
                         CONDUCTED ON THE SCRUBBER  CONTROLS  TO CHECK  ON EARLIER MODIFICATIONS.

                         THE SCRUBBING SYSTEM WENT  OFF LINE  DUE  TO AN ALARM  TRIGGERED BY HIGH
                         TEMPERATURE, WHICH WAS DETERMINED TO BE A FALSE ALARM.

                         A POSSIBLE TUBE LEAK SHUT  THE BOILER DOWN ON JULY  27.  THE  UNIT WENT  BACK
                         ON LINE WITHOUT FINDING THE LEAK.   THE  BOILER WAS  THEN TAKEN OFF LINE ON
                         JULY 28 TO FIND THE LEAK AND MAKE THE NECESSARY REPAIRS.

                         PROBLEMS WITH THE BURNER HANAGEHENT CONTROL  SYSTEH  ALSO  CAUSED  A BOILER-
                         RELATED OUTAGE.

 8/80  SYSTEM      98.8        99.$        99.5        98.8    80.00         744   739     735   74.3

       ** PROBLEHS/SOLUTIONS/COHNENTS

                         THE BOILER WAS OUT OF  SERVICE APPROXIMATELY  FIVE HOURS DURING AUGUST  DUE
                         TO A BOILER TUBE LEAK.

                         AFTER THE REPAIRS TO THE BOILER TUBE AN ADDITIONAL  FOUR  HOURS OF OUTAGE
                         TIME WAS NECESSARY TO  START UP THE  FGD  SYSTEH.

 a/80  SYSTEM      98.8        99.5        99.5        98.8    80.00         744   739     735   74.3

       • • PROBLEMS/SOLUTIONS/COHMENTS

                         DURING AUGUST THE FGD  SYSTEM HAS SHUT DOWN FOR FOUR HOURS FOR REPAIR  OF  A
                         TUBE LEAK,

 9/80  SYSTEM      99.8        99.}        99.5        88.3                  720   639     636   62.4

       *• PROBLENS/SOLUTIONS/COHMENTS

                         DURING SEPTEMBER THE BOILER WAS TAKEN OUT OF SERVICE FOR APPROXIMATELY
                         SI HOURS DUE TO A TUBE LEAK.

                         A BOILER INSPECTION AND AN ELECTRICAL SHORT  IN THE  CONTROLS CAUSED THE
                         FED SYSTEM TO SHUT DOWN WITH THE BOILER FOR APPROXIMATELY 1 1/2 HOURS.
                                               186

-------
                                              EPA  UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
              DESI6N AND PERFORMANCE  OAT*  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
(ROSS UNIT GENERATING  CAPACITY  -  MM
WET UNIT  6ENERATIN6  CAPACITY  W/F6D -  MW
EQUIVALENT SCRUBBED  CAPACITY  -  MW

**  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT  -  J/S
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  X
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  X

»•  GENERAL EMISSION  CONTROL SYSTEM  DATA
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM SUPPLIER
    MEM/RETROFIT
    ENERGY CONSUMPTION -  X
    INITIAL START-UP DATE
    COMMERCIAL  START-UP  DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE DESIGN REMOVAL  EFFICIENCY
    ABSORBER  SPARE  CAPACITY INDEX - X
    ABSORBER  SPARE  COMPONENTS INDEX

 ..  MATER  LOOP
     TYPE
     FRESH MAKE-UP WATER  - LITER'S

 ••  TREATMENT
     TYPE

 »•  DISPOSAL
     TYPE
                                    - X
                                        SOUTHERN ILLINOIS
                                        MARION
                                        4
                                        MARION
                                        ILLINOIS
                                          173.0
                                          161.0
                                          173.0
                                                          POWER  COOP
                                        COAL/REFUSE
                                        BITUMINOUS
                                         23841.
                                            16.69
                                            17.20
                                             3.75
                                              .10
                 WET SCRUBBING
                 LIMESTONE
                 BABCOCK  t UILCOX
                 NEW
                     2.3
                  5/79
                  6/79
                    89.40
                      .00
                    38.0
                      .6
                                 (  10250  BTU/LB)
                                         CLOSED
                                                        (*•**•* 6PM)
                                         FLVASH STABILIZATION
                                                LANDFILL
	—	—	———PERFORMANCE  DATA	
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   X  REMOVAL   PER  BOILER  FGO   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
13/79
11/79
12/79
SYSTEM
SYSTEM
SYSTEM

100
100

.0
.0

26
71
.0
.7
.0
74*
720
744
0
192
528
0
192
528
.0


       ** PROBLEMS/SOLUTIONS/COMNENTS
                          THE  UNIT  HAS  DOWN  FROM  OCTOBER 1 THROUGH NOVEMBER 17 FOR A BOILER/TURBINE
                          INSPECTION.   NO  MAJOR  FGD RELATED PROBLEMS HERE ENCOUNTERED DURING THE
                          FOURTH  QUARTER OF  1979  OTHER THAN SOME FREEZE-UPS CAUSED BY THE WINTER
                          HEATHER.
 1/80

 2/60

 J/BO
SYSTEM

SYSTEM

SYSTEM
100.0

100.0

100.0
10.0

31.0

48.4
744

696

744
 72

216

360
 72

216

360
        •»  PROBLEMS/SOLUTIONS/COMMEMTS
                          DURING JANUARY THE LOU BOILER AND SCRUBBER HOURS HERE  A  RESULT  OF  AN
                          18 DAY BOILER OUTAGE NEEDED FOR CORRECTION OF  TUBE  PROBLEMS.  BOILER
                          OUTAGES DUE TO TUBE PROBLEMS HERE ALSO EXPERIENCED  IN  FEBRUARY  AND MARCH.

                          THE ONLY REPORTED FGD-RELATED PROBLEM DURING THE FIRST QUARTER  OF  1980 WAS
                                                187

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 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

S3UTHERN ILLINOIS POKER COOP: MARION 4 (CONT.)
------------------------------------------ PERFORMANCE DATA ------------------------------- -— ------- .
PERIOD NODULE AVAILABILITY OPERA8ILITY RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  F6D   CAP.
                                                                $02  PART. HOURS HOURS  HOURS  FACTOR
 i/80
                        MAINTAINING THE BELT ALIGNMENT IN THE SLUDGE DISPOSAL SYSTEM.

      SYSTEM      66.7        66.7        66.7        66.7                  720   720

      ** PROBLEMS/SOLUTIONS/COMMENTS
                                                                                          480  81.3
                         SHAFT BREAKAGE UITHIN THE RECLAIM WATER PUMP CAUSED FGD SYSTEM OUTAGE TINE
                         DURING APRIL.
                                           58. 8
                                                       32.3
                                                                             744
                                                                                  408
                                                                                          240  49.6
5/80  SYSTEM      77.4        58.8

      • * PROBLEMS/SOLUTIONS/COMMENTS

                        A BOILER OUTAGE CAUSED THE FGD SYSTEM NOT (TO OPERATE FOR TWO WEEKS.

                        SHAFT BREAKAGE UITHIN THE WATER RECLAIM PUMP CONTINUED THROUGH HAY.

6/80  SYSTEM      50.0        50.0        50.0        50.0                  720   720    360  82.3

      *• PROBLEMS/SOLUTIONS/COMMENTS

                        SHAFT BREAKA6E WITHIN THE WATER RECLAIM PUMP CONTINUED TO CAUSE FGD
                        OUTAGE TIME.  A SOLUTION HAS BEEN PROPOSED TO SIPCO BY THEIR ENGINEERING
                        CONSULTANT FOR CONSIDERATION.
 7/80  SYSTEM      96.7       100.0

       ** PROBLEMS/SOLUTIONS/COMRENTS
                                         100.0
                                     95.9
                                                           744
                                                                                  714
                                                                                         714  82.0
                         AFTER REVIEW OF THE PROPOSED SOLUTION OF THE SHAFT BREAKAGE PROBLEM WITHIN
                         THE RECLAIM WATER PUMP, SIPCO AUTHORIZED THEIR CONSULTANT TO PROCEED
                         WITH THE WORK TO CORRECT THE PROBLEM.
 S/80  SYSTEM     100.0       100.0

       ** PROBLENS/SOLUTIONS/CONMENTS
                                          100.0
                                                       90.5
                                                                            744   673
                                                                                         673  89.6
                         PROBLEMS WITH THE SHAFT BREAKAGE IN THE RECLAIM WATER PUMPS CONTINUED
                         THROUGH AUGUST.  A REPLACEMENT PUMP HAS BEEN PURCHASED TO SOLVE THE
                         PROBLEM.
 9/80
      A
      B
      SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
                                                                             720   720    7ZO 100.0
       *•  PROBLEMS/SOLUTIONS/COMMENTS
                                             SUMMARY OF GENERAL PROBLEMS TO DATE
                         THE MAJOR CAUSES OF SCRUBBER OUTAGES HAVE CENTERED AROUND COLD WEATHER-RE-
                         LATED CONVEYOR BELT AND PIPING PROBLEMS, PU6 MILL BEARING FAILURES, AND
                         RECLAIM WATER PUMP SHAFT FAILURES.  OTHER PROBLEMS HAVE BEEN RELATED TO
                         PROCESS CHEMISTRY CONTROL.  THE UTILITY REPORTED THAT NUMEROUS SMALL PRO-
                         BLEMS ALSO HAVE OCCURRED BUT HAVE GENERALLY BEEN CORRECTED SOON AFTER THEIR
                         DISCOVERY.  DETAILS OF THE PRIMARY SCRUBBER PROBLEMS ARE OUTLINED BELOW:

                         COLD WEATHER PROBLEMS

                            THE MOST SEVERE FREEZING PROBLEM CONCERNS THE SLUDGE CONVEYOR SYSTEM.
                            WHEN THE AMBIENT TEMPERATURE DROPS BELOW 30 F THE CONVEYOR SYSTEM BE-
                            COMES INOPERABLE.  THE UTILITY HAS ATTEMPTED TO REMOVE THE FROZEN SLUDGE
                            USING VARIOUS COMMERCIAL AND COMPANY-BUILT SCRAPERS WITH LITTLE SUCCESS.
                            THE UTILITY ALSO INSTALLED HEATERS AT THE VARIOUS TRANSFER POINTS TO
                            THAW THE SLUDGE.  THIS PROVED UNSUCCESSFUL AS WELL.  THE PROBLEM HAS NOT
                            YET BEEN SOLVED.

                            AN ADDITIONAL PROBLEM WITH THE CONVEYOR SYSTEM HAS BEEN THE FAILURE OF
                            THE BELT TO TRACK CORRECTLY.  ON SEVERAL! OCCASIONS THE BELT HAS TOUCHED
                            THE STRUCTURAL STEEL SUPPORTS RESULTING IN BELT DAMAGE.  HOWEVER, BY RE-
                                               188

-------
                                              EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980

SOUTHERN ILLINOIS POWER COOP: MARION 4  (CONT.)
....	—	PERFORMANCE  DATA-———	————	"	~
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR

                             DUCIN6  THE  CONVEYOR  SPEED  THE UTILITY HAS INCREASED THE ESTIMATED BELT
                             LIFE  FROM  FIVE  TO  10 YEARS.

                             THE OTHER  COLD  HEATHER  PROBLEM IS RELATED TO THE SCRUBBER VESSEL PIPING
                             SYSTEM. ON SEVERAL  OCCASIONS MATER LINE FREEZE UPS HAVE RESULTED IN
                             SCRUBBER OUTAGES.   WHEN THE  PROBLEM HAS DISCOVERED, THE UTILITY IN-
                             STALLED EXTENSIVE  HEAT  TRACING ON EXPOSED HATER LINES.  ALTHOUGH THERE
                             HAS BEEN NO COLD HEATHER SINCE THE HEAT TRACING INSTALLATION. THE
                             UTILITY BELIEVES THAT  THE  PROBLEM IS SOLVED.

                          PUG MILL PROBLEM

                             SEVERAL BEARING FAILURES HAVE OCCURRED ON THE PUG MILL.  THE UTILITY
                             HAS  INCREASED THE  MAINTENANCE ON THE MILL SYSTEM TO LESSEN THE  LIKELI-
                             HOOD  OF ANOTHER FAILURE.  THE UTILITY REPORTED  THAT IF THIS PROCEDURE
                             MODIFICATION DOES NOT  INCREASE THE PUG MILL  RELIABILITY  TO AN ACCEPTABLE
                             LEVEL OTHER ACTION HILL BE TAKEN.

                          RECLAIM HATER PUMP SHAFT FAILURE

                             THE  RECLAIM WATER PUMPS PRODUCE  A VERY F.LAT  OUTPUT  PRESSURE CURVE  BUT
                             THET FEED  A SYSTEM COMPOSED  OF MANY  AUTOMATICALLY  CONTROLLED  DIAPHRAGM
                             VALVES.  THE OPENING AND CLOSING  OF  THESE VALVES  EXPOSES THE  PUMPS TO
                             A HIDE VARIABILITY IN HATER  REQUIREMENTS.   MOTOR  SHAFT  FATIGUE  RESULTS
                             VHEN THE PUMPS  ATTEMPT  TO RESPOND TO THE. VARIABLE  DEMAND.  THE  SYSTEM
                             SUPPLIER IS CURRENTLY SUPPLYING  THE  UTILITY  UITH  INFORMATION  ON THE
                             OPERATION OF THE DIAPHRAGM VALVES.   THE  UTILITY'S  CONSULTANT  ENGINEERING
                             FIRM HILL  REVIEU THE MATERIAL  AND SUGGEST POSSIBLE CONTROL VALVE
                             CHANGES.   THE  UTILITY REPORTED THAT  IF  IHIS  IS NOT POSSIBLE  OR  DOES NOT
                             WORK,  A DESIGN  CHANGE TO A DIFFERENT PUMP TYPE HILL BE CONSIDERED.
                             WHILE  THE  PROBLEM CONTINUES, THE UTILITY. IS  KEEPING A COMPLETE  SHAFT AND
                             IMPELLER ON  SITE.

                          PROCESS CHEMISTRY

                             THE  UTILITY  HAS LOST CONTROL OF  THE  PROCESS CHEMISTRY SEVERAL TIMES.
                             THE  SLURRY  SOLIDS LEVEL HAS  CONSEQUENTLY INCREASED TO THE POINT THAT
                             THE  THICKENER  RAKE  HAS  BECOME  INOPERABLE.   TO SOLVE THE PROBLEM THE
                             UTILITY HAS  BEEN  IMPROVING  THE CHEMISTRl MONITORING SYSTEM.  IN THE
                             INTERIM,  WHERE  EXISTING MONITORS ARE OUT OF SERVICE, LAB PERSONNEL
                             PERFORM MANUAL  TESTS TO MAINTAIN PROCESS CHEMISTRY CONTROL.

                          THE  BOILER AND  THE FGD SYSTEM  OPERATED THE ENTIRE MONTH OF SEPTEMBER HITH
                          NO PROBLEMS.
                                                  189

-------
 EP* UTILITY  F6D SURVEY: JULY  -  SEPTEMBER  1980

                                            SECTION  3
               DESI6N AND PERFORMANCE  DATA  FOR OPERATIONAL  DOMESTIC  FGD  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 EftOSS UNIT GENERATING CAPACITY  - MW
 NET UNIT 6ENERATIN6 CAPACITY U/F6D -  MW
 EQUIVALENT SCRUBBED CAPACITY -  MU

 *• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/6
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT -  t
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT -  X

 • • GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     $02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 •* WATER LOOP
     TYPE
     FRESH MAKE-UP HATER - LITER/S

 •* TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
                        - X
                              SOUTHERN INDIANA 6A9 > ELEC
                              A.B. BROWN
                              1
                              WEST FRANKLIN
                              INDIANA
                                265.0
                                2SO.O
                                265.0
                              COAL
                              BITUMINOUS
                               25819.
                                 9.40
                                 13.30
                                 3.35
                                   .05
                 WET  SCRUBBING
                 DUAL ALKALI
                 FMC
                 NEW
                       .8
                   3/79
                   4/79
                    85.00
                    99.50
                    20.0
                       .3
                             CLOSED
                             *******
                             NONE
                                                LANDFILL
                                 (  11100  BTU/LB)
                                             (***** 6PM)
---——————————————-PERFORMANCE DATA--
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                                X REMOVAL   PER  BOILER  FGD    CAP.
                                                                S02  PART. HOURS HOURS  HOURS  FACTOR
1/80 A 99.0 96.5 99.1 96.4
B 99.0 99.0 99.1 99.0
SYSTEM 99.0 98.0 99.1 97.7


744 744 727 65.8
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         SEVEN HOURS OF FGD SYSTEM FORCED OUTAGE TIME DURING JANUARY WERE CAUSED
                         BY A THICKENER RAKE STALL.
 2/80
       A
       B
       SYSTEM
99.1
98.4
98.8
70.3
70.0
70.2
98.8
97.8
98.3
69.4
68.7
69.1
                                                                             696   687
                                                                                               75.5
       **  PROBLEMS/SOLUTIONS/COMMENTS
                         SOME OUTAGE TIME IN FEBRUARY RESULTED FROM A WET SLUDGE PRODUCT.
                         CHEMICAL IMBALANCE CAUSED THE SLUDGE PROBLEM.
 3/80
       A
       B
       SYSTEM
98.7
99.2
99.0
64.8
51.6
58.2
95.2
94.3
95.8
26.5
21.1
23.8
                                                                             744
                                                                                   304
                                                                                          177  23.8
                                               190

-------
                                              EPA UTILITY FGD SURVEY: JULY -  SEPTEMBER  1980


SOUTHERN INDIANA G«S t ELEC: A.B. BROUN 1 (CONT.)
_____—	_____——__	—-PERFORMANCE DATA———-	———————	——
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  X REMOVAL    PER  BOILER  FGD   CAP.
                                                                S02   PART.  HOURS HOURS   HOURS  FACTOR
       ** PROBLENS/SOLUTIONS/COMMENTS
                         DURING MARCH, BOILER  DOWN  TIME  WAS  DUE  TO  A  SCHEDULED  UNIT OUTAGE* DURING
                         WHICH TIME MAINTENANCE  HAS  PERFORMED  ON THE  SCRUBBER.
 4/80
A
8
SYSTEM
100.0
100.0
100.0
 96.8
 99.7
 98.3
100.0
100.0
100.0
92.9
95.7
94.3
                                                                              7?0   691
                                                                                           679  58.6
          PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  APRIL,  THERE  HERE  NO OPERATIONAL PROBLEMS WITH THE FGD SYSTEM.
                          SYSTEM  VAS  AVAILABLE 100X OF THE  TIME.
                                                                                                 THE
  5/80
A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
82.8
82.8
82.8
                                                                              744   604
616  53.7
        »*  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING KAY  NO FORCED OUTAGES WERE EXPERIENCED WITH THE FGD SYSTEM.  THE
                          BOILER WAS  OFF LINE FOR 140 HOURS DURING THE MONTH FOR GENERAL MAINTENANCE,
                          DURING WHICH TIME SOME GENERAL FGD SYSTEM MAINTENANCE WAS ALSO PERFORMED.
  4/80
A
B
SYSTEM
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
98.2
98.2
98.2
                                                                              720   706
707  55.4
        *• PROBLEMS/SOLUTIONS/COMMENTS
                          NO FGD RELATED PROBLEMS WERE REPORTED FOR THE MONTH OF JUNE.
                          SYSTEM OPERATED 100X OF THE TIME THE BOILER WAS ON LINE.
                                                                                        THE  FGD
  7/80
        A
        B
        SYSTEM
             98.1
             86.8
             92.4
              97.9
              87.7
              92.8
             97.9
             87.7
             92.8
              92.5
              82.9
              87.7
                       744   703
 653   62.6
        •• PROBLEMS/SOLUTIONS/COMMENTS
                          THE B NODULE RECIRCULATION PUMPS WERE  THE MAJOR  CAUSE  OF  DOWNTIME.  TWO
                          PIECES OF THE CHEVRON MIST ELIMINATOR  FELL  CAUSING  THE SUCTION  LINES TO
                          PLUG.
                          ADDITIONAL PROBLEMS WITH THE PUMP WERE  CAUSED  BY  THE THRUST BEARING.
                          WAS CORRECTED BY THE MANUFACTURER.
                                                                                                 THIS
                          THE UNAVAILABILITY  OF  THE  VACUUM  FILTERS  AND  ASSOCIATED EQUIPMENT REQUIRED
                          THE SCRUBBER TO SHUTDOWN TO  AVOID A  STOPPAGE  OF  THE THICKENER RAKE.  THIS
                          SITUATION  ACCOUNTED FOR APPROXIMATELY  15  HOURS  OF  SYSTEM OUTAGE TIME
                          DURING JULY.
  3/80
 A
 B
 SYSTEM
  94.5
  94.8
  94.6
  94.5
  94.8
  94.6
  94.5
  94.8
  94.6
 94.5
 94.8
 94.6
                                                                               744   744
 704  61.4
         ** PROBLEMS/SOLUTIONS/COMMENTS
                           THE  MAJOR  CAUSE OF  UNAVAILABLITY FOR AUCUSI WAS PROBLEMS WITH SOLIDS
                           DISPOSAL,  INCLUDING PROBLEMS WITH PRIMARY LIQUID-SOLID SEPARATION UP TO
                           AND  INCLUDING  FINAL LANDFILLING.
   9/80
 A
 B
 SYSTEM
 100.0
 100.0
 100.0
  99.6
  99.6
  99.6
  99.6
  99.6
  99.6
 99.6
 99.6
 99.6
                                                                               720   720
                                                                                            717   $9.8
                                                 191

-------
 EPA UTILITY FGD SURVEY: JULY -  SEPTEMBER  1980

SOUTHERN INDIAN* GAS I ELEC: A.B. BROWN 1  CCONT.)
...	PERFORMANCE  BATA	—	.	——__
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X  REMOVAL    PER   BOILER  F6D   CAP."
                                                                 S02   PART.  HOURS HOURS   HOURS FACTOR


       »* PROBLE1S/SOLUTIONS/COMHENTS

                         SLUDGE DISPOSAL REMAINS THE HOST PREVALENT  PROBLEM  DUE  TO  MECHANICAL
                         BREAKDOWN OF THE DISPOSAL  TRUCKS AND UNDERFLOW  PUMPS, IN ADDITION  TO THE
                         HIGH MAINTENANCE REQUIREMENTS OF THE ROTARY  VACUUM  FILTERS.

                         THE MONTH OF SEPTEMBER ALSO SAW AN  EXTREMELY HIGH  RATE  OF  FAILURE  OF
                         RECIRCULATION PUMPS, WITH  DAMAGE TO THE RUBBER  LINED CASINGS  AND IMPELLERS
                         THE CAUSE OF THIS PROBLEM  IS  UNKNOWN TO THE  UTILITY AT  THIS POINT.
                                               192

-------
                                              EPA UTILITT F60 SURVEY: JULT -  SEPTEMBER  1980

                                           SECTION 3
               DESIGN  AND  PERFORMANCE  DATA FOR OPERATIONAL DOMESTIC FGD  SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUM3ER
CITY
STATE
5R05S UNIT GENERATING  CAPHCITY - MM
*ET JNIT  GENERATING  CAPACITY  U/FGD - Mb
EBUIVALENT SCRUBBED  CAPACITY  - MW

••  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT - J/G
    AVERAGE ASH  CONTENT - X
    AVERAGE MOISTURE CONTENT  - X
    AVERAGE SULFUR CONTENT -  X
    AVERAGE CHLORIDE CONTENT  - X

*•  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP BATE
    COHHERCIAL  START-UP DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE  DESIGN REMOVAL EFFICIENCY
    A3SORBER  SPARE CAPACITY INDEX - X
    ABSORBER  SPARE COMPONENTS INDEX

 »*  WATER  LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 •*  DISPOSAL
     TYPE
                                    -  X
                                        SPRINGFIELD  CITY  UTILITIES
                                        SOUTHWEST
                                        1
                                        SPRINGFIELD
                                        MISSOURI
                                          194.0
                                          173.0
                                          194.0
                                                        (  11500 BTU/LB)
                            COAL
                            BITUMINOUS
                             26749.
                                13.00
                                9.00
                                3.50
                                  .30
                            WET  SCRUBBING
                            LIMESTONE
                            AIR  CORRECTION  DIVISION, UOP
                            NEW
                                 4.6
                              4/77
                              9/77
                                eo.oo
                                99.70
                                20.0
                                  .3
                                         CLOSED
                                                 LANDFILL
                                                        (*..«* GPM)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD   CAP.
                                                                 S02  PART. HOURS HOURS   HOURS FACTOR
 1/80  S-1
       S-2
       SYSTEM
            54.5
            68. 7
            61.6
            38.7
            72.6
            55.7
            47.9
            73.1
            60.5
36.3
68.1
52.2
                                                                               744
                                                                                     698
                                                                                            388  65.4
       «• PROBLEMS/SOLUTIONS/COMMENTS
  2/80
S-1
S-2
SYSTEM
36.7
73.8
55.3
                          AT  THE  BEGINNING OF JANUARY AN S-1  ID  FAN EXPANSION  JOINT FAILED.
                          BOILER  WAS  SHUTDOWN SOON AFTER FOR  BOILER-RELATED  PROBLEMS.
                                                                                              THE
                          DURING  THE LATTER PART OF THIS PERIOD  THE  S-1  MIST  ELIMINATOR AND TRAP OUT
                          TRAY  HEADER FROZE.  AFTER REPAIRS WERE MADE  BOTH  MODULES WERE PUT ON LINE.
                          BOTH  WERE  KEPT RUNNING UNTIL JANUARY  20  WHEN A FLANGE BROKE LOOSE ON THE
                          HIST  ELIMINATOR HEADER.

                          AFTER MIST ELIMINATOR REPAIRS WERE  COMPLETED THE  S-1 MODULE OPERATED UNTIL
                          JANUARY 27 WHEN FREEZING AIR LINES  TO  THE  BALL MILLS PREVENTED THE USE OF
                          BOTH  MODULES DUE TO THE LACK OF  SLURRY.

                          THE S-2 MODULE WAS ON LINE  AT THE BEGINNING  OF THE  MONTH BUT DEVELOPED
                          PRESATURATOS SPRAY NOZZLE PROBLEMS.  WHILE THIS WAS BEING REPAIRED THE
                          UNIT  WAS TAKEN OFF LINE.  APART  FROM  THIS  IIME THE  MODULE WAS ON LINE.
2P.1
71.7
5".4
                                            31.5
                                            73.2
                                            52.4
 29.1
 71.6
 5C.4
                                                                               696   695
                                                                                     350  59.9
                                                 193

-------
 EPA UTILITY FGD SURVEY: JULY  - SEPTEMBER 1980

SPRINGFIELD CITY UTILITIES:  SOUTHWEST  1  (CONT.)
	PERFORMANCE OAT A	
PERIOD MODULE AVAILABILITY  OPERABIL1TY  RELIABILITY UTILIZATION  * REMOVAL    PER   BOILER   FGD   CAP.
                                                                 S02  PART.  HOURS  HOURS   HOURS FACTOR


       •* PROBLEMS/SOLUTIONS/COMMENTS

                          THE  S-1  MODULE WAS OUT OF SERVICE IN THE FIRST  PART OF  FEBRUARY OUE TO
                          FROZEN  AND  BROKEN LINES.  THE SUPERNATE LINE BROKE  IN SEVERAL  PLACES TAKING
                          BOTH  MODULES  OUT OF SERVICE FOR SEVERAL DAYS.   ONCE THIS  HAS REPAIRED BOTH
                          MODULES  WERE  IN SERVICE AS REQUIRED BY LOAD EXCEPT  FOR  A  FEU MINOR TRIPS.
                          THE  S-2  MODULE  WAS EITHER IN SERVICE OR AVAILABLE  FOR HOST  OF  THE  MONTH.
 5/80
      S-1
      S-2
      SYSTEM
            64.5
            22.0
            43. 3
                               64.1
                                5.8
                               35.0
64.4
 6.9
35.7
64.1
 5.8
35.0
                                                                               7*4
                                                                                     744
                                                                                            260  57.7
       • * PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  MARCH THE S-1 MODULE WAS OUT FOR 11 DAYS  TO  CLEAN  THE  ABSORBER
                          SECTION.

                          THE  S-2 MODULE  WAS OUT OF SERVICE FOR CLEANING THE  ABSORBER SECTIONS AND
                          MIST ELIMINATORS FOR NEARLY ALL THE PERIOD BUT WAS  AVAILABLE  ON  MARCH
                          25.   IT WAS  NOT OPERATED, HOWEVER, BECAUSE OF LOU UNIT  LOAD DEMANDS.
4/80  S-1
      S-2
      SYSTEM
                   78.2
                   15.1
                   46.7
                               69.1
                                6.9
                               37.9
                                            37.9
                                                 59.6
                                                  6.0
                                                 32.8
                                                                               720
                                                                                     621
                                                                                            236  42.4
       *• PROBLEMS/SOLUTIONS/COMMENTS
                          THE  S-1  MODULE  EXPERIENCED SHORT OUTAGES DURING APRIL  CAUSED BY SLURRY
                          DRAW-OFF  PUMP  FAILURES AND MIST ELIMINATOR AND PRESATURATOR  SPRAY SYSTEM
                          PROBLEMS.

                          THE  S-2  MODULE  EXPERIENCED RECURRING HIGH FLUE GAS  TEMPERATURE-RELATED
                          PROBLEMS  DURING THE MONTH.  THIS WAS CORRECTED BY REPAIRING  THE SCRUBBER
                          INLET  SCREEN.
 5/80  S-1
       S-2
       SYSTEM
                  72.9
                  43.6
                  58.3
                         60.7
                         30.7
                         45.7
                                           69.1
                                           35. 2
                                           52.2
            60.6
            30.7
            45.7
                                                                              74*
                                                                                     744
                                                                                            340  56.7
       »* PROSLEMS/SOLUTIONS/COMMENTS

                          DURING  MAY  THE  S-1  SCRUBBER KEQUIRED CLEANING.

                          PUMP  AND  PUMP  CONTROL PROBLEMS ON THE S-1 SCRUBBING  TRAIN  OCCURRED
                          DURING  THE  PERIOD.

                          THE  S-2 MODULE  WAS  OFF LINE SEVERAL DAYS BECAUSE  OF  RECYCLE  PUMP AND
                          RECYCLE SYSTEM  REPAIRS.
4/80  S-1
      S-2
      SYSTEM
                  FLUE  GAS  OUTLET  DUCT REPAIRS WERE REQUIRED ON THE s-2 MODULE  IN  MAY.

                         85.6         85.5         84.9
                          6.8          7.2          6.8
                         45.8         47.4         45.8                   720    720     330   66.6

*« PROBLEMS/SOLUTIONS/COMMENTS
                   85.4
                   12.8
                   49.2
                         THE  S-1  MODULE  WAS  IN  CONTINUOUS SERVICE DURING JUNE WITH  SHORT  DURATION
                         OUTAGES  FOR  CLEANING,  CONTROL SYSTEM DAMAGE CAUSED BY  LIGHTNING, AND OTHER
                         MINOR  MISCELLANEOUS  PROBLEMS.

                         THE  S-2  MODULE  HAS  OUT OF SERVICE FOR APPROXIMATELY 23  DAYS  IN  JUNE BECAUSE
                         OF A BROKEN  SLURRY  HOLD TANK AGITATOR SHAFT.

                         IN ADDITION  TO  THE  OUTAGE CAUSED BY THE BROKEN SHAFT,  THE  S-2  MODULE HAD
                         SHORT  DURATION  OUTAGES CAUSED BY RECYCLE PUMP AGITATOR  PROBLEMS, CONTROL
                         SYSTEM PROGRAMMING,  AND OTHER MINOR MISCELLANEOUS PROBLEMS.
                                                194

-------
                                               EPA UTILITY F60 SURVEY: JULY -  SEPTEMBER  1980

SPRINGFIELD CITY UTILITIES:  SOUTHWEST  1  (CONT.)
.	---	"PERFORMANCE DATA	——
»ERIOD NODULE AVAILABILITY  OPERAPILITY  RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER   F6D   CAP.
                                                                 S02  PART.  HOURS  HOURS   HOURS FACTOR
 7/BO   S-1
        S-2
        SYSTEM
80.5
57.0
68.7
69.6
39.0
54.3
           69. 5
           39.0
           54.3
                                    72.4         54.3                   744   743    404  80.6

** PROBLE1S/SOLUTIONS/COM«ENTS

                  DURING JULY THE S-1  MODULE  WAS CLEANED AND THE SPHERES WERE REPLACED.

                  THE S-1 MODULE DUCTWORK  NEEDED REPAIR DURING JULY CAUSING SOME OUTAGE TIME.

                  THE SLUDGE DEWATERING  FILTER  BELT AND THE HOLD TANK BEARING FAILED
                  ACCOUNTING FOR SOME  OF  THE  S-1 MODULE DOWNTIME.

                  THE S-1 MODULE SPRAY CONTROL  VALVE  FAILED ADDING TO THE OUTAGE TIME.

                  HIGH  FLUE  GAS  TEMPERATURE CONDITIONS RESULTED  IN A SHUTDOWN OF BOTH THE
                  FGD MODULES.

                  THE S-2 MODULE AGITATOR SHAFT IN THE HOLD TANK FAILED  CAUSING  THE  MODULE
                  TO COME OFF LINE.

                  PROBLEMS  WERE  ENCOUNTERED WITH THE SLURRY DRAW OFF PUMP,  SUPERNATANT PUMP
                  AND THE RECYCLE  PUMP CAUSING  THE S-2 MODULE TO SHUTDOWN.

                  A POWER SUPPLY EflUIPMENT FAILURE RESULTED IN  A S-2 MODULE OUTAGE.

                  AN EXPANSION  JOINT  FAILURE  OCCURRED ON THE  S-2 MODULE  SEAL  AIR FAN.

                  A HIGH LEVEL  CONDITION IN THE DRAW OFF SUMP WAS  ALSO  A CAUSE  OF  THE
                  S-2 MODULE LOW AVAILABILITY.  THE PROBLEMS  EXPERIENCED WITH THE  CONTROL
                  SYSTEM CONTRIBUTED  ALSO.
  3/80  S-1
        S-2
        SYSTEM
 73.7
 71.9
 72.8
 67.4
 55.4
 61.4
                                             62.4
            67.4
            55.4
            61.4
                                                                                744
                                                                                      744
                                                                                             457  86.2
        *• PR03LEMS/SOLUTIONS/COMMENTS
                           THICKENER  PROBLEMS ENCOUNTERED DURING AUGUST  CAUSED  BOTH MODULES TO
                           SHUT  DOWN  FOR  PART OF THE MONTH.

                           THE OUTLET DUCT EXPERIENCED LEAKAGE CAUSING SOME  SYSTEM DOWN TIME.

                           THE S-1  MODULE DAMPER DRIVE FAILED CAUSED  ADDITIONAL OUTAGE TIME.

                           THE LIMESTONE  FEEDER FOR MODULE S-2 FAILED CAUSING  THE S-2 MODULE TO
                           SHUT  DOWN  FOR  PART OF THE MONTH.

                           THE  FGD  SYSTEM WAS SHUT DOWN DURING PART Of THE  MONTH SO THAT VALVE REPAIRS
                           COULD BE MADE.

                           PROBLEMS WERE  ENCOUNTERED WITH THE S-2  MODULE RECYCLE PUMP.
  ?/80   S-1
         S-2
         SYSTEM
 78.5
 57.5
 68.0
 85.8
   .6
 43.2
87.4
  .2
43.8
                                                  78.5
                                                    .2
                                                  39.4
                                                             720    658
283  80.3
         »•  PROBLEMS/SOLUTIONS/COMMENTS
                           DURING SEPTEMBER, THE  SCRUBBER  OUTLET DUCTS EXPERIENCED LEAKING CAUSING
                           THE SYSTEM TO SHUTDOWN  FOR  PART OF  THE MONTH.

                           THE S-1 NODULE EXPERIENCED  INLET DAMPER PROBLEMS.

                           THE RECYCLE SPRAY NOZZLES  ON THE S-2 MODULE PLUGGED CAUSING ADDITIONAL
                           OUTAGE TIME.
                                                  195

-------
 EPA  UTILITY  FGO  SURVEY:  JULY - SEPTEMBER 1980

                                            SECTION  3
                DESIGN  AND PERFOR"ANCE DATA FOB OPERATIONAL  DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 5ROSS UNIT GENERATING  CAPACITY - MW
 NET JNIT GENERATING  CAPACITY W/FGD - My
 EQUIVALENT SCRUBBED  CAPACITY - MW

 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT - J/G
     AVERAGE ASH  CONTENT  - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

 •* GENERAL EMISSION  CONTROL SYSTEM DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP  DATE
     S02 DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE  DESIGN  REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS  INDEX
   ST. JOE ZINC
   G.F. WEATON
   1
   MONACA
   PENNSYLVANIA
      60. 0
      60.0
      60.0
   COAL
   BITUMINOUS
    29075.
      11.50
   *»******
       2.00
        .20
   WET SCRUBBING
   CITRATE
   MORRISON t KNUDSEN/U.S,
   RETROFIT
(  12500 BTU/LFJ)
        B.M.
   11/79
    1/80
      90.00
X     99.60
        .3
        .0
 •« WATER LOOP
     TYPE
     FRESH MAKE-UP  HATER  -  LITER/S

 •* BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
   CLOSED
                  («»*.* GPM)
   ELEMENTAL SULFUR
.	.	-PERFORMANCE DATA	—
PERIOD HODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION
                                                                 x REMOVAL    PER   BOILER  FGD   CAP.
                                                                 SO?  PART.  HOURS  HOURS   HOURS FACTOR
 1/60  SYSTEM

 2/80  SYSTEM

 5/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                 744

                                 696
                                 744
                          THE  SYSTEM  IS  STILL GOING THROUGH THE DEBUGGING  PHASE  OF  OPERATION.  SOME
                          EQUIPMENT PROBLEMS HAVE OCCURRED, ESPECIALLY WITH  THE  HYDROGEN SULflDE
                          GENERATOR AND  HEAT EXCHANGERS, ONE OF WHICH HAD  TO  BE  REMOVED  AND RETURNED
                          TO THE  MANUFACTURER.  NO OPERATING HOURS WERE LOGGED DURING THE FIRST
                          QUARTER OF  1980 BRINGING THE TOTAL SYSTEM OPERATING HOURS TO 42 IN 1979.
 WBO  SYSTEM
 5/30  SYSTEM

 4/80  SYSTEM

       •« PROBLEMS/SOLUTIONS/COMMENTS
                                 720

                                 744

                                 720
                         THE  GEORGE  F.  UNEATON STATION HAS BEEN OPERATING  AT  A  REDUCED  LOAD OF 2P
                         TO  30  MW  SINCE  DECEMBER, 1979 DUE TO THF SHUTDOWN OF THE  ST. JOE ZINC co.
                         SMELTER.   ALTHOUGH A NUMBER OF TRIAL RUNS OF THE  CITRATE  DEMONSTRATION
                         PLANT  HAVE  BEEN MADE DURING THE PAST SIX MONTHS,  MECHANICAL BREAKDOWNS OF
                         EQUIPMENT  AND  PROBLEMS  RELATED TO LOU TEMPERATURE OPERATION HAVE PREVENTED
                         CONTINUOUS  OPERATION TO OBTAIN MEANINGFUL DATA.   ST. JOE  IS ATTEMPTING TO
                                                196

-------
                                               EPA UTILITY  F6D SURVEY: JULY - SEPTEMBER  1980

ST. JOE ZINC: G.F.  WEATON  1  (CONT.)
„__	PERFORMANCE  DATA —	—~	~ —
PERIOD MODULE  AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER   BOILER   F60   CAP.
                                                                  SO?  PART. HOURS  HOURS   HOURS FACTOR

                          NEGOTIATE A POWER SALES  AGREEMENT THAT WILL PERMIT FULL  UTILIZATION OF THE
                          STATION CAPACITY AND  ALSO  PROVIDE DESIGN FLUE GAS QUANTITIES TO THE DEMON-
                          STRATION PLANT.  OPERATION OF THE POWER PLANT AT THE  DESIGN RATES IS RE-
                          QUIRED FOR ACCEPTANCE  AND  DEMONSTRATION TESTING.

 7/80  SYSTEM                                                                   7*4

 5/80  SYSTEM                                                                   74*

       **  PROBLtMS/SOLUTIONS/COHMENTS

                          THE CITRATE  PROCESS  DID  NOT OPERATE DURING  THE  MONTHS OF JULY AND AUGUST
                          1980.

                          NEGOTIATIONS  TO  PERMIT THE POUER PLANT  TO OPERATE  AT HIGHER RATES AND
                          ALLOW  THE  DEMONSTRATION  PLANT TEST PROGRAM  TO  PROCEED AS PLANNED  ARE
                          CONTINUING.

  9/80  SYSTEM                                                                  720

        •*  PROBLEMS/SOLUTIONS/COMMENTS

                           NEGOTIATIONS MENTIONED EARLIER CONTINUED  THROUGH SEPTEMBER.  MINIMAL
                           F&D OPERATIONS  WERE  REPORTED FOR THE  MONTH.
                                                   197

-------
 EPA UTILITY  F6D  SURVEY: JULY - SEPTEMBER 1980

                                            SECTION  3
                OESI6N  AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING  CAPACITY - NU
 1ET UNIT GENERATING  CAPACITY V/FGD - MW
 EQUIVALENT SCRUBBED  CAPACITY - *U

 •• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT  - X
     AVERAGE CHLORIDE CONTENT - X

 •* GENERAL EMISSION  CONTROL SYSTEM DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     HEM/RETROFIT
     ENERGY CONSUMPTION -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     A9SORBER SPARE CAPACITY INDFX - X
     ABSORBED SPARE COMPONENTS INDEX

 •• HATER LOOP
     TYPE
     FRESH MAKE-UP WATER - L1TER/S
- X
     TENNESSEE VALLEY  AUTHORITY
     SHAWNEE
     10A
     PADUCAH
     KENTUCKY
        10.0
        10.0
        19.0
     COAL
     BITUMINOUS
         2.90
                  «  (»***.*  BTU/LB)
     UET SCRUBBING
     LIME/LIMESTONE
     AIR CORRECTION  DIVISIONt  OOP
     RETROFIT
 4/72
»*/ **
   90.00

     .3
     .0
     CLOSED
                     (»***-* 6PM)
	.—_.-	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION
                     X REMOVAL    PER  BOILER  FGD   CAP.
                     SO?  PART.  HOURS  HOURS  HOURS FACTOR
 3/60  SYSTEM

       *» PROBLEMS/SOLUTIONS/COMMENTS

                          REFER  TO THE PERFORMANCE UPDATE  INFORMATION  FOR  SHAWNEE 10B.
                                                198

-------
                                              EPA  UTILITY  F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
               DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
SROSS  UNIT GENERATING  CAPACITY  -  MU
NET UNIT  GENERATING  CAPACITY  U/FGD  -  NW
EQUIVALENT SCRUBBED  CAPACITY  -  MW

• *  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT  - X
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR CONTENT -  X
    AVERAGE  CHLORIDE CONTENT  -  X

• *  GENERAL  EMISSION CONTROL SYSTEM DATA
     GENERAL  PROCESS TYPE
     PROCESS  TYPE
     SYSTEM  SUPPLIER
     NEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL  START-UP DATE
     COMMERCIAL START-UP DATE
     S02  DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY - X
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS  INDEX

 • • WATER  LOOP
     TYPE
     FRESH MAKE-UP HATER - LITER/S
TENNESSEE VALLEY AUTHORITY
SHAUNEE
10B
PADUCAH
KENTUCKY
   10.0
   10.0
   10.0
COAL
BITUMINOUS
                (****«* BTU/LB)
    2.90
********
WET SCRUBBING
LIME/LIMESTONE
CHEMICO  DIVISION,  ENVIROTECH
RETROFIT
 4/72
**/**
    90.00
********
      .0
      .0
 CLOSED
                (•***• 6PM)
_.__„_——--—--——	—PERFORMANCE  DATA—-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
                 X REMOVAL
                 SO?  PART.
 PER  BOILER  F6D   CAP.
HOURS HOURS  HOURS FACTOR
 |/80  SYSTEM

 2/80  SYSTEM

 3/60  SYSTEM

       «• PROBLEMS/SOLUTIONS/COMMENTS
                              744

                              696

                              744
                          DURING  THE  FIRST QUARTER OF 1980, ONLY THE VENTURI/SPRAV TOMER  SYSTEM  UAS
                          OPERATED.   THE  TCA SYSTEM CONTINUED TO OPERATE DURING THE QUARTER  ON DOWA
                          BASIC  ALUMINUM  SULFATE PROCESS UNDER EPRI/UOP/TVA SPONSORSHIP.
                          THE  LIMESTONE/ADIPIC ACID TEST SERIES ON THE VENTURI/SPRAY  TOWER SYSTEM,
                          WHICH  HAD  BEEN  INITIATED IN MID-DECEMBER TO INVESTIGATE THE RELATIONSHIP
                          BETWEEN THE SLURRY PH AND THE ADIPIC ACID CONSUMPTION {DEGRADATION) RATE,
                          UAS  COMPLETED IN MID-FEBRUARY.  THE TESTS WERE CONDUCTED WITHOUT FORCED
                          OXIDATION  AND WITH A SINGLE HOLD TANK.  AT THE SCRUBBER INLET PH OF 4.6
                          TO  5.0, ESSENTIALLY ALL OF THE ADIPIC ACID ADDED WAS ACCOUNTED  FOR IN
                          THE  LIQUID PHASE Of THE WASTE SLUDGE DISCHARGED FROM THE SYSTEM.   AT THE
                          SCRUBBER INLET  PH 5.25 AND 5.5, THE ADIPIC ACID UNACCOUNTED FOR WERE
                          6X  AND 26X , RESPECTIVELY.  THEREFORE. IT APPEARS THAT THE  ADIPIC
                          ACID COR CARBOXYLIC ACID) DEGRADATION TAKES PLACE AT SCRUBBER INLET
                          PH  ABOVE ABOUT  5.1 UNDER CONDITIONS ASKED.
                          A SERIES OF LIMESTONE/ADIPIC ACID TESTS WERE CONDUCTED FROM MID-FEBRUARY
                          TO  EARLY MARCH  USING THE VENTURI SCRUBBER ONLY WITH A SINGLE  TANK  AND
                          WITHOUT FORCED  OXIDATION TO INVESTIGATE THE S02 REMOVAL CAPABILITY OF  THE
                          VENTURI AT 5.1  INLET PH AND HIGH ADIPIC ACID CONCENTRATION.  AT 4000  PPM
                          ADIPIC ACID. L/G OF 21 GAL/MCf, AND 8.3 INCHES H20 PRESSURE DROP,  S02
                          REMOVAL WAS 65X WITH 2200 PPM INLET S02 CONCENTRATION.
                          FORCED OXIDATION USING A SINGLE TANK WITH LIMESTONE/ADIPIC  ACID SLURRY ON
                          THE VENTURI/SPRAY TOWER SYSTEM BEGAN IN MID-MARCH.  AS IN  THE CORRESPONDING
                          TEST SERIES CONDUCTED ON TCA IN APRIL 1979, LIMESTONE BLINDING  BY  CALCIUM
                          SULFITE OCCURRED.  SOLUTION OF THE  PROBLEM CAN BE  EXPECTED  BY USING  TWO
                                                 199

-------
 EPA UTILITY FGD SURVEY:  JULY  -  SEPTEMBER  19PO

TENNESSEE VALLEY AUTHORITY:  SHAWNEE  1CB  (CONT.)
	PERFORMANCE DATA	
PERIOD NODULE AVAILABILITY OPERAEILITY  RELIABILITY UTILIZATION  t REMOVAL    PER   BOILER  F6D   CAP.
                                                                 SO?  PART.  HOURS  HOURS   HOURS FACTOR

                          TANKS  IN  SERIES WITH FORCED OXIDATION IN THE FIRST TANK  AND  LIMESTONE
                          ADDITION  IN  THE SECOND.  THIS MODE IS PLANNED  ON BEING  DEMONSTRATEB NEXT
                          QUARTER.

 W80  SYSTEM                                                                  "0

 S/gn  SYSTEM                                                                  744

 4/80  SYSTEM                                                                  720

       • * PROBLEMS/SOLUTIOHS/COMMENTS

                          THE  VENTURI/SPRAY TOMER SYSTEM (TRAIN 100) WAS  SHUT  DOUN FROM  HAY 28
                          THROUGH JUNE  17 FOR CONVERSION TO A SPRAY TOWER-ONLY  SYSTEM  BY THE PHYSICAL
                          REMOVAL OF THE  VENTURI  SECTION.  THE SPRAY TOWER-ONLY TESTING  BEGAN
                          JUNE  17 ON A  SERIES OF  LIMESTONE FACTORIAL TESTS,  BOTH  WITH  AND WITHOUT
                          FORCED OXIDATION, TO CHARACTERIZE THE EFFECTS  OF LIQUID-TO-6AS RATIO AND
                          SLURRY PH ON  SO? REMOVAL IN THE SPRAY TOWER (THE FIRST  SPRAY TOWER-ONLY
                          TESTING AT SHAWNEE).

 7/80  SYSTEM                                                                  7*4

 S/80  SYSTEM                                                                  7*4

 J/80  SYSTEM                                                                  720

       •• PROBLEMS/SOLUTIONS/COMMENTS

                          TRAIN  100 WAS  AGAIN SHUT DOWN FROM AUGUST 11-38 FOR  MODIFICATION OF THE
                          SLURRY PIPING  AND INTERNAL HEADERS TO INCREASE  THE SLURRY FLOW CAPACITY
                          FROM  1600 TO  2400 GPM.   TESTING RESUMED ON AUGUST  28  ON  ANOTHER
                          LIMESTONE FACTORIAL TEST SERIES WITH AND WITHOUT FORCED  OXIDATION, BUT AT
                          HIGHER LIQUID-TO-GAS RATIOS (UP TO 150 6AL/.MCF  AT  20,000 ACFM  AT 300 F GAS
                          RATE  ANO  2400  GPM MAXIMUM SLURRY fLOW fUTEJ.   THIS TEST  SERIES IS EXPECTED
                          TO BE  COMPLETED BY MID  OCTOBER.
                          TESTING OF THE  TCA SYSTEM (TRAIN 200) RESUMED  ON JULY 15 AFTER THE SYSTEM
                          HAD  BEEN  RESTORED FRO1*  THE DOHA PROCESS OPERATING  MODE.   AS  PART Of THE
                          EPA  FULL-SCALE  ADIPIC ACID DEMONSTRATION PROGRAM,  THE SYSTEM HAD BEEN USED
                          THROUGHOUT THE  THIRD QUARTER TO SIMULATE THE OPERATION  OF THE  FULL-SCALE
                          TCA  UNITS OPERATING WITH LIMESTONE/ADIPTIC ACID SLURRY  AT THE  SOUTHWEST
                          STATION OF THE  SPRINGFIELD CITY UTILITIES. AT  SPRINGFIELD MISSOURI.  TESTS
                          HAVE  BEEN CONDUCTED BOTH WITH ANO WITHOUT FORCED OXIDATION TO  GENERATE
                          INFORMATION  USEFUL FOR  THE FULL-SCALE DEMONSTRATION.
                                                200

-------
                                              EPA UTIL1TT F60 SURVEY: JULY - SEPTEMBER  1980

                                           SECTION 3
              DESIGN  AND  PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
COMPANY NAME
PLANT NAME
JNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING  CAPACITY  - Mw
VET UNIT  GENERATING  CAPACITY  W/FGD - MW
EQUIVALENT SCRUBBED  CAPACITY  -  MW

• *  FUEL DATA
    FUEL  TYPE
    FJEL  GRADE
    AVERAGE  HEAT  CONTENT - J/6
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR CONTENT -  X
    AVERAGE  CHLORIDE CONTENT  -  X

••  GENERAL EMISSION  CONTROL SYSTEM DATA
    GENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     A3SORBER SPARE COMPONENTS INDEX

 •*  DISPOSAL
     TYPE
                                    - X
                                         TENNESSEE  VALLEY AUTHORITY
                                         WIDOWS  CREEK
                                         8
                                         BRIDGEPORT
                                         ALABAMA
                                           550.0
                                           516.0
                                           550.0
                                                        ( 10000 BTU/LB)
                             COAL
                             * ** ***
                              23260.
                                25.oo
                                10.00
                                 3.70
                             ********
                             WET  SCRUBBING
                             LIMESTONE
                             TENNESSEE VALLEY AUTHORITY
                             RETROFIT
                                 4.7
                              5/77
                              1/78
                                70.00
                                99.50
                                  .0
                                  .0
                                                 POND
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
 2/80
                                                         X  REMOVAL    PER  BOILER  FGD   CAP.
                                                         SO?   PART.  HOURS HOURS  HOURS FACTOR
1/80




A
B
C
D
SYSTEM
70.4
83.5
100.0
28.3
70.6
79.8
100.0
100.0
54.7
83.6
39.2
56.3
55.5
26.9
44.5 83.60




744 366 331 23.9
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  JANUARY  THE  UNIT 8 BOILER EXPERIENCED LOW AVAILABILITY,  CAUSING THE
                          FORCED  OXIDATION  TESTS TO BE DISCONTINUED UNTIL AFTER  THE  SCHEDULED
                          MAINTENANCE  OUTAGE  WHICH WILL BEGIN IN SEPTEMBER 1980.   THE  FORCED
                          OXIDATION  TESTS ARE EXPECTED TO RESUME IN JANUARY  1981.
A
B
C
D
SYSTEM
80.0
86.5
91.1
87.6
86.3
83.6
9C.2
97.6
9R.2
93.7
                                                        72.7
                                                        74.0
                                                        80.0
                                                        80.6
                                                        76.8
                                                         84.00
                                                           696   571
                                                                        535  43.6
        *•  PROBLEMS/SOLUTIONS/COMMENTS
  3/80
A
3
C
D
SYSTEM
93.6
93.0
71.9
93.3
86.C
                          BY FEBRUARY 27, 1980, THE DIFFERENTIAL PRESSURE  ACROSS  THE TRAIN C ABSORB-
                          ER HAD REACHED 19 INCHES WATER GAGE.   THE  HIGH  ABSORBER DIFFERENTIAL
                          PRESSURE WAS CAUSED BY PLUGGING OF  TURBULENT  CONTACT ABSORBER (TCA)
                          SPHERES WHICH WERE INSTALLED  DURING SCRUBBED  OPTIMIZATION TESTS.  1HE TCA
                          SPHERES WILL BE REMOVED IN MARCH.
88.3
5C.6
73.!
63.9
79.0
                                                        85.4
                                                        87.9
                                                        71.1
                                                        62.0
                                                        76.6
                                                                 62.60
                                                                               744
                                                                                     722
                                                                                     570  50.4
                                                 £01

-------
 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

TENNESSEE VALLEY AUTHORITY: WIDOWS CREEK 8  
-------
                                               EPA UTILITY F60 SURVEY:  JULY  - SEPTEMBER 1980

TENNESSEE VALLEY AUTHORITY:  WIDOWS  CREEK 8 (CONT.)
	—-—	— —	PERFORMANCE DATA	—.-	—--—--
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   X  REMOVAL   PER  BOILER  F6D   CAP.
                                                                  302   PART. HOURS HOURS  HOURS FACTOR


       ** PR08LEHS/SOLUTIONS/COMMENTS

                          INFORMATION FOR THE MONTHS  OF  AUGUST  AND  SEPTEMBER IS NOT AVAILABLE AT
                          THIS TIME.
                                                  203

-------
  EPA  UTILITY  FGD  SURVEY: JULY - SEPTEMBER 19*0

                                            SECTION 3
                DESIGN  AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  FGD  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 6ROSS UNIT GENERATING  CAPACITY - MW
 YET UNIT GENERATING  CAPACITY  W/FGD - MW
 EQUIVALENT SCRUBBED  CAPACITY  - MW

 **  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  - X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  - X

 **  GENERAL EMISSION  CONTROL SYSTEM DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     MEM/RETROFIT
     ENERGY CONSUMPTION  -  X
     INITIAL START-UP DATE
     C3MMERCIAL START-UP DATE
     S02 DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE DESIGN  REMOVAL EFFICIENCY
     A9SORBER SPARE CAPACITY INDEX - X
     A3SORBER SPARE COMPONENTS  INDEX

 •*  WATER LOOP
     TYPE
     FRESH MAKE-UP WATER - LITER/S

 •» TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
                   -  X
                        TEXAS UTILITIES
                        MARTIN LAKE
                        1
                        TATUM
                        TEXAS
                          793.0
                          750.0
                          595.0
                        COAL
                        LIGNITE
                         17166.
                            8.00
                           3J.OO
                             .90
                  7380 BTU/LBJ
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
NEW
    1.3
 4/77
10/78
   71.00
   99.40
     .0
     .0
                        CLOSED
                           34.6
                                       C  550 GPH>
                        FLYASH  STABILIZATION
                        LANDFILL
.	..—..	.....	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION
                                        X  REMOVAL   PER  BOILER  F6D   CAP.
                                        503  PART. HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 J/80  SYSTEM

       «• PROBLEMS/SOLUTIONS/COMMENTS
                                                     744

                                                     696

                                                     744
 4/80  SYSTEM

 5/80  SYSTEM

 4/80  SYSTEM
                         PLUGGING  PROBLEMS  CONTINUED IN THE FIRST QUARTER OF 1980, PARTICULARLY  IN
                         THE  WETTED  FILM  CONTACT AREA AND THE MIST ELIMINATOR SECTION.   THE
                         HIST ELIMINATOR  PLUGGING WAS RECENTLY SOLVED BY SWITCHING BACK  TO LAKE
                         WATER  FOR HIST ELIMINATOR WASH FROM AN ASH POND WATER WASH  THEY HAD  BEEN
                         TESTING.
                         THE FRP STRUCTURAL  WORK  IS  BECOMING A PROBLEM.
                         WORK WAS REPLACED WITH  STAINLESS STEEL.
                                                 MUCH OF THE FRP SUPPORT
THE UTILITY HAS PLANS  TO  INSTALL  TWO NEW  SCRUBBING TOWERS IN EARLY 1982.
THE NEW TOWERS HAVE BECOME  NECESSARY DUE  TO THE INCREASING LIGNITE
SULFUR CONTENT AND THE NEED FOR SPARE  SCRUBBER CAPACITY.

                                                     720

                                                     744

                                                     720
                                                204

-------
                                               EPA UTILITY FGD SURVEY: JUtY - SEPTEMBER 1980

TEXAS UTILITIES: MARTIN LAKE  1  (CONT.i
       .—————	..	«—....—-PERFORMANCE DATA——	———	————————
       MODULE  AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGD    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS FACTOR


       •*  PROBLEMS/SOLUTIONS/COMMENTS

                         HIGH MAINTENANCE PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
                         THE  SECOND  QUARTER OF 1980.  THE ABSORBERS ARE STILL EXPERIENCING PLUGGING
                         PROBLEMS.

  7/80  SYSTEM                                                                 744

       ••  PROBLEMS/SOLUTIONS/COMMENTS

                          CORROSION  IN THE SCRUBBER NODULES WAS A PROBLEM DURING  JULY.

                          THE  FOUNDATION FOR THE TWO NEW SCRUBBING TOUERS WAS COMPLETED  DURING THE
                          MONTH.

  J/80   SYSTEM                                                                  744

        SYSTEM                                                                  720

        **  PROBLEMS/SOLUTIONS/COMMENTS

                          THE UTILITY REPORTED THAT  THE  FGO SYSTEM OPERATED WITHOUT ANY MAJOR
                          PROBLEMS DURING AUGUST AND  SEPTEMBER.
                                                  205

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980


                                           SECTION 3

               DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY - MW
 WET UNIT GENERATING CAPACITY M/FGD - HW
 EQUIVALENT SCRUBBED CAPACITY - MW

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

 • * GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 *• WATER LOOP
     TYPE
     FRESH MAKE-UP HATER - LITER/S

 ** TREATMENT
     TYPE

 •* DISPOSAL
     TYPE
                                    - X
                                         TEXAS UTILITIES
                                         MARTIN LAKE
                                         2
                                         TATUM
                                         TEXAS
                                           793.0
                                           750.0
                                           595.0
                                         COAL
                                         LIGNITE
                                          17166.
                                             8.00
                                            33.00
                                              .90
                                         ********
                       WET SCRUBBING
                       LIMESTONE
                       RESEARCH-COTTRELL
                       NEW
                           1.3
                        5/78
                       **/**
                          71.00
                          99.40
                            .0
                            .0
                                      C  7380 BTU/LB)
                                         CLOSED
                                            34.6
                                                         (  550 GPM)
                                         FLYASH STABILIZATION
                                                LANDFILL
............	PERFORMANCE DATA	

PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                                                         X REMOVAL   PER   BOILER   FGD    CAP.
                                                         $02  PART.  HOURS  HOURS   HOURS  FACTOR
 1/80

 2/80

 3/80
SYSTEM


SYSTEM


SYSTEM


** PROBLEMS/SOLUTIONS/COMMENTS
                                                     744


                                                     696

                                                     744
 fc/80

 5/80

 6/ao
SYSTEM


SYSTEM

SYSTEM
                         PLUGGING PROBLEMS CONTINUED  IN  THE  FIRST  QUARTER  OF  I960,  PARTICULARLY IN
                         THE WETTED FILM CONTACT AREA AND THE MIST ELIMINATOR  SECTION.   THE
                         MIST ELIMINATOR PLUGGING WAS RECENTLY  SOLVED  BY SWITCHING  BACK TO LAKE
                         MATER FOR MIST ELIMINATOR WASH  FROM AN  ASH  POND WATER WASH THEY HAD BEEN
                         TESTING.
                         THE FRP STRUCTURAL WORK IS BECOMING  A  PROBLEM.
                         WORK WAS REPLACED WITH STAINLESS STEEL.
                                                                          MUCH OF  THE FRP SUPPORT
THE UTILITY HAS PLANS TO INSTALL TWO NEW SCRUBBING TOWERS  IN  EARLY  1983.
THE NEW TOWERS HAVE BECOME NECESSARY DUE TO THE  INCREASING  LIGNITE  SULFUR
CONTENT AND THE NEED FOR SPARE SCRUBBER CAPACITY.


                                                     720


                                                     744


                                                     720
                                                206

-------
                                               EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

fEMAS UTILITIES: HARTIN  LAKE  2  UONT.)
.	....	.	.	PERFORMANCE DATA	—	
PERIOD NODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  i REMOVAL   PER  BOILER  FGD   CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS  FACTOR


       o» PROBLE^S/SOLUTIOIS/COMHEMTS

                         HIGH  MAINTENANCE  PROBLEMS REPORTED IN PREVIOUS MONTHS CONTINUED THROUGHOUT
                         THE SECOND  QUARTER OF  1980.  THE ABSORBERS ARE STILL OPER1EWCIN6 PLU66IN6
                         PROBLEMS.

 f/80  SYSTER                                                                 7*4

       oo PftOBLEnS/SOLUTIONS/COnnENTS

                         CORROSION  IN  THE  SCRUBBER MODULES bAS A PROBLEM DURING JULY.

                         THE FOUNDATION FOR THE 2 NE« SCRUBBING TOUS.RS HAS COMPLETED DURING THE
                         RONTH.

 J/BO  SYSTEM                                                                 744

 J/BO  SYSTEH                                                                 720

       0* PROSLEnS/SOLUTIONS/COMWENTS

                         THE UTILITY REPORTED THAT THE FGD SYSTEH OPERATED HITHOUT ANY HAJOB
                         PROBLEMS  DURING AUGUST AND SEPTEMBER.
                                                207

-------
 EPA UTILITY  FGD  SURVEY:  JULY  - SEPTEMBER  1980

                                            SECTION 3
               DESIGN  AND  PERFORMANCE  DATA  FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY NAME
 PLANT NME
 JNIT NUMBER
 CITY
 STATE
 SROSS UNIT GENERATING CAPACITY  -  MW
 NET UNIT GENERATING CAPACITY  W/FGD -  MW
 EBUIVALENT SCRUBBED CAPACITY  -  My

 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT -  X
     AVERAGE CHLORIDE CONTENT  -  X

 •* GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     SOZ DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - t
     ABSORBER SPARE COMPONENTS INDEX

 •* TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
                        TEXAS  UTILITIES
                        MARTIN  LAKE
                        3
                        TATUM
                        TEXAS
                         793.0
                         750.0
                         595.0
                       COAL
                       LIGNITE
                        17166.
                           8.00
                          J3.00
                             .90
<  7380 BTU/LB)
                       WET SCRUBBING
                       LIMESTONE
                       RESEARCH-COTTRELL
                       NEW
                           1.3
                        2/79
                       **/ **
                          71.00
                  - X     99.40
                            .0
                            .0
                       FLYASH  STABILIZATION
                                                 LANDFILL
.	_ — ..	....	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
                                       x  REMOVAL    PER   BOILER  FGD   CAP.
                                       502   PART.  HOURS  HOURS   HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM
                                                     7*4

                                                     696

                                                     74*
       *• PROSLEMS/SOLUTIONS/COMMENTS
                         PLUGGING PROBLEMS  CONTINUED  IN  THE  FIRST QUARTER OF 1980, PARTICULARLY IN
                         THE WETTED  FILM  CONTACT  AREA AND  THE MIST ELIMINATOR SECTION.  THE
                         MIST ELIMINATOR  PLUGGING WAS RECENTLY SOLVED BY SWITCHING BACK TO LAKE
                         WATER FOR MIST ELIMINATOR WASH  FROM AN ASH POND WATER WASH THEY HAD BEEN
                         TESTING.
                         THE FRP STRUCTURAL  WORK  IS  BECOMING A  PROBLEM.
                         WORK WAS REPLACED WITH STAINLESS  STEEL.
                                                 MUCH  OF  THE  FRP SUPPORT
 1/80  SYSTEM

 S/BO  SYSTEM

 S/80  SYSTEM
THE UTILITY HAS PLANS TO INSTALL TWO NEW  SCRUBBING  TOWERS  IN EARLY 1983.
THE NEW TOWERS HAVE BECOME NECESSARY DUE  TO  THE  INCREASING LIGNITE SULFUR
CONTENT AND THE NEED FOR SPARE  SCRUBBER CAPACITY.

                                                     720

                                                     744

                                                     720
                                                208

-------
                                              EPA UTILITY F6D SURVEY: JULY -  SEPTEMBER  1980

TEXAS UTILITIES: MARTIN LAKE 3 (CONT.)
---—————————	————PERFORMANCE DATA——	————————
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  t  REMOVAL    PER   BOILER   FGD    CAP.
                                                                S02   PART.  HOURS  HOURS   HOURS  FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         HIGH MAINTENANCE PROBLEMS REPORTED  IN  PREVIOUS  MONTHS  CONTINUED THROUGHOUT
                         THE SECOND QUARTER OF  1980.  THE  ABSORBERS  ARE  STILL  EXPERIENCING PLUGGING
                         PROBLEMS.

 7/80  SYSTEM                                                                 7**

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         CORROSION  IN THE SCRUBBER MODULES WAS  A  PROBLEM DURING JULY.

                         THE FOUNDATION FOR THE  2 NEW SCRUBBING TOWERS WAS  COMPLETED DURING THE
                         MONTH.

 5/80  SYSTEM                                                                 744

 9/80  SYSTEM                                                                 720

       *• PROBLENS/SOLUTIONS/COMffENTS

                         THE UTILITY  REPORTED  THAT  THE  FGD SYSTEM OPERATED  WITHOUT ANY MAJOR
                         PROBLEMS  DURING  AUGUST AND  SEPTEMBER.
                                                 209

-------
 EPA UTILITY  F6D SURVET:  JULY  -  SEPTEMBER  1980

                                            SECTION 3
               DESIGN  AND PERFORMANCE  DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 (ROSS UNIT GENERATING  CAPACITY  - MU
 NET UNIT GENERATING CAPACITY  U/F6D -  MU
 EOUIVALENT SCRUBBED CAPACITY  -  MU

 *• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - Z
     AVERAGE MOISTURE CONTENT  -  S
     AVERAGE SULFUR CONTENT -  X
     AVERAGE CHLORIDE CONTENT  -  X

 •* GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEU/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL EFFICIENCY - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 •* MATER LOOP
     TYPE
     FRESH MAKE-UP UATER - LITER/S

 •• TREATMENT
     TYPE

 *• DISPOSAL
     TYPE
- X
     TEXAS UTILITIES
     MONTICELLO
     3
     NT. PLEASANT
     TEXAS
       800.0
       750.0
       aoo.o
                     (••**.** BTU/L61
COAL
LIGNITE

   18.90
   31.90
    1.50
     .04
UET SCRUBBING
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
NEU
*******
 5/78
10/78
   74.00
   99.50
     .0
     .0
     CLOSED
                    (  5*6 GPM)
     FLYASH STABILIZATION


     LANDFILL
....„...__„„.._ — -...__..	.	—PERFORMANCE  DATA — —	——"—————	
PERIOD MODULE AVAILABILITY OPERABILITV  RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  FSD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM                                                                 744

 2/80  SYSTEM                                                                 696

 3/80  SYSTEM                                                                 744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NO PROBLEMS UERE  ENCOUNTERED DURING  THE FIRST QUARTER OF 1980.

 4/80  SYSTEM                                                                 720

 5/80  SYSTEM                                                                 744

 6/80  SYSTEM                                                                 720

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         THE MONTICELLO 3  SCRUBBING  SYSTEM  PERFORMED UELL THROUGHOUT THE SECOND
                         BUARTER OF 1980.  THE  TEXAS  AIR  CONTROL BOARD REPORTED THAT IT HAD RECEIVED
                         VERY FEU EXCESS EMISSIONS REPORTS  FROM THE  STATION DURING THE APRIL-JUNE
                         PERIOD.
 7/80  SYSTEM
                                  744
                                                210

-------
                                               EPA UTILITY F6D  SURVEY:  JULY - SEPTEMBER I960

TEXAS UTILITIES: MONTICELLD  3  (CONT.)
	—PERFORMANCE DATA--	—	—————-
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   t  REMOVAL   PER  BOILER  FGO   CAP.
                                                                  SOZ  PART. HOURS HOURS  HOURS  FACTOR


       •* PROBLENS/SOLUTIONS/COMMENTS

                          NO MAJOR FGD-RELATED PROBLEMS  WERE  ENCOUNTERED CURING JULY.

 S/80  SYSTEM                                                                  7*4

 »/BO  SYSTEM                                                                  720

       «• PROBLEMS/SOLUTlONS/COfmENTS

                          THE UTILITY REPORTED THAT THE  RECYCLE  PUMP LININGS HAVE BEEN  A  CONTINUAL
                          PROBLEM DURING AUGUST AND SEPTEMBER.  AT ONE TIME DURING  THE  TWO  MONTH
                          PERIOD THREE RECYCLE PUMP LINERS FAILED.

                          THE FGD SYSTEM CONTINUES TO PERFORM  WELL AND IS  IN COMPLIANCE MORE  THAN
                          95Z OF THE TIME.
                                                  Z11

-------
 EPA  UTILITY  FGO  SURVEY: JULY - SEPTEMBER 1980

                                            SECTION  3
                DESIG-N  AND PERFORMANCE DATA FOR OPERATIONAL  DOMESTIC  F6D  SYSTEMS
 COMPANY NAME
 PLANT NAME
 JNIT NUMBER
 CITY
 STATE
 •ROSS UNIT GENERATING  CAPACITY - MU
 NET UNIT GENERATING  CAPACITY W/FGO - MU
 EQUIVALENT SCRUBBED  CAPACITY - My

 •* FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT - J/6
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - I

 •• GENERAL EMISSION  CONTROL SYSTEM DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION  - X
     INITIAL START-UP DATE
     CONtERCIAL START-UP  DATE
     S52 DESIGN REMOVAL  EFFICIENCY - X
     PARTICULATE DESIGN  REMOVAL EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 •* WATER LOOP
     TYPE
     FRESH MAKE-UP VATER  - LITER/S
                   UTAH POWER K LIGHT
                   HUNTER
                   1
                   CASTLE  DALE
                   UTAH
                     400.0
                     400.0
                     360.0
                                  ( 12500 BTU/LR)
COAL
BITUMINOUS
 29075.
   10.00
    6.50
     .55
     .00
                   WET  SCRUBBING
                   LIME
                   CHEMICO  DIVISION. ENVIROTECH
                   NEW
                    5/79
                    5/79
                      80.00
               X      99.50
                        .0
                        .0
                   OPEN
                   *******
                                                                 (»***«  GPM)
 •• TREATMENT
     TYPE

 »* DISPOSAL
     TYPE
                   FLYASH  STABILIZATION
                                                 POND
	PERFORMANCE DATA	.—....—.——.	
»Ef»IOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL    PER  BOILER  F6D   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR
13/79
11/79
12/79
1/80
2/80
SYSTEM
SYSTEM
SYSTEM
SYSTEM
SYSTEM
100.
100.
100.
100.
100.
0
0
0
0
0
95
91
98
95
86
.6
.1
.2
.9
.8
7*4
720
744
744
696
711
656
731
715
604
711
6S6
7J1
713
604
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE  UTILITY  REPORTED THAT THERE WERE NO MAJOR  FGD  PROBLEMS  ENCOUNTERED
                         FROM  OCTOBER 1979 THROUGH FEBRUARY 1980.
 5/80  SYSTEM                   57.8

       »* PROBLEMS/SOLUTIONS/CONMENTS
                                                        56.9
                                                                               744    732
                                                             423
                         THE  FGD  SYSTEM  HAS FORCED OF SERVICE IN MARCH  BECAUSE  THE THICKENER RAKE
                         SHAFT  FAILED  AND THE TANK HAD TO BE DRAINED.   THIS  OUTAGE KEPT THE SYSTEM
                         DOVN FOR  APPROXIMATELY 309 HOURS.
 4/80  SYSTEM

 5/80  SYSTEM
100.0

100.0
       60.1

       64.0
720   433

744   476
433

476
                                                212

-------
                                              EPA UTILITY F60  SURVEY:  JULY  -  SEPTEMBER  1980

UTAH POWER I LIGHT: HUNTER 1 CCONT.)
	PERFORMANCE  DATA	—-—	———-
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X  REMOVAL   PER   BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE LOU  FGD HOURS  DURING  APRIL  AND MAT  RESULTED FROM THE ANNUAL OUTAGE
                         FOR GENERAL FGD  SYSTEM  MAINTENANCE.

 5/80  SYSTEM                  100.0                     97.9                  720   70S    705

       *• PROBLEMS/SOLUTIONS/COMMENTS

                         NO FGD SYSTEM PROBLEMS  UERE  REPORTED FOR  JUNE.

 7/80  SYSTEM                  100.0                    100.0                  7**   744    744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NO MAJOR F6D-RELATED  PROBLEMS UERE REPORTED DURING JULY.

 9/80  SYSTEM      100.0                                                       744   744

 9/80              100.0
       SYSTEM                                                                 720   713

       *• PROBLE1S/SOLUTIONS/COHMENTS

                          THE  UTILITY  REPORTED  THAT NO MAJOR FGD PROBLEMS UERE ENCOUNTERED  DURING
                          THE  MONTHS  OF  AUGUST  AND  SEPTEMBER.
                                                 213

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 3
               DESIGN AND PERFORMANCE DATA FOR OPERATIONAL DOMESTIC F6D SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 REGULATORY  CLASSIFICATION
 PARTICULATE  EMISSION LIMITATION - NG/J
 S02 EMISSION  LIMITATION -  N6/J
 NET PLANT 6ENERATIN6 CAPACITY - MU
 6ROSS  UNIT GENERATING CAPACITY  - MW
 NET UNIT GENERATING  CAPACITY  U/FGD - MW
 NET UNIT GENERATING  CAPACITY  UO/FGD - MU
 E3UIVALENT SCRUBBED  CAPACITY  -  MU
 UTAH  POWER  t  LIGHT
 HUNTER
 2
 CASTLE  DALE
 UTAH
 B
    43.
   516.
 *******
   400.0
   400.0
 *******
   360.0
(  .100 LB/MNBTU)
( 1.COO LB/MHBTU)
 *•  BOILER  DATA
     SUPPLIER
     TYPE
     SERVICE LOAD
     COMMERCIAL  SERVICE  DATE
     MAXIMUM BOILER  FLUE  GAS  FLOU - CU.H/S
     FLUE GAS  TEMPERATURE - C
     STACK  HEIGHT  -  M
     STACK  TOP DIAMETER  - M

 •*  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT - J/6
     RANEE  HEAT  CONTENT  - BTU/LB
     AVERAGE ASH CONTENT  - X
     RANEE  ASH CONTENT -  X
     AVERAGE MOISTURE CONTENT - X
     RANGE  MOISTURE  CONTENT - X
     AVERAGE SULFUR  CONTENT - X
     RANGE  SULFUR  CONTENT - X
     AVERAGE CHLORIDE CONTENT - X
     RANGE  CHLORIDE  CONTENT - X

 **  GENERAL EMISSION CONTROL  SYSTEM  DATA
     SALEABLE  PRODUCT/THROUAUAY PRODUCT
     GENERAL PROCESS TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     A-E FIRM
     DEVELOPMENT LEVEL
     NEU/RETROFIT
     PARTICULATE DESIGN REMOVAL EFFICIENCY -  X
     S02 DESIGN  REMOVAL EFFICIENCY  - X
     COMMERCIAL  DATE
     INITIAL START-UP
COMBUSTION  ENGINEERING
PULVERIZED  COAL
BASE
 4/80
********        (***«***  ACFM)
*******         (**•*  F)
******          !*•*»  FT>
*******         (****• FT)
COAL
******
 29075.

    10.00
9-12
    6.50
******
     .55
******
********
(  12500 BTU/LB)
 12,COO - 12.700
THROUAUAY PRODUCT
UET SCRUBBING
LIME
CHEMICO DIVISION, EHVIROTECH
STEARNS-ROGER
FULL SCALE
NEU
   99.50
   80.00
 6/80
 6/80
   ESP
    NUMBER                                       1
    SUPPLIER                                    BUELL
    FLUE GAS CAPACITY - CU.M/S                   886.2
    FLUE GAS TEMPERATURE - C                     127.8
                (1878000 ACFM)
                (  262 F)
*• PARTICLE SCRUBBER
    TYPE

•* A3SOR3ER
    TYPE
    INITIAL START UP
    SUPPLIER

•* MIST ELIMINATOR
    TYPE
NONE
SPRAY TOUER
 6/80
CHEHICO DIVISION, ENVIROTECH
                                               CHEVRON
*• REHEATER
    TYPE

•• REHEATER
    TYPE
HOT AIR INJECTION
                                               BYPASS
                                               214

-------
                                               EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980
UTAH POWER t LIGHT: HUNTER 2  (CONT.)
 »• HATER LOOP
     TYPE

 ** TREATMENT
     TYPE

 *• DISPOSAL
     NATURE
     TYPE
     LOCATION
OPEN
FLTASH STABILIZATION
FINAL
POND
ON SITE
	...—... ... -.	PERFORMANCE DATA	—	—	
PERIOD NODULE  AVAILABILITY  OPERABILITV RELIABILITY UTILIZATION  t REMOVAL    PER   BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
 6/BO   SVSTEN                  100.0

        **  PROBLEMS/SOLUTIONS/COMMENTS
       99.5
                                                                               720   717    717
                          INITIAL AND COMMERCIAL OPERATIONS  AT  HUNTER  2  BEGAN IN JUNE.  NO MAJOR
                          STARTUP PROBLEMS WITH THE  F6D SYSTEM  HERE  ENCOUNTERED.
                                                        98.9
                                                                               74*   736    736
  7/80  SYSTEM                 100.0

        *•  PROBLEMS/SOLUTIOVS/COHNENTS

                          NO MAJOR FGD-RELATED PROBLEMS HERE  REPORTED DURING JULY.

  8/80  SYSTEM      99.7                                                       74*   7*3

  9/80  SYSTEM     100.0                                                       730   720

        • *  PROBLENS/SOLUTIONS/CONMENTS

                          THE UTILITY REPORTED THAT  NO MAJOR  FGD PROBLEMS HERE ENCOUNTERED DURING
                          AUGUST AND SEPTEMBER.
                                                  215

-------
 EPA  UTILITY  F6D  SURVEY:  JULY  - SEPTEMBER 1980

                                            SECTION 3
                DESIGN  AND PERFORMANCE  DATA FOR OPERATIONAL DOMESTIC FGD SYSTEMS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 SROSS UNIT GENERATING  CAPACITY  - MM
 VET UNIT GENERATING  CAPACITY  U/FGD  - MW
 EQUIVALENT SCRUBBED  CAPACITY  -  MW

 •• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT  CONTENT  -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  -  t

 •• GENERAL EMISSION  CONTROL SYSTEM  DATA
     GENERAL PROCESS  TYPE
     PROCESS TYPE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENER6Y CONSUMPTION  -  X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     S02 DESIGN REMOVAL  EFFICIENCY - X
     PHRTICULATE DESIGN  REMOVAL  EFFICIENCY
     ABSORBER SPARE CAPACITY INDEX - X
     ABSORBER SPARE COMPONENTS INDEX

 •* WATER LOOP
     TYPE
     FRESH MAKE-UP HATER - LITER/S

 •• TREATMENT
     TYPE

 •• DISPOSAL
     TYPE
                                                            t LIGHT
                                  (  12500 BTU/LB)
                   UTAH  POWER
                   HUNTINGTON
                   1
                   PRICE
                   UTAH
                    430.0
                    400.0
                    366.0
COAL
BITUMINOUS
 29075.
   10.00
    6.50
     .55
                  WET  SCRUBBING
                  LIME
                  CHEHICO  DIVISION.  ENVIROTECH
                  NEW
                       1.6
                   5/78
                   5/78
                     80.00
                     99.50
                       .0
                       .0
                  CLOSED
                      18.9
               (  300 6PM)
                  FLYASH  STABILIZATION
                                                 LANDFILL
	.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITV  RELIABILITY UTILIZATION
                                  X  REMOVAL
                                  S02   PART.
                            PER  BOILER  FGD    CAP.
                           HOURS HOURS  HOURS  FACTOR
ID/79  SYSTEM

       •* PROBLEMS/SOLUTIONS/COMMENTS
                                                                              744   497
                         ON OCTOBER  15  FGD  OPERATIONS WITH LJMESTON& WERE INITIATED  FOR TESTING
                         PURPOSES.   IF  THE  FGD  SYSTEM OPERATIONS ARE ADEQUATE WITH LIMESTONE  THE
                         UTILITY  WILL  STUDY THE ECONOMIC TRADEOFFS OF LIME VS LIMESTONE SUCH  AS
                         PUMP WEAR ETC.   IF THE RESULTS FAVOR LIMESTONE THE HUNTINGTON 1 FGD  SYSTEM
                         NAY BE SHIFTED  FROM LIME  TO LIMESTONE.
11/79  SYSTEM

12/79  SYSTEM

 1/80  SYSTEM
                                                720

                                                744

                                                744
                                    28

                                   642

                                   668
       •* PROBLEMS/SOLUTIONS/COMMENTS
                         DUE  TO A  LACK  OF  RECORDS, DATA CONCERNING THE FGD SYSTEM OPERATIONS WAS
                         UNAVAILABLE  FOR THE  MONTHS OF OCTOBER 1979 THROUGH JANUARY  1980.   IN
                         NOVEMBER  THE BOILER  WAS DOWN MOST OF THE MONTH FOR A SCHEDULED UNIT
                         OVERHAUL.
 2/80  SYSTEM

 i/80  SYSTEM
100.0

100.0
       87.0

       89.2
696   60S

744   664
605

664
                                                216

-------
                                              EPA UTILITY  FGD  SURVEY:  JULY  - SEPTEMBER 1980

UTAH POWER ( LIGHT: HUNTIN6TON 1 (CONT.)
.	.	...	.......	..	.	-PERFORMANCE  DATA	———-—	.——-———
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   I  REMOVAL   PER  BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR


 4/80  SYSTEM                  98.1                     92.1                   720   676    663

       ** PROBLENS/SOLUTIONS/COMMENTS

                         THE FED SYSTEM OPERATED  ALONG WITH  THE BOILER DURING FEBRUARY AND MARCH
                         WITH NO MAJOR PROBLEMS.

 5/80  SYSTEM                 100.0                     99.7                   74*   742    742

 S/BO  SYSTEM                 100.0                     99.2                   720   714    714

       •• PROBLEMS/SOLUTIONS/CONMENTS

                         THE FGD SYSTEM OPERATED  ALONG WITH  THE BOILER DURING THE APRIL THROUGH
                         JUNE PERIOD  EXCEPT FOR  A FEW HOURS  IN APRIL.  THE UTILITY REPORTED THAT
                         NO MAJOR  PROBLEMS  OCCURRED DURING  THIS TIME.

 7/80  SYSTEM                 100.0                     87.2                   744   649    649

       *• PROBLEKS/SOLUTIONS/COMMENTS

                         NO MAJOR  F6D-RELATED PROBLEMS WERE  REPORTED  CURING  JULY.

 3/80  SYSTEM      100.0                                                      744   695

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          NO  MAJOR  OPERATIONAL PROBLEMS WERE REPORTED  IN  AUGUST.

 J/80  SYSTEM         .0                                                       7?0      0

       •* PROBLE1S/SOLUT10NS/COMMENTS

                          THE  FGD SYSTEM AND BOILER WERE DOWN THROUGHOUT  SEPTEMBER  FOR A SCHEDULED
                          MAINTENANCE OVERHAUL.
                                                 217

-------
EPA UTILITY F6D SURVEYS  JULY  -  SEPTEMBER 1980
                                             SECTION 4
                                 SUMMARY OF F6D SYSTEMS BY COMPANY

TOTAL
COMPANY NAME
ALABAMA ELECTRIC COOP
ARIZONA ELECTRIC POWER COOP
ARIZONA PUBLIC SERVICE
ASSOCIATED ELECTRIC COOP
ATLANTIC CITY ELECTRIC
BASIN ELECTRIC POWER COOP
BIG RIVERS ELECTRIC
CAJUN ELECTRIC POWER COOP
CENTRAL ILLINOIS LIGHT
CENTRAL ILLINOIS PUBLIC SERV
CENTRAL MAINE POWER
CENTRAL POWER t LIGHT
CINCINNATI 6AS K ELECTRIC
COLORADO UTE ELECTRIC ASSN
COLUMBUS t SOUTHERN OHIO ELEC
CON10NWEALTH EDISON
COOPERATIVE POWER ASSOCIATION
OELHARVA POWER t LIGHT
DESERET GEN t TRANS COOP
DUBJESNE LIGHT
EAST KENTUCKY POWER COOP
GENERAL PUBLIC UTILITIES
GRAND HAVEN BRD OF LIGHT K PWR
HOOSIER ENERGY
HOUSTON LIGHTING t POWER
INDIANAPOLIS POWER I LIGHT
IOWA ELECTRIC LIGHT t PWR
JACKSONVILLE ELEC AUTHORITY
KANSAS CITY POWER ft LIGHT
KANSAS POWER t LIGHT
KENTUCKY UTILITIES
LAKELAND UTILITIES
LANSING BOARD OF WATER R LIGHT
LOS ANGELES DEPT OF WTR ft PWR
LOUISVILLE GAS I ELECTRIC
MAR8UETTE BOARD OF LIGHT S PWR
MICHIGAN SO CENTRAL PWR AGENCY
KIDDLE SOUTH UTILITIES
MINNESOTA POWER t LIGHT
NINNKOTA POWER COOPERATIVE
NONONGAHELA POWER
MONTANA POWER
MONTANA-DAKOTA UTILITIES
HUSCATINE POWER t WATER
NEBRASKA PUBLIC POWER DISTRICT
NEVADA POWER
NEW YORK STATE ELEC t GAS
NIAGARA MOHAWK POWER COOP
NORTHERN INDIANA PUB SERVICE
NORTHERN STATES POWER
PACIFIC G*S I ELECTRIC
PACIFIC POWER t LIGHT
PENNSYLVANIA POWER
PHILADELPHIA ELECTRIC
PLAINS ELECTRIC G ( T COOP
PLATTE RIVER POWER AUTHORITY
PUBLIC SERVICE INDIANA
PU3LIC SERVICE OF NEW MEXICO
PWR AUTHORITY OF STATE OF NY
SALT RIVE« PROJECT
SAN MIGUEL ELECTRIC COOP
SENINOLE ELECTRIC
SIKESTON BRD OF MUNICIPAL UTIL
SOUTH CAROLINA PUBLIC SERVICE
SOUTH MISSISSIPPI ELEC PWR
NO.
2
2
8
1
1
5
4
1
2
1
1
1
2
3
t
1
2
4
2
2
3
6
1
2
3
5
1
2
3
4
1
1
1
4
10
1
1
6
1
1
2
4
1
1
1
10
1
1
3
3
2
4
3
3
1
1
1
4
1
3
1
2
1
5
2
MW
358.
196.
2598.
670.
330.
2590.
1364.
540.
866.
617.
600.
720.
1300.
1294.
1572.
450,
654.
730.
820.
918.
1800.
3880.
65.
882.
1992.
3012.
720.
1200.
1000.
1575.
64.
364.
160.
3280.
3554.
44.
55.
5340.
475.
185.
1236.
2120.
440.
166.
650.
3215.
625.
100.
957.
1590.
1600.
2203.
2751.
724.
233.
279.
650.
1779.
700.
P40.
400.
1240.
235.
1700.
248.
OPERATIONAL
NO.
2
2
5
0
0
1
1
0
1
1
0
0
0
1
2
1
2
3
0
2
0
0
0
0
0
1
0
0
3
4
1
0
0
0
5
0
0
0
1
1
1
2
0
0
0
3
0
0
1
2
0
1
3
0
0
0
0
3
0
2
0
0
0
2
2
NW
358.
196.
962.
0.
0.
570.
242.
0.
416.
617.
0.
0.
0.
400.
822.
450.
654.
180.
0.
918.
0.
0.
0.
0.
0.
532.
0.
0.
1000.
1575.
64.
0.
0.
0.
1201.
0.
0.
0.
475.
185.
618.
720.
0.
0.
0.
375.
0.
0.
115.
1480.
0.
550.
2751.
0.
0.
0.
0.
1245.
0.
560.
0.
0.
0.
420.
248.
CONSTRUCTION CONTRACT
AWARDED
NO.
0
0
1
1
0
3
1
0
0
0
0
0
1
1
0
0
0
0
0
0
1
0
1
2
1
1
0
0
0
0
0
1
0
0
3
0
0
0
0
0
1
2
1
0
0
0
0
1
0
1
0
0
0
2
0
0
1
1
0
0
1
0
1
1
0
MW
0.
0.
ie6.
670.
0.
1580.
242.
0.
0.
0.
0.
0.
650.
447.
0.
0.
0.
0.
0.
0.
500.
0.
65.
882.
492.
530.
0.
0.
0.
0.
0.
364.
0.
0.
1203.
0.
0.
0.
0.
0.
618.
14QC.
440.
0.
0.
0.
0.
100.
0.
110.
0.
0.
0.
574.
0.
0.
650.
534.
0.
0.
400.
0.
235.
280.
0.
NO.
0
0
2
0
0
0
2
0
0
0
0
0
0
1
0
0
0
0
1
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
1
0
0
0
0
0
0
1
0
0
0
0
2
0
0
0
0
1
1
1
0
0
0
0
0
2
0
2
0
MW
0.
0.
1510.
0.
0.
0.
880.
0.
0.
0.
0.
0.
0.
447.
0.
0.
0.
0.
410.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
55.
0.
0.
0.
0.
0.
0.
166.
0.
0.
0.
0.
842.
0.
0.
0.
0.
150.
233.
279.
0.
0.
0.
0.
0.
1240.
0.
1000.
0.
PLANNED
NO.
0
0
0
0
1
1
0
1
1
0
1
1
1
0
2
0
0
1
1
0
2
6
0
0
2
3
1
2
0
0
0
0
1
4
2
1
0
6
0
0
0
0
0
0
1
7
1
0
0
0
2
3
0
0
0
0
0
0
1
1
0
0
0
0
0
MW
0.
0.
0.
0.
330.
440.
0.
540.
450.
0.
600.
720.
650.
0.
750.
0.
0.
sso.
410.
0.
1300.
3880.
0.
0.
1500.
1950.
720.
1200.
0.
0.
0.
0.
160.
3280.
1150.
44.
0.
5340.
0.
0.
0.
0.
0.
0.
650.
2840.
625.
0.
0.
0.
1600.
1650.
0.
0.
0.
0.
0.
0.
700.
280.
0.
0.
0.
0.
0.
      NOTE - PLANNED  STATUS  INCLUDES LETTER OF INTENT SIGNED, HEQUESTING/EVALUTING BIDS,
               AND  CONSIDERING  ONLY FGD SYSTEMS
                                               218

-------
                                           EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980
                                          SECTION 4
                              SUMMARY OF FGD SYSTEMS BY COMPANY
TOTAL
C01PANY NAME
SOUTHERN ILLINOIS POWER COOP
SOUTHERN INDIANA GAS & ELEC
SOUTHWESTERN ELECTRIC POWER
SPRINGFIELD CITY UTILITIES
SPRINGFIELD WATER, LIGHT t PWR
ST. JOE ZINC
SUNFLOWER ELECTRIC COOP
TA^PA ELECTRIC
TENNESSEE VALLEY AUTHORITY
TEXAS MUNICIPAL POWER AGENCY
TEXAS POWER & LIGHT
TEXAS UTILITIES
TUCSON ELECTRIC POWER
UNITED POWER ASSOCIATION
UTAH POWER S LIGHT
WEST PENN POWER
WEST TEXAS UTILITIES
NO.
2
1
3
1
1
1
1
1
7
1
3
8
2
1
6
1
1
MW
473.
265.
2160.
194.
205.
60.
347.
475.
3153.
400.
1882.
5585.
740.
50.
2216.
JOO.
720.


OPERATIONAL
NO.
1
1
0
1
0
1
0
0
3
0
0
4
0
0
3
0
0
MW
173.
265.
0.
194.
0.
60.
0.
0.
570.
0.
0.
2585.
0.
0.
1086.
0.
0.


CONSTRUCTION
NO.
0
0
0
0
1
0
0
0
3
1
1
0
0
1
1
0
0
MW
0.
0.
0.
0.
205.
0.
0.
0.
1983.
4QO.
382.
0.
0.
SO.
330.
0.
0.


CONTRACT
AWARDED
NO.
0
0
2
Q
0
0
1
1
1
0
2
1
2
0
2
1
0
MW
0.
0.
1440.
0.
0.
0.
347.
475.
600.
0.
1500.
750.
740.
0.
800.
300.
0.


PLANNED
NO.
1
0
1
0
0
0
0
0
0
0
0
3
0
0
0
0
1
MW
3CC.
0.
720.
Q.
C.
0.
C.
0.
0.
0.
0.
2250.
0.
0.
0.
0.
720.
TOTALS
                               208 94737.
                                             76 25832.
                                                           39  16442.
                                                                        30 14164.
                                                                                     63 38299.
     NOTE  -  PLANNED STATUS INCLUDES LETTER OF INTENT SIGNED,  REOUESTIN6/EVALUTING  BIDS*
             AND  CONSIDERING ONLY FGD SYSTEMS
                                             219

-------
EPA UTILITY FSB  SURVEY:  JULY - SEPTEMBER 1980
                                            SECTION  5
                             SUMMARY OF FED SYSTEMS  BY  SYSTEM SUPPLIER

TOTAL
SYSTEM SUPPLIER/PROCESS
AIR CORRECTION DIVISION, UOP
LIME
LIMESTONE
LIME/LIMESTONE
SODIUM CARBONATE
TDTAL -
AMERICAN AIR FILTER
LIME
LIMESTONE
TOTAL -
BABCOCK I WILCOK
LIME
LIMESTONE
LIME/SPRAY DRYING
TOTAL -
BUELL DIVISION, ENVIROTECH
DUAL ALKALI
TOTAL -
CHEMICO DIVISION, ENVIROTECH
LIME
LIMESTONE
LIME/ALKALINE FLYASH
LIME/LIMESTONE
TOTAL -
COMBUSTION ENGINEERING
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLYASH
TOTAL -
COMBUSTION EOUIP ASSOCIATES
DUAL ALKALI
LIME
LIME/ALKALINE ILYASH
SODIUM CARBONATE
TOTAL -
DAVY MCKEE
riELLMAN LORD
TOTAL -
ENV1RONEERIN6, RILEY STOKER
LIMESTONE
MAGNESIUM OXIDE
TOTAL -
DUAL ALKALI
TOTAL -
JOY MFE/NIRO ATOMIZER
LIME/SPRAY DRYING
TOTAL -
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
TOTAL -
NO.

2
5
1
2
1C

6
1
7

4
8
2
14

1
1

8
8
3
1
20

6
9
2
2
19

1
1
5
3
10

8
8

3
1
4
3
3

6
6

2
2
MW

822.
2616.
10.
880.
4328.

1673.
280.
1953.

1951.
2467.
1017.
5435.

617.
617.

4138.
5000.
579.
10.
9727.

1160.
3575.
1480.
654.
6869.

299.
500.
2305.
375.
3479.

2074.
2074.

664.
600.
1264.
1107.
1107.

1916.
1916.

882.
882.
OPERATIONAL
NO.

?
3
1
1
7

4
0
4

1
4
0
5

1
1

7
1
3
1
12

4
4
2
2
12

1
n
3
3
7

7
7

3
0
3
1
1

0
0

0
0
MU

822.
1176.
10.
550.
2558.

936.
0.
936.

618.
1413.
9.
2031.

617.
617.

3838.
800.
579.
10.
5227.

452.
1575.
1480.
654.
4161.

299.
0.
905.
375.
1579.

1540.
1540.

664.
0.
664.
265.
265.

0.
0.

0.
0.
CONSTRUCTION
NO.

0
0
c
1
1

2
1
3

3
1
1
7

0
C

0
3
0
0
3

2
3
0
0
5

0
1
2
0
3

1
1

0
0
0
0
0

2
2

2
2
MW

0.
0.
0.
330.
330.

737.
280.
1017.

1333.
999.
570.
2902.

0.
0.

0.
1900.
0.
0.
1900.

708.
1357.
0.
0.
2065.

0.
500.
1400.
0.
1900.

534.
534.

0.
0.
0.
0.
0.

550.
550.

882.
882.
CONTRACT
AWARDED
NO.

0
2
0
0
2

0
0
0

0
1
1
2

0
0

1
4
0
0
5

0
2
0
0
2

0
0
0
0
G

0
0

0
1
1
2
2

4
4

0
0
MU

0.
1440.
0.
0.
1440.

0.
0.
0.

0.
55.
447.
502.

0.
0.

300.
2300.
0.
0.
2600.

0.
643.
0.
0.
643.

0.
0.
0.
0.
c.

0.
0.

0.
600.
600.
842.
842.

1366.
1366.

0.
0.
                                               220

-------
                                     EPA UTILITY FSB SURVEY: JULY - SEPTEMBER 1980
                                   SECTION 5
                    SUMMARY OF F60 SYSTEMS BY SYSTEM SUPPLIER

TOTAL
SYSTEM SUPPLIER/PROCESS
MORRISON t KNUDSEN/U.S.B.M.
CITRATE
TOTAL -
PEABODY PROCESS SYSTEMS
LIMESTONE
LIME/ALKALINE FLYASH
TOTAL -
PULLMAN KELLOG
LIMESTONE
TOTAL -
PULLMAN KELLOGG
LIME
LIMESTONE
TOTAL -
RESEARCM-COTTRELL
LIMESTONE
LIME/LIMESTONE
LIME/SPRAY DRYING
TOTAL -
ROCKWELL INTERNATIONAL
AQUEOUS CARBONATE/SPRAY DRYING
TOTAL -
TENNESSEE VALLEY AUTHORITY
LIMESTONE
TOTAL -
UNITED ENGINEERS
LIME
MAGNESIUM OXIDE
TOTAL -
UHEELA8RATQR-FRYE/R.I.
SODIUM CARBONATE/SPRAY DRYING
TOTAL -
NO.

1
1

8
1
9

2
2

1
4
5

14
1
1
16

1
1

1
1

2
3
5

1
1
MU

60.
60.

3445.
475.
3920.

880.
880.

917.
1880.
2797.

5281.
475.
50.
5806.

100.
100.

550.
550.

1510.
724.
2234.

440.
440.
OPERATIONAL
NO.

1
1

3
1
4

0
0

1
2
3

8
0
0
8

0
0

1
1

0
0
0

0
0
MU

60.
60.

758.
475.
1233.

0.
0.

917.
560.
1477.

2934.
0.
0.
2934.

0.
0.

550.
550.

0.
0.
0.

0.
0.
CONSTRUCTION
NO.

0
0

1
0
1

0
0

0
2
2

4
0
1
5

1
1

0
0

0
2
2

1
1
MU

0.
0.

447.
0.
447.

0.
0.

0.
1320.
1320.

1431.
0.
50.
1481.

100.
100.

0.
0.

0.
574.
574.

440.
440.
CONTRACT
AUARDED
NO.

0
0

4
0
4

2
2

0
0
0

2
1
0
3

0
0

0
0

2
1
3

0
0
MU

0.
0.

2240.
0.
2240.

880.
880.

0.
0.
0.

916.
475.
0.
1391.

0.
0.

0.
0.

1510.
150.
1660.

0.
0.
TOTAL -
                                 145 56438.
76 25832.
39 16442.
30 14164.
                                        221

-------
EPA UTILITY FED SURVEY: JULY - SEPTEMBER 1980
                                           SECTION 6
                                SUMMARY OF FCD SYSTEMS BY PROCESS
          	STATUS	
TOTAL     OPERATIONAL  CONSTRUCTION   CONTRACT
                                      AWARDED
                                                                                      PLANNED
  PROCESS
                                 NO.
                                       RU
                                              NO.
                                                    MU
                                                           NO
                                                                 nu
                                                                        NO.
                                                                              MU
                                                                                     NO.
                                                                                           KU
AQUEOUS CARBONATE/SPRAY DRYING
CITRATE
LIMESTONE
LIME/LIMESTONE
MAGNESIUM OXIDE
WELLNAN LORD
1
1
3
1
4
8
100.
60.
1766.
475.
1324.
2074.
0
1
0
0
0
7
0.
60.
0.
0.
0.
1540.
1
0
0
0
2
1
100.
0.
0.
0.
574.
534.
0
0
1
1
2
0
0.
0.
166.
475.
7-50.
0.
0
0
2
0
0
0
0.
0.
1600.
0.
0.
0.
    SUBTOTAL  -  SALEABLE   PRODUCT   18   5799.
             8  1600.
4  1208.
4  1391.
                                                                                       2  1600.
DUAL ALKALI
LIME
LIMESTONE
LIMESTONE/ALKALINE FLYASH
LIME/ALKALINE FLVASH
LIME/LIMESTONE
LINE/SPRAY DRVIN6
PROCESS NOT SELECTED
SODIUM CARBONATE
SODIUM CARBONATE/SPRAY DRYING
SUBTOTAL - THROUAWAY PRODUCT
TOTALS
SALEABLE PRODUCT PROCESS
X OF TOTAL MU
5
34
73
2
11
2
10
12
9
1
159
177


2023.
15951.
32569.
1480.
4013.
20.
3027.
7020.
3155.
440.
69698.
75497.

8
3
19
29
2
9
2
0
0
4
0
68
76


1181.
7583.
10430.
1480.
2613.
20.
0.
0.
925.
0.
24232.
25832.

6
0
8
19
0
2
0
4
0
1
1
35
39


0
3278
8616
0
1400
0
1170
0
330
440
15254
16442

7
»
•
•
•
•
•
9
•
•
*
•
•


2
3
15
0
0
0
5
0
0
0
25
29


842.
1810.
7588.
0.
0.
0.
1813.
0.
0.
0.
12053.
13444.

10
0
4
10
0
0
0
1
12
4
0
31
33


0.
3280.
5935.
0.
0.
0.
44.
7020.
1900.
0.
18179.
19779.

8
  NOTE:   31  UNITS  ARE  UNDECIDED  AND  ARE  NOT  INCLUDED  IN  THIS  TABLE
                                             222

-------
                               EPA UTILITY  F6D SURVEY:  JULY  - SEPTEMBER  1980

                             SECTION  7
       SUMMARY OF OPERATIONAL F6D SYSTEMS BY PROCESS AND  UNIT
PROCESS/
UNIT NAME
CITRATE
6.F. MEATON

DUAL ALKALI
A.B. BROUN
CANE RUN
NEUTON

LIME
BRUCE MANSFIELD
BRUCE MANSFIELD
BRUCE MANSFIELD
CANE RUN
CANE RUN
CONESVILLE
CONESVILLE
ELRAMA
GREEN
6REEN RIVER
HAWTHORN
HAWTHORN
HUNTER
HUNTER
HUNTIN6TON
MILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANTS

LIMESTONE
APACHE
APACHE
CHOLLA
CHOLLA
CORONADO
CORONADO
CRAI6
DUCK CREEK
JEFFREY
JEFFREY
LA CVGNE
LARAMIE RIVER
LAWRENCE
LAWRENCE
MARION
MARTIN LAKE
MARTIN LAKE
MARTIN LAKE
MONTICELLO
PETERSBURG
POWERTON
R.D. HORROUt SR.
R.D. MORROW, SR.
SOUTHWEST
TDMBI6BEE
TOMBI6BEE
WIDOWS CREEK
WINVAH
WINYAH
UNIT NO.

1


1
6
1


1
2
3
4
5
5
6
1-4
1
1-3
3
4
1
2
1
3
6
1-6
1


2
3
1
2
1
2
2
1
1
2
1
1
4
5
4
1
2
3
3
3
51
1
2
1
2
3
8
2
3
CAPACITY
nw

60.
60.

26S.
299.
617.
1181.

917.
917.
917.
188.
200.
411.
411.
510.
242.
64.
90.
90.
360.
360.
366.
442.
72.
408.
618.
7583.

98.
98.
119.
264.
280.
280.
400.
416.
540.
490.
820.
570.
125.
420.
173.
595.
595.
595.
800.
532.
450.
124.
124.
194.
179.
179.
550.
140.
280.
INITIAL
STARTUP

11/79


3/79
4/79
9/79


12/7.5
7/77
6/80
8/76
12/77
1/77
6/78
10/75
12/Z9
9/75
11/72
8/72
5/79
6/80
5/78
8/78
4/7.3
7/73
3/79


8/78
6/19
10/73
4/78
11/79
7/&0
12/359
7/76
8/78
4/80
2/73
7/80
1/76
11/71
5/79
4/77
5/78
2/79
5/78
12/77
4/80
8/78
6/79
4/77
9/78
6/79
5/7-7
7/77
5/&0
COMMERCIAL
STARTUP

1/80


4/79
O/ 0
12/79


6/76
10/77
6/80
8/77
7/78
2/77
7/78
10/75
12/79
6/76
O/ 0
O/ 0
5/79
6/80
5/78
3/79
O/ 0
6/74
3/79


1/79
4/79
12/73
6/78
12/79
10/80
5/80
8/78
O/ 0
1/80
6/73
7/80
O/ 0
O/ 0
6/79
10/78
O/ 0
O/ 0
10/78
12/77
6/81
8/78
6/79
9/77
9/78
6/79
1/78
O/ 0
6/80
                                       10430.

THIS TABLE IDENTIFIES UNITS IN ALPHABETICAL ORDER.
RESPECTIVE COMPANIES CAN BE FOUND IN SECTION 1.
                                 223

-------
EPA UTILITY FSO SURVEY: JULY - SEPTEMBER  1980
                                           SECTION  7
                     SUMMARY OF OPERATIONAL FGD SYSTEMS BY PROCESS  AND  UNIT
             PROCESS/
               UNIT NAME
                                       UNIT NO.
CAPACITY
   MW
INITIAL
STARTUP
COMMERCIAL
 STARTUP
             LIMESTONE/ALKALINE FLVASH
               SHERBURNE               1
               SHERBURNE               2
             LIME/ALKALINE FLYASH
               CLAY BOSWELL            4
               COAL CREEK              1
               COAL CREEK              2
               COLSTRIP                1
               COLSTRIP                2
               FOUR CORNERS            1
               FOUR CORNERS            ?
               FOUR CORNERS            3
               1ILTON R. YOUNG         2
             LIME/LIMESTONE
               SHAWNEE                 10A
               SHAHNEE                 10B
             SODIUM CARBONATE
               JIM BRID6ER             4
               REID GARDNER            1
               REID GARDNER            2
               REID GARDNER            3
             WELLMAN  LORD
               DEAN H.  MITCHELL        11
               DELAWARE CITY           1
               DELAWARE CITY           2
               DELAWARE CITY           3
               SAN JUAN                1
               SAN JUAN                2
               SAN JUAN                3
   740.
   7*0.

  14?0.
   475.
   327.
   327.
   360.
   360.
   175.
   17S.
   229.
   185.

  2613.
    10.
    10.

    20.
   550.
   125.
   125.
   125.

   925.
  3/76
  3/77
  4/80
  7/79
  7/80
  9/75
  5/76
 11/79
 11/79
 11/79
  9/77
  4/72
  4/72
  9/79
  3/74
  4/74
  6/76
   5/76
   4/77
   01 0
   8/79
   9/80
  11/75
  10/76
   01 0
   O/ 0
   01 0
   6/78
   O/ 0
   O/ 0
   2/80
   4/74
   01 0
   7/76
115.
60.
60.
60.
361.
350.
534.
7/76
5/80
5/80
5/80
4/78
8/78
12/79
6/77
5/80
5/80
5/80
4/78
8/78
O/ 0
                                                     1540.
             TOTAL
                                                    25832.
                                              224

-------
                                              EPA UTILITY F60 SURVEY: JULY - SEPTEMBER  1980
                                            SECTION 8
              SUMMARY  OF  END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL FED SYSTEMS
99 nr EC c t
r » UU c a 9 /
JKIT NAME
CITRATE
E.F. riEATDN
»UAL ALKALI
».B. SROUN
CANE RUN
ME W TON
LIME
JRUCE MANSFIELD
JRUCE MANSFIELD
3RUCE MANSFIELD
CANE RUN
CANE RUN
C3NESVILLE
CONESVILLE
ELRA*»
SREEN
5REEN RIVER
DAWTH3RN
HAWTHORN
HUNTER
HUNTER
HJNTI1STON
1ILL CREEK
PADDY'S RUN
PHILLIPS
PLEASANT;

UNIT NO

1

1
6
1

1
2
3
4
5
5
6
1-4
1
1-3
3
4
1
2
1
3
6
1-6
1
... ... . ...... .............. ..
STABILIZED UNSTABILIZED TYPE DISPOSITION

ELEMENTAL. SULFUR

LANDFILL
LANDFILL


LANDFILL
LANDFILL

LINED POND
LINED POND
POND
POND
LANDFILL

LINED POND
POND
POND
POND
POND
LANDFILL
POND
POND
LANDFILL

LIMESTONE
»P«CME
APACHE
CHOLLA
CHOLLA
C3RONADO
CORONADO
CRAIG
»JCK CREEK
JEFFREY
JEFFREY
LA CVGNE
LARAMIE RIVER
LAURENCE
LAWRENCE
IARION
4ARTIM LAKE
4ARTIN LAKE
4ARTIN LAKE
15NTICELLO
PETERSBURG
P3WERTON
t.D. MORROU, SR.
«.». MORROW, SR.
SOUTHJEST
F3MBI&BEE
rSMBICBEE
WIDOWS CREEK
«INYAH
JIMVAH
I
3
1
2
1
2
2
1
1
2
1
1
4
5
4
1
2
3
3
3
51
1
2
1
2
3
8
2
3








POND
LINED POND

LANDFILL
POND
POND
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LANDFILL
LINED POND
LINED POND



                                             POND
                                             POND
                                             POND
                                             UNLINED  POND
                                             LINED  POND
                                             LINED  POND
                                             MINEFILL
                                             LINED  POND
                                              UNLINED POND
                                                                                 LANDFILL
                                              POND
                                              POND
LIMESTONE/ALKALINE  FLVASH
SNERBURNE
SHERBURNE
LINED POND
LINED POND
                                                225

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                            SECTION 8
              SUMMARY OF END-PRODUCT DISPOSAL PRACTICES FOR OPERATIONAL F6D SYSTEMS
PROCESS/
UNIT NAME
        	THROUAUAY	
UNIT NO  STABILIZED   UNSTABILIZED
                                                                          -BYPRODUCT-
                                                             DISPOSITION
LIKE/ALKALINE FLVASH

CLAY BOSUELL           4                     LINED POND
COAL CREEK             1       LINED POND
COAL CREEK             2       LINED POND
COLSTRIP               1                     POND
COLSTRIP               2                     POND
FOUR CORNERS           1
FOUR CORNERS           2
FOUR CORNERS           3
HILTON R. YOUNG        2                     MINEFILL

LINE/LIMESTONE

SHAWNEE                IDA
SNANNEE                108

SODIUM CARBONATE

JIN BRID6ER            4                     LINED POND
»EIO GARDNER           1                     LINED POND
REID GARDNER           2                     LINED POND
«EIP GARDNER           3                     LINED POND

HELLMAN LORD

ftEAN H. RITCHELL       11
ftELAWARE CITY          1       LINED POND
DELAWARE CITY          2       LINED POND
DELAWARE CITY          3       LINED POND
SAN JUAN               1
SAN JUAN               2
SAN JUAN               3
                                    ELEMENTAL SULFUR
                                    SULFUR 1C ACID
                                    SULFURIC ACID
                                    SULFURIC ACID
                                    ELEMENTAL SULFUR
                                    ELEMENTAL SULFUR
                                    SULFURIC ACID
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
MARKETED
                                               226

-------
               EPA  UTILITY F60 SURVEY: JULY  - SEPTEMBER 1980
            SECTION  9
SUMMARY OF FGD  SYSTEMS IN OPERATION
COHPAMY NAME/
UNIT NAME UNIT NO.
ALABAMA ELECTRIC COOP
TOMBI6BEE 2
ALABAMA ELECTRIC COOP
T01BIGBEE 3
ARIZONA ELECTRIC POWER COOP
APACHE 2
ARIZONA ELECTRIC POWER COOP
APACHE 3
ARIZONA PUBLIC SERVICE
CHDLLA 1
ARIZONA PUBLIC SERVICE
CHDLLA 2
ARIZONA PUBLIC SERVICE
F9UR CORNERS 1
ARIZONA PUBLIC SERVICE
FOUR CORNERS 2
ARIZONA PUBLIC SERVICE
FOUR CORNERS 3
BASIN ELECTRIC POWER COOP
LARA'IE RIVER 1
BIS RIVERS ELECTRIC
GREEN 1
CENTRAL ILLINOIS LIGHT
DUCK CREEK 1
CENTRAL ILLINOIS PUBLIC SERV
NEKTON 1
COLORADO UTE ELECTRIC ASSN
CRAIG 2
COLUMBUS K SOUTHERN OHIO ELEC
CDXESVILLE 5
COLUMBUS 1 SOUTHERN OHIO ELEC
CONESV1LLE 6
COMMONWEALTH EDISON
POriERTON 51
COOPERATIVE POWER ASSOCIATION
COAL CREEK 1
COOPERATIVE POWER ASSOCIATION
COAL CREEK 2
DELNARVA POWER t LIGHT
DELAWARE CITY 1
OELNARVA POWER t LIGHT
DELAWARE CITY 2
DELNARVA POWER I LIGHT
DELAWARE CITY 3
DUBUESNE LIGHT
ELUAHA 1-4
DUBUESNE LIGHT
PHILLIPS 1-6
NEW OR (
RETROFIT
NEW
NEW
NEW
NEW
RETROFIT
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
IAPACITY
NW
179.0
179.0
98.0
98.0
119.0
264.0
175.0
175.0
229.0
570.0
242.0
416.0
617.0
400.0
411.0
411.0
450.0
327.0
327.0
60.0
60.0
60.0
510.0
408.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODV PROCESS SYSTEMS
LIMESTONE
RESEARCH-COYTRELL
LIMESTONE
RESEARCH-COT-TRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COT-TRELL
LIME/ALKALINE FLYASH
CHEHICO DIVISION, ENVIROTECH
LIME/ALKALINE FLYASH
CHEMICO DIVISION. ENVIROTECH
LIME/ALKALINE FLYASH
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COTTRELL
LIME
AMERICAN AIR FILTER
LIMESTONE
ENVIRONEERING, RILEV STOKER
DUAL ALKALI
BUELL DIVISION. ENVIROTECH
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
AIR CORRECTION DIVISION, UOP
LIME
AIR CORRECTION DIVISION, UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/ALKALINE FLYASH
COMBUSTION ENGINEERING
LIME/ALKALINE FLVASH
COMBUSTION KNGINEERING
WELLMAN LORD
DAVY MCKEE
WELLMAN LORD
DAVY NCKEE
WELLMAN LORD
DAVY MCKEE
LIME
CHEMICO DIVISION, ENVIROTECH
LINE
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
9/78
6/79
8/78
6/79
10/73
4/76
11/79
11/79
11/79
7/80
12/79
7/76
9/79
12/79
1/77
6/78
4/80
7/79
7/80
5/80
5/80
5/80
10/75
7/73
                 227

-------
EPA UTILITY  F6D SURVEY: JULY  -  SEPTEMBER 1980
                                             SECTI-ON  9
                                 SUMMARY OF FGO  SYSTEMS IN OPERATION
COMPANY NAME/
LIMIT NAME UNIT NO.
INDIANAPOLIS POWER & LIGHT
PETERSBURG 3
KANSAS CITY POWER 8 LIGHT
HAWTHORN 3
KANSAS CITY POWER S LIGHT
HAWTHORN 4
KANSAS CITY POWER K LIGHT
LA CY6NE 1
KANSAS POWER 8 LIGHT
JEFFREY 1
KANSAS POWER I LIGHT
JEFFREY 2
KANSAS POWER & LIGHT
LAWRENCE 4
KAMSAS POWER ( LIGHT
LAWRENCE 5
KENTUCKY UTILITIES
6REEN RIVER 1-3
LOUISVILLE GAS & ELECTRIC
CANE RUN 4
LOUISVILLE GAS t ELECTRIC
CANE RUN S
LOUISVILLE GAS I ELECTRIC
CANE RUN 6
LOUISVILLE GAS t ELECTRIC
MILL CREEK 3
LOUISVILLE GAS t ELECTRIC
PADDY'S RUN 6
MINNESOTA POWER t LIGHT
CLAY BOSWELL t
MINNKOTA POWER COOPERATIVE
MILTON R. YOUNG 2
MONONGAHELA POWER
PLEASANTS 1
MONTANA POWER
COLSTRIP 1
MONTANA POWER
COLSTRIP 2
NEVADA POWER
REID GARDNER 1
NEVADA POWER
REID GARDNER 2
NEVADA POWER
REID GARDNER 3
NORTHERN INDIANA PUB SERVICE
DEAN H. MITCHELL 11
NORTHERN STATES POWER
NEW OR
RETROFIT
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
RETROFIT
NEW
CAPACITY
MW
5J2.0
90.0
90.0
820.0
540.0
490.0
125.0
420.0
64.0
188.0
200.0
299.0
442.0
72.0
475.0
185.0
618.0
360.0
360.0
125.0
125.0
125.0
115.0
740.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK ft WILCOX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
DUAL ALKALI
COMBUSTION EQUIP ASSOCIATES
LIME
AMERICAN AIR FILTER
LIME
COMBUSTION ENGINEERING
LIME/ALKALINE FLVASH
PEABODV PROCESS SYSTEMS
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
LIME
BABCOCK ( WILCOX
LIME/ALKALINE FLVASH
COMBUSTION BQUIP ASSOCIATES
LIME/ALKALINE FLYASH
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION fcQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE
COMBUSTION fcQUIP ASSOCIATES
WELLMAN LORD
DAVY MCKEE
LIMESTONE/ALKALINE FLYASH
START-UP
DATE
12/77
11/72
8/72
2/75
8/78
4/80
1/76
11/71
9/75
8/76
12/77
4/79
8/78
4/73
4/80
9/77
3/79
9/75
5/76
3/74
4/74
6/76
7/7'6
3/76
                                                          COMBUSTION ENGINEERING
                                                228

-------
               EPA  UTILITY F6P SURVEY:  JULY - SEPTEMBER 1980
             SECTION 9
SUMMARY OF FGD  SYSTEMS IN OPERATION
COMPANY NAME/
UNIT NAME UNIT NO.
NORTHERN STATES POWER
SHERBURNE 2
PACIFIC POWER K LIGHT
Jit BRIDGED I
PENNSYLVANIA POWER
BRUCE MANSFIELD 1
PENNSYLVANIA POWER
BRUCE MANSFIELD 2
PENNSYLVANIA POWER
BRUCE MANSFIELD 3
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 1
PUBLIC SERVICE OF NEU MEXICO
SAN JUAN 2
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 3
SALT RIVER PROJECT
CBRONAOO 1
SALT RIVER PROJECT
CORONADO 2
SOUTH CAROLINA PUBLIC SERVICE
UINVAH 2
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 3
SOUTH MISSISSIPPI ELEC PUR
R.D. SORROW, SR. 1
SOUTH MISSISSIPPI ELEC PUR
R.D. MORROW, SR. 2
SOUTHERN ILLINOIS POUER COOP
MARION 4
SOUTHERN INDIANA GAS I ELEC
A. 3. BROUN 1
SPRINGFIELD CITY UTILITIES
SOUTHWEST 1
ST. JOE ZINC
G.F. iJ EATON 1
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10A
TENNESSEE VALLEY AUTHORITY
SHAWNEE 10B
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 8
TEXAS UTILITIES
MARTIN LAKE 1
TEXAS UTILITIES
MARTIN LAKE 2
TEXAS UTILITIES
MARTIN LAKE 3
NEU OR (
RETROFIT
NEU
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
NEU
NEU
NEU
NEU
NEU
NEW
NEU
NEU
NEU
NEU
RETROFIT
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEU
:APACITT
MU
740.0
S50.0
917.0
917.0
917.0
361.0
350.0
534.0
280.0
280.0
140.0
280.0
124.0
124.0
173.0
265.0
194.0
60.0
10.0
10.0
550.0
595.0
595.0
595.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE/ALKALINE FLYASH
COMBUSTION ENGINEERING
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
CHEMICO DIVISION, ENVIROTECH
LIME
PULLMAN KELLOGG
UELLHAN LORD
DAVY MCKEE
UELLMAN LORD
DAVY MCKEE
UELLMAN LORD
DAVY MCKEE
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
PULLMAN KELLOGG
LIMESTONE
BABCOCK I UILCOX
LIMESTONE
BABCOCK 1 UH.COX
LIMESTONE
ENVIRONEERINC, RILEY STOKER
LIMESTONE
ENVIRONEERING, RILEV STOKER
LIMESTONE
BABCOCK S UILCOX
DUAL ALKALI
FHC
LIMESTONE
AIR CORRECTION DIVISION, UOP
CITRATE
MORRISON ( KNUDSEN/U.S.B.M.
LIME/LIMESTONE
AIR CORRECTION DIVISION. UOP
LIME/LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
TENNESSEE VALLEY AUTHORITY
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
RESEARCH-COTTRELL
START-UP
DATE
3/77
9/79
12/75
7/77
6/80
4/78
8/78
12/79
11/79
7/80
7/77
5/80
8/78
6/79
5/79
1/79
4/77
11/79
4/72
4/72
5/77
4/77
5/78
2/79
                 229

-------
EPA UTILITY FSB SURVEY: JULY - SEPTEMBER 1980
                                           SECTION 9
                               SUMMARY OF FGD SYSTEMS IN OPERATION
COMPANY NAME/ NEW OR
UMIT NAME UNIT NO. RETROFH
TEXAS UTILITIES NEW
MONTICELLO 3
UTAH POWER & LIGHT NEW
HUNTER 1
UTAH POWER t LIGHT NEW
HUNTER 2
UTAH POWER I LIGHT NEW
HUNTINGTON 1
CAPACITY PROCESS/
r MW SYSTEM SUPPLIER
800.0 LIMESTONE
CHEHICO DIVISION, ENVIROTECH
360.0 LINE
CHEMICO DIVISION, ENVIROTECH
360.0 LIME
CHEMICO DIVISION, ENVIROTECH
366.0 LIME
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
5/78
5/79
6/80
5/78
   TOTAL
                                             25832.0
                                              230

-------
                 EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980
               SECTION 10
SUMMARY OF F6» SYSTEMS UNDER  CONSTRUCTION
C01PANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
CHOLLA 4
ASSOCIATED ELECTRIC COOP
THOMAS HILL 3
BASIN ELECTRIC POKER COOP
ANTELOPE VALLEY 1
BASIN ELECTRIC POWER COOP
LARA1IE RIVER 2
BASIN ELECTRIC POWER COOP
LARANIE RIVER 3
BI6 RIVERS ELECTRIC
GREEN ?
CINCINNATI 6AS I ELECTRIC
EAST 9END 2
COLORADO UTE ELECTRIC ASSN
CRAI6 1
EAST KENTUCKY POWER COOP
SPURLOCK Z
GRAND HAVEN BRD OF LIGHT t PWR
J.9. SINS 3
HOOSIER ENERGY
HERO* 1
HOOSIER ENERGY
MEROM Z
HOUSTON LIGHTING 1 POWER
U.A. PARISH 8
INDIANAPOLIS POWER t LIGHT
PETERSBURG 4
LAKELAND UTILITIES
MCINTOSH 3
LOUISVILLE 6AS t ELECTRIC
HILL CREEK 1
LOUISVILLE GAS t ELECTRIC
MILL CREEK Z
LOUISVILLE GAS I ELECTRIC
MILL CREEK 4
MONONSAHELA POWER
PLEASANTS 2
MONTANA POWER
COLSTRIP 3
MONTANA POWER
COLSTRIP 4
MONTANA-DAKOTA UTILITIES
COYOTE 1
NIAGARA MOHAWK POWER COOP
CHARLES R. HUNTLEV 66
NORTHERN STATES POWER
NEW OR CAPACITY
RETROFIT NW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
NEW
NEW
NEW
NEM
NEW
RETROFIT
RETROFIT
126.0
670.0
440.0
570.0
570.0
242.0
650.0
447.0
500.0
65.0
441.0
441.0
492.0
530.0
364.0
3S8.0
350.0
495.0
618.0
700.0
700.0
440.0
100.0
110.0
PROCESS/ START-UP
SYSTEM SUPPLIER DATE
LIMESTONE
RESEARCH-COTTRELL
LIMESTONE
PULLMAN KELLOC6
LIME/SPRAY DRYING
JOY HF6/NIRO ATOMIZER
LIMESTONE
RESEARCH-COfTRELL
LIME/SPRAY DRYING
BABCOCK * WILCOX
LIME
AMERICAN AIR FILTER
LIME
BABCOCK t WILCOX
LIMESTONE
PEABODY PROCESS SYSTEMS
LIME
COMBUSTION EQUIP ASSOCIATES
LIME
BABCOCK t VILCOX
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
MITSUBISHI HEAVY INDUSTRIES
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
RESEARCH-COXTRELL
LIMESTONE
BABCOCK t WILCOX
LIME
COMBUSTION ENGINEERING
LIME
COMBUSTION ENGINEERING
LIME
AMERICAN AIR FILTER
LIME
BABCOCK ( WftLCOX
LIME/ALKALINE FLVASH
COMBUSTION EQUIP ASSOCIATES
LINE/ALKALINE FLVASH
COMBUSTION EQUIP ASSOCIATES
SODIUM CARBONATE/SPRAT DRYING
UHEELABRATOR-FR YE/R.I.
AQUEOUS CARBONATE/SPRAY DRYING
ROCKWELL INTERNATIONAL
LIME/SPRAY DRYING
6/81
1/82
4/83
6/81
4/82
11/80
12/80
10/80
1/81
6/83
5/82
9/81
11/82
10/84
8/81
1/81
12/81
6/B2
10/80
5/83
3/84
3/81
4/82
11/80
                             JOY MFG/NIRO ATOMIZER
                    231

-------
EPA UTILITY F6D SURVEY:  JULY - SEPTEMBER 1980
                                            SECTION  10
                             SUMMARY OF F6D SYSTEMS  UNDER  CONSTRUCTION
COMPANY NAME/
UNIT NAME UNIT NO.
PHILADELPHIA ELECTRIC
EDDYSTONE 1
PHILADELPHIA ELECTRIC
EDDYSTONF. 2
PUBLIC SERVICE INDIANA
GIBSON 5
PUBLIC SERVICE OF NEW MEXICO
SAN JUAN 4
SAN MIGUEL ELECTRIC COOP
SAN MIGUEL 1
SIKESTON 3RD OF MUNICIPAL UTIL
SIKESTON 1
SOUTH CAROLINA PUBLIC SERVICE
WINYAH 4
SPRINGFIELD WATER, LIGHT 8 PWR
DALLMAN 3
TENNESSEE VALLEY AUTHORITY
PARADISE 1
TENNESSEE VALLEY AUTHORITY
PARADISE 2
TENNESSEE VALLEY AUTHORITY
WIDOWS CREEK 7
TEXAS MUNICIPAL POWER AGENCY
GIBBONS CREEK 1
TEXAS POWER t LIGHT
SANDOW 4
UNITED POWER ASSOCIATION
STANTON 1A
UTAH POWER & LIGHT
NAJGHTON 3
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
RETROFIT
RETROFIT
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
240.0
334.0
650.0
534.0
400.0
235.0
280.0
205.0
704.0
704.0
575.0
400.0
382.0
50.0
330.0
PROCESS/
SYSTEM SUPPLIER
MAGNESIUM OXIDE
UNITED ENGINEERS
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOGG
VELLKAN LORD
DAVY MCKEE
LIMESTONE
BABCOCK K W1LCOX
LIMESTONE
6ABCOCK K WI1COX
LIMESTONE
AMERICAN AIR FILTER
LIMESTONE
RESEARCH-COITRELL
LIMESTONE
CHEM1CO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
COMBUSTION 6N6INEERIN6
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
RESEARCH-COTTRELL
SODIUM CARBONATE
AIR CORRECTION DIVISION, UOP
START-UP
DATE
12/82
12/82
0/82
6/82
11/80
3/81
7/81
10/80
3/82
6/82
9/81
1/82
11/80
6/82
6/81
   TOTAL
                                              16442.0
                                               232

-------
                EPA UTILITY f6D SURVET: JULY  -  SEPTEMBER  1980
              SECTION 11
SUMMARY OF CONTRACT AWARDED  FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
ARIZONA PUBLIC SERVICE
FOUR CORNERS 4
ARIZONA PUBLIC SERVICE
FOUR CORNERS 5
BIG RIVERS ELECTRIC
D.B. WILSON 1
BIG RIVERS ELECTRIC
D.B. WILSON 2
COLORADO UTE ELECTIUC ASSN
CRAI6 3
OESERET GEN I TRANS COOP
MOON LAKE 1
MICHIGAN so CENTRAL PWR AGENCY
PROJECT 1
MUSCATINE POWER I HATER
MUSCATINE 9
NORTHERN INDIANA PUB SERVICE
SCHAHFER 17
NORTHERN INDIANA PUB SERVICE
SCMAHFER 18
PHILADELPHIA ELECTRIC
CRONBV 1
PLAINS ELECTRIC 6 K T COOP
PLAINS ESCALANTE 1
PLATTE RIVER POWER AUTHORITY
RAWHIDE 1
SEAINOLE ELECTRIC
SE1INOLE 1
SEMINOLE ELECTRIC
SENINOLE 2
SOUTH CAROLINA PUBLIC SERVICE
CROSS 1
SOUTH CAROLINA PUBLIC SERVICE
CROSS 2
SOUTHWESTERN ELECTRIC POWER
DOLET HILLS 1
SOUTHWESTERN ELECTRIC POWER
HENRY W. PIRKEV 1
SUNFLOWER ELECTRIC COOP
HOLCONB 1
TAMPA ELECTRIC
BI6 SEND 4
TENNESSEE VALLEY AUTHORITY
JOHMSONV1LLE 1-10
TEXAS POWER t LIGHT
TWIN OAKS 1
TEXAS POWER t LIGHT
TWIN OAKS 2
NEW OR (
RETROFIT
RETROFIi
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
NEW
NEW
APACITT
MW
755.0
755.0
(40.0
440.0
447.0
410.0
55. 0
166.0
421.0
421.0
150.0
233.0
279.0
620.0
620.0
500.0
500.0
720.0
720.0
347.0
475.0
600.0
750.0
750.0
PROCESS/
SYSTEM SUPPLIER
LIME
UNITED ENGINEERS
LIME
UNITED ENGINEERS
LIMESTONE
PULLMAN KELLOG
LIMESTONE
PULLMAN KELLOG
LIME/SPRAY DRYING
BABCOCK ( NU.COX
LIMESTONE
COMBUSTION ENGINEERING
LIMESTONE
BABCOCK I WILCOX
LIMESTONE
R£SEARCH-COTTRELL
DUAL ALKALI
FMC
DUAL ALKALI
FMC
MAGNESIUM OXIDE
UNITED ENGINEERS
LIMESTONE
COMBUSTION ENGINEERING
LIME/SPRAY DRYING
JOY NFG/NIRO ATOMIZER
LIMESTONE
PEABODV PROCESS SYSTEMS
LIMESTONE
PEABODY PROCESS SYSTEMS
LIMESTONE
PEABODV PROCESS SYSTEMS
LIMESTONE
PEABOOY PROCESS SYSTEMS
LIMESTONE
AIR CORRECTION DIVISION. UOP
LIMESTONE
AIR CORRECTION DIVISION, UOP
LIME/SPRAY DRYING
JOY MF6/NIRO ATOMIZER
LINE/LIMESTONE
RESEARCM-COTTRELL
MAGNESIUM OXIDE
ENVIRONEERING, RILEY STOKER
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
LIMESTONE
CHEMICO DIVISION, ENVIROTECH
START-UP
DATE
0/82
0/82
7/S4
1/86
0/82
9/84
6/82
9/82
6/83
6/85
5/83
12/83
12/83
3/83
3/85
1/85
11/83
0/86
12/84
9/83
12/84
12/81
8/84
8/85
                   233

-------
EPA UTILITY F60 SURVEY: JULY - SEPTEMBER 1980
                                           SECTION 11
                             SUMMARY Of CONTRACT AWARDED F6D SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
TEXAS UTILITIES
MARTIN LAKE 4
TUCS»N ELECTRIC POWER
SPRIMSERVILLE 1
TUCSON ELECTRIC POWER
SPRINGERVILLE 2
UTAH POWER « LIGHT
HUNTER 3
UTAH POWER t LIGHT
HUNTER 4
WEST PENN POWER
MITCHELL 33
NEW OR
'RETROFIT
NEW
NEW
NEW
NEW
NEW
RETROFIT
CAPACITY
MW
750.0
370.0
370.0
400.0
400.0
300.0
PROCESS/
SYSTEM SUPPLIER
LIMESTONE
RESEARCH-COiTTRELL
LIME/SPRAY DRYING
JOY NFG/NIRO ATOMIZER
LIME/SPRAY DRYING
JOY MFG/NIRO ATOMIZER
LIMESTONE
CHEHICO DIVISION, ENVIROTECH
LIMESTONE
CHEHICO DIVISION, ENVIROTECH
LIME
CHEHICO DIVISION, ENVIROTECH
START-UP
DATE
0/85
1/85
5/87
6/83
6/85
8/82
   TOTAL
                                             14164.0
                                              234

-------
            EPA UTILITY  FG6  SURVEY:  JULY - SEPTEMBER 1980
          SECTION 12
SUMMARY OF PLANNED F60 SYSTEMS
COMPANY NAME/
UNIT NINE UNIT NO.
NEW OR
RETROFIT
CAPACITY
MW
PROCESS/
SYSTEM SUPPLIER
START-UP
DATE
LETTER OF INTENT SIGNED
MIDDLE SOUTH UTILITIES
ARKANSAS LI6NITE 5
MIOOLE SOUTH UTILITIES
ARKANSAS LIGNITE 6
HI DOLE SOUTH UTILITIES
UNASSIGNED 1
MIDDLE SOUTH UTILITIES
UNASSIGNED 2
MIDDLE SOUTH UTILITIES
WILTON 1
MIDDLE SOUTH UTILITIES
UILTON 2
NEVADA POWER
REID 6ARDNER 4
TOTAL
REQUESTING /EVALUATING
BASIN ELECTRIC POWER COOP
ANTELOPE VALLEY 2
CENTRAL ILLINOIS LIGHT
DUCK CREEK 2
DESERET GEN I TRANS COOP
MOON LAKE 2
GENERAL PUBLIC UTILITIES
COHO 1
GENERAL PUBLIC UTILITIES
SEWARD 7
HOUSTON LIGHTING t POKER
LI1ESTONE 1
HOUSTON LIGHTING t POKER
LI'ESTOttE 2
IOWA ELECTRIC L16HT t PUR
GUTHRIE CO. 1
LOUISVILLE GAS ( ELECTRIC
TRIMBLE COUNTY 1
LOUISVILLE GAS ( ELECTRIC
TRIMBLE COUNTY 2
MARQUETTE BOARD OF LIGHT C PHR
SMIRAS 3
NEVADA POWER
WARNER VALLEY 1
NEVADA POWER
WARNER VALLEY 2
NEK YORK STATE ELEC ( GAS
SOMERSET 1
PACIFIC POWER t LIGHT
JIM BRIDGES 1
NEW
NEW
NEW
NEW
NEW
NEW
NEW

BIDS
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
RETROFIT
890.0
890.0
890.0
890.0
890.0
890.0
250.0
890.0

440.0
450.0
410.0
690.0
690.0
750. 0
750.0
720.0
575.0
575.0
44.0
295.0
295.0
625.0
550.0
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
SODIUM CARBONATE
COMBUSTION 80UIP ASSOCIATES


LINE/SPRAY DRYING
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIME/SPRAY DRYING
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT (ELECTED
LIMESTONE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
0/90
0/92
0/89
0/93
0/88
0/91
4/83


10/85
1/86
0/88
5/91
5/87
12/84
12/85
11/84
7/85
7/88
10/82
6/85
6/86
6/84
0/88
               235

-------
EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
                                           SECTION 12
                                 SUMMARY OF PLANNED FGD SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
PACIFIC POWER * LIGHT
JH 9RID6ER 2
PACIFIC POWER t LIGHT
lit BRIDGES 3
TEXAS UTILITIES
FOREST GROVE 1
TOTAL
NEW OR
RETROFIT
RETROFIT
RETROFIT
NEW

CAPACITY
MW
SSO.O
550.0
750.0
440.0
PROCESS/
SYSTEM SUPPLIER
SODIUM CARBONATE
VENDOR NOT SELECTED
SODIUM CARBONATE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED

START-UP
DATE
0/84
0/86
0/87

CONSIDERING FGD SYSTEMS
ATLANTIC CITY ELECTRIC
CUMBERLAND 1
CAJUN ELECTRIC POWER COOP
BIS CAJUN III 1
CENTRAL MAINE POKER
SEARS ISLAND 1
CENTRAL POWER ft LIGHT
COLETO CREEK 2
CINCINNATI 6AS 1 ELECTRIC
EAST BEND 1
COLUMBUS 1 SOUTHERN OHIO ELEC
POSTON 5
COLUMBUS I SOUTHERN OHIO ELEC
POSTON 6
DELMARVA POWER 1 LIGHT
VIENNA 9
EAST KENTUCKY POWER COOP
J.K. SMITH 1
EAST KENTUCKY POWER COOP
J.K. SMITH 2
GENERAL PUBLIC UTILITIES
COAL 1
GENERAL PUBLIC UTILITIES
COAL 2
GENERAL PUBLIC UTILITIES
COAL 3
GENERAL PUBLIC UTILITIES
COAL 4
INDIANAPOLIS POWER I LIGHT
PATRIOT 1
INDIANAPOLIS POWER t LIGHT
PATRIOT 2
INDIANAPOtIS POWER t LIGHT
PATRIOT 3
JACKSONVILLE ELEC AUTHORITY
NEW PROJECT 1
JACKSONVILLE ELEC AUTHORITY
NEW PROJECT 2
LANSING BOAR» OF WATER t LIGHT
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
330.0
540.0
600.0
720.0
650.0
375.0
375.0
550.0
650.0
650.0
62S.O
625.0
625.0
625.0
650.0
650.0
650.0
600.0
600.0
160.0
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
1/88
0/8S
1/89
9/86
10/87
8/86
0/89
6/87
1/85
1/87
12/92
5/94
12/95
5/97
0/87
O/ 0
O/ 0
12/85
6/87
1/87
                                                       VENDOR  NOT  SELECTED
                                             236

-------
                                          EPA  UTILITY F66 SURVEY: JULY - SEPTEMBER 1980
                                        SECTION  12
                             SUMMARY  OF  PLANNED fGO SYSTEMS
COMPANY NAME/
UNIT NAME UNIT NO.
LOS ANGELES DEPT OF UTR ( PUR
IMTERHOUNTAIN 1
LOS ANGELES DEPT OF WTR 1 PUR
INTERNOUNTAIV 2
LOS ANGELES DEPT OF WTR I PUR
INTERNOUNTAIN 3
LOS ANGELES DEPT OF WTR 1 PUR
INTERHOUNTAIN 4
NEBRASKA PUBLIC POWER DISTRICT
FOSSIL III 1
NEVADA POUER
HARRY ALLEN 1
NEVADA POUER
HARRY ALLEN 2
NEVADA POUER
HARRY ALLEN 3
NEVADA POUER
HARRY ALLEN *
PACIFIC GAS t ELECTRIC
NONTEZUMA 1
PACIFIC GAS t ELECTRIC
MONTEZUHA Z
PtfR AUTHORITY OF STATE OF NY
FOSSIL
SALT RIVER PROJECT
CORONADO 3
SOUTHERN ILLINOIS POUER COOP
MARION 5
SOUTHWESTERN ELECTRIC POUER
OOLET HILLS 2
TEXAS UTILITIES
HILL CREEK 1
TEXAS UTILITIES
HILL CREEK 2
UEST TEXAS UTILITIES
OKLAUNION 1
NEU OR
RETROFIT
NEW
NEU
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEW
NEU
NEW
NEW
NEW
NEW
NEW
CAPACITY
NU
820.0
820.0
820.0
820.0
650.0
500.0
500.0
500.0
500.0
800.0
800.0
700.0
280.0
300.0
720.0
750.0
750.0
720.0
PROCESS/
SYSTEM SUPPLIER
LIME
VENDOR NOT SELECTED
LINE
VENDOR NOT SELECTED
LINE
VENDOR NOT SELECTED
LIME
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
LIMESTONE
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
PROCESS NOT SELECTED
VENDOR NOT SELECTED
START-UP
DATE
0/86
0/87
0/88
0/89
3/87
6/86
6/87
6/88
6/89
6/89
6/90
4/87
0/89
0/88
0/88
0/85
0/86
12/86
TOTAL
                                             330.0
                                            237

-------
EPA UTILITY FG6 SURVEY: JULY - SEPTEMBER 1980
                                           SECTION 13
                        TOTAL F60 UNITS AND CAPACITY  INSTALLED BY YEAR
YEAR
1968
1969
1971
1972
197J
1974
1975
1976
1977
1978
1979
1980
1981
1982
1983
1984
198S
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1997
UNDEFINED
NEV I
NO.
1
0
1
6
4
?
6
8
10
13
20
20
13
22
12
12
15
11
14
9
a
2
2
2
1
1
1
1
9
9N LINE
MU
140.
0.
420.
485.
1419.
250.
2018.
2824.
4464.
4553.
6300.
7383.
5169.
9523.
4405.
6946.
8411.
6340.
8540.
5095.
5065.
1690.
1580.
1515.
890.
625.
625.
625.
3262.
TERM
NO.
0
1
0
0
1
3
3
3
1
0
2
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0

1NATED
RW
0.
140.
0.
0.
175.
340.
1637.
850.
47.
0.
143.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.

TOTAL
NO.
1
0
1
7
10
9
12
17
26
39
57
77
90
112
124
136
151
162
176
185
193
195
197
199
200
201
202
203

ON LINE
NU
140.
0.
420.
905.
2149.
2059.
2440.
4414.
8831.
13384.
19541.
26924.
32093.
41616.
46021.
52967.
61378.
67718.
76258.
81353.
86418.
88108.
89688.
91203.
92093.
92718.
93343.
93968.

                                             238

-------
                                              EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 1*
                 DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING  CAPACITY  -  HU
NET UNIT GENERATING  CAPACITY  W/SCRUBBER  -  MW
EQUIVALENT SCRUBBED  CAPACITY  -  HU

•*  FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT - J/6
    AVERAGE  ASH CONTENT  - X
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR CONTENT -  X
    AVERAGE  CHLORIDE CONTENT  -  X

**  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL  PROCESS  TYPE
    PH  CONTROL  ADDITIVE
    SYSTEM  SUPPLIER
    HEM/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP  DATE
    TYPICAL  S02  REMOVAL  - X
    PARTICLE DESIGN REMOVAL EFFICIENCY - X

**  ESP
    NUMBER
    TYPE

**  PARTICLE SCRUBBER
     NUMBER
     TYPE
                            COMMONWEALTH  EDISON
                            UILL COUNTY
                            1
                            ROMEOVILLE
                            ILLINOIS
                               167.0
                               137.0
                             COAL
                             »»****
                              22260.
                                 7.40

                                 1.50
                             WET SCRUBBING
                             LIMESTONE
                             BAB COCK t UILCOX
                             RETROFIT
                                 (   9S70  BTU/L8)
                              4/72
                              2/73
                                76.00
                                98.00
                              1
                             COLD SIDE
                                                VENTURI
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
                                             X  REMOVAL
                                             S02   PART.
                                                                             PER  BOILER  FGD   CAP.
                                                                            HOURS HOURS  HOURS FACTOR
12/79
       A
       B
       SYSTEM
77.0
64.9
77.0
 99.5
100.0
 99.5
57.5
57.8
57.5
                                                744    431
             4Z8
       ** PROBLEHS/SOLUTIONS/COMMENTS
                         ON  DECEMBER 4i  UNIT  1  CAME  OFF  LINE SO THAT THE AID HEATER HOPPERS AND
                         PRECIPITATOR  HOPPERS COULD  BE EMPTIED OF CARBON CARRY-OVER AND DEBRIS.
                         DURING  THIS OUTAGE THE SHOP REPAIRED A LEAK IN THE POND RETURN LINE.

                         ON  DECEMBER 10, THE  A-NODULE DEVELOPED A SERIOUS STEAM LEAK (25,000 MAKE-
                         UP)  IN  A  LOWER  REHEAT  BUNDLE.  THE LEAKING BUNDLE HAD TO BE REMOVED AND
                         REPLACED.  THIS RESULTED IN A TUO DAY FORCED OUTAGE.  LATER IN THE MONTH
                         THE A-MOOULE  BLEU ANOTHER REHEATER TUBE FORCING THE BOILER OFF FOR AN
                         ADDITIONAL 25 HOURS  AND 12  MINUTES.

                         THE A-MODULE  WAS REMOVED FROM THE GAS PATH ON DECEMBER 29, FOR THREE HOURS
                         TO  ALLOW  THE  MAINTENANCE SHOP TO WELD A LEAKING REHEATER FLANGE.

                         THE S02 PLANT FORCED THE BOILER OFF TWICE THIS MONTH.  TOTAL  FORCED OUTAGE
                         TIME ATTRIBUTED TO THE SCRUBBER WAS 54 HOURS AND 39 MINUTES.
  1/80   A
        B
        SYSTEM
91.0
88.6
88.6
 87. 5
 84.1
 84.1
63.0
60.6
60.6
744   536
             451
        «*  PROBLEMS/SOLUTIONS/COMMENTS
                          THE FIRST SIX DAYS OF JANUARY, UNIT 1  BOILER WAS  OFF  THE  SYSTEM BECAUSE
                          OF A SLAG SCREEN TUBE LEAK.  THE UNIT  RETURNED  TO SERVICE ON JANUARY 7.

                          ON JANUARY 16, THE UTILITY HAD TO  DERATE  UNIT  1 TO 50 MW  BECAUSE THE RE-
                                                239

-------
 EPA UTILITY FGD SURVEY: JULY  - SEPTEMBER  1980

COMMONWEALTH EDISON: MILL COUNTY  1  (CONT.)
	PERFORMANCE DATA--	
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                                               z  REMOVAL   PER  BOILER  FGD   CAP.
                                               S02   PART. HOURS HOURS  HOURS FACTOR
                         HEATER SECTIONS  ON  A  AND  B  MODULES WERE PLUGGING.  ON JANUARY 17, THE
                         MODULES WERE  TAKEN  OUT  OF THE  GAS PATH TO BEGIN REMOVING AND CLEANING THE
                         REHEATER SECTIONS WITH  A  HIGH  PRESSURE (4000 PSD WATER SPRAY.  UNIT 1
                         BOILER WAS LEFT  ON  TO PROVIDE  STABILITY FOR THE 138 KV SYSTEM.

                         IN THE PAST,  ALL 42 BUNDLES CONSISTING OF SEVEN TUBES PER BUNDLE.
                         HAD TO BE TAKEN  OUTSIDE TO  BE  CLEANED ON A CONCRETE SLAB.  IN THIS CASE
                         SINCE TIME WAS THE  MOST IMPORTANT FACTOR. A DIFFERENT APPROACH WAS USED.
                         ONLY THE MIDDLE  SIX BUNDLES ON EACH MODULE WERE REMOVED.  THIS PROVIDED A
                         LARGE ENOUGH  SPACE  SO THAT  A LANCE WITH AN EXTENSION ON IT COULD BE USED
                         TO CLEAN THE  BOTTOM OF  THE  TWO TOP BUNDLES AND THE TOP OF THE TWO BOTTOM
                         BUNDLES.  THERE  ARE DOORS THAT ALLOW EASY ACCESS TO THE TOP AND BOTTOM
                         OF THE REHEATER. USING THIS METHOD, ONLY 12 OR THE 42 BUNDLES WERE
                         REMOVED.  IN  THE PAST,  THIS JOB HAS TAKEN AS LONG AS TWO WEEKS TO
                         COMPLETE.  USING THE  NEW  METHOD. ALL THE REHEATER BUNDLES WERE CLEANED IN
                         20 HOURS.

                         THE B-MODULE  WAS FORCED OFF LINE ON TWO OTHER OCCASIONS IN JANUARY.  BOTH
                         THESE OUTAGES WERE  CAUSED BY THE REHEATER (A COIL LEAK AND A FLANGE LEAK)
                         TOTALING 18 HOURS AND 24  MINUTES.
 2/80
       A
       B
       SYSTEM
 79.7
 78.6
 74.1
90.5
89.2
84.2
79.7
78.6
74.1
                                                                              696   613
                                                                                           516
       ** PROBLEMS/SOLUTIONS/COMPENTS
                         SCRUBBER PROBLEMS  IN  FEBRUARY  WERE  CAUSED  FROM LEAKS IN THE VENTURI SPRAY
                         HEADER.  THESE LEAKS  DEVELOP WHERE  THE  RUBBER  LINING INSIDE THE VENTURI
                         PIPING HAS WORN AWAY  SO THAT THE  BARE METAL IS EXPOSED.  THIS EXPOSED METAL
                         IS THEN SUBJECT TO  ERROSION/CORROSION.   THE LINING IS HOST LIKELY TO WEAR
                         AT THE HELD HEAD OF THE SPRAY  NOZZLE TO THE MAIN HEADER.  ALL THE VENTURI
                         SPRAY PIPING I.S BEING  REPLACED.

                         TUBE LEAKS IN THE  STEAM COIL REHEAT SYSTEM CAUSED SCRUBBER PROBLEMS THIS
                         MONTH.  MODULE A WAS  FORCED OUT ONCE AND MODULE B MAS FORCED OUT THREE
                         TIMES.  THESE TUBES WILL BE REPLACED DURINC THE NEXT OUTAGE.
 3/80
       A
       A
       SYSTEM
 83.9
 83.9
 83.9
                                                                              744
       •* PROBLEMS/SOLUTIONS/COMHENTS
                         THE BOILER WAS OUT OF SERVICE  FOR  ALL  OF  MA.RCH DUE TO BOILER TUBE LEAKS IN
                         THE REHEAT SECTION OF THE BOILER.
 4/80
       A
       B
       SYSTEM
100.0
 87.7
 93.9
71.0
71.0
71.4
17.3
17.3
17.3
                                                                              720   175
                                                                                           125
       **  PROBLEMS/SOLUTIONS/COMMENTS
 5/80  SYSTEM
       DURING THE FIRST 15 DAYS OF APRIL  THE  BOILER  WAS  OUT  OF  SERVICE DUE TO
       TUBE LEAKS IN THE AIR PREHEATER.

       WHEN ATTEMPTS WERE MADE TO BRING THE BOILER ON'LINE ON THE  16 THE
       B-HODULE OF THE S02 SYSTEM DEVELOPED REHEAJER TUBE LEAKS.   THIS CAUSED
       A FORCED OUTAGE OF 53 HOURS AND 40 MINUTES.

       WHEN ATTEMPTS WERE MADE TO RETURN  THE  BOILER  TO SERVICE  AGAIN, THE AUXIL-
       IARY LOW PRESSURE GOVENOR DEVELOPED AN OIL LEAK CAUSING  A  FOUR DAY OUTAGE,
       FOLLOWED BY ANOTHER REHEATER TUBE  LEAK OUTAGE ON  THE  B MODULE.  THIS
       OUTAGE LASTED 35 HOURS.  THE UNIT  RETURNED TO SERVICE ON APRIL 24  AND
       WAS AVAILABLE FOR THE REST OF APRIL.

                                                           744
                                               240

-------
                                              EPA UTILITY  F6D  SURVEY:  JULY  - SEPTEMBER  1980
COMMONWEALTH EDISON: WILL COUNTY 1 CCONT.)
— -------------- - ------------- - ---- —— -PERFORMANCE  DATA- --- — --- - --- — —————— ---------
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   » REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR


       *• PROBLEMS/SOLUTIONS/COHMENTS
                         INFORMATION UAS NOT  AVAILABLE  FOR  THE  MONTH OF HAY.
 6/80
A
B
SYSTEM
                  86. 5
                  86.5
                  86.5
                       100.0
                       100.0
                       100.0
                                    81.2
                                    81. Z
                                    81. Z
                                                                             720    584
                                                                                           584
       ** PROBLEMS/SOLUTIONS/COMMENTS
                         THE  SCRUBBING  SYSTEM  FORCED THE BOILER OUT OF SERVICE FROM JUNE 6 TO
                         JUNE  10.  THE  OUTAGE  HAS  CAUSED BY PLUGGED REHEATERS ON BOTH MODULES.
                         THIS  UAS THE ONLY  FORCED  OUTAGE EXPERIENCE* DURING JUNE.
7/80
A
B
SYSTEM
87.8
87.8
87.8
                              78.3
                              78.3
                              78.3
                                                        55.0
                                                        S5.0
                                                        55.0
                                                                              744
                                                                                     522
                                                                                           409
       ** PROBLEMS/SOLUT IONS/COMMENTS
                          DURIN6  THE  MONTH OF JULY THERE HERE NO FORCED SCRUBBER  OUTAGES.

                          TWO  SLAG LINE OUTAGES. ONE FORCED DRAFT FAN AND ONE BOILER  SCREEN  HALL
                          TUBE OUTAGE OCCURRED.  THIS ACCOUNTED FOR 193 HOURS OF  BOILER-RELATED
                          OUTAGE  TIME DURING THE MONTH.

                          ON NINE OCCASIONS IN JULY THE SCRUBBER MAS BY-PASSED  SO THAT  THE BOILER
                          COULD CARRY MAXIMUM LOAD (163 MH>.  THE UNIT HAS LIMITED TO 13S  MU AFTER
                          A RECENT STACK EMISSION TEST.
B/80  SYSTEM

»/80  SYSTEM

      *• PROBLEMS/SOLUTIONS/COMMENTS
                                                                               744

                                                                               720
                          NO INFORMATION HAS AVAILABLE FOR THE  MONTHS OF  AUGUST AND SEPTEMBER.
                                                 241

-------
 EPA UTILITY FGD  SURVEY:  JULY  - SEPTEMBER  1980
                                            SECTION 1*
                  DESIGN AND  PERFORMANCE  DATA FOR OPERATIONAL PARTICLE SCRUBBERS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING  CAPACITY  -  MU
 NET UNIT 6ENERATIN6 CAPACITY  W/SCRUBBER  -  MW
 EQUIVALENT SCRUBBED CAPACITY  -  MU

 ** FUEL DATA
     FUEL TYPE
     FUEL 6RADE
     AVERAGE HEAT CONTENT - J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT -  X
     AVERAGE CHLORIDE CONTENT  -  X

 *» GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PH CONTROL ADDITIVE
     STSTEM SUPPLIER
     NEy/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     TYPICAL S02 REMOVAL - X
     PARTICLE DESIGN REMOVAL EFFICIENCY - X

 ** ESP

 • * MECHANICAL COLLECTOR

 •* PARTICLE SCRUBBER
     NUMBER
     TYPE
                        DETROIT EDISON
                        ST. CLAIR
                        6
                        BELLE RIVER
                        MICHIGAN
                          260.0
                          130.0
                        COAL
                        SUBBITUMINOUS
                         22330.
                            4.00
                           22.60
                             .35
(  9600 BTU/LB)
                        WET  SCRUBBING
                        LIMESTONE
                        PEABODV  PROCESS SYSTEMS
                        RETROFIT
                         6/75
                         9/75
                           90.00
                           99.70
                         2
                        VENTURI
	_——_.	PERFORMANCE  DATA-	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION
                                        X  REMOVAL   PER  BOILER  FGD   CAP.
                                        S02   PART.  HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 3/80  SYSTEM
                                                     744

                                                     696

                                                     744
       *• PROBLEMS/SOLUTIONS/COMMENTS
 4/80  SYSTEM
THE SCRUBBING SYSTEM OPERATED  WITH  BETTER  THAN  SOX  AVAILABILITY DURING THE
FIRST QUARTER OF 1980.

THE SCRUBBER ID FAN FAILED.  THE BOLTS  HOLBIN6  PART  OF THE  SHROUDING
IN PLACE SHEERED CAUSING THE PLATE  TO  FALL  ONTO THE  SHAFT.

BECAUSE OF ADDITIONAL PROBLEMS  WITH THE A-S-H  SUMP  PUMPS.  THE  DENVER PUMPS
INSTALLED TO ASSIST THE A-S-H  PUMPS NOW CARRY  THE  ENTIRE  LOAD.  THE A-S-H
PUMPS DRIVES HAVE BEEN DISCONNECTED.   THE  SLURRY CIRCULATES THROUGH THE
THE NON-OPERATING A-S-H PUMPS  TO THE DENVER PUMPS.

THE CONTINUAL PROBLEMS WITH THE LOUVER  BY  PASS  DAMPERS WAS  SOLVED BY DIS-
CONNECTING THE EXTREME LOUVER  AT EITHER END.   THE  DAMPERS  OPERATE NOW WITH
12 OF THE 14 LOUVERS.  THE UTILITY  IS  PLEASED  WITH  RECENT  DAMPER
OPERATIONS.

SOME RECENT SCRUBBER OUTAGES RESULTED  FROM  THE  OCCASIONAL  UNAVAILABILITY
OF LIMESTONE.

                                                     720
                                               242

-------
                                               EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

DETROIT EDISON: ST. CLAIR 6 (CONT.)
...—_	.	.-..---..-.-.._.-__._.-.—PERFORMANCE DATA	——	—	—	......	...
PERIOD MODULE AVAILABILITY OPERABIL1TV  RELIABILITY UTILIZATION  t REMOVAL   PER  BOILER  F6t    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                          THE  SCRUBBER WAS OUT OF SERVICE THROUGH APRIL WHILE  REPAIRS CONTINUED ON
                          THE  SCRUBBER ID FAN HOUSING.  BECAUSE BOILER OPERATED  AT  LOW LOAD THE
                          SCRUBBER  SERVICES WERE NOT REQUIRED IN APRIL.

 5/80  SYSTEM                                                                  74*

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          THE  SCRUBBER WAS OUT OF SERVICE UNTIL MAY 21 WHEN  THE  FAN HOUSING REPAIR
                          WAS  COMPLETED.  THE SCRUBBER WAS SHUT DOWN  AGAIN ON  MAY  25 WITH A SCRUBBER
                          ID  FAN BEARING FAILURE.

 6/80  SYSTEM                                                                  720

       • • PROBLEMS/SOLUTIONS/COMMENTS

                          THE  SCRUBBER  WAS NOT OPERATED THROUGH JUNE  BECAUSE  PARTS FOR  THE SCRUBBER
                          IB  FAN HAD NOT ARRIVED AT THE PLANT.  SCRUBBER  SERVICE WAS NOT REQUIRED
                          BECAUSE OF LOW BOILER LOAD.

                          SCRUBBER REPAIRS AT ST CLAIR REQUIRE  MORE  OUTAGE  TIME THAN ONE WOULD  EXPECT
                          BECAUSE THE UTILITY DOES NOT STOCK  A  GREAT  DEAL OF  PARTS FOR  THE SCRUBBER.
                          THE  ST CLAIR  6 SCRUBBER  IS  SCHEDULED  TO BE  PERMANENTLY REMOVED FROM SERVICE
                          IN  SEPTEMBER  1981 WHEN THE  NEW  100X CAPACITY  ESP  FACILITY  CURRENTLY UNDER
                          CONSTRUCTION  IS  COMPLETE.   AT PRESENT  SOX  OF  THE  FLUE GAS  IS  SCRUBBED  AND
                          SOX PASSES THROUGH  THE ESP.  DURING LOW LOA.D  PERIODS EITHER THE  SCRUBBER OR
                          ESP CAN BE SHUT  DOWN.

 7/80  SYSTEM                                                                  7**

 8/80  SYSTEM                                                                  74*

 9/80  SYSTEM                                                                  720

        ** PROBLEMS/SOLUTIONS/COMMENTS

                          THE SCRUBBING  SYSTEM  DID NOT OPERATE DURING THE JULY THROUGH  SEPTEMBER
                          PERIOD.   THE  UTILITY  IS  WAITING ON A UNIT OUTAGE TO PERFORM THE  NECESSARY
                          REPAIRS  ON THE  BOOSTER  FAN  AND  TO REPAIR SOME MINOR SCRUBBER  INTERNAL
                          PROBLEMS.
                                                  243

-------
  EPA  UTILITY  F6D SURVEY: JULY - SEPTEMBER 1980
                                            SECTION  U
                   DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE  SCRUBBERS
  COMPANY  NAME
  PLANT  NAME
  UNIT NUMBER
  CITY
  STATE
  GROSS  UNIT GENERATING CAPACITY - MW
  NET UNIT  GENERATING  CAPACITY W/SCRUBBER - MW
  EQUIVALENT SCRUBBED  CAPACITY - MW

  **  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE HEAT  CONTENT - J/G
     AVERAGE ASH CONTENT  - X
     AVERAGE MOISTURE  CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE  CONTENT - X

  *•  GENERAL EMISSION  CONTROL SYSTEM DATA
     KENERAL PROCESS  TYPE
     PH CONTROL ADDITIVE
     SYSTEM SUPPLIER
     NEy/RETROFIT
     ENERGY CONSUMPTION  - X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP  DATE
     TYPICAL S02 REMOVAL  - X
     PARTICLE DESIGN  REMOVAL EFFICIENCY - X

  *•  FABRIC FILTER
     NUMBER
     TYPE

  •*  ESP
     NUMBER

  •* MECHANICAL COLLECTOR
     NUMBER

  «• PARTICLE SCRUBBER
     NUMBER
     TYPE
                   MINNESOTA POWER t LIGHT
                   CLAY BOSWELL
                   3
                   COHASSET
                   MINNESOTA
                     364.0
                     347.1
                     350.0
                                  (  8400 BTU/LB)
      COAL
      SUBBITUMINOUS
       19538.
          9.00
          26.00
            .92
            .01
                   WET  SCRUBBING
                   ALKALINE  FLVASH
                   KREBS  ENGINEERS
                   NEW
                        .8
                    1/73
                    5/73
                        .00
                     98.70
                   0
                  NONE


                   0


                   0


                   1
                  SPRAY IMPINGEMENT  TOWER
....	-._._—.__________	„..	—PERFORMANCE DATA	—..	.......	........_
PERIOD MODULE AVAILABILITY OPERABIL1TY RELIABILITY UTILIZATION  J REMOVAL   PER  BOILER   F60    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 5/80  SYSTEM

       •* PROBLEMS/SOLUTIONS/COMMENTS
                                                744

                                                696

                                                744
                         THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS  DURING  THE
                         1ST QUARTER OF  1980.
 4/80  SYSTEM

 5/80  SYSTEM

 6/80  SYSTEM

       ** PROBLEHS/SOLUTIONS/COMMENTS
                                                720

                                                744

                                                720
                         THE UTILITY  REPORTED  THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DURING  THE
                         SECOND QUARTER  OF  1980.  DOWN TIME FOR MAINTENANCE WAS NOT  REQUIRED  SINCE
                         GENERAL MAINTENANCE  CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT  PAR-
                         TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
 7/80  SYSTEM

 8/80  SYSTEM
100.0

100.0
100.0

100.0
90.3

78.0
720   650

744   580
650  60.2

580  52.3
                                                244

-------
                                               EPA UTILITY F60 SURVEY: JULY -  SEPTEMBER  1980

MINNESOTA POWER * LIGHT: CLAV BOSWELL  3  CCONT.)
---—	PERFORMANCE DATA —	——	—.........
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER  FGD   CAP.
                                                                 SOZ   PART.  HOURS HOURS  HOURS FACTOR


 9/80  SYSTEM                  100.0        100.0        84.0                   744   625    625  54.8

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          NO  OPERATIONAL PROBLEMS WERE REPORTED  FOR THE  JULY THROUGH SEPTEMBER
                          PERIOD.
                                                  245

-------
  EPA  UTILITY  FED  SURVET:  JULY  - SEPTEMBER  1980
                                            SECTION U
                   DESIGN  AND  PERFORMANCE  DATA  FOR OPERATIONAL PARTICLE  SCRUBBERS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 BROSS UNIT 6ENERATIN6  CAPACITY  -  MW
 NET UNIT GENERATING  CAPACITY  U/SCRUBBER  - MW
 EQUIVALENT SCRUBBED  CAPACITY  -  MW
                                          MINNESOTA POWER ( LIGHT
                                          SVL  LASKIN
                                          1
                                          AURORA
                                          MINNESOTA
                                             62.0
                                             57.3
                                             58.0
 •*  FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT  - J/6
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE  CONTENT  -  X
     AVERAGE SULFUR  CONTENT -  X
     AVERAGE CHLORIDE  CONTENT  -  X

 •*  GENERAL EMISSION CONTROL SYSTEM  DATA
     GENERAL PROCESS TYPE
     PH CONTROL ADDITIVE
     SYSTEM SUPPLIER
     NEU/RETROFIT
     ENERGY CONSUMPTION -  X
     INITIAL START-UP  DATE
     COMMERCIAL START-UP DATE
     TYPICAL S02 REMOVAL - X
     PARTICLE DESIGN REMOVAL EFFICIENCY -  X

 **  FABRIC FILTER
     NUMBER
     TYPE

 • *  ESP
     NUMBER
     TYPE

 ••  MECHANICAL COLLECTOR
     NUMBER
     TYPE

 *•  PARTICLE SCRUBBER
     NUMBER
     TYPE
                                                         (   8800 BTU/LB)
                               COAL
                               SUBBITUMINOUS
                                20469.
                                   9.00
                                  26.70
                                   1.00
                                    .01
                                          WET  SCRUBBING
                                          ALKALINE  FLYASH
                                          KREBS  ENGINEERS
                                          RETROFIT
                                              1.1
                                           6/71
                                           6/71
                                              .00
                                            98.70
                                           0
                                         NONE
                                          0
                                         NONE
                                          0
                                         NONE
                                          1
                                         SPRAY IMPINGEMENT TOWER
__—.....—-—....—........	PERFORMANCE DATA—-	—————————...._._.__.

PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  X  REMOVAL    PER   BOILER   FGD    CAP.
                                                                S02   PART.  HOURS  HOURS   HOURS  FACTOR
 1/80

 2/80

 3/80
SYSTEM


SYSTEM


SYSTEM


•• PROBLEMS/SOLUTIONS/COMNENTS
                                                            744

                                                            696

                                                            744
                         THE UTILITY REPORTED THAT THE SCRUBBER EXPERIENCED NO PROBLEMS  DURING  THE
                         1ST GUARTER OF 1980.
 4/80

 5/80

 6/80
SYSTEM

SYSTEM

SYSTEM


** PROBLEHS/SOLUTIONS/COMNENTS
                                                            720

                                                            744

                                                            720
                         THE UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED  DURING  THE
                         SECOND QUARTER OF 1980.  DOWN TIME FOR MAINTENANCE WAS NOT  REQUIRED  SINCE
                         GENERAL MAINTENANCE CAN BE PERFORMED ON THE MINNESOTA POWER AND LIGHT  PAR-
                         TICLE SCRUBBERS WHILE THEY ARE IN SERVICE.
 7/80

 8/80
SYSTEM


SYSTEM
100.0

100.0
100.0

100.0
100.0

100.0
56.6

19.0
744


744
421

140
421

140
25.2

12.0
                                                    246

-------
                                               EPA UTILITY  F6D SURVEY: JULY - SEPTEMBER 1980

MINNESOTA POWER 8 LIGHT: SVL LASKIN 1 CCONT.)
	—_—_—PERFORMANCE  DATA———	———————	——— -
PERIOD MODULE AVAILABILITY OPERABUITY RELIABILITY  UTILIZATION  t REMOVAL   PER  BOILER  F6D   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLEHS/SOLUT10NS/COMMENTS

                         THE  UTILITY REPORTED  THAT  NO  BOILER OR FCC-RELATED PROBLEMS HERE ENCOUNTER-
                         ED DURING  JULY AND  AUGUST. LOW UTILIZATION FACTORS WERE DUE TO A LACK
                         OF POWER DEMAND.

 9/80  SYSTEM     100.0        100.0       100.0         t.4                  720    33     33    1*9

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         NO SCRUBBER OUTAGES OCCURRED  »URIN6 SEPTEMBER.  THE LOW UTILIZATION  FACTOR
                         WAS  AGAIN  THE  RESULT  OF A  LACK OF DEMAND FOR POWER.
                                                 2*7

-------
 EPA  UTILITY  FGO  SURVEY: JULY - SEPTEMBER  1980
                                             SECTION  14
                   DESIGN AND PERFORMANCE DATA  FOR OPERATIONAL PARTICLE SCRUBBERS
 COMPANY  NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING CAPACITY - MW
 NET UNIT GENERATING CAPACITY" W/SCRUBBER - MW
 EQUIVALENT SCRUBBED CAPACITY - MW
                               MINNESOTA POWER ft LIGHT
                               SYL LASKIH
                               2
                               AURORA
                               MINNESOTA
                                  63.0
                                  57.3
                                  58.0
 **  FUEL  DATA
      FUEL TYPE
      FUEL GRADE
      AVERAGE HEAT  CONTENT - J/G
      AVERAGE ASH CONTENT - X
      AVERAGE MOISTURE CONTENT - X
      AVERAGE SULFUR  CONTENT - X
      AVERAGE CHLORIDE CONTENT - X

 »*  GENERAL EMISSION CONTROL SYSTEM DATA
      GENERAL PROCESS TYPE
      PH CONTROL ADDITIVE
      SYSTEM SUPPLIER
      NEW/RETROFIT
      ENERGY CONSUMPTION - X
      INITIAL START-UP DATE
      COMMERCIAL START-UP DATE
      TYPICAL S02 REMOVAL - X
      PARTICLE DESIGN REMOVAL EFFICIENCY - X
                               COAL
                               SUBBITUMINOUS
                                20469.
                                   9.00
                                  26.70
                                   1.00
                                    .01
                               WET SCRUBBING
                               ALKALINE FLVASH
                               KREBS ENGINEERS
                               RETROFIT
                                   1.1
                                6/71
                                6/71
                                    .00
                                  98.70
                                  <  8600 BTU/LB)
 •* FABRIC  FILTER
     NUMBER
     TYPE
                                0
                               NONE
 •* ESP
     NUMBER
     TYPE

 •• MECHANICAL  COLLECTOR
     NUMBER
     TYPE

 •* PARTICLE  SCRUBBER
     NUMBER
     TYPE
                                0
                               NONE
                                0
                               NONE
                                1
                               SPRAY IMPINGEMENT TOWER
	_	..—PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION
                                               X REMOVAL    PER   BOILER   FGO   CAP.
                                               S02  PART. HOURS  HOURS   HOURS FACTOR
 1/fcO  SYSTEM
                                                                               744
 2/80  SYSTEM

 J/80  SYSTEM
                                                            696

                                                            744
          PROBLEMS/SOLUTIONS/COMMENTS
 4/80  SYSTEM

 5/80  SYSTEM

 6/80  SYSTEM
       THE UTILITY REPORTED  THAT  THE SCRUBBER EXPERIENCED NO  PROBLEMS  DURING THE
       1ST QUARTER OF  1980.

                                                            720

                                                            744

                                                            720
       •* PROBLEMS/SOLUTIONS/COMMENTS
                          THE  UTILITY REPORTED THAT NO SCRUBBER-RELATED OUTAGES OCCURRED DUR1N6 1HE
                          SECOND  QUARTER OF 1980.  DOWN  TIME  FOR  MAINTENANCE WAS NOT REQUIRED SINCE
                          GENERAL MAINTENANCE CAN BE PERFORMED  ON THE MINNESOTA POWER AND LI6HT PAR-
                          TICLE  SCRUBBERS WHILE THEY ARE  IN SERVICE.
 7/80  SYSTEM
100.0
100.0
            100.C
24.5
744   182
                                                                                            182   12.3
                                                248

-------
                                               EPA UTILITY FGO SURVEY.: JULY -  SEPTEMBER  1980

MINNESOTA POWER 8 LI6HT: STL LASKIN  2  (CONT.)
	....	.	——PERFORMANCE DATA-—-—-—-..———	..............
PERIOD MODULE AVAILABILITY  OPERABILITV RELIABILITY UTILIZATION  I REMOVAL    PER   BOILER  FGO   CAP.
                                                                 502   PART.  HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                          THE  BOILER DID NOT OPERATE MOST OF JULY CUE  TO  A BOILER INSPECTION.  NO
                          PROBLEMS WERE ENCOUNTERED WITH THE F6D UNIT.

 B/80  SYSTEM     100.0        100.0       100.0        15.0                   7*4   115    115   5.0

       ** PROBLEMS/SOLUTIONS/COMMENTS

                          THE  BOILER OPERATED ONLY 115 HOURS DURING AUGUST  DUE TO A LACK OF DEMAND.

 9/80  SYSTEM     100.0        100.0       100.0         5.2                   720    39     39   2.4

       «» PROBLEMS/SOLUTIONS/COMMENTS

                          THE  UTILITY REPORT THAT NO SCRUBBER OUTACCS  OCCURRED DURINC SEPTEMBER.
                          THE  LOW UTILIZATION FACTOR RESULTED FROM  A  LACK OF DEMAND FOR
                          POWER.
                                                  249

-------
 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980
                                           SECTION H
                  DESIGN AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 CROSS UNIT GENERATING CAPACITY - MW
 NET UNIT GENERATING CAPACITY U/SCRUBBER - MW
 EQUIVALENT SCRUBBED CAPACITY - My

 ** FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT - J/6
     AVERAGE ASH CONTENT - Z
     AVERAGE MOISTURE CONTENT - X
     AVERAGE SULFUR CONTENT - X
     AVERAGE CHLORIDE CONTENT - X

 •* GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PH CONTROL ADDITIVE
     SYSTEM SUPPLIER
     NEU/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     TYPICAL $02 REMOVAL - X
     PARTICLE DESIGN REMOVAL EFFICIENCY - X

 ** MECHANICAL COLLECTOR
     NUMBER
     TYPE
MONTANA-DAKOTA UTILITIES
LEWIS > CLARK
1
SIDNEY
MONTANA
   55.1
   50.3
   55.1
COAL
LIGNITE
 15003.
    7.80
   36.20
     .61
     .03
WET SCRUBBING
LIMESTONE
RESEARCH-COTTRELL
RETROFIT
    2.2
»«/•»

12/75
     .00
   98.00
 1
MULTICLONES
f  6450 BTU/LB)
    PARTICLE SCRUBBER
     TYPE
VENTURI
	PERFORMANCE DATA—-

PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION
                X REMOVAL
                S02  PART.
             PER  BOILER  FGD   CAP.
            HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM


 2/60  SYSTEM


 3/80  SYSTEM


       • • PROBLEMS/SOLUTIONS/COMMENTS
                             744


                             696


                             744
 4/80  SYSTEM


 5/80  SYSTEM
                         DURING THE JANUARY THROUGH MARCH PERIOD THE SCRUBBER HAS AVAILABLE MORE
                         THAN 95X OF THE TIME.


                         THE EROSION PROBLEM MENTIONED DURING NOVEMBER CONTINUED.  SECTIONS OF THE
                         LINED CARBON STEEL COLUMN WALL SUPPORTING tHE FLOODED DISC HERE RUPTURING,
                         FILLING THE INNER CHAMBER WITH SLURRY AND ULTIMATELY RENDERING THE DISC
                         MOVEMENT MECHANISM INOPERATIVE.  THE UTILITY HAS MANAGED TO KEEP THE
                         SCRUBBER OPERATING AS A STOP-GAP MEASURE BETWEEN UNIT SHUTDOWNS BY INSERT-
                         ING A GARDEN HOSE IN THE COLUMN HOLES AND CONTINUALLY FLUSHING THE INNER

                         CHAMBER.  THE UTILITY HAS HAD SOME SUCCESS IN OTHER EROSION AREAS BY
                         MAKING REPAIRS WITH A HASTELLOY MATERIAL.  PLANS ARE BEING MADE TO JACKET
                         THE ENTIRE DISC SUPPORT COLUMN WITH HASTELLOY 6.


                                                                             720
 6/80  SYSTEM


       •• PROBLEHS/SOLUTIONS/COHMENTS
                             744
                                                                             720
                         THE BOILER WAS SHUT DOWN FOR TWO WEEKS IN HAY.


                         CREWS INSPECTING THE SCRUBBING SYSTEM DISCOVERED THAT THE NINE FOOT  SCRUB-
                         BER LINER SECTION AT THE BOTTOM OF THE CYCLONIC MIST ELIMINATOR  WAS  SEVERE-
                                               250

-------
                                               EPA  UTILITY  F60 SURVEY: JULY - SEPTEMBER 1980

MONTANA-DAKOTA UTILITIES: LEWIS t CLARK 1  (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F66   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR

                         LY ERRODED.  THE LINER  HAS LASTED THREE YEARS.  THE UTILITY CONSIDERS THIS
                         A NORMAL MAINTENANCE  PROBLEM.  AT ONE TIME LINERS IN THIS SECTION HERE  RE-
                         PLACED EVERY SIX MONTHS.   REPLACEMENT UORK ON THE LATEST FAILURE IS  EXPECT-
                         ED TO BE6IN BY  JULY  21.

                         THE  ENTIRE SCRUBBER  COLUMN SUPPORTING THE DISC WHICH HAS ERODING AS  REPORT-
                         ED DURING THE PREVIOUS  TWO QUARTERS HAS BEEN CLAD WITH HASTELLOY C.

                         THE  UTILITY REPORTED THAT  THE SCRUBBER HAS EXPERIENCED PLUGGING AT WET/DRY
                         INTERFACES WITHIN  THE STRUCTURE.  IT APPEAR* THAT THIS IS RELATED TO COAL
                         SULFUR CONTENT.  WHEN THE  SULFUR CONTENT IS RELATIVELY HIGH  (0.7 TO  1.OS AT
                         LEWIS AND CLARK)  THE PLUGGING DOES NOT OCCUR.  LIMESTONE IS  ADDED AS RE-
                         QUIRED TO PREVENT  THE OCCURRANCE OF LOW PH LEVELS.  WHEN THE  SULFUR  CONTENT
                         FALLS TO  THE  O.W  RANGE THE PH RISES AS A RESULT OF THE ALKALINE CONSTITU-
                         ENTS IN THE  FLY ASH  UNTIL  SOFT SCALE PLUGGING RESULTS.  THE  UTILITY  HAS
                         CONSIDERED ADDING  ACID  TO  STABILIZE THE PH WHEN  THE COAL SULFUR  CONTENT
                         DROPS.

  7/80   SYSTEM                                                                 7**

        «•  PROBLEMS/SOLUTIONS/COMMENTS

                          DURING  JULY  TWO WEEKS OF DOWN TIME WAS  NECESSARY TO REPLACE  THE  HIST
                          ELIMINATOR  LINER.

                          THE  PROBLEM  WITH THE FLOODED DISC BUILDUP MENTIONED EARLIER  CONTINUED.
                          THE  UTILITY  PERFORMS THE NECESSARY REPAIRS  IN  THREE TO FOUR  HOURS  WHEN
                          THIS OCCURS.

  8/80  SYSTEM                                                                 7*4

  »/80  SYSTEM                                                                 7?0

        **  PROBLEMS/SOLUTIONS/COMMENTS

                          THE UTILITY REPORTED THAT NO MAJOR PROBLEMS WERE ENCOUNTERED WITH SCRUBBING
                          OPERATIONS DURING THE  MONTHS OF  AUGUST AND  SEPTEMBER.
                                                 251

-------
 EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980
                                            SECTION 14
                   DESIGN AND  PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
 COMPANY NAME
 PLANT NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS UNIT GENERATING CAPACITY  -  MM
 WET UNIT GENERATING CAPACITY  y/SCRUBBER  -  MW
 EQUIVALENT SCRUBBED CAPACITY  -  MU

 *• FUEL DATA
     FUEL TYPE
     FUEL GRADE
     AVERAGE HEAT CONTENT -  J/G
     AVERAGE ASH CONTENT - X
     AVERAGE MOISTURE CONTENT  -  X
     AVERAGE SULFUR CONTENT  -  X
     AVERAGE CHLORIDE CONTENT  -  t

 •* GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL PROCESS TYPE
     PH CONTROL ADDITIVE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL START-UP DATE
     TYPICAL S02 REMOVAL - X
     PARTICLE DESIGN REMOVAL EFFICIENCY - X

 ** PARTICLE SCRUBBER
     NUMBER
     TYPE
PACIFIC POWER S LIGHT
DAVE JOHNSTON
I
GLENROCK
WYOMING
  330.0
  326.5
  330.0
                (  7430 BTU/LB)
COAL
SUBBITUMJNOUS
 17282.
   12.00
   26.00
     .50
     .04
WET SCRUBBING
LIME/ALKALINE FLYASH
CHEMICO DIVISION, EMVIROTECH
RETROFIT
    1.1
 4/72
**/ **
********
                                                 VENTURI
— _	........—..	.	_—PERFORMANCE  DATA	———	............
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILEJ)  FSO   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS  FACTOR


 1/80  SYSTEM                                                                 744

 2/80  SYSTEM                                                                 696

 3/80  SYSTEM                                                                 744

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         NO INFORMATION HAS  AVAILABLE  FOR THE FIRST QUARTER OF 1980.

 4/80  SYSTEM                                                                 720

 5/80  SYSTEM                                                                 744

 6/80  SYSTEM                                                                 720

       *• PROBLEMS/SOtUTIONS/COMMENTS

                         THE UTILITY REPORTED  THAT  NO  MAJOR PROBLEMS OCCURRED DURIN6 THE SECOND
                         QUARTER OF 1980.

 7/80  SYSTEM                                                                 744

 8/80  SYSTEM                                                                 744

 9/80  SYSTEM                                                                 720

       ** PROBLEMS/SOLUTIONS/COHMENTS

                         NO INFORMATION WAS  AVAILABLE  FOR THE THIRD QUARTER OF 1980.
                                                252

-------
                                              EPA UTILITY  FGD SURVEY:  JULY  - SEPTEMBER 1980

                                           SECTION U
                  DESIGN  AND PERFORMANCE DATA FOR OPERATIONAL PARTICLE  SCRUBBERS
COMPANY  NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
SROSS  UNIT GENERATING CAPACITY - MM
NET UNIT GENERATING  CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED  CAPACITY - MU

»*  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X

**  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL  PROCESS  TYPE
    PH CONTROL ADDITIVE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL START-UP DATE
     TYPICAL  SOZ REMOVAL - X
     PARTICLE DESIGN  REMOVAL EFFICIENCY -  X

 •*  ESP
     TYPE

 ••  PARTICLE SCRUBBER
     TYPE
                                         POTOMAC ELECTRIC POWER
                                         DICKERSON
                                         1
                                         DICKERSON
                                         MARYLAND
                                           190.0
                                           183.0
                                         COAL
                                         ******
                                          27214.
                                            14.00
                                         *•***•**
                                             2.00
                                         UET SCRUBBING
                                         RETROFIT
                                      ( 11700 BTU/LB)
                                         **/ «*
                                          0/78

                                            99.00
                                         COLD SIDE
                                                 VENTURI
..	.	.	-PERFORMANCE DATA	—	—	...———
PERIOD MODULE AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION  X REMOVAL    PER   BOILER  FGD   CAP.
                                                                 SOZ  PART. HOURS  HOURS   HOURS FACTOR
1/80
2/80
J/8C
SYSTEM
SYSTEM
SYSTEM
100.
94.
100.
0
3
0
100.
95.
100.
0
8
0
100.
94.
100.
0
3
0
744
696
744
744
685
744
744
656
744
       •* PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  THE  FIRST QUARTER OF 1980 ONLY ONE  SCRUBBER  OUTAGE OCCURRED.  IN
                          FEBRUARY OUTAGE TIME WAS NECESSARY TO REPAIR  A  SLURRY  RECYCLE LINE LEAK.
 4/80

 5/80

 6/8C
SYSTEM

SYSTEM

SYSTEM

** PROBLEMS/SOLUTIONS/COMMENTS
                                                     720

                                                     744

                                                     720
 7/80

 3/80

 9/80
SYSTEM

SYSTEM

SYSTEM
DICKERSON 1 SCRUBBER DEPENDABILITY  FACTORS WERE UNAVAILABLE FOR THE APRIL-
JUNE PERIOD.  THESE FIGURES  SHOULD  BE  AVAILABLE BY THE THIRD QUARTER
REPORT.  THE UTILITY REPORTED  THAT  THE FGD SYSTEM OPERATED THE ENTIRE
SECOND QUARTER WITH ESSENTIALLY 100X AVAILABILITY.  NO SCRUBBER-RELATED
PROBLEMS WERE REPORTED.

                                                     744

                                                     744

                                                     720
                                                 253

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

POTOMAC ELECTRIC POWER: DICKERSON  1  (CONT.)
	.......	.	.	PERFORMANCE  DATA	——.—.-..	
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   x  REMOVAL   PER   BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR


       •* PROBLEBS/SOLUT10NS/COMMENTS

                         THE UTILITY HAS NOT  FIGURED OUT  THE  DEPENDABILITY  FIGURES AS YET.

                         THE UTILITY REPORTED  HAVING MINIMAL  SCRUBBING  SYSTEM  PROBLEMS DURING THE
                         JULY-SEPTEMBER PERIOD.

                         THE BOILER CAPACITY  WAS  REDUCED  DURING  PART  OF  THE PERIOD DUE TO A LINING
                         FAILURE IN THE SCRUBBING SYSTEM  PIPING.
                                               254

-------
                                              EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

                                           SECTION U
                  DESIGN  AND  PERFORMANCE  DATA FOR OPERATIONAL PARTICLE SCRUBBERS


COMPANY NAME                                    POTOMAC ELECTRIC POWER
PLANT NAME                                      DICKERSON
UNIT NUMBER                                     Z
CITY                                            DICKERSON
STATE                                           MARYLAND
GROSS UNIT GENERATING  CAPACITY  - Hy              190.3
YET UNIT  GENERATING  CAPACITY W/SCRUBBER  - MU     183.3
EQUIVALENT SCRUBBED  CAPACITY -  MU              *******

••  FUEL DATA
    FUEL  TYPE                                   COAL
    FUE.L  GRADE                                  ******
    AVERAGE  HEAT  CONTENT - J/G                   27214.         ( 11700 BTU/LB)
    AVERAGE  ASM CONTENT  - X                       14.00
    AVERAGE  MOISTURE CONTENT -  T               ********
    AVERAGE  SULFUR CONTENT - X                       2.00
    AVERAGE  CHLORIDE CONTENT •  X               ********

 ••  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL  PROCESS  TYPE                       UET  SCRUBBING
    PH  CONTROL  ADDITIVE
    SYSTEM  SUPPLIER
    NEy/RETROFIT                                RETROFIT
    ENERGY  CONSUMPTION - X                     *******
    INITIAL  START-UP DATE                      **/*«
    COMMERCIAL  START-UP  DATE                     0/78
    TYPICAL  S92 REMOVAL  - X                    ********
    PARTICLE DESIGN  REMOVAL EFFICIENCY - X        99.00

 «*  ESP
     TYPE                                         COLD SIDE

 **  PARTICLE SCRUBBER
     TYPE                                         VENTURI



	PERFORMANCE DATA	
PERIOD NODULE AVAILABILITY OPERAPILITY RELIABILITY  UTILIZATION  X  REMOVAL   PER  BOILER   FGD    CAP.
                                                                 SO?  PART. HOURS HOURS   HOURS  FACTOR
 1/80
 2/80

 5/80
  4/80

  5/80

  6/80
SYSTEM      95.4        96.4

** PROBLEMS/SOLUTIONS/COMMENTS
                                                        95.4
                                                                               744
                                                                                     736
                                                                                            710
                          IN  JANUARY  THE  SCRUBBER WAS DOWN FOR THREE HOURS TO  REPAIR  A  SLURRY
                          RECYCLE  LINE  LEAK.

                          31  HOURS OF THE OUTAGE TIME IN JANUARY UAS NECESSARY TO  REPAIR  A  RECYCLE
                          PUMP.
SYSTEM     100.0        100.0

SYSTEM      96.9        96.9

•• PROBLEMS/SOLUTIONS/COMMENTS
100.0

 96.9
696

744
696

744
696

721
                          IN MARCH THE SCRUBBER UAS DOUN FOR A SCRUBBER  LINING  WARRANTY  INSPECTION.
                          NO REPAIR WORK UAS NECESSARY.
SYSTEM

SYSTEM

SYSTEM

• *  PROBLEMS/SOLUTIONS/COMMENTS
                        720
                        720
  7/80  SYSTEM
                   DICKERSON 2 SCRUBBER DEPENDABILITY  FACTORS  MERE  UNAVAILABLE FOR THE APRIL-
                   JUNE PERIOD.  THESE FIGURES SHOULD  BE  AVAILABLE  BY  THE THIRD QUARTER
                   REPORT.  THE UTILITY REPORTED THAT  THE  FGD  SYSTEM OPERATED THE ENTIRE
                   SECOND OUARTER WITH ESSENTIALLY  100X  AVAILABILITY.   NO SCRUBBER-RELATED
                   PROBLEMS UERE REPORTED.

                                                                        744
                                                 Z55

-------
 EPA UTILITY  FGD SURVEY: JULY  -  SEPTEMBER 19?C

POTOMAC ELECTRIC POWER: DICKERSON  2  (CONT.)
	p£PfONMANCE DATA	
PERIOD MODULE  AVAILABILITY OPERABILITY  RELIABILITY UTILIZATION   X  REMOVAL   PEP  BOILER   fGO   C»P.
                                                                   SO?  PART. HOURS HOURS   HOURS FACTOR


 B/60  SYSTEM                                                                   744

 9/80  SYSTEM                                                                   7?0

       •* PROBLEHS/SOLUTIONS/COMMENTS

                          THE UTILITY HAS  NOT  FIGURED OUT THE  DEPENOA6ILITY FIGURES  AS  YtT.

                          THE UTILITY REPORTED HAVING MINIMAL  SCRUBBING SYSTEM PROBLEMS DURING THE
                          JULY-SEPTEMBER PERIOD.

                          THE BOILER CAPACITY  HAS REDUCED DURING  PART OF THE PERIOD  DUE TO  A  LINING
                          FAILURE IN THE SCRUBBING SYSTEM PIPING.
                                                 256

-------
                                              EPA UTILITY F6D SURVEY: JULY -  SEPTEMBER  1980

                                           SECTION U
                  DESI6N  AND  PERFORMANCE DATA FOR OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING  CAPACITY - My
NET UNIT  GENERATING  CAPACITY  W/SCRUB8ER - HU
EQUIVALENT SCRUBBED  CAPACITY  - MU

••  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT - J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  - X
    AVERAGE SULFUR CONTEXT -  X
    AVERAGE CHLORIDE CONTENT  - X

*•  GENERAL EMISSION  CONTROL SYSTEM DATA
    GENERAL PROCESS  TYPE
    PH  CONTROL  ADDITIVE
    SYSTEM SUPPLIER
    NEW/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP DATE
    TYPICAL  S02 REMOVAL - X
    PARTICLE  DESIGN REMOVAL EFFICIENCY -  X

 • •  ESP
    NUMBER
    TYPE

 • *  PARTICLE  SCRUBBER
    NUMBER
     TYPE
                                         POTOMAC ELECTRIC POWER
                                         DICKERSON
                                         3
                                         DICKERSON
                                         MARYLAND
                                           190.0
                                           183.0
                                         *******
                                         COAL
                                         BITUMINOUS
                                          27214.
                                            14.00
                                         ********
                                             2.00
                                         WET SCRUBBING
                                         RETROFIT
(  11700 BTU/LB)
                                          9/75
                                         **/ •*
                                               .00
                                            99.3C
                                         COLD  SIDE
                                           1
                                         VENTURI
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY OPERABILITV  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 SO?  PART. HOURS HOURS   HOURS  FACTOR
 1/80
 2/80

 3/80
 4/80

 5/8C

 6/80
SYSTE"      78.7        88.2                     7?.7                  744   664     586

«* PROBLEMS/SOLUTIONS/COMMENTS

                  DURING JANUARY  THE  SCRUBBER HAS DOWN TO REPAIR THE FLAKEGLASS  LINING.

SYSTEM     100.0        100.0                    100.0                  696   696     696

SYSTEM     100.0        10C.O                    100.0                  744   744     744

** PROBLEMS/SOLUTIONS/COMMENTS

                  DURING  FEBRUARY AND MARCH THE SCRUBBER OPERATED UITH NO MAJOR  PROBLEMS.

SYSTE*                                                                 720

SYSTEM                                                                 744

SYSTEM                                                                 720

** PROBLEMS/SOLUTIONS/COMMENTS

                  THE  UNIT 3  SCRUBBER EXPERIENCED  SOME DOWN  TIME  DURING  THE APRIL-JUNE PERIOD
                  AS  A RESULT OF  THE CONTINUING DETERIORATION  OF  THE  SCRUBBER FLAKEGLASS
                  LINING.   THE  UTILITY REPORTED THAT  MAINTENANCE  CREWS  ARE  PATCHING OLD
                  PATCHES.  A STUDY WILL BEGIN IN  LATE JULY  iTO ESTABLISH THE  OPTIMUM LINEP
                  MATERIAL AND  APPLICATION STRATEGY  FOR  THE  UNIT  3  SCRUBBING  SYSTEM.
  7/80

  8/BO

  9/80
 SYSTEM

 SYSTEM

 SYSTEM
                744

                744

                720
                                                 257

-------
 EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

POTOMAC ELECTRIC POWER: DICKERSON  3  CCONT.)
——	—	—	PERFORMANCE DATA—————	—.———.	—_.._.__._..
PERIOD MODULE AVAILABILITY OPERABILITV  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  FGt   CAP.
                                                                 502  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLENS/SOLUTIONS/COMMENTS

                         THE UTILITY HAS  NOT  FIGURED OUT THE DEPENDABILITY FIGURES AS VET.

                         THE UTILITY REPORTED HAVIN6 MINIMAL SCRUBBING SYSTEM PROBLEMS DURING THE
                         JULY-SEPTEMBER PERIOD.

                         THE BOILER CAPACITY  WAS  REDUCED TO 1/2 LOAtt DURING PART OF THE PERIOD DUE
                         TO THE NECESSARY PATCHING OF THE SCRUBBER LINING.  THE UTILITY IS PRESENTLY
                         STUDYING  THE POSSIBILITY OF REPLACING THE PLAKEGLASS LINER WITH A RUBBER
                         LINER.
                                                   258

-------
                                              EPA  UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 14
                 DESIGN AND PERFORMANCE DATA  FOR  OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING  CAPACITY  -  MU
NET UNIT GENERATING  CAPACITY  W/SCRUBBER  -  MU
EQUIVALENT SCRUBBED  CAPACITY  -  MU

•*  FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT  - X
    AVERAGE MOISTURE CONTENT  -  X
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  X

**  GENERAL EMISSION CONTROL SYSTEM DATA
    GENERAL PROCESS TYPE
    PH  CONTROL  ADDITIVE
    SYSTEM SUPPLIER
    NEK/RETROFIT
    ENERGY CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP  DATE
    TYPICAL  SOZ  REMOVAL  - X
    PARTICLE  DESIGN REMOVAL EFFICIENCY - X

**  FABRIC  FILTER
    NUMBER
    TYPE

• •  ESP
    NUMBER

• *  MECHANICAL COLLECTOR
     NUMBER

 •*  PARTICLE  SCRUBBER
     NUMBER
     TYPE
PUBLIC SERVICE OF COLORADO
ARAPAHOE
4
DENVER
COLORADO
  113.0
  109.8
  112.0
                (  10200  BTU/LB)
COAL
SUBBITUNINOUS
 33725.
    9.30
   13.70
     .95
     .01
MET  SCRUBBING
ALKALINE  FLVASH
AIR  CORRECTION  DIVISION, UOP
RETROFIT
*******
  9/73
**/ **

********
  0
 NONE
  1
 MOBILE PACKED TOWER
	PERFORMANCE  DATA	
PERIOD NODULE AVAILABILITY OPERABILITY  RELIABILITY  UTILIZATION
                 X REMOVAL
                 502  PART.
                             PER  BOILER  FGD    CAP.
                            HOURS HOURS  HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 5/80  SYSTEM

       ** PROBLEWS/SOLUTIONS/COMMENTS
                               744

                               696

                               744
  4/80  SYSTEM
                          THE  MODULE  ISOLATION PROBLEMS CONTINUED THROUGH THE  FIRST  QUARTER  OF  1980.
                          USE  OF  THE  CARBON STEEL DAMPERS HAS BEEN ABANDONED.  THE PROGRAM  FOR  RE-
                          PLACING THE DAMPERS HAS BEEN SUSPENDED INDEFINITELY.  THE  UNIT  IS  SHUTDOWN
                          yHEN MAJOR  SCRUBBER PROBLEMS OCCUR.

                          REHEATER STEAM TUBE LEAKS ARE STILL CAUSING PROBLEMS.   THE SIX  STEAM  COILS
                          ON THIS IN-LINE REHEAT SYSTEM, TWO OF WHICH ARE 316SS AND  FOUR  OF  WHICH
                          ARE  CARBON  STEEL, ARE EXPERIENCING CORROSION PROBLEMS.   A  SOLUTION TO THE
                          PROBLEM HAS NOT VET BEEN DETERMINED.

                          IN FEBRUARY THE UTILITY REPLACED  THE  SCRUBBER  BALLS  AND GRIDS.   THE OLD
                          BALLS WERE  REPLACED WITH THE NEW  HOLLOW HARD PLASTIC-WALLED BALLS WITH
                          NOTCHED SEAMS.  THE GRIDS WERE ORIGINALLY  116L SS,  CERAMIC, POLYPROPYLENE,
                          AND RUBBER  LINED CARBON STEEL, BUT HAVE BEEN REPLACED  WITH 317L SS GRIDS.

                          THE SCRUBBERS OPERATED CONTINUOUSLY THROUGHOUT THE  QUARTER EXCEPT FOR THE
                          BALL AND GRID REPLACEMENT DOWNTIME.
                               100.0
                                                        100.0
                                                                               720   720
                                             720
                                                 259

-------
 EPA UTILITY FGO SURVEY: JULY -  SEPTEMBER  1980
PUBLIC SERVICE OF COLORADO: ARAPAHOE 4  (CONT.)
	PERFORMANCE DATA	.	.._
PERIOD MODULE AVAILABILITY OPERABILITr RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER  F6D   CAP.
                                                                $02  PART. HOURS HOURS  HOURS FACTOR
 5/80  SYSTEM                 100.0                   100.0                  7*4   7*4    744
 6/80  SYSTEM                 100.0                   100.0                  720   720    720
       ** PROBLEMS/SOLUTIONS/COMKENTS
                         BOTH BOILER AND SCRUBBERS OPERATED THE ENTIRE APRIL-JUNE PERIOD.
                         THE ISOLATION DAMPERS ARE STILL EFFECTIVELY. INOPERABLE AND A REPLACEMENT
                         PLAN AS YET HAS NOT BEEN REESTABLISHED.
                         THE UTILITY REPORTED THAT THE REHEATER TUBE LEAK PROBLEM CONTINUED THROUGH
                         THE SECOND  QUARTER.  THE TUBES  WILL BE ENTIRELY REPLACED WITH NEW 316L SS
                         BUNDLES DURING THE  NEXT SCHEDULED OUTAGE IM NOVEMBER AND DECEMBER.  DURING
                         THE SECOND  QUARTER  MORE TUBES WERE  BLANKED OFF AFTER STEAK LEAKS OCCURRED.
                         TO  DATE ROUGHLY SOX OF THE TUBES ARE SEALED OFF AND ARE OUT OF SERVICE
                         BECAUSE OF  LEAKS THAT OCCURRED  OVER THE PAST MONTHS.
7/80 SYSTEM
8/80 SYSTEM
9/80 SYSTEM
100.0
100.0
100.0
10C.O
100.0
100.0
100.0
100.0
100.0
100.0
100.0
100.0
                                                                             7*4
                                                                             7*4
                                                                             720
7*4
744
720
744
744
720
       **  PROBLEMS/SOLUTIONS/COMMENTS
                        THE BOILER  AND  SCRUBBERS  OPERATED ACCEPTABLY DURING THE JULY-SEPTEMBER PER-
                        IOD.   NO  PLANS  HAVE  BEEN  MADE  TO REPAIR THi ISOLATION DAMPERS.  THE FAULTY
                        REHEATER  TUBES  WILL  BE  REPLACED DURING THE SCHEDULED OUTAGE NOW SET FOR THE
                        FIRST  THREE  KEEKS  Of DECEMBER.
                                               260

-------
                                              EPA UTILITY  F6D  SURVEY:  JULY - SEPTEMBER 1980

                                           SECTION U
                  DESIGN  AND  PERFORMANCE DATA FOR OPERATIONAL  PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
CROSS UNIT GENERATING  CAPACITY - HU
NET UNIT  GENERATING  CAPACITY W/SCRUBBER - HU
EQUIVALENT SCRUBBED  CAPACITY - MW

**  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE  NEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - T

**  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL  PROCESS  TYPE
    PH  CONTROL  ADDITIVE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP DATE
    TYPICAL  S02 REMOVAL - X
    PARTICLE DESIGN REMOVAL EFFICIENCY  -  X

**  FABRIC FILTER
    NUMBER
    TYPE

 • *  ESP
     NUMBER

 **  MECHANICAL COLLECTOR
    NUMBER

 ••  PARTICLE SCRUBBER
     NUMBER
     TYPE
PUBLIC SERVICE OF COLORADO
CHEROKEE
1
DENVER
COLORADO
  115.0
  100.0
  102.2
                (  10100 BTU/LB)
COAL
BITUMINOUS
 23493.
   12.50
   11.30
     .65
     .01
WET SCRUBBING
ALKALINE  FLYASH
AIR CORRECTION  DIVISION, UOP
RETROFIT
    4.3
 6/73
• */ «»
  0
 NONE
                                                 MOBILE PACKED TOWER
...... — .......	......	. — PERFORMANCE DATA	•	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  X  REMOVAL    PER  BOILER  FGD   CAP.
                                                                 SO?   PART.  HOURS HOURS  HOURS FACTOR
1/80
2/60
3/80
SYSTEM
SYSTEM
SYSTEM
IOC.
100.
1CC.
c
0
o
100
100
ion
.0
.0
.0
744
696
744
744
696
744
744
696
744
        **  PROBLEMS/SOLUTIONS/COMPENTS

                          THE  SCRUBBERS OPERATED CONTINUOUSLY  THROUGHOUT THE FIRST QUARTER OF  198C.

                          THE  ISOLATION DAMPERS HAVE NOT  CAUSED  ANY PROBLEMS BECAUSE MODULE
                          ISOLATION HAS NOT REQUIRED DURING  THE  PERIOD.

                          THE  FANS ARE STILL EXPERIENCING EROSION PROBLEMS.

                          IN MARCH A BOILER/SCRUBBER OVERHAUL  BEGAN.  DURING THIS TIME THE CARBON
                          STEEL ISOLATION DAMPERS WILL  BE REPLACED WITH 316 SS.  THE NEW  FANS
                          WILL BE INSTALLED IN THE  OLD  HOUSINGS.  THE NEW HIGH STRENGTH  CARBON STEEL
                          FANS WILL BE EQUIPPED tolTH REPLACABLE  CHROMIUM ALLOY WEAR  PLATE BLADE
                          TIPS.
  4/EO  SYSTEM

  5/80  SYSTEM

  6/60  SYSTEM
                               720

                               744

                               720
                                                 261

-------
 EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980

PUBLIC SERVICE OF COLORADO: CHEROKEE  1  UONT.>
	.........	........	——PERFORMANCE DATA———————	—————....
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY UTILIZATION  f REMOVAL   PER  BOILER  FED   CAP.
                                                                 SOZ  PART. HOURS HOURS  HOURS FACTOR


       «* PROBLEMS/SOLUTIONS/COMHENTS

                         THE 1B  10  FAN UAS  SEVERELY  ERRODEO.  THE F*N WAS REBUILT DURING THE OUTAGE.

                         THE OLD CARBON  STEEL  ISOLATION DAMPERS UER8 REPLACED WITH 316 SS DAMPERS
                         DURING THE CONTINUING MAY-JULY OUTAGE.

 7/8C  SYSTEM                                                                 74*

 3/60  SYSTEM                                                                 744

 9/80  SYSTEM                                                                 730

       •* PROBLEMS/SOLUTIONS/COMMENTS

                         SHAFT BEARING FAILURES  ON THE  RECIRCULATION PUMP CAUSED SCRUBBER SYSTEM
                         PROBLEMS THROUGHOUT THE JULY-SEPTEMBER PERIOD.
                                               26Z

-------
                                              EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 14
                 DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL PARTICLE SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING  CAPACITY  -  MU
NET UNIT GENERATING  CAPACITY  U/SCRUBBER  -  MV
EBUIVALENT SCRUBBED  CAPACITY  -  MW

••  FUEL DATA
    FUEL TYPE
    FULL GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  I
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE CONTENT  -  X

• •  GENERAL  EMISSION CONTROL SYSTEM DATA
    GENERAL PROCESS TYPE
    PH  CONTROL  ADDITIVE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION -  X
    INITIAL START-UP DATE
    COMMERCIAL  START-UP  DATE
    TYPICAL  SOZ REMOVAL  - X
    PARTICLE  DESIGN REMOVAL EFFICIENCY - X

**  FABRIC  FILTER
    NUMBER
    TYPE

• *  ESP
    NUMBER

 • «  MECHANICAL COLLECTOR
     NUMBER

 **  PARTICLE SCRUBBER
     NUMBER
     TYPE
                      PUBLIC SERVICE OF COLORADO
                      CHEROKEE
                      4
                      DENVER
                      COLORADO
                        375.0
                        350.0
                        356. 4
                                      (  10100  BTU/LB)
COAL
BITUMINOUS
 23493.
   12. 50
   11.30
      .65
      .01
                      WET  SCRUBBING
                      ALKALINE  FLVASH
                      AIR  CORRECTION  DIVISION, UOP
                      RETROFIT
                           6.7
                        7/74
                      **/**
                      ********
                      ********
                        0
                       NONE
                                                 MOBILE PACKED TOWER
                                                       DATA
PERIOD MODULE AVAILABILITY OPERABILITV  RELIABILITY  UTILIZATION
                                       X REMOVAL    PER   BOILER   FGD   CAP.
                                       SO?  PART.  HOURS  HOURS   HOURS FACTOR
 1/80  SYSTEM

 2/80  SYSTEM

 J/80  SYSTEM

       ** PROBLEMS/SOLUTIONS/COMMENTS
                                                     744

                                                     696

                                                     744
  4/80   SYSTEM

  5/80   SYSTEM

  6/80   SYSTEM
THE OUTLET DUCT WORK IS BEING  REBUILT  INTERNALLY WITH FIBERGLASS FOR
STRUCTURAL SUPPORT AND ACID RESISTANCE.   WITH REGULAR MAINTENANCE THE
UTILITY EXPECTS THIS TO PROVE  TO  BE  A  PERMANENT SOLUTION TO THE EROSION/
CORROSION PROBLEM.

THE OLD FANS ARE BEING REPLACED WITH HIGH STRENGTH CARBON STEEL FANS HAVING
REPLACABLE CHROMIUM ALLOY  WEAR PLATE BLADE TIPS.

                                                     720

                                                     744

                                                     720
                                                 263

-------
 EPA UTILITY FGD  SURVEY:  JULY - SEPTEMBER 1980

PUBLIC SERVICE OF  COLORADO:  CHEROKEE 4 (CONT.)
.	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION
X REMOVAL
SO?  PART.
                                                                              PER  BOILER  FGD    CAP.
                                                                             HOURS HOURS  HOURS  FACTOR
          PROBLEMS/SOLUTIONS/COMMENTS
                          THE  NEW FANS DESCRIBED DURIN6 THE  LAST  REPORT PERIOD HERE INSTALLED IN  ONE
                          OF  THE  FOUR MODULES.  NEW FANS WILL  BE  INSTALLED IN THE OTHER THREE MODULES
                          DURING  A SCHEDULED LATE SEPTEMBER  OUTAGE  UNLESS THE UTILITY HAS AN OPPOR-
                          TUNITY  TO MAKE THE REPLACEMENTS SOONER.
 7/80  SYSTEM
                                                                               7*4
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          THE  SCRUBBER RETURNED TO SERVICE  IN MID  JULY  AFTER A TWO WEEK OUTAGE.
                          DURING  THIS TIME, THE FIBERGLASS  INSIDE  THC DUCTVORK WAS REPLACED, AND  A
                          VERTICAL  GRID WAS INSTALLED ON THE SECOND  LEVEL OF THE MOBILE BED TOUER TO
                          IMPROVE  SYSTEM PERFORMANCE.
 8/80  SYSTEM
 >/80  SYSTEM

       ** PR08LEMS/SOLUTIONS/COMMENTS
                                                                               74*
             720
                         THE  BOILER  AND  FGO SYSTEM WENT DOUN ON  SEPTEMBER  15, 1980 FOR A SCHEDULED
                         OVERHAUL.   CURING THIS TIME, FANS HERE  INSTALLED  ON MODULES A, C, AND 0.

                         THE  UTILITY IS  CURRENTLY EVALUATING THE VERTICAL  GRID ON THE SECOND LATER.
                         IF  THE  GRID IMPROVES SYSTEM PERFORMANCE. THEY  WILL INSTALL ANOTHER ONE
                         ON  THE  THIRD LEVEL.
                                                264

-------
                                              EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER 1980

                                           SECTION U
                  DESIGN  AND  PERFORMANCE OAT* FOR OPERATIONAL  PARTICLE  SCRUBBERS
COMPANY NAME
PLANT  NAME
UNIT NUMBER
CITY
STATE
GROSS  UNIT GENERATING  CAPACITY - MW
NET UNIT  GENERATING  CAPACITY W/SCRUBBER - MW
EQUIVALENT SCRUBBED  CAPACITY - MU
                             PUBLIC  SERVICE
                             VALMONT
                             5
                             VALHONT
                             COLORADO
                               166.0
                               157.0
                               166.0
                                            Of COLORADO
•*  FUEL  DATA
     FUEL  TYPE
     FUEL  GRADE
     AVERAGE  HEAT CONTENT - J/G
     AVERAGE  ASH CONTENT - X
     AVERAGE  MOISTURE CONTENT - t
     AVERAGE  SULFUR CONTENT - X
     AVERAGE  CHLORIDE CONTENT - X

•*  GENERAL EMISSION CONTROL SYSTEM DATA
     GENERAL  PROCESS TYPE
     PH  CONTROL  ADDITIVE
     SYSTEM SUPPLIER
     NEW/RETROFIT
     ENERGY CONSUMPTION - X
     INITIAL START-UP DATE
     COMMERCIAL  START-UP DATE
     TYPICAL S02 REMOVAL - X
     PARTICLE DESIGN REMOVAL EFFICIENCY  -  t

 .*  FABRIC FILTER
     NUMBER
     TYPE
                             COAL
                             SUBBITUMINOUS
                              25121.
                                 6.00
                                15.00
                                  .70
(  1080C BTU/LB)
                             WET SCRUBBING
                             LIMESTONE/ALKALINE FLVASH
                             UOP/PUBLIC SERVICE OF  COLORADO
                             RETROFIT
                                 3.6
                             11/71
                             10/74
                                85.00
                                95.00
                              0
                             NONE
 • * ESP
     NUMBER
     TYPE

 »* MECHANICAL COLLECTOR
     NUMBER
                              1
                             COLD SIDE


                              1
  * PARTICLE SCRUBBER
     NUMBER
     TYPE
                                                 MOBILE PACKED TOWER
— .	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABIL1T1 RELIABILITY UTILIZATION
                                              X REMOVAL   PER  BOILER   FGD    CAP.
                                              S02  PART. HOURS HOURS   HOURS  FACTOR
 1/80  A
       B
       SYSTEM

 Z/BO  A
       B
       SYSTEM
98.5
98.5
98.5

84. *
94.9
89.7
               7*4
                                                                               696
 3/8C
       A
       B
       SYSTEM
90.8
87.7
89.0
                                                                               74*
                                                                                     615
        •«  PROBLEMS/SOLUTIONS/COMMENTS
                          DURING THE FIRST QUARTER OF  1980,  NO MAJOR PROBLEMS HERE ENCOUNTERED  WITH
                          THE SCRUBBER.
        A
        B
        SYSTEM
88.1
88.1
88.1
                                                                                720    716
        *• PROBLEMS/SOLUTIONS/COMMENTS
                          THE SCRUBBER WAS  SHUT  DOWN ON APRIL U FOR A WEEK  TO  MAKE  REPAIRS TO A HOLE
                          IN THE SCRUBBER RUBBER  LINING, RECYCLE PUMP LININGS  AND  A  STEAM REGULATOR
                          ON ONE OF THE REHEATERS.
                                                 265

-------
 EPA UTILITY F6D SURVEY: JULY - SEPTEMBER  1980

PUBLIC SERVICE OF COLORADO: VALMONT 5 (CONT.)
	-PERFORMANCE DATA--	—	-.___.
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY UTILIZATION  t REMOVAL   PER  BOILER  FGD   CAP.
                                                                $02  PART. HOURS HOURS  HOURS FACTOR
5/80


A
B
SYSTEM
96.8
100.0
98.4


7** 74*
       •« PROBLEMS/SOLUTIONS/COMMENTS

                         NO PROBLEMS WERE REPORTED FOR MAY.

 6/80  A            8.0
       B            8.0
       SYSTEM       8.0                                                      720   720

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING JUNE THE SCRUBBER WAS FORCED OUT OF SERVICE WHEN AN INBOARD FAN
                         PEOISTLE  BEARING FAILED.  THE BEARING SECTION WAS REBUILT.

                         WHILE  fAN REPAIRS WERE  IN PROGRESS EXTENSIVE MAINTENANCE WAS PERFORMED ON
                         THE  SCRUBBER.   MAINTENANCE  WORK INCLUDED COMPLETE BALL REPLACEMENT, ADDI-
                         TIONAL REPAIR  WORK  ON  THE SCRUBBER LINER, REPAIR OF HOLES IN THE TOWER
                         SHELL  AND OF A  RUPTURED MIST ELIMINATOR WASH LINE AND THE REHEATER WAS
                         CLEANED.

                         DAMPER JAMMING  AT VALMONT HAS OCCURRED  PERIODICALLY.  SOMETIMES DAMPERS 00
                         NOT  READILY CLOSE.   THE OPERATOR MUST MOVE THE  DAMPER UP AND DOWN UNTIL THE
                         GUILLOTINE  SEATS.  BECAUSE  OF CONTINUOUS FLY ASH ACCUMULATION IT APPEARS
                         THAT THE  DAMPERS MUST  BE EXERCISED FREOUEN.TLY TO PREVENT JAMMING.

 7/80  5A                       4g.3                     46.6
       SB                       48.3                     46.6
       SYSTEM                   48.3                     *6.6                  744   719    347

       **  PROBLEMS/SOLUTIONS/COMMENTS

                         THE  SCRUBBER SYSTEM WAS SHUT DOWN BECAUSE OF SCRUBBER BOOSTER FAN
                         BEARING FAILURE.

 8/80  5A                       87.5                     84.8
       58                       95.6                     92.6
       SYSTEM                   91.5                     87.7                  7*4   721    660

       •*  PROBLEMS/SOLUTIONS/COMMENTS

                         THE  RECIRCULATION PUMP  MOTOR BEARING  FAILED CAUSING SOME MINOR OUTAGE
                         TIME IN AUGUST.

 9/80  SYSTEM                                             .0                  720     0      0

       •*  PROBLEMS/SOLUTIONS/COMMENTS

                         THE  BOILER  AND  SCRUBBER WERE SHUT OOVN  DURING SEPTEMBER FOR  SCHEDULED
                         MAINTENANCE.
                                               266

-------
                                              EPA UTILITY F€0 SURVEY: JUtY -  SEPTEMBER  1980

                                           SECTION U
                 DESIGN  AND  PERFORMANCE DAT* FOR OPERATIONAL PARTICLE  SCRUBBERS
COMPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING  CAPACITY  - HU
NET UNIT  GENERATING  CAPACITY  W/SCRUBBER - MW
EQUIVALENT SCRUBBED  CAPACITY  -  *W

»*  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE HEAT  CONTENT - J/G
    AVERAGE ASH CONTENT  - X
    AVERAGE MOISTURE CONTENT  -  X
    AVERAGE SULFUR CONTENT -  X
    AVERAGE CHLORIDE CONTENT  -  X

••  GENERAL  EMISSION  CONTROL SYSTEM DATA
    GENERAL PROCESS  TYPE
    PH  CONTROL  ADDITIVE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP  DATE
    TYPICAL  SOE  REMOVAL  - X
    PARTICLE  DESIGN  REMOVAL EFFICIENCY - %

• •  ESP
     NUMBER
     TYPE

 • *  PARTICLE SCRUBBER
     NUMBER
     TYPE
                                              SOUTHWESTERN  PUBLIC  SERVICE
                                              HARRINGTON
                                              1
                                              AMARILLO
                                              TEXAS
                                                 360.0
                                                 320.0
                                                 360.0
                                               COAL
                                               SUBBITUMINOUS
                                                19538.
                                                   5.00
                                                  27.10
                                                    .42
(  8400 6TU/LB)
                                               UET  SCRUBBING
                                               LIMESTONE
                                               COMBUSTION ENGINEERING
                                               NEW
                                                4/77
                                               **/ **
                                                  50.00
                                                  99.00
                                               COLD SIDE
                                                 MOBILE  PACKED TOWER
.	.........	.................—.......pERfORMANCE DATA——
PERIOD NODULE AVAILABILITY OPERABILITV  RELIABILITY  UTILIZATION
                                                               X REMOVAL    PER   BOILER  fGD   CAP.
                                                               S02   PART.  HOURS  HOURS  HOURS FACTOR
10/79  SYSTEM                                                                 744

11/79  SYSTEM                                                                 720

12/79  SYSTEM                                                                 744

       *• PROBLEMS/SOLUTIONS/COMMENTS

                          DURING  OCTOBER  THROUGH DECEMBER, TUO SPRAY PUMP MOTORS  FAILED.

                          THE  FRP FLUSH PIPING HAS FAILED CAUSING SOME LEAKING.

                          PLUGGING IN ONE MARBLE BED WAS ENCOUNTERED WHEN THE CHEMISTRY  CONTROL U*S
                          TEMPORARILY LOST.

                          THE  CONE SHAPED EXPANDED METAL (316L SS) SCREENS  COVERING  THE  BED DRAIN
                          PIPES HAVE  ERODED AWAY FROM BALL MOVEMENT.   THE MARBLE  BALLS HAVE BEEN
                          DROPPING INTO THE RECYCLE TANK.  WHERE THE UTILITY  HAS  REPLACED THE METAL
                          SCREEN WITH EXPANDED PLASTIC SCREEN, EROSION HAS  NOT  OCCURRED.

                                                                               744

                                                                               696
1/80  SYSTEM

2/80  SYSTEM
  3/80   SYSTEM

        •*  PROBLENS/SOLUTIONS/COMPENTS
                                                                             744
                          DURING THE FIRST QUARTER  OF  1980 THE MIST ELIMINATOR WASH PIPING RUPTURED
                          CAUSING PLUGGING IN SCRUBBERS  4  AND 5.  THE UTILITY PLANS TO REPLACE
                          ALL FRP PIPING WITH STEEL.   THE  RUPTURE ON NO. 5 ALSO DAMAGED THE MATER
                          SUPPLY HEADER.
                                                 267

-------
 EPA UTILITT  F6D SURVEY:  JULY - SEPTEMBER 1980

SOUTHWESTERN  PUBLIC  SERVICE:  HARRINGTON 1 (CONT.)
	PERFORMANCE  DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION
                                        X  REMOVAL    PER   BOILER  FGD   CAP.
                                        SO?   PART.  HOURS  HOURS  HOURS FACTOR
                          THE  WARBLE  BED PLUGGING REPORTED  DURING THE  LAST QUARTER IS NOT YET
                          COMPLETELY  CLEARED.  THE SOFT SCALE  IS  GRADUALLY GOING BACK INTO THE
                          SOLUTION.   THF PLATE AREA  IS CLEAN.

                          THE  DUCT BENEATH THE REHEATEK TUBING ON ONE  OF  THE MODULES HAS CORRODED TO
                          THE  POINT  THAT HOLES HAVE  FORMED.   SCALE  AND MOISTURE WERE FOUND ON THE
                          PLATE  WHERE THE CORROSION  FORMED.   THE  PLATE WAS REMOVED AND A NEW CARBON
                          STEEL  PLATE yAS WELDED IN.  NO OTHER REHEATER DUCTS HAVE EXPERIENCED ANY
                          SCALE  OR MOISTURE ACCUMULATION.
       SYSTEM
       «* PROBLcMS/SOLUTIONS/COMPIENTS
                          A  PUMP  LINER FAILURE OCCURRED IN APRIL.
                          PAIRED  AND REPLACED.
 s/e:
       SYSTEM
                                                                               720
                                          THE IMPELLER  SHAFT LINER WAS RE-
                                                                               7(4
          PROBLEMS/SOLUTIONS/COMMENTS
                          THE  BOILER  WAS SHUT DOWN A F£W DAYS  IN  LATE  APRIL AND 12 TO U DAYS  IN
                          EARLY  MAY  FOR AIR PREHEATER REPAIRS.

                          DURING APRIL AND MAY THE SCRUBBING SYSTEM  EXPERIENCED AGITATOR PROBLEMS.
                          THE  RECENT  PROBLEMS HAVE BEEN RELATED  TO BEARING FAILURE. HOWEVER, THE
                          SEALS  HAVE  BEEN LEAKING AS WELL.  THE  AGITATORS AT THIS FACILITY ARE SIDE
                          MOUNTED.   THE AGITATOR SHAFT ENTERS  THE TANK  AT ROUGHLY 12 FT BELOW  THE
                          FLUID  SURFACE.  IT APPEARS THAT THE  SEAL LEAKING MAY BE ATTRIBUTABLE TO
                          FAULTY INSTALLATION.
 6/80  SYSTEM      92.1

       *» PROBLEMS/SOLUTIONS/COMMENTS
                                                                               720
                                                                                     696
                                                                        79.3
 7/80  SYSTEM

 8/80  SYSTEM

 9/8P  SYSTEM
DURING JUNE THE SCRUBBER  EXHIBITED AN AVAILABILITY  OF  92.U.  THERE WAS
GREATER SCRUBBED  CAPACITY AVAILABLE THAN REQUIRED BY  THE  BOILER.  NO
PROBLEMS WERE  REPORTED  FOR JUNE.

DAMPER PROBLEMS REPORTED  PREVIOUSLY HAVE PEEN ELIMINATED.   THE OLD OPERATOR
MECHANISMS WERE REPLACED  WITH OPERATORS SUPPLIED BY ANOTHER MANUFACTURER.

ONE OF THE MARBLE  BEDS  IS STILL PARTIALLY PLUGGED.  THE MATERIAL SEEMS TO
BE HARD CALCIUM SULFATE  SCALE.  THE SCALE WILL PROBABLY NOT CLEAR FURTHER
THROUGH DISSOLUTION  DURING NORMAL SCRUBBER OPERATIONS  AS  HAD BEEN HOPED.
ALTHOUGH THE MODULE  MUST  OPERATE AT LOWER 1HAN DESIGN  GAS  FLOW SCRUBBER
OPERATIONS ARE NOT HAMPERED OVERALL BECAUSE THE SYSTEM HAS  SOME DESIGN
SPARE CAPACITY.

THE REHEATER PROBLEM REPORTED PREVIOUSLY HAS OCCURRED  ON  THREE REHEATERS
NOW.  THE FAILURE  OF THE  REHEATER DUCT BOTITOM PANELS  KAY  BE A RESULT OF AN
UNDERSIZED DEFLECTION  SHIELD BENEATH THE TUBE BANKS.   IT  IS ALSO POSSIBLE
THAT THF DUCTING  WAS IMPROPERLY WELDED.

                                                     744

                                                     744

                                                     720
          PROBLEMS/SOLUTIONS/COMMENTS
                         THE UTILITY  REPORTED THAT NO MAJOR SCRUBBING  SYSTEM PROBLEMS OCCURRED
                         DURING  THE  THIRD  QUARTER 1980.

                         THE PROBLEM  REPORTED EARLIER WITH THE  HIST  ELIMINATOR WASH PIPING IS
                         PRESENTLY BEING SOLVED BY REPLACING THE  PIPING  WITH CARBON STEEL.
                                                268

-------
                                              EPA  UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

                                           SECTION IS
               DESIGN AND PERFORMANCE  DATA  FOR  OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAHE
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING  CAPACITY  -  MU
NET UNIT GENERATING CAPACITY  W/FGD  - My
EQUIVALENT SCRUBBED CAPACITY  -  Mw

*•  FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT  - X
    AVERAGE MOISTURE  CONTENT  -  X
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE  CONTENT  -  X

•*  F6D  SYSTEM
    GENERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
     INITIAL START-UP  DATE
     COMMERCIAL  START-UP DATE
     $02 DESIGN  REMOVAL EFFICIENCY - X
     PARTICULATE  DESIGN REMOVAL EFFICIENCY
     ABSORBER  SPARE COMPONENTS INDEX

**  WATER  LOOP
     TYPE
     FRESH  MIKE-UP WATER - LITER/S

 •«  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
     CHU60KU  ELECTRIC
     SHIMONOSEKI
     1
     SHIMONOSEKI
     JAPAN
       175.0
       175.0
       175.0
- X
                    ( 10768 BTU/LB)
COAL
******
 25046.
   24.60
    2.30
     .59
     .04
     WET SCRUBBING
     LIMESTONE
     MITSUBISHI HEAVY INDUSTRIES
     RETROFIT
 5/79
 7/79
   85.00

      .0
     OPEN
         6.8
     GYPSUM
                     (   108  6PM)
...	—	........	.	PERFORMANCE DATA	—	—	
PERIOD MODULE AVAILABILITY OPERAPILITT  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   F6D   CAP.
                                                                 S02  PART. HOURS HOURS   HOURS FACTOR
1/80
2/80
SYSTEM
SYSTEM
100.0
55.2
100
100
.0
.0
10C
55
.0
.2
100
55
.0
.2
744
696
744
384
744
384
       ** PROBLEMS/SOLUTIONS/COMMENTS
                          DURING  JANUARY AND THE FIRST HALF OF  FEBRUARY  THE  F6D UNIT OPERATED WITH
                          NO  PROBLEMS.   THE BOILER WAS TAKEN OFF-LIN6  ON  FEBRUARY 8 FOR SCHEDULED
                          MAINTENANCE.
                                                           .0
                                                                               744
 J/80   SYSTEM      100.0

        **  PROBLEMS/SOLUTIONS/COMMENTS

                          THE BOILER REMAINED DOWN THROUGH MARCH  FOR  ANNUAL MAINTENANCE.
 4/80   SYSTEM      100.0       100.0

        **  PROBLEMS/SOLUTIONS/COHMENTS
10C.O
        83.1
                               720   598
S98
                          DURING THE ANNUAL MAINTENANCE  THE  SCR (SELECTIVE CATALYTIC REDUCTION  OF
                          NOX) UNIT WAS CONNECTED  BETWEEN  THE BOILER AND AIR PREHEATER.   AFTER  THE
                          STARTUP ON APRIL 6, COAL ONLY  HAS  BEEN USED (BEFORE FEBRUARY,  COAL  AND
                          OIL WERE USED 50:50).   EXCEPT  FOR  A 2 HOUR SHUTDOWN FOR A  TURBINE TEST  ON
                          APRIL 7, THE FGD SYSTEM  HAS  OPERATED CONTINUOUSLY WITH NO  PROBLEMS.
  5/80   SYSTEM
                   100.0
                               100.0
                                            100.0
                                                         90.3
                                                                               744    672
                                                                                             672
                                                 269

-------
 EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980

CMUGOKU ELECTRIC: SHIMONOSEKI  1  (CONT.)
......	....	.......	.—.—-PERFORMANCE DATA	.....	_	
PERIOD NODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F60   CAP.
                                                                 SO?  PART. HOURS HOURS  HOURS FACTOR


       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM  OPERATED  CONTINOUSLV WITH NO PROBLEMS.  A THREE DAY
                         SHUTDOWN FOR INSPECTION  OF  THE  SCR  UNIT FROM HAY 16 TO MAY 19 HAS THE
                         ONLY DOWN TIME  EXPERIENCED  DURING MAY.

 6/80  SYSTEM     100.0       100.0        100.0        100.0                  720   720    720

       *• PROBLEMS/SOLUTIONS/COMPENTS

                         THE FGD SYSTEM  OPERATED  CONTINOUSLV WITH NO PROBLEMS DURING JUNE.

 7/80  SYSTEM                                                                 744

 8/80  SYSTEM                                                                 744

 »/80  SYSTEM                                                                 720

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE THIRD QUARTER UPDATE INFORMATION IS NOiT VET AVAILABLE.
                                               270

-------
                                              EPA UTILITY FGD SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 15
               DESIGN  AND  PERFORMANCE  DATA FOR  OPERATIONAL FOREICN FED SYSTEMS
 COMPANY NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 GROSS  UNIT GENERATING  CAPACITY  -  My
 NET UNIT  GENERATING  CAPACITY  U/FGD  - MU
 EQUIVALENT SCRUBBED  CAPACITY  -  MU

 • *  FUEL DATA
    FUEL  TYPE
    FUEL  GRADE
    AVERAGE  HEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT  - X
    AVERAGE  MOISTURE CONTENT  -  X
    AVERAGE  SULFUR  CONTENT -  X
    AVERAGE  CHLORIDE CONTENT  -  X

 ••  FGO SYSTEM
    GENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP HATE
    COMMERCIAL  START-UP  DATE
    S02  DESIGN  REMOVAL EFFICIENCY - X
    PARTICULAR DESIGN REMOVAL  EFFICIENCY
    ABSORBER SPARE  COMPONENTS INDEX

 ••  WATER  LOOP
    TYPE
     FRESH MAKE-UP WATER  - LITER/S

 ••  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
                             ELECTRIC POWER DEVELOPMENT CO
                             ISOGO
                             1
                             YOKOHAMA
                             JAPAN
                               265.0
                               238.0
                               265.0
                        - X
                             COAL
                             *** **•
                              25956.
                                16.00
                                 7.00
                                  .60
WET SCRUBBING
LIMESTONE
IHI - CMEMICO
RETROFIT
*** **•*
12/75
 3/76
   90.00
   96.70
     .0
                             OPEN
                                 22.3
                              GYPSUM
                              MARKETED
               ( 11160 BTU/LB)
                                             <   354  6PM)
_.._...__..—..—.——.._——-_„—... PERFORMANCE  DATA-———————	
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X REMOVAL   PER  BOILER  F6D   CAP.
                                                                 S02   PART. HOURS HOURS  HOURS FACTOR
 4/79  SYSTEM

 5/79  SYSTEM

 5/79  SYSTEM

 7/79  SYSTEM

 ft/79  SYSTEM

 »/79  SYSTEM

ID/79  SYSTEM

11/79  SYSTEM

12/79  SYSTEM

 1/80  SYSTEM

 2/80  SYSTEM

 5/80  SYSTEM

       **  PROBLEMS/SOLUTIONS/COMMENTS
                                                           720

                                                           7*4

                                                           720

                                                           744

                                                           744

                                                           720

                                                           744

                                                           720

                                                           744

                                                           744

                                                           696

                                                           744
  4/80   SYSTEM
       NO INFORMATION WAS AVAILABLE FOR THE APRIL  1979  THROUGH  MARCH 1980 PERIOD.

100.0       10C.O       100.0       100.0                   720    720    720
                                                271

-------
 EPA UTILITY FGD SURVEY:  JULY  - SEPTEMBER 198C

ELECTRIC POWER DEVELOPMENT  CO:  ISOSO 1 (CONT.)
	.	PERFORMANCE DATA	—	
PERIOD MODULE AVAILABILITY  OPERABILITY RELIABILITY UTILIZATION   *  REMOVAL   PER  BOILER  FGD   CAP.
                                                                  S02   PART. HOURS HOURS  HOURS FACTOR
       ** PROBLEMS/SOLUTIONS/COMMENTS
 5/8P
 ft/en
 7/80

 8/80

 9/80
                          THE  FGD  SYSTEM OPERATED ALONG WITH  THE BOILER  FOR THE ENTIRE MONTH OF
                          APRIL.
SYSTEM     100.0        100.0        100.0

SYSTEM     100.0        100.0        10C.O

»* PROBLE*S/SOLUTIONS/COMI«£NTS
51.6

13.3
744

720
384

 96
384

 96
                  THE BOILER  WAS  SHUT DOWN FROM MAY 17 TO JUNE  27  FOR  ANNUAL MAINTEN-
                  ANCE.   THE  FGD  SYSTEM WAS OPERATED DURING ALL OF  THE  BOILER OPERATION
                  IN MAY  AND  JUNE.

SYSTEM                                                                  744

SYSTEM                                                                  744

SYSTEM                                                                  720

** PROBLEMS/SOLUTIONS/COMMENTS

                  THE THIRD QUARTER  UPDATE INFORMATION IS NOT YET  AVAILABLE.
                                                272

-------
                                              EPA UTILITY  F6D  SURVEY:  JULY - SEPTEMBER 1960
                                           SECTION 15
                DESIGN  AMD  PERFORMANCE DATA FOR OPERATIONAL  FOREIGN  FGD  SYSTEMS
 COMPANY  NAME
 PLANT  NAME
 UNIT NUMBER
 CITY
 STATE
 SROSS  UNIT GENERATING CAPACITY - MM
 NET UNIT GENERATING CAPACITY W/FGD - My
 EBUIVALENT SCRUBBED CAPACITY - MW

 •*  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE  HEAT  CONTENT - J/G
    AVERAGE  ASH CONTENT - X
    AVERAGE  MOISTURE CONTENT - *
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT - X

 •*  FSO SYSTEM
    GENERAL  PROCESS TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEri/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP BATE
    COMMERCIAL START-UP DATE
    S02  DESIGN REMOVAL EFFICIENCY  - X
    PARTICULATE DESIGN REMOVAL EFFICIENCY
    ABSORBER SPIRE COMPONENTS INDEX

 • *  WATER LOOP
     TYPE
     FRESH MAKE-UP  WATER - LITER/S

 ••  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
ELECTRIC POWER DEVELOPMENT  CO
I SO GO
2
YOKOHAMA
JAPAN
  265.0
  238.0
  265.0
COAL

 25958.
   16.00
    7.00
     .60
*** *****
{  11160 BTU/LFI)
WET SCRUBBING
LIMESTONE
IHI - CHENICO
RETROFIT
    3.C
 3/76
 5/76
   90.00
   96.70
      .0
OPEN
    22.3
 GYPSUM
 MARKETED
(  554 GPM)
	PERFORMANCE DATA	.	
PERIOD MODULE AVAILABILITY  OPERAPILITY  RELIABILITY UTILIZATION  i  REMOVAL    PER   BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS HOURS  HOURS FACTOR


 4/79  SYSTEM                                                                  7?0

 5/79  SYSTEM                                                                  744

 i/79  SYSTE"                                                                  720

 7/79  SYSTEM                                                                  744

 3/79  SYSTEM                                                                  744

 9/79  SYSTEM                                                                  720

ID/79  SYSTEM                                                                  744

11/79  SYSTEM                                                                  720

12/70  SYSTEM                                                                  744

 1/80  SYSTEM                                                                  744

 2/80  SYSTEM                                                                  696

 3/60  SYSTEM                                                                  744

       **  PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION WAS  AVAILABLE  FOR THE APRIL 1979 THROUGH  MARCH  1980 PERIOD.

 4/80  SYSTEM      100.0       100.0        1CO.O         33.3                  720    240     240
                                                 273

-------
 EPA UTILITY F6D SURVEY: JULY  -  SEPTEMBER  1980

ELECTRIC POWER DEVELOPMENT CO: ISOGO  2  
-------
                                              EPA  UTILITY F6D SURVEY: JULY - SEPTEMBER 1980

                                           SECTION 15
               DESIGN AND PERFORMANCE  DATA FOR  OPERATIONAL FOREIGN FGD SYSTEMS
COMPANY NAME
PLANT NAflE
UNIT NUMBER
CITY
STATE
GROSS UNIT GENERATING CAPACITY  -  MW
NET UNIT GENERATING  CAPACITY  V/F6D -  MU
EQUIVALENT SCRUBBED  CAPACITY  -  MU

**  FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT  -  J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE  CONTENT  -  X
    AVERAGE SULFUR  CONTENT  -  X
    AVERAGE CHLORIDE  CONTENT  -  X

**  FGD  SYSTEM
    GENERAL PROCESS  TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION  -  X
    INITIAL STABT-UP DATE
    COMMERCIAL  START-UP DATE
    S02 DESIGN  REMOVAL  EFFICIENCY - X
    PARTICULATE  DESIGN  REMOVAL  EFFICIENCY
    ABSORBER  SPARF  COMPONENTS INDEX

 »*  WATER  LOOP
    TYPE
     FRESH  MAKE-UP WATER  - LITER/S

 **  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
- X
     ELECTRIC  POWER  DEVELOPMENT CO
     TAKASAGO
     1
     TAKASAGO
     JAPAN
       250.0
       230.0
       250.0
     COAL
     ******
      25958.
        22.00
         7.00
         1.80
     ********
     WET SCRUBBING
     LIMESTONE
     MITSUI - CHEMICO
     RETROFIT
         3.2
      2/75
     **/ **
        93.00
( 11,160 BTU/LB)
          .0
     OPEN
        13.1
     GYPSUM
(  208 GPM)
                                                       DATA ------ - --- - -------------------------------
PERIOD NODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION   X REMOVAL   PER  BOILER  FGD   CAP.
                                                                 S02  PART. HOURS HOURS  HOURS FACTOR
 t/79  SYSTEM                                                                 720

 6/79  SYSTEM                                                                 720

 7/79  SYSTEM                                                                 74<,

 S/79  SYSTEM                                                                 744

 9/79  SYSTEM                                                                 720

13/79  SYSTEM                                                                 744

11/79  SYSTEM                                                                 720

12/79  SYSTEM                                                                 744

 1/80  SYSTEM                                                                 744

 Z/80  SYSTEM                                                                 696

 J/80  SYSTEM                                                                 744

       **  PROBLEMS/SOLUTIONS/COMMENTS

                          NO INFORMATION WAS AVAILABLE FOR THE APRIL  1979  THROUGH  MARCH 1980 PERIOD.

 4/80  SYSTEM      100.0       10?. 0       100.?        30.0                   720    216    216
                                                 275

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 EPA UTILITY FGD SURVEY: JULY  -  SEPTEMBER  1980

ELECTRIC POWER DEVELOPMENT CO: TAKASAGO  1  (COST.)
	_	PERFORMANCE DATA	——	
PERIOD NODULE AVAILABILITY OPERABIL1TY  RELIABILITY UTILIZATION  X REMOVAL   PER  BOILER   FGD    CAP.
                                                                 S02  PART. HOURS HOURS   HOURS  FACTOR


       ** PROBLE«IS/SOLUTIONS/COM«ENTS

                         THE BOILER  WAS  SHUTDOWN ON MARCH 29 FOR ANNUAL MAINTENANCE.  THE UNIT
                         REMAINED  OFF LINE  THROUGH APRIL 21.  WHEN OPERATIONS COMMENCED  THE FGD
                         SYSTEM OPERATED WITH  THE BOILER FOR THE REST OF THE MONTH.

 5/80  SYSTEM     100.0       100.0        100.0        100.0                  744    744    744

 6/80  SYSTEM     100.0       100.0        100.0        100.0                  720    720    720

       «* PROBLEHS/SOLUTIONS/COMMENTS

                         THE FGD SYSTEM  EXPERIENCED NO PROBLEMS DURING THE HAY-JUNE PERIOD.

 7/80  SYSTEM                                                                 744

 S/80  SYSTEM                                                                 744

 9/80  SYSTEM                                                                 720

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         THE THIRD QUARTER  UPDATE INFORMATION IS NOJ YET AVAILABLE.
                                               276

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                                              EPA UTILITY  FGD  SURVEY:  JULY - SEPTEMBER  1980

                                           SECTION 15
               DESIGN AND  PERFORMANCE  DATA FOR OPERATIONAL  FOREIGN FGD SYSTEMS
COBPANY NAME
PLANT NAME
UNIT NUMBER
CITY
STATE
6ROSS UNIT GENERATING  CAPACITY  - fW
MET UNIT GENERATING  CAPACITY  W/FGD - My
EBUIVALENT SCRUBBED  CAPACITY  -  MU

»* FUEL DATA
    FUEL TYPE
    FUEL GRADE
    AVERAGE HEAT  CONTENT - J/G
    AVERAGE ASH CONTENT - X
    AVERAGE MOISTURE CONTENT  -  *
    AVERAGE SULFUR CONTENT - X
    AVERAGE CHLORIDE CONTENT  -  T

**  F6D  SYSTEM
    SENERAL PROCESS TYPE
    PROCESS TYPE
    SYSTEM  SUPPLIER
     NEW/RETROFIT
     ENERGY  CONSUMPTION - X
     INITIAL  START-UP DATE
     COMMERCIAL  START-UP DATE
     S02 DESIGN  REMOVAL EFFICIENCY  - X
     PARTICULATE DESIGN REMOVAL  EFFICIENCY
     ABSORBER  SPARE  COMPONENTS  INDEX

 ••  WATER  LOOP
     TYPE
     FRESH  MAKE-UP WATER  -  LITER/S

 ••  BYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
- X
    ELECTRIC  POWER DEVELOPMENT CO
    TAKASAGO
    z
    TAKASAGO
    JAPAN
       Z50.0
       230.0
       250.0
     COAL
     ******
      25958.
        22.00
         7.00
         1.80
     WET SCRUPBING
     LIMESTONE
     MITSUI - CHEMICO
     RETROFIT
         3.2
      3/76
     **/ **
        93.PO
( 11160 BTU/LB)
          .0
     OPEN
         17.1
     GYPSUM
 (  208  GPM)
	PERFORMANCE  DATA	---
PERIOD MODULE AVAILABILITY  OPERARILITY RELIABILITY  UTILIZATION  X REMOVAL   PER   BOILER  FGD   CAP.
                                                                  SO?  PART. HOURS  HOURS  HOURS FACTOR


 4/79  SYSTE"                                                                   720

 5/79  SYSTEM                                                                   74*

 5/79  SYSTE"                                                                   720

 7/79  SYSTEM                                                                   744

 S/79  SYSTEM                                                                   744

 ?/79  SYSTEM                                                                   720

13/79  SYSTEM                                                                   744

11/79  SYSTEM                                                                   720

12/79  SYSTEM                                                                   744

 1/8T  SYSTEM                                                                   744

 2/80  SYSTEM                                                                   696

  3/bC   SYSTE"                                                                   744

        •* PROBLEMS/SOLUTIONS/COWENTS

                          NO  INFORMATION WAS AVAILABLE  FOR  THE APRIL 1979 THROUGH MARCH 1980 PERIOD.

  4/80  SYSTEM      100.fi        100.0       1CC.O        100.0                  720   720    720
                                                  277

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 EPA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

ELECTRIC POWER DEVELOPMENT CO: TAKASA60  2  (CONT.)
	PERFORMANCE  DATA	--—--—__
PERIOD MODULE AVAILABILITY OPERABILITV RELIABILITY  UTILIZATION   X  REMOVAL    PER   BOILER  F6D   CAP.
                                                                 SO?   PART.  HOURS  HOURS  HOURS FACTOR


 5/80  SYSTEM     100.0       10C.O       100.0        100.0                   744    744    744

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         DURING APRIL AND MAY THE UTILITY  EXPERIENCED  NO PROBLEMS WITH THE FGft
                         SYSTEM.

 6/80  SYSTEM     100.0       100.0       100.0          4.4                   7?0     32     32

       •• PROBLEMS/SOLUTIONS/COMMENTS

                         THE BOILER WAS SHUTDOWN FROM  JUNE 3  TO  JUNE  24  FOR  ANNUAL MAINTENANCE.
                         THE FGD SYSTEM OPERATED ALONG  WITH  THE  BOILER  THE  REMAINDER  OF THE TIME.

 7/80  SYSTEM                                                                 744

 9/BO  SYSTEM                                                                 744

 9/8C  SYSTEM                                                                 720

       *» PROBLtMS/SOLUTIONS/COMMENTS

                         THE THIRD QUARTER UPDATE INFORMATION IS NOT  YET AVAILABLE.
                                               278

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                                              6PA UTILITY FGD SURVEY: JULY - SEPTEMBER  1980

                                           SECTION 15
               DESIGN  AND  PERFORMANCE  DATA FOR  OPERATIONAL FOREIGN FGD SYSTEMS
 COMPANY  NAME
 PLANT  NINE
 JNIT NUM9ER
 CITY
 STATE
 6ROSS  UNIT GENERATING  CAPACITY  - M*
 MET UNIT GENERATING  CAPACITY W/FGD - "U
 EQUIVALENT SCRUBBED  CAPACITY -  My

 *•  FUEL  DATA
    FUEL TYPE
    FUEL GRADE
    HVESAGE  HEAT CONTENT - J/G
    AVERAGE  ASH CONTENT - I
    AVERAGE  MOISTURE CONTENT -  X
    AVERAGE  SULFUR CONTENT - X
    AVERAGE  CHLORIDE CONTENT -  X

 **  F&D SYSTEM
    GENERAL  PROCESS  TYPE
    PROCESS  TYPE
    SYSTEM  SUPPLIER
    NEW/RETROFIT
    ENERGY  CONSUMPTION - X
    INITIAL  START-UP DATE
    COMMERCIAL  START-UP DATE
     S02 DESIGN  REMOVAL EFFICIENCY  - %
    PARTICULATE DESIGN REMOVAL EFFICIENCY
    ABSORBER SPARE COMPONENTS INDEX

 «*  WATER LOOP
     TYPE
     FRESH MAKE-UP WATER -  LITER/S

 **  PYPRODUCT
     BYPRODUCT NATURE
     DISPOSITION
                             ELECTRIC POWER DEVELOPMENT CO
                             TAKEHARA
                             1
                             MIHARA
                             JAPAN
                               Z50.0
                               231.0
                               250.0
                        - X
                             COAL
                             ******
                              25130.
                                23.00
                                 9.05
                                 2.00
                                  .05
WET SCRUBBING
LIMESTONE
BABCOCK - HITACHI
RETROFIT
    3.2
 2/77
 2/79
   94.20
   91.70
     .0
               ( 10804 BTU/LB)
                             OPEH
                                 U.9
                              6YPSUH
                              MARKETED
                (   237  6PM)
__	—	—	——PERFORMANCE  DATA—-—-————-.—.__..—.—.—...—
PERIOD MODULE AVAILABILITY OPERABILITY RELIABILITY  UTILIZATION  X REMOVAL   PER  BOILER  F60   CAP.
                                                                 SOJ  PART. HOURS HOURS  HOURS FACTOR
       SYSTEM

 5/79  SYSTEM

 J/79  SYSTEM

 7/79  SYSTEM

 B/79  SYSTEM

 9/79  SYSTEM

10/79  SYSTEM

11/79  SYSTEM

12/79  SYSTEM

 1/80  SYSTEM

 2/80  SYSTEM

 J/8P  SYSTEM

       **  PROBLEMS/SOLUTIONS/COMMENTS
                                                           720

                                                           7*4

                                                           720

                                                           744

                                                           744

                                                           720

                                                           744

                                                           720

                                                           744

                                                           744

                                                           696

                                                           744
  4/80  SYSTEM
       NO INFORMATION WAS AVAILABLE  FOR  THE  APRIL  1979 THROUGH MARCH 1980 PERIOD.

100.0       100.0       100.0        100.0                   720   720    720
                                                 279

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 EPA UTILITY FGD SURVEY:  JULY  - SEPTEMBER 19?0

ELECTRIC POWER DEVELOPMENT  CO:  TAKEHARA 1 (CONT.)
	PERFORMANCE DATA	
PERIOD MODULE AVAILABILITY  OPERABILITY  RELIABILITY UTILIZATION  t REMOVAL    PER   BOILER  FGD   CAP.
                                                                 S02   PART.  HOURS  HOURS  HOURS FACTOR
5/e?
6/80
SYSTEM
SYSTEM
100.0
100.0
IOC
100
.0
.0
100.
100.
0
0
100
100
.0
.0
744
720
744
720
744
720
       ** PROBLEMS/SOLUTIONS/COMKENTS

                         DURING  THE  APRIL,  MAY AND JUNE PERIOD THE FGD  SYSTEM  OPERATED  CONTINUOUSLY
                         WITHOUT  APPRECIABLE TROUBLE.

 7/80  SYSTEM                                                                  744

 3/8C  SYSTEM                                                                  744

 J/80  SYSTEM                                                                  720

       ** PROBLEMS/SOLUTIONS/COMMENTS

                         THE  THIRD  QUARTER  UPDATE INFORMATION IS NOT  VET  AVAILABLE.
                                                280

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                         APPENDIX A




FGD SYSTEM COST DATA:   OPERATIONAL AND NONOPERATIONAL SYSTEMS
                             A-l

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                          INTRODUCTION

     The cost of flue gas desulfurization  (FGD) systems for the
control of sulfur dioxide emissions is an area of intense inter-
est and substantial controversy.  As a result, many computer
models have recently been developed to estimate capital and
annual costs.  As part of an effort by the U.S. Environmental
Protection Agency to provide meaningful economic data concerning
FGD systems, reported economic data have been incorporated into
the EPA Utility FGD Survey report.  This information has appeared
as a separate appendix of the report since October 1976.  Until
January 1978, this cost appendix consisted entirely of data
reported by the utilities with little or no interpretation pro-
vided by PEDCo Environmental, Inc.  Beginning with the May 1978
report, the format and content of the cost appendix were revised
to include reported and adjusted costs for the operational FGD
systems.
     The rationale for including adjusted as well as reported
costs stems primarily from the lack of comparability of the
reported costs.  Many of the reported cost figures, both capital
and operating, are largely site-sensitive values that cannot be
accurately compared because they refer to different FGD battery
limits and different years in which the expenditures were made.
As a result, an analysis of the cost data was made for the opera-
tional units since these systems offer the potential of having
complete and accurate economic data.  The adjustments were made
to provide comparable, accurate cost data for the sulfur dioxide
portion of the emission control system.  This, in effect, will
eliminate much of the confusion that exists concerning the re-
ported data, and it will provide a common basis for the reported
costs.

                               A-2

-------
     In an attempt to promote further comparability of the
figures, the adjustment procedure was carried one step further
and standardized adjusted figures were developed.  This was done
by modifying the fixed annual cost rates such that they would be
identical for each unit (i.e. cost of depreciation, interim re-
placement, taxes, insurance and capital costs).   The newly ad-
justed total fixed annual cost rate was applied to the total ad-
justed capital cost in each case and a standardized adjusted
annual cost was obtained.
                                A-3

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                            APPROACH


     In March 1978, each utility having at least one operational

FGD system was given a cost form containing all available cost

information then in the PEDCo files.  The utility was asked to
verify the data and fill in any missing information called for

on the form.  A follow-up visit by the PEDCo Environmental staff

was arranged to assist in data acquisition and to insure com-

pleteness and reliability of information.  Results of the cost

analysis were forwarded to each participating utility for final

review and comment.

     The cost data were treated solely to establish the accurate

costs for FGD systems, on a common basis, not to critique the

design or reasonableness of the costs reported by any utility.

Adjustments focused primarily on the following items:

     0    All capital costs were adjusted to July 1, 1977, dol-
          lars using the Chemical Engineering Index.  All capital
          costs, represented in dollars/kilowatt ($/kW), were
          expressed in terms of gross megawatts (MW).  Actual
          costs were reported by utilities in dollar values for
          years 1970 to 1980.   These values are represented in
          terms of the year of greatest capital expenditures.

     0    Gross unit capacity was used to express all FGD capital
          expenditures because the capital requirement of an FGD
          system is dependent on actual boiler size before de-
          rating for auxiliary and air quality control power
          requirements.

     0    Particulate control costs were deducted.   Since the
          purpose of the study was to estimate the incremental
          cost for sulfur dioxide control, particulate control
          costs were deducted using either data contained in the
          cost breakdowns or as a percentage of the total direct
          cost (capital and annual).  The percentage reduction
          varied depending upon system design and operation.
                               A-4

-------
The capital costs associated with the modification or
installation of equipment not part of the FGD system
but needed for its proper functioning, were included
(e.g. - stack lining, modification to existing ductwork
or fans, etc.).

Indirect charges were adjusted to provide adequate
funds for engineering, field expenses, legal expenses,
insurance, interest during construction, allowance for
startup, taxes, and contingency.

All annual costs, represented in mills/kilowatt-hour
(mills/kWh), were expressed in terms of net megawatts
(MW) .

Net unit capacity was used to express all FGD annual
expenditures because the annual cost requirement  of  an
FGD  system is dependent on the actual amount of kilo-
watt-hours  (kWh) produced by the unit after derating
for  auxiliary and air quality control power require-
ments.

All  annual costs were adjusted  to  a  common  capacity
factor  (65%).

Replacement  power costs were not  included  since  only a
few  utilities  reported such costs  and  these were  pre-
sented  using a  variety of methods.

Sludge  disposal costs were  adjusted  to  reflect  the
costs of  sulfur dioxide waste  disposal  only (i.e.,
excluding fly ash disposal) and to provide for  disposal
over the  anticipated lifetime  of  the FGD system.   This
 latter  correction was necessary since several utilities
 reported  costs for  sludge  disposal capacity that would
 last only a fraction of  the FGD system life.   The
 adjustments were based  on  a land cost of $2000/acre
with a sludge depth of  50  ft  in a clay-lined pond (clay
 is assumed to be available at  the site).

 A 30-year life was  assumed for all process and economic
 considerations for  all  new systems that were installed
 for the life of the unit.   A 20-year life was assumed
 for all process -and economic considerations for  retro-
                      A-5

-------
          fit systems that were installed for the remaining por-
          tion of the life of the unit.*

     0    Regeneration and by-product recovery facility costs
          were added for those regenerable systems not reporting
          such costs.

     To the extent possible, all cost adjustments were made using

the previous assumptions developed by PEDCo Environmental.  When

cost data were inadequate, adjustments were made using process

design data in conjunction with the previous cost assumptions.

In some cases, no adjustments were possible because of in-

sufficient data.
   The use of a 30-year service life for new units coincides with
   the conclusion of the National Power Survey of the Federal
   Power Commission which recognized this value as reasonable for
   steam-electric plants.  A 20-year service life was assumed for
   all retrofit units even if the remaining life of the units is
   less than this value.   Thus, two different rates are used and
   should be noted when making comparisons between new and retro-
   fit systems.

                              A-6

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                  DESCRIPTION  OF  COST  ELEMENTS

     Capital costs consist of  direct costs,  indirect  costs,  con-
tingency costs,  and other  capital costs.   Direct costs  include
the "bought-out" cost of the equipment,  the  cost of installation,
and site development.  Indirect costs  include interest  during
construction, contractor's fees and expenses, engineering,  legal
expenses, taxes, insurance, allowance  for start-up and  shake-
down, and spares.  Contingency costs include those costs result-
ing from malfunctions, equipment alterations, and similar un-
foreseen sources.  Other capital costs include the nondepreciable
items of land and working capital.
     Annual costs consist of direct costs, fixed costs, and over-
head costs.  Direct costs include the cost of raw materials,
utilities, operating labor and supervision,  and maintenance and
repairs.  Fixed costs include those of depreciation, interim
replacement, insurance, taxes, and interest on borrowed capital.
Overhead costs  include  those of plant and payroll expenses.  The
various capital and  annual cost components are discussed and
defined  in  greater detail  in the following paragraphs.
     The direct capital costs include the following  elements:
     °    Equipment  required for the FGD  system.  Table A-l
          provides a summary of  the major process equipment  used
          in regenerable  and nonregenerable  systems.
     °    Installation  of  equipment,  including  foundations;  steel
          work  for support, buildings, piping and ducting  for
          effluents,  slurries, sludge, and make-up water,  control
          panels,  instrumentation,  insulation of ducting,  buildings,
          piping,  and other equipment, painting and  piling.
      0    Site  development may  include clearing and  grading,
          construction  of access roads and  walkways, establish-
          ment  of rail, barge,  and/or truck facilities,  and
          parking facilities.

                                 A-7

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         TABLE A-l.  MAJOR FGD SYSTEM EQUIPMENT SUMMARY
    Category
             Description
Material handling-
raw materials
Feed preparation-
raw materials
Sulfur dioxide
absorption
Flue gas reheat
Gas handling
Sludge disposal
Utilities
By-product
handling
Equipment for the handling and transfer of
raw materials includes unloading facilities,
conveyors, storage areas and silos, vibrators,
atmospheric emission control associated with
these facilities, and related accessories.

Equipment for the preparation of raw material
to produce a feed slurry consists of feed
weighers, crushers, grinders, classifiers,
ball mills, mixing tanks, pumps, agitators,
and related accessories.

Equipment for treating the flue gas includes
absorbers, mist eliminators, hold tanks,
agitators, circulating pumps, pond water re-
turn pumps, and related accessories.

Equipment required includes air, steam, or
hot water heaters, condensate tanks, pumps,
soot blowers, fans, fuel storage facilities,
gas bypass equipment, and related accessories.

Equipment to handle the boiler flue gas in-
cludes booster fans, ductwork, flue gas by-
pass system, turning vanes, supports, plat-
forms, and related accessories.

Nonregenerable FGD systems require solids/
water separation equipment such as clarifiers,
vacuum filters,  centrifuges, sludge fixation
equipment, and related accessories.

Equipment to supply power and water to the
FGD equipment consists of switch-gear, break-
ers,  transformers, piping, and related
accessories.

Equipment for processing the by-product of
regenerable FGD systems may include a rotary
kiln, fluid bed dryer, conveyor, storage silo,
vibrator, combustion equipment and oil stor-
age tanks, waste heat boilers, hammer mills,
evaporators, crystallizers, strippers, tanks,
agitators, pumps,  compressors, sulfuric acid
absorber and cooling, mist eliminator, pumps,
acid coolers, tanks,  etc.
(continued)
                               A-8

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TABLE A-L.   (continued)
    Category
             Description
Regeneration
Purge treatment
Auxiliary
Equipment for regeneration of the absorbing
medium of an FGD system may consist of re-
actor vessels, material handling system,
storage, weigh feeder, conveyor, rotary kiln,
fluid bed calciner, dust collector, storage
silo, vibrator, combustion equipment and oil
storage tanks, waste heat boiler, hammer
mill, evaporators, crystallizers, strippers,
tanks, agitators, pumps, compressors, sul-
furic acid absorber and cooling, mist elimi-
nator, pumps, acid coolers, tanks, etc.

Equipment for the removal of purge material
(e.g. sodium sulfate) includes refrigeration,
pumps, tanks, crystallizer, centrifuge,
dryer, dust collector, conveyors, storage,
and related equipment.

Equipment not directly related to the
FGD system, but which may require design or
modification to accommodate an FGD system
may include such  items as existing fans,
ducts, or stack.  If new fans, ducts, or
stacks are added to improve boiler perfor-
mance and accommodate the FGD systen, the
costs are prorated to the boiler and FGD
system.
                               A-9

-------
 Indirect capital costs  include  the  following  elements:

 0    Interest accrued on borrowed capital during construction,

 0    Contractor's  fee and expenses,  including costs  for
     field labor payroll; field office  supervision;  person-
     nel; construction  offices; temporary roadways;  railroad
     trackage; maintenance and  welding  shops; parking  lot;
     communications; temporary  piping and electrical and
     sanitary facilities; safety security  (fire, material,
     medical, etc.); construction tools and rental equip-
     ment; unloading and storage of  materials; travel  ex-
     penses; permits; licenses; taxes;  insurance; overhead;
     legal liabilities; field testing of equipment;  start-
     up; and labor relations.

 0    Engineering costs, including administrative, process,
     project, and general; design and related functions for
     specifications; bid analysis;  special studies;  cost
     analysis; accounting; reports;  consultant fees; pur-
     chasing; procurement; travel expenses; living expenses;
     expediting; inspection; safety; communications; model-
     ing; pilot plant studies  (if required because of  pro-
     cess design or application novelty); royalty payments
     during construction; training of plant personnel; field
     engineering; safety engineering; and consultant ser-
     vices.

 0    Legal expenses, including  those for securing permits,
     rights-of-way/ etc.

 0    Taxes, including sales, and excise taxes.

 0    Insurance covering liability for equipment in transit
     and at site; fire, casualty, injury, and death; damage
     to property; delay; and noncompliance.

 0    Allowance for start-up and shakedown includes the cost
     associated with system start-up.

 0    Spare parts including pumps, valves, controls, special
     piping and fittings, instruments, spray nozzles,  and
     similar items.

Other capital costs include the following elements:

 0    Land required for the FGD process, waste disposal, re-
     generation facility, and storage.

 0    Working capital,  including the total amount of money
     invested in raw materials and supplies in stock,
     finished products in stock, and unfinished products

                         A-10

-------
          in the  process  of  being manufactured;  accounts  re-
          ceivable;  cash  kept  on hand  for  payment  of  operating
          expenses  such as  salaries, wages,  and  raw materials
          purchases;  accounts  payable;  and taxes payable.

     Annual cost  of an FGD  system includes the following  direct,
fixed and overhead  charges:

°    Direct Charges

          Raw materials,  including  those required  by  the  FGD
          process for sulfur dioxide control, absorbent regenera-
          tion,  sludge treatment, sludge fixation, flocculants,
          etc.

          Utilities,  including water for slurries, cooling and
          cleaning; electricity for pumps, fans, valves,  lighting
          controls, conveyors, and  mixers; fuel  for reheating  of
          flue gases; and stream for processing.

     •    Operating labor,  including supervisory,  skilled, and
          unskilled labor required  to  operate, monitor, and
          control the FGD process.

          Maintenance and repairs,  consisting of both manpower
          and materials to keep the unit operating efficiently.
          The function of maintenance  is both preventive and
          corrective to keep outages  to a  minimum.

          Byproduct Sales:   credit  from the sale of byproducts
          regenerable FGD processes (e.g.  sulfur,  sulfuric acid)
          is a negative charge deducted from the annual direct
          cost to obtain the net annual direct cost of the FGD
          system.

0    Fixed Charges

          Depreciation - the annual charge to recover direct and
          indirect costs of physical  assets over the life of the
          asset.

      •    Interim, replacement - costs expended for temporary or
          provisional replacement of equipment  that has failed or
          malfunctioned prematurely.

          Insurance, including the costs  of protection from loss
          by  a specified contingency,  peril, or unforeseen event.
          Required coverage could include losses  due to  fire,
          personal injury or death, property damage, explosion,
          lightning, or other natural phenomena.
                                A-ll

-------
          Taxes, including franchise, excise, and property taxes
          levied by a city, county, state, or Federal government.
      *    Interest on borrowed funds.
 0    Overhead
          Plant and administrative overhead is a business expense
          that is not charged directly to a particular part of a
          project, but is allocated to it.  Overhead costs in-
          clude administrative, safety, engineering, legal and
          medical services; payroll? employee benefits; recrea-
          tion; and public relations.
     Table A-2 provides a summary of the means used to determine
 the missing cost elements if the costs were not reported or
 insufficient information prevented their actual determination.
 The assumptions and cost bases for determining the capital and
 annual costs of FGD systems were developed by the PEDCo staff
 based upon previous economic studies conducted for the U.S. EPA
 (Flue Gas Desulfurization Process Cost Assessment, May 1975;
 Simplified Procedures for Estimating Flue Gas Desulfurization
 System Costs, June 1976, EPA-600/2-76-150; Particulate and Sulfur
Dioxide Emission Control Costs for Large Coal-Fired Boilers,
March 1978,  EPA-600/7-78-032).
                               A-12

-------
                TABLE  A-2.   COST  ELEMENT FACTORS
Category
Value
Indirect capital costs:
  Interest during
    construction
  Field overhead
  Contractor's fee and
    expenses
  Engineering
  Taxes
  Spares
  Shakedown allowance
Other capital costs:
  Contingency

Direct annual costs:
  Raw materials:
    Fixation chemicals
    Lime
    Limestone
    Magnesium oxide
    Sodium carbonate
    Salt  cake  (credit)
    Sulfur  (credit)
    Sulfuric  acid  (credit)
  Utilities:
    Electricity
    Water
    Steam
  Operating  labor:
    Direct  labor
    Supervision
10% of total direct capital costs

10% of total direct capital costs
 5% of total direct capital costs

10% of total direct capital costs
 2% of total direct capital costs
 1% of total direct capital costs
 5% of total direct capital costs
20% of total direct and indirect
  capital costs
             $2/ton
             $40/ton
             $10/ton
             $150/ton
             $80/ton
             $50/ton
             $65/ton
             $25/ton

           25 mills/kWh
           $0.20/103 gal
           $0.80/106 Btu

 $8.50/man-hour
 15%  of direct  labor  costs
   Contingency costs are used only when the cost data supplied are
   incomplete (such as equipment costs or direct costs only) and a
   contingency cost must be factored in to give an accurate estimate
   of the total capital cost.
 (continued)
                               A-13

-------
TABLE A-2.   (continued)
     Category
               Value
  Maintenance:
    Labor and materials
    Supplies
  Overhead:
    Plant
    Payroll

Fixed annual costs:
  Depreciation
  Interim replacement
  Taxes
  Insurance
  Capital costs
 4% of total direct capital costs
15% of labor and materials costs

50% of operation and maintenance costs
20% of operating labor costs


3.33% or 5% (new or retrofit)
0.7% or 0.35%
4%
0.3%
9%
   Some system components have life spans less than the expected
   service life of the system.  Interim replacement is an allow-
   ance factor used in estimating annual revenue requirements to
   provide for the replacement of these short-lived items.  An
   average allowance of 0.35% of the total investment is normally
   provided and used for systems with an expected service life of
   20 years or less.  A higher allowance of 0.70% of the total
   investment is provided and used for systems with an expected
   service life of 30 years or more.
                              A-14

-------
                   DEFINITION OF COST ELEMENTS

     The costs displayed in Appendix A are accompanied by a
series of alphabetic characters summarizing data presented for
each FGD system.   These relate to the cost elements described
earlier in this section and identify what has been included and
excluded for reported and adjusted capital and annual costs.  The
alphabetic characters, along with their titles, are briefly de-
scribed in Table A-3.
                               A-15

-------
                      TABLE  A-3.    DESCRIPTION OF  COST
Code
                      Title
                                                      Description
L


M



N


0
     Particulate control (required for FGD pro-
     cess) included in capital cost.
     Particulate control (included in FGD
     process) included in capital cost.

     Total direct capital costs included.
     Partial direct capital costs included.
     Total indirect capital costs included.
     Partial indirect costs included.
     Chemical fixation of sludge included in
     capital cost.
     Dry sludge disposal included in capital
     cost.
     Off-site landfill area included in
     capital cost.

     Sludge pond included in capital cost.
     Additional sludge disposal capacity
     added for life of system.
Stack included in capital cost.

Modifications to stack, ducts, and/or
fans included in capital cost.


Total regeneration facility cost included
in capital cost.

Partial regeneration facility cost in-
cluded in capital cost.


R & D costs included in capital cost.
Particulate precollection device (ESP,
fabric filter, venturi) prior to FGD
system required for proper operation of
SO- control system.

Particulate collection equipment (venturi
scrubber) is included in the FGD system.
Complete cost of all FGD equipment, the
labor and materials required for equip-
ment installation, and interconnecting
the system is included in the total
capital cost.
One or a number of direct cost items, or
the cost associated with one or a number
of direct cost items, are excluded from
the total capital cost.
Complete cost of all the indirect cost
elements, including interest during con-
struction, contractor's fees, engineer-
ing, legal expenses, taxes, insurance,
allowance for start-up, and spares, is
included in total capital cost.

One or a number of indirect cost items,
or the cost associated with one or a
number of indirect cost items, are ex-
cluded from the total capital cost.
The cost of a chemical fixation process
which stabilizes the flue gas cleaning
wastes prior to disposal is included in
the total capital cost.

The coat of a secondary dewatering or
treatment method, such as filtration, cen-
trifugation, or forced oxidation, which
ultimately produces a dry sludge cake
for final disposal, is included in the
total capital cost.
The cost of an off-site area used as a
landfill for flue gas cleaning wastes is
included in the total capital cost.
The cost of an on-site disposal area for
ponding of treated or untreated flue gas
cleaning wastes is included in the total
capital cost.

The cost of additional SO. waste disposal
capacity required for FGD system operation
over the anticipated service life of the
unit is included in the total capital cost.
The cost of the stack is included in the
total capital cost.

Modifications to existing equipment (stack,
fans, ducts, etc.) which are required be-
cause of inclusion of an FGD system.
Complete cost of entire regeneration
facility included in total capital cost.

Part of the cost associated with the ret
generation facility included in the total
capital cost.
Bench scale or pilot plant studies to de-
termine process and design characteristics.
 (continued)
                                          A-16

-------
                           TABLE  A-3.    (continued)
Code
                      Title
                                                     Description
 w

 X
      losts underwritten by system  supplier  in-
      :luded in capital cost.
     Excess reagent supply costs included  in
     capital cost.

     Total direct annual costs included.
     Partial direct annual costs included.
     Total fixed annual costs included.
     Partial fixed annual costs included.
Overhead cost included in total annual
cost.
Particulate control costs included in
direct annual cost.
      Sludge disposal service costs  (contract)
      included  in direct annual cost.
      Replacement energy costs included in
      total  annual costs.
Capital expenditures underwritten by the
system supplier for system repairs or
modifications for optimization of perfor-
mance or R S D programs.
Capital expenditures for reagent supply
exceeds the amount required for the period
of initial operation.
Complete cost of all raw materials,
utilities, operating labor and maintenance
and repairs is included in the total
annual cost.
One or a number of direct annual cost items,
or the cost associated with one or a number
of direct annual cost items,  are excluded
from the total annual cost.

Complete cost of all fixed cost elements,
including depreciation, interim replace-
ment,  insurance, taxes, and interest,  is
included in the  total annual  cost.

One or a number  of  fixed  annual cost  items,
or  the cost associated  with one or a
number of  fixed  annual  cost items,  are ex-
cluded from  the  total annual  cost.

Plant  and  payroll  overhead costs  are  in-
cluded in  the  total annual cost.

The cost  of  operating particulate collection
equipment  included in the FGD system is in-
 cluded in the  total annual cost.

 The treatment  and disposal of flue gas
 cleaning wastes that are  handled by an
 outside firm.

 The cost of additional  power-generating
 capacity required to compensate for power
 used by the PGD system.
                                          A-17

-------
                    RESULTS OF COST ANALYSIS

     The results of the operational FGD system survey are summarized
in Table A-4 and Section A-l.  Table A-4 produces a summary of a
categorical analysis of the reported and adjusted capital and
annual costs for the operational FGD systems addressed in the
survey.  Included in this categorical analysis are the ranges,
means, and standard deviation for all the various types and
categories of FGD systems examined.  Section A-l summarizes the
reported and adjusted capital and annual costs for all the oper-
ational FGD systems that were addressed in the cost study
(Section A-2 summarizes available cost data for nonoperational
FGD systems).
                              A-18

-------
                              TABLE  A-4.   CATEGORICAL  RESULTS OF THE  REPORTED  AND ADJUSTED/
                                   CAPITAL  AND ANNUAL COSTS FOR  OPERATIONAL  FGD SYSTEMS
3=>
I
        CATEGORY
 ALL


 MEU


 RETROFIT


 TNROUAUAT PROOUCT


 SALEAILE PROIUCT


 LINESTONE


 LINE


 •UAL ALKALI


LINE/ALKALINE FLTASM


SOIIUN CARIONATE


UELLNAN LORI


LIHESTOHE/ALKALIHE FLTASN
                                 			REPORTEI	-	   	AIJUSTED	
                                 —CAPITAL. I/KU	ANNUAL, NIILS/KUH-—   	CAPITAL.  «/«J	  	ANNUAL. HILLS/KIM	

                                 RAN6E     AVG   IEV      RANGE     AVB    DEV       RANGE    AVG   DEV      RANGE     AVO   KV
                                      29.2-189.0  79.7  38.4


                                      3I.8H89.0  7V.3  38.7


                                      29.2-154.9  80.1  38.5


                                      2V.2-187.0  71.2  34.8
                           .1- 14.V   4.4   4.4    34.0-140.A  88.0


                           .1- 14.3   3.2   3.9    44.4-117.4  84.1


                          2.1- 14.V   4.5   4.3    54.0-140.4  90.0


                           .1- 14.3   4.1   4.0    56.0-140.4  14.2
127.9-134.9 137.4   13.7   14.V- 14.V   14.V


 31.1-148.0  75.7   37.0     .V-  3.3   2.0


 29.2-128.3  74.V   32.2


 43.2-I8V.O  V4.7   45.5


 77.1- 85.V  80.0   4.1


 42.V-120.0  7V.8  37.0


!27.V-154.V 137.4   13.7   14.V-  14.V  14.9


 47.V- 47.V  47.V    .0   2.0-  2.0   2.0
                  .0   134.8-134.8  134.8


                  .7    34.0-117.4  88.6


 .1- 14.3   4.9   4.8    67.3-140.4  90.8


3.2-  3.2   3.2    .0   *•*•*-    .0    .0


 .3-   .3   .3    .0    77.2- 93.0  82.3


2.1-  2.1    2.1    .0    60.9-I07.V  76.6


                  .0   134.BH34.8 134.8


                  .0    71.2- 71.2  71.2
 23.4


 17.8


 28.1


 21.9


  .0


 29.9


 22.2


  .0


 7.4


22.2


  .0


  .0
  2.4-


  2.8-


  2.6-


  2.4-


 12.4-


  2.4-


  2.7-


***•*-


  4.1-


  3.2-


 12.4-


  2.8-
 12.4


 1.7


 12.4


 8.7


 12.4


 4.6


 8.7


  .0


 3.2


 4.4


12.4


 2.8
  3.4   2.4


  3.2   2.0


  3.6   2.7


  3.1   2.8


12.4    .8


 4.4   1.6


 6.4   2.8


  .0    .8


 4.3    .3


 3.6    .6


12.4    .8


 2.8    .0

-------
  EPA  UTILITY FGO SURVEY: JULY -  SEPTEMBER  19PO
                                             SFCTION A-1
                                  COSTS  FOR  OPERATIONAL FGD SYSTEMS
 J4IT  DESCRIPTION
                                COST  DESCRIPTION
                                                                  REPORTED
                                                                               ---COST- —
                                                                                ADJUSTED
                                                                                           STANDARDIZED
                                                                                             ADJUSTED
 ALABAMA  ELECTRIC COOP
 T31BI&3EE
 3
  179.3  NW  (NET)
 CAPACITY FACTOR, X
 TOTAL  CAPITAL, t/KW(YEAR)
 TOTAL  ANNUAL, HILLS/KWH(YEAR)
 COST  ELEMENTS
  •*»            65
   69.5(1978)  •**•••(
******(    0)  ******(
C.E.J
      65
0)  *••***(
0)  ******(
0)
0)
 ARIZONA  ELECTRIC POKER COOP
 APACHE
 2
   9fc.D  HU  (NET)
 CAPACITY  FACTOR, X
 TOTAL  CAPITAL, WKW(YEAR)
 TOTAL  ANNUAL,  MILLS/KWH(YEAR)
 COST ELEMENTS
  *«            65            65
  35.9(1977)  ******(    0) *•**»«(   o>
   2.1(1978)  ******(    0) ****•*(   oj
C,E,H,J,L,S,
U,W,Y,Z
 ARIZONA  ELECTRIC  POWER COOP
 APACHE
 3
   96.3  nw  (NET)
CAPACITY  FACTOR,  *
TOTAL  CAPITAL, S/KW(YEAR)
TOTAL  ANNUAL,  HILLS/KWH(YEAR)
COST ELEMENTS
  44            65
  31.8(1977)  **••*•(
   2.1(1978)  ••*•»•(
C ,E,H,J,L,S,
U.W.Y.Z
     65
0) •••««*(
0) •***•*{
0)
0>
 ARIZONA  PUBLIC  SERVICE
 CHOLLA
 1
 119.3 MU  (N£T)
CAPACITY  FACTOR,  X               85            65            65
TOTAL CAPITAL.  S/try (TEAR)        53.0(1973)    56.0(1977)    56.0(1977)
TOTAL ANNUAL,  «ILLS/KMH(TEAR)     3.ZU976)     ?.6(1977)     2.3(197?)
COST ELEMENTS                   B,C,E,S,U,X  C,E.K,S,U,W   C.E.K.S.U.W
ARIZON* PUBLIC  SERVICE
CHOLLA
3
 2S4.3 MU  (NET)
CAPACITY  FACTOR,  X               65            65            65
TOTAL CAPITAL,  $/KH(YEAR)       168.0(1978) **•*•*(    0)  ******(
TOTAL ANNUAL,  MILLS/KWH(YEAR)     1.5(1978) ***••*(    0)  •••«•*<
COST ELEMENTS                   B,D,T,X
3ASIN ELECTRIC  POWER  COOP
LARA»IE RIVER
1
 570.3 MW (NET)
CAPACITY  FACTOR,  X              ••*           65            65
TOTAL CAPITAL,  f/KU(YEAR)        56.0(1980) ****«*(    0)  ***««.(
TOTAL ANNUAL,  HILLS/KtfH(YEAR)      .9(7800) •*•••«(    0)  **».«.(
COST ELEMENTS                   C,E
                                     0)
                                     0)
sis RIVERS ELECTRIC
SHEEN
1
 242.0 MW (NET)
CAPACITY  FACTOR,  X
TOTAL CAPITAL,  */KU(YEAR)
TOTAL ANNUAL, MILLS/HUM(YEAR)
COST ELEMENTS
 •*•            65
  43.2(1976) ******!
***•**<   0) ••»*••<
B,C
     65
0) ••••**(
0) ******(
0>
0)
CENTRAL ILLINOIS LIGHT
DJCK CREEK
1
 416.0 MW (NET)
CAPACITY FACTOR,  X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
 *•*           65
  93.3(1978) •***••<
   3.3(1976) ******(
     65
0) •*•»*»(
0) •••«**<
0)
0)
CENTRAL ILLINOIS PUBLIC  SERV
MEWTON
1
 617.3 MW (NET)
CAPACITY FACTOR,  X               **»           65            65
TOTAL CAPITAL, $/KW(YEAR)        189.0(1979) ****»•<   0)  •*•«•*(
TOTAL ANNUAL, MILLS/KUH(YEAR)   •****•(   0) •*****<   0)  »•*•**(
COST ELEMENTS                   C,E,6
                                   INDICATES COST FIGURES NOT  YET  AVAILABLE

                                             A-  20

-------
                                               EPA  UTILITY  FGD SURVEY:  JULY - SEPTEMBER 198C
                                            SECTION  A-1
                                COSTS FGS OPERATIONAL  fGD  SYSTEMS
UNIT DESCRIPTION
                               COST DESCRIPTION
                                 	COST	
                                 REPORTED      ADJUSTED   STANDARDIZED
                                                            ADJUSTED
COLORADO UTE ELECTPIC ASSN
CRAIG
2
 400.3 MU  (NET)
CAPACITY FACTOR, X               **•
TOTAL CAPITAL, S/KW(YEAR)         73.7(1979)
TOTAL ANNUAL, M 1LLS/KWH(YEAR)   *••*»»<    C)
COST ELEMENTS                   A.C
                                                                              65
                           65
                      0) ..••*•(
                      0) **»•*»(
C)
0)
COLUMBUS £ SOUTHERN OHIO  E.LEC   CAPACITY  FACTOfc, X               48            65            65
C3NESV1LLE                      TOTAL  CAPITAL, S/KW(YEAR)        55.5(1975)    7C.7(1977)    70.7(1977)
5                               TOTAL  ANNUAL, MILLS/K.WH(YEAR)     5.8(1978)     7.4(1977)     7.4(1977)
 411.0  MW  (NET)                 COST  ELEMENTS                  P,C,J,M,$,U,  C,E,J,M,S,U,  C,E,J,",S,U,
                                                               W,X,Y         U,Y          V,t
COLUMBUS S SOUTHERN OHIO ELEC
C JNESVILLE
411.3 MW (NET)

COMMONWEALTH EDISON
P3WERTON
51
450.0 MW (NET)
CAPACITY FACTOR, X

COST ELEMENTS

CAPACITY FACTOR, 1


COST ELEMENTS
*e

Bft ,J9P,S ,Ut
»(>T,Y
*+ *


C.E.H.J
65

C,E, J
w,t
65





,M,S.U,





65



65



 pjOUESNE LIGHT
 1-4
  510.3 MU (NET)
 OPACITY  FACTOR, X
 TOTAL  CAPITAL, t/KW(YEAR)
 TOTAL  ANNUAL, MI LLS/K.UH ( Y E AR )
 COST ELEMENTS
  64            65           65
 113.4(1976)   127.1(19771  127.K1977)
                                                                   8.6(1977)
                                                                                7.8C1977)
                                                                                              7.5<1977>
                                R.D.F.I.J.M.  C,E,I,J,M,S, C.E.l.J.M.S,
                                T,V,«^Y       U,Y          U,Y
 OjauESNE LIGHT
 PHILLIPS
 1-6
  498.0 MM  (NET)
 CAPACITY FACTOR, X
 TOTAL CAPITAL, }/KW(YEAR)
 TOTAL ANNUAL, MILLS/KWH{YEAR)
 COST ELEMENTS
  70           65            65
 106.9(1972)  UO.6(1977)   140.6(1977)
   7.8(1977)    8.6(1977)     8.2(1977)
e,D,F,I,J,H, C.E.l.J.M.S-,  C.E.l.J.M.S,
T.V.X.Y      U.Y           u.Y
 INDIANAPOLIS POWER  S  LIGHT
 PETERSBURG
 5
  532.0 MH  (NET)
 CAPACITY FACTOR,  X               ***           65            65
 TOTAL CAPITAL,  S/KW(YEAR)         99.5(1976)  110.6(1977)   110.6(1977)
 TOTAL ANNUAL, MILLS/KHH(YEAR)  ••*»•*(   0)    6.6C1977)     7.411977)
 COST ELEMENTS                   t.F.G.J.R    C.E,6,J,H,S,  C,E,6,J,M,S,
                                              U,«,t         U.W.t
         CITY  POWER  8  LIGHT
 HAWTHORN
 3
    90.3  MW  (NET)
 CAPACITY  FACTOR,  »
 TOTAL  CAPITAL,  */KW
 TOTAL  ANNUAL,  MILLS/HWH(YEAR)
 COST  ELEMENTS
  1*            65            65
  29.2(1972)    87.3   87.2(1977)
   8.4(1977)     4.3(1977)    4.4(1977)
9,D,F,T,X     B.C.E.J.K.S, B,C,E.J,K,S,
              U.U.X        U.U.X
  KANSAS CITY POWER * LIGHT
  HAWTHORN
  4
    90.0 MW (NET)
  CAPACITY FACTOR, X
  TOTAL CAPITAL, $/KW(YEAR)
  TOTAL ANNUAL. MILLS/KWM(YEAR)
  COST ELEMENTS
  •«•            65           65
   29.4(1972)   87.2(19771   87.2(1977)
    8.4(1977)    4.3(1977>    4.4(1977)
 e,0,F,T,I    B.C.E.J.K.S. B.C.E.J.K.S.
              U,W.X        U.W.X
                            ......    INDICATES COST FIGURES NOT  YET  AVAILABLE

                                               A-  21

-------
 EPA UTILITY FGO SURVEY: JULY  -  SEPTEMBER  1980
                                            SECTION A-1
                                 COSTS  FOR  OPERATIONAL F6D SYSTEMS
JSIT DESCRIPTION
                                COST  DESCRIPTION
                                                                 REPORTED
                                                                                 COST
                                                                               ADJUSTED
                                                                                          STANDARDIZED
                                                                                            ADJUSTED
KANSAS CITY POWER  K  LIGHT
LA CYSNt
1
 320. 3 NW  (NET)
                                CAPACITY FACTOR, X
                                TOTAL  CAPITAL, $/KU(YEAR)
                                TOTAL  ANNUAL, M I LLS/KWH ( YE AR)
                                COST  ELEMENTS
                                                                 42            65            65
                                                                 53.6(1972)    68.0(1977)    68.0(1977)
                                                                  1.3(1978)    3.8(1977)     3.9(1977)
                                                               T            C,E,J,K,S,U   C,E,J,K,S,U
KANSAS POWER & LI6HT
JEFFREY
1
 5*0. 0 MW (NET)
                                CAPACITY  FACTOR, X              ••*           65            65
                                TOTAL  CAPITAL, t/KU(YEAR)        56.8(1978) *•*••*(    0)  «**•••(    0)
                                TOTAL  ANNUAL,  HI LLS/ KWH( YEAR)  ****•»{ 19 78) *****»(    0)  ***•**(    0)
                                COST  ELEMENTS                   B ,C
KENTUCKY UTILITIES
SHEEN RIVER
1-3
  64.0 MM  (NFT)
                                CAPACITY  FACTOR, X
                                TOTAL  CAPITAL, S/KW(YEAR)
                                TOTAL  ANNUAL, HI LLS/KWH ( YEAR)
                                COST  ELEMENTS
                                                                 16           65            65
                                                                 70.3(1975)   77.5(1977)    77.5(1977)
                                                                 U. 3(1977)    2.7(1977)     5.2(1977)
                                                               B.C.E.J.S.U, C,E,J,S,U,y   C.E.J.S.U.U
                                                               W
LOUISVILLE  GAS  &  ELECTRIC
CANE RUN
I
 188. 3 MW  (NFT)
                                CAPACITY FACTOR, X
                                TOTAL  CAPITAL, S/KW(VEAR)
                                TOTAL  ANNUAL, MI LLS/KUH ( YEAR)
                                COST  ELEMENTS
                                                                 55           65            65
                                                                 66.5(1975)   80.6(1977)    80.6(1977)
                                                                  2.7(1977)     5.8(1977)     6.2(1977)
                                                               C,E,HI,JtQ,T  C,E,H,J,K,0,  C,E,H,J,K,0,
                                                                            s.u.w         s.u.w
LOUISVILLE GAS & ELECTRIC
CANE RUN
5
 200.0 MW (NET)
                                CAPACITY  FACTOR,  X              •**           65            65
                                TOTAL  CAPITAL, t/KW(YEAR>        62.4(1977)   67.5(1977)    67.5(1977)
                                TOTAL  ANNUAL,  HI LLS /KWH ( YEAR)  *****»(   0)    5.6(1977)     5.6(1977)
                                COST  ELEMENTS                   C.E.H.J      C,E,H,J,K,S,  C,E,H,J,K,S,
                                                                            u.y           u,u
LSU1SVILLE GAS & ELECTRIC
CANE RUN
i
 299.3 HU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, f I LLS/KWM( YEAR)
COST ELEMENTS
                                                                 ***            65
                                                                 57.9(1977)  ******(
                                                                  3.2(1979)  •*•**•(
                                                               C ,E ,H>,M ,S , V,
                                                               M
                                                                                            65
                                                                                       0)  •*•***<
                                                                                       0)  ***•**(
                                                                                                    0)
                                                                                                    0)
LOUISVILLE GAS I ELECTRIC
1ILL CREEK
]
 «4?. 3 MU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, SyKU(VEAR)
TOTAL ANNUAL, H I LLS/KUH ( YE AR)
COST ELEMENTS
                                                                 10            65
                                                                 42.6(1978)  «••*••(
                                                                  1.3(1978)  *••*•*(
                                                               c,s
                                                                                            65
                                                                                       0)  •**...(
                                                                                       0)  *****.(
                                                                                                    Q)
LOUISVILLE GAS & ELECTRIC
PADDY'S RUN
6
  72.0 MW (NET)
                                CAPACITY  FACTOR, X              ***
                                TOTAL  CAPITAL, S/KU(VEAR)        52.8(1973)
                                TOTAL  ANNUAL,  M I LLS/KMN ( V EAR)  •**«•*(   0)
                                COST ELEMENTS                   C,E          C,E,S,U,W
                                                                              65            65
                                                                              76.4(1977)    76.4(1977)
                                                                               6.5(1977)     6.4(1977)
                                                                                          C.E. S.U.W
H1NNKOTA POWER COOPERATIVE
HILTON R. YOUNG
2
 195.3 MW (NET)
                                CAPACITY  FACTOR,  X
                                TOTAL  CAPITAL, S/KV(YEAR>
                                TOTAL  ANNUAL,  HI LLS/KWN ( YEAR)
                                COST ELEMENTS
                                                                ••*           65            65
                                                                 85.SM976)   93.0(1977)    93.0(1977)
                                                               ••**•*(   0)    5.2(1977)     5.2(1977)
                                                               C.E.H.P      C.E.H.M.P.S,  C.E.H.R.P.S.
                                                                            U,U           U.W
                         ......   INDICATES  COST  FIGURES NOT YET AVAILABLE

                                             A-   22

-------
                                             EPA UTILITY  FGO  SURVEY:  JULY  - SEPTEMBER 1980
                                           SECTION  A-1
                               COSTS FOR OPERATIONAL  F60  SYSTEMS

UNIT DESCRIPTION
40NONGAHELA POWER
PLEASANTS
1
618.0 MW (NET)
MONTANA POWER
COLSTRIP
1
360.0 MW (NET)

MONTANA POWER
CDLSTRIP
2
360.0 NW (NET)
NEVADA POWER
REID GARDNER
125.0 MW (MET)

COST DESCRIPTION
CAPACITY FACTOR, X
TOTAL ANNUAL, HI LLS/ KUH ( t EAR )
COST ELEMENTS
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, HI LLS/KWH ( YEAR )
COST ELEMENTS

CAPACITY FACTOR, X
TOTAL CAPITAL, S*tCW(YEAR>
TOTAL ANNUAL, MI LLS/KVH ( YEAR )
COST ELEMENTS
CAPACITY FACTOR. X
TOTAL CAPITAL, S/KW(YEAR>
TOTAL ANNUAL, MI LLS/KWH( YEAR)
COST ELEMENTS

REPORTED
65
2.8(1978)
B.C.J.S
76
77.1(1975)
.3(1977)

76
77.1(1975)
.3(1977)
B,C,F,J,P,T
67
42.9(1973)
2.1(1977)
B.D.E.P.S.U,

ADJUSTED
65
*•***•( 0)
65
77.2(1977)
4.1(1977)
U.W
65
77.2(1977)
4.1(1977)
C,E,J.K,P,S.
U.W
65
60.9(1977)
3.2(1977)
8,D,E,P,S,U,

STANDARDIZED
ADJUSTED
65
•«««•*( 0)
65
77.2(1977)
4.1(1977>
U.W
65
77.211977)
4.1(1977)
C.E.J.K.P.S.
U.W
65
60.9t1977>
3.4(1977)
B.D.E.P.S.U,
                                                               w.x
                                                                            w.x
                                                                                         w.x
NEVADA POWER
REID GARDNER
I
 125.0 MW  (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, NILLS/KUH(YEAR)
COST ELEMENTS
  67           65            65
  42.0(1973)   60.9(1977)    60.9(1977)
   2.1(1977)    5.2(1977)    3.4<1977>
B.O.E.P.S.U. B.D.E.P.S.U, B.D.E.P.S.U,
W,X          W,X          U,K
NEVADA POWER
REID GARDNER
5
 125.0 MW  (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
  67           65            65
 113.6(1975)  107.9(1977)   107.9(1977)
   2.1(1977)    4.4(1977)     5.0(1977)
B,C,E,L,S,U, B.C.E.L.S.U.  B.C.E.L.S.U,
w,x          y.x           w.i
NORTHERN  INDIANA  PUB  SERVICE
»EAN  H. MITCHELL
11
  115.0  MW (NET)
CAPACITY  FACTOR,  X
TOTAL CAPITAL,  S/KW(YEAR)
TOTAL ANNUAL, MILLS/KWH(YEAR)
COST ELEMENTS
  77            65            6S
  156.0(1976)   134.8(1977)   1J4.8(1977>
  14.9(1976)    12.4(1977)    11.0(1977)
B,C,Ei,L.N.S.  C,E,L,N,S,U,  C,E,L,N,S,U,
U,U,X,Z       W,I           U.Z
 NORTHERN  STATES POWER
 SHERBURNE
 1
  740.3 NW (NET)
 CAPACITY  FACTOR,  X
 TOTAL  CAPITAL,  &/KW(VEAR>
 TOTAL  ANNUAL.  HILLS/KWH(YEAR)
 COST  ELEMENTS
   73            65            65
   47.9«1972)    71.2(1977)   71.2(1977)
    2.0(1977)     2.8(1977)    3.3(1977)
 B.C.j.S.U.X,  C.E.J.K.S.U. C.E.J.K.S.U.
 I             W            W
 NORTHERN STATES POWER
 SHERBURNE

  740.0 MW (NET)
 CAPACITY FACTOR, X
 TOTAL CAPITAL, SSKU(VEAR)
 TOTAL ANNUAL, HILLS/KWH(YEAR)
 COST ELEMENTS
   73
   47.0(1972)
    2.0(1977)
65
71.2(1977)
 2.8(1977)
65
71.2(1977)
 3.3(1977)
                                B,C,J,S,U,X,  C.E.J.K.S.U,  C.E.J.K.S.U,
                           .»***.    INDICATES  COST FIGURES NOT YET AVAILABLE

                                              A-  23

-------
  EPA  UTILITY FGD SURVEY: JULY - SEPTEMPf  198C
                                             SECTION  A-1
                                 COSTS FOR OPERATIONAL  FGD SYSTEMS
 JNIT  DESCRIPTION
                                COST DESCRIPTION
                                                                  REPORTED
                                                                              -"COST-
                                                                               ADJUSTED
                                                                                           STANDARDIZED
                                                                                             ADJUSTED
 PACIFIC  POWER  8  LIGHT
 JI1  PRIDGER
 4
 550.3 MW  (NET)
                                CAPACITY  FACTOR,  X
                                TOTAL CAPITAL,  $/KW(YEAR)
                                TOTAL ANNUAL, PILLS/KWh{YEAR)
                                COST ELEMENTS
  ***            65
  120.0(1979)  *••«**(
*****»(    C)  •*****(
C.E.J
                                                                                             65
                                                                                       C) ******(    0)
                                                                                       0) *****»(    0)
PENNSYLVANIA  POWER
3RUC E  1ANSFIELD
1
  J17.0  MU  (NET)
                                CAPACITY FACTOR,  X
                                TOTAL CAPITAL, t/KW(YEAR)
                                TOTAL ANNUAL, MILLS/KWH(YEAR)
                                COST ELEMENTS
  40            65            65
 120.6(1975)   102.1(1977)   102.1C1P77)
  14.3(1977)     ?.7(1977)    1C.6(1977>
B,C,E,G,I,L,  C.E.G.I.H.S,  C,E.G.I,M.S.
S,U,Wi,X       U,U          U,W
PENNSYLVANIA  POWER
3RUCF 1ANSFIELD
2
 J17.3 MW  (NET)
                                CAPACITY FACTOR, X
                                TOTAL CAPITAL, S/KW(YEAR)
                                TOTAL ANNUAL, MILLS/K«H(YEAR)
                                COST ELEMENTS
  40            65            65
 120.6(1975)   102.1(1977)   102.1(1977)
  14.3(1977>     8.7(1977)    10.8(1977)
B.C.E.G.I.L,  C,E,G,I,H,S,  C.E.G.I,M.S.
s.u.w.x       u,.           u,w
PJBLIC SERVICE OF NEW MEXICO
«
361 .D MW (NFT)
PJBLIC SERVICE OF NEU MEXICO

550. C MW (NET)
SALT RIVER PROJECT
CORONADO
280.3 MW (NET)
SALT RIVER PROJECT

280.3 MU (NET)
CAPACITY FACTOR, X *** 65

COST ELEMENTS A,C,E>.N
CAPACITY FACTOR, X *** 65

COST ELEMENTS A,C,E,N
CAPACITY FACTOR, X *•* 65
TOTAL CAPITAL, $/KW(YEAR) 74.0(1978) ****•*(
COST ELEMENTS C ,E
CAPACITY FACTOR, X *** 65

COST ELEMENTS C ,E

0)



0)
0)
0)

0)
0)
65


65


65
******(

65



0)
l»

0)
0)
0)
0)

p>
0)
SDUTH CAROLINA PUBLIC SERVICE   CAPACITY FACTOR, X
4INYAH
2
 140.0 HW (NET)
                                TOTAL  CAPITAL, S/KW
                                COST  ELEMENTS
  80           65            65
  47.4(1976)   66.4(1977)    66.4(1977)
   1.6(1975)    2.9(1977)     3.2(1977)
C.F.J.M.S.V  C.E.J,K.H.S,  C,E,J,K,M,S.
             u.w           u,w        '
SOUTH MISSISSIPPI ELEC PWR
R.D. lORROy, SR.
1
 124.3 MW (NET)
                                CAPACITY FACTOR, X
                                TOTAL  CAPITAL, S/KHCYEAR)
                                TOTAL  ANNUAL, M I LLS/ KWH( YEAR >
                                COST ELEMENTS
 ***           65
  37.4(1975) *«****(    0)
****•*(   0) «*****(    0)
C.E
                                                                                            65
                                                                                          •*****(
                                                                                          «•«•«»(
                                     0}
                                     0)
                         ******    INDICATES  COST FIGURES NOT YET AVAILABLE

                                             A-  24

-------
                   EPA UTILITY  F6D  SURVFY: JUIY - SEPTEMBER  1980
                SECTION A-1
     COSTS FOP OPERATIONAL FGD  SYSTEMS

UMIT DESCRIPTION
SOUTH 1ISSISSIPPI ELEC PYR
D. D. 10RROU t SR •
2
124.3 MU (NET)
SOUTHERN ILLINOIS POWER COOP
^AR ION
173.0 MU (NET)
SOUTHERN INDIANA GAS & ELEC
A. 8. BROWN
1
265. D MW (NET)

COST DESCRIPTION
CAPACITY FACTOR, X

COST ELEMENTS
CAPACITr FACTOR, X

COST ELEMENTS
CAPACITY FACTOR, X

COST ELEMENTS

REPORT? D
** *

C.E
65

B»C,T?X
** *

C,E,G

ADJUSTED STANDARDIZED
ADJUSTED
65 65


65 65


65 65


SPRINGFIELD CITY UTILITIES
SJUTHJEST
I
 194.3 HW (NFT)
CAPACITY FACTOR, X
TOTAL CAPITAL, t/KW(YEAR)
TOTAL ANNUAL, HI LLS/ KWM ( YE AR )
COST ELEMENTS
                                      **•            65            65
                                       77.3(1974)  117.6(1977)   117.6(1977)
                                     •*•*••(    0)    6.2(1977)     6.9(1977)
                                     C,F,H,J,P    C.E.H.J.K.P,  C,E,H,J,r,P,
                                                  S.U.U         S,U,U
TENNESSEE VALLEY AUTHOR!!
WIDOWS CREEK
J
550.3 MU (NET)
jTAH POWER & LIGHT
HUNTER
1
360. 3 MW (NET)
UTAH POKER 8 LIGHT
HUNTINGTON
1
366.3 MU (NET)
'Y CAPACITY FACTOR, X 60 65 65
TOTAL CAPITAL, J/KW(YEAR> 98.1(1976) 117.1(1977) 113.1(1077)
TOTAL ANNUAL, M I LLS/ KUM( Y EAR ) 3.0(1977) 5.3(1977) 5.1(1977>
U
CAPACITY FACTOR, X 65 65
TOTAL CAPITAL, */KW(YEAR) 91.1(1978) •***•«(
TOTAL ANNUAL, M I LL S/ kWH ( Y E AR ) .1(1978) *»••••(
COST ELEMENTS B,C,T,X
CAPACITY FACTOR, X ?C 65
TOTAL ANNUAL, M I LLS/KUH ( YEAR ) 1.4(1978) «***«»(
COST ELEMENTS B,C,T,X
65


65
0) ••••••( 0)
•*«***   INDICATES  COST  FIGURES NOT »ET AVAILABLE

                    A-   25

-------
 £PA UTUITr FGO SURVEY: JULY  -  SEPTEMBER  1980
                                            SECTION A-2
                              COSTS  FOR  NON-OPERATIONAL F6D SYSTEMS
UNIT DESCRIPTION
                                COST  DESCRIPTION
                                                                 REPORTED
                                              	COST	
                                               ADJUSTED
                                                                                         STANDARDIZED
                                                                                           ADJUSTED
9ASIN ELECTRIC POWER COOP
LARAMIE RIVER
2
 570.3 NU (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR)
TOTAL ANNUAL, HILLS/KUH(YEAR)
COST ELEMENTS
 ...           65
  56.0(1980) ****••(
    .e<7800) •«•*••(
C,E
     65
0) **«**•(
0) •*«.»«{
             0)
             0)
JOSTON EDISON
CYSTIC
6
 150.3 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KV(VEAR)
TOTAL ANNUAL, HILLS/KWH(YEAR>
COST ELEMENTS
 • *•           65
  63.4(1972) •«•**•(
   3.0(1974) *•«*••(
B.C.E.N.Q
     65
0) **«.*.(
0) •«««..<
             QJ
CDLORA60 UTE ELECTRIC ASSM
CRAIG
I
 447.0 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KU(YEAR>
TOTAL ANNUAL, MlLLS/KWH(YEAR)
COST ELEMENTS
 **•           65
  86.5(1979) **•*»•(
.....*<   0) ••**••{
B.D.E
     65
0) »*•••»(
0) ••«•*•(
             0)
             0)
ILLINOIS POWER COMPANY
     RIVER
 110. 0 HW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(YEAR)
TOTAL ANNUAL, MILLS/KUH(YEAR)
COST ELEMENTS
                                                                 82.5(1972) •****•(
                                                               .....«(   0) ...*..(
                            6S
                       0) ***••*(
                       0) .»..*.(
             0)
             0)
PHILADELPHIA ELECTRIC
EDDYSTONE
1A
120.0 NW (NET)
CAPACITY FACTOR, X
TOTAL CAPITAL, S/KW(VEAR>
TOTAL ANNUAL, HI LLS/KWH (YEAR )
COST ELEMENTS
•*« 65 65
156.7(1972) 233.2(1977) 233.2(1977)
2.0(1972) 13.0(1977) 12.4(1977)
D.F.N.P C.E.N.P C.E.N.P
                         •***•»   INDICATES COST FIGURES NOT YET AVAILABLE

                                            A-  26

-------
APPENDIX B




DEFINITIONS
   B-l

-------
                            DEFINITIONS
 Boiler  Commercial  Service  Date
Byproduct
Commercial Service Date
   (FGD System)
Company Name
Disposal
Efficiency:
     Particulate Matter
     SO,
Date when boiler and auxiliary
equipment  (including FGD sys-
tem for new boilers) has met
initial supplier guarantees
and begins to contribute elec-
trical power to the power
grid.

The nature (e.g. elemental
sulfur, sulfuric acid) and
disposition (e.g. stockpile on
site, marketed) of the end
product by systems that gen-
erate a saleable product.
Date when the FGD system suc-
cessfully completes compliance
testing and the utility is
satisfied that the system
meets supplier contractual
guarantees.

Name of corporation as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - as space permits.

Disposal method for throwaway
product systems producing
sludge including:  stabilized
or unstabilized sludge, inter-
im and final disposal sites
and disposal type (minefill,
landfill, etc.)  as well as
disposal location.
The actual percentage of par-
ticulate matter removed by the
emission control system (me-
chanical collectors, ESP,  or
fabric filter and FGD) from
the untreated flue gas.

The actual percentage of SC>2
removed from the flue gas by
the FGD system.
                             B-2

-------
FGD Viability Indexes
     Availability Index
      Reliability Index
Several parameters have been
developed to quantify the vi-
ability of FGD system technol-
ogy.  Various terms such as
"availability," "reliability,"
"operability," and "utiliza-
tion" are used to accurately
represent the operation of any
FGD system during a given per-
iod.  The above-mentioned pa-
rameters are defined below and
discussed briefly.  The objec-
tives of this discussion are
to make the reader aware that
several different definitions
are being used and to  select
appropriate parameters  that
can be used for reporting  pur-
poses  so that  reasonably con-
sistent comparisons  can be
made.

Hours  the FGD  system is avail-
able  for  operation  (whether
operated  or  not)  divided by
hours  in  period,  expressed as
a percentage.   This  parameter
tends  to  overestimate the vi-
ability of  the FGD system be-
cause it does not penalize for
 election not to operate the
 system when it could have been
 operated.   Boiler downtime may
 tend to increase the magnitude
 of the parameter because FGD
 failures generally cannot oc-
 cur during such periods.

 Hours the FGD system was oper-
 ated divided by the hours the
 FGD system was called upon to
 operate, expressed as a per-
 centage.  This parameter has
 been developed in order not to
 penalize the FGD system for
 elected outages, e.g.,  periods
 when the FGD  system could have
 been run but was not run  be-
 cause of chemical shortages,
  lack of manpower, short dura-
  tion boiler operations,  etc.
  The main problem in using this
                               B-3

-------
     FGD Operability Index
     FGD Utilization Index
End Product
     Saleable
formula is the concise determi-
nation whether or not the sys-
tem was "called upon to oper-
ate" during a given time per-
iod.  In addition, an undefined
value can result when the FGD
system is not called upon to
operate for a given period
(e.g., turbine or boiler out-
age when FGD system is avail-
able) .

Hours the FGD system was oper-
ated divided by boiler operat-
ing hours in period, expressed
as a percentage.  This param-
eter indicates the degree to
which the FGD system is actu-
ally used, relative to boiler
operating time.  The parameter
is penalized when options are
exercised not to use the FGD
system in periods when the
system is operable.  In addi-
tion, an undefined value can
result when the FGD system is
not called upon to operate for
a given period (e.g., turbine
or boiler outage when FGD sys-
tem is available).

Hours that the FGD system op-
erated divided by total hours
in period.  This parameter is
a relative stress factor for
the FGD system.  It is not a
complete measure of FGD system
viability because the parameter
can be strongly influenced by
conditions that are external
to the FGD system (e.g., in-
frequent boiler operation will
lower the value of the parame-
ter although the FGD system
may be highly dependable in
its particular application).
The SO2 removed from the flue
gas is recovered in a usable
or marketable form (e.g., sul-
fur, sulfuric acid, gypsum,
                              B-4

-------
     Throwaway
Energy Consumption,  %
Equivalent Scrubbed Capacity
   (ESC)
FGD Status:
     Category 1
      Category 2
      Category  3
      Cateogry 4
      Category 5
ammonium sulfate, sodium sul-
fate).

The SC-2 removed from the flue
gas is not recovered in a us-
able or marketable form and
resulting sulfur-bearing waste
products must be disposed in
an environmentally acceptable
fashion.

The percentage of gross unit
electrical generating capacity
consumed by the FGD system, as
defined by the following equa-
tion:

 [Net MW w/o FGD  - Net MW w/FGD]/
Gross  unit rating]
 The effective scrubbed flue
 gas in equivalent MW based on
 the percent of flue gas scrubbed
 by the FGD system.
 Operational - FGD system is in
 service removing SC>2 •

 Under construction - ground
 has been broken for installa-
 tion of FGD system, but FGD
 system has not become opera-
 tional .

 Planned, Contract Awarded -
 contract has been signed for
 purchase of FGD system but
 ground has not been broken for
 installation.

 Planned, Letter of Intent
 Signed - letter of intent has
 been  signed, but  legal con-
 tract for  purchase has not
 been  awarded.

 Planned, Requesting/Evaluating
 Bids  -  bid requests have been
 released but no letter of in-
 tent or contract has  been is-
 sued.
                               B-5

-------
     Category 6



     Category 7


     Category 8
Fuel Firing Rate - TPH
General Process Type
Initial Start-Up  (FGD System)
New
Plant Name
Process Additives
Considering only FGD Systems -
an FGD system is proposed as a
means to meet an S02 regulation

Considering an FGD system as
well as alternative methods.

Nonoperational - FGD system
has been operated in the past
but has been shut down perma-
nently or for an extended in-
definite period of time.

Boiler fuel firing rate in
terms of tons per hour at max-
imum continuous load.

The manner in which the SC>2
from the flue gas is collected,
e.g., wet scrubbing, spray
drying, dry adsorption.

Date when flue gas first
passes through any component
of the FGD system (or is
scheduled to do so).

FGD unit and boiler were de-
signed at the same time or
space for addition of an FGD
unit was reserved when boiler
was constructed.

Unit identification as it ap-
pears in Electrical World -
Directory of Electrical Util-
ities, McGraw-Hill - Current
Edition - or as indicated by
utility representative for in-
stallations in planning stages.

A chemical compound or element
which is added to the process
or normally found with the
main process reagent in small
quantities (e.g., Mg, adipic
acid)  to promote improved
process operation (e.g., scale
reduction,  increased SC>2
removal efficiency).
                              B-6

-------
Process Type
Regulatory Class
 Retrofit
 Spare Capacity  Index  -  %
 Spare Component Index
 System Supplier
 Total Controlled Capacity
   (TCC)
Company name if process is
patented.  Generic name if
several companies have similar
processes (e.g., Lime, Lime-
stone, Wellman Lord, Thorough-
bred 121) .

A.   New boiler constructed
     subject to Federal New
     Source Performance Stan-
     dards  (NSPS),  8/17/71.

B.   Existing boiler  subject
     to  State Standard that is
     more stringent than  the
     NSPS,  8/17/71.

C.   Existing boiler  subject
     to  State Standard that is
     equal  to or  less stringent
     than NSPS,  8/17/71.

D.   Other  (unknown,  undeter-
     mined) .

FGD unit will  be/was  added to
an existing boiler not specif-
ically designed to accommodate
FGD unit.

The summation of the individ-
 ual component capacities  (%)
minus 100%.

 The equipment spare capacity
 index (%) divided by the  indi-
 vidual component capacity (%).

 A firm that fabricates and
 supplies flue gas desulfuriza-
 tion systems.
 The gross rating  (MW) of a
 unit brought into compliance
 with FGD, regardless of the
 percent of  flue gas treated at
 the facility.  In the case of
 prototype and  demonstration
 FGD systems, this figure will
 be identical to  the Equivalent
 Scrubbed Capacity rather  than
                               B-7

-------
Unit Rating
     Gross
     New w/FGD
     Net w/o FGD
                                   the gross unit rating if the
                                   system is not meant to bring
                                   the facility into compliance
                                   with S02 emission standards.
Operational - Maximum contin-
uous gross generation capacity
in MW; Preoperational - maxi-
mum continuous design genera-
tion capacity in MW.

Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
inclusive of emission control
systems.

Gross unit rating less the en-
ergy required to operate
ancillary station equipment,
exclusive of emission control
systems.
                             B-8

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      APPENDIX C




TABLE OF UNIT NOTATION
          C-l

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                               TABLE OF UNIT NOTATION
Classification
Area
Concentration
Flow
Heat Content
Length
L/C Ratio
Mass/Weight
Pressure
Temperature
Volume
English Unit
Acre
Square foot
Grains per standard
cubic foot
Parts per million
Pounds per million
Btu
Actual cubic feet
per minute
Gallons per minute
Pounds per minute
Ton per day
Ton per hour
Btu per pound
Foot
Inch
Mile
Gallons per
thousand actual
cubic feet
Pound
Ton
Inches of water
Degree Fahrenheit
Cubic feet
Acre-feet
Symbol
acre
ft*
gr/scf
ppm ,
lb/10 Btu
ft3/min
(actual)
gal/min
Ib/min
t/day
t/h
Btu/lb
ft
in
mi
gal/1000
(actual)
Ib
t
in. H20
•r
ft3
Acre-ft
Survey Report
Notation
ACRE
SQ. FT
GR/SCF
PPM
LB/MMBTU
ACFM
GPM
LB/MIN
TPD
TPH
BTU/LB
FT
IN
MI
GAL/1000ACF
LB
T
IN. H20
F
CU.F
ACRE-FT
ASTM/SI Unit
Square meter
Square meter
Grams per cubic meter
Parts per million
Nanograms per joule
Cubic meters per
second
Liters per second
Kilogram per second
Metric ton per day
Metric ton per hour
Joules per
gram
Meter
Centimeter
Kilometer
Liters per cubic
meter
Kilogram
Megagram
Kilopascal
Degree Celsius
Cubic meter
Cubic meter
Symbol
M2
g/m3
ppm
ng/J
m3/s
liter/s
kg/s
M t/d
M t/h
J/q
m
cm
km
liter/m3
kg
Mg
kPa
•c
•j
Survey Report
Notation
SO.M
SQ.M
G/CU.M
PPM
NG/J
CU.M/S
LITER/S
KG/S
M T/D
M T/H
J/G
M
CM
KM
LITER/CU.M
KG
MG
KPA
C
CU.M
CU.M
o
I

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        APPENDIX D



FGD PROCESS FLOW DIAGRAMS
           0-1

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                                 To Stack
o
i
ro
                     From
                  Precipitator
                                                Mist Eliminator
                                                             Make
                                       Flyash Silo
Reaction Tank
  In-Tank
  Strainer
  Bleed
^ Pump

  «	*
                                                                                       lime Silo
                                                                    «3i
                                                              Flyash Wet'G
                                                                 Tank
                                                                      Lime
                                                                Feed Pumps
                                                                                             Feeder
                                                                                 Lime
                                                                              Feed Tank
To Disposal
                                    Cooperative Power Association,  Coal  Creek 2
                                          Simplified Process Flow Diagram

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[ TECHNICAL REPORT DATA
| (Plccsr read Instruction* on llii romi Ix/ort itnni>lrinifi
h. REPORT NO. 2
EPA-600/7-80-029d
4. TITLE AND SUBTITLE
EPA Utility FGD Survey: July - September 1980
7. AUTHOR
-------